    [From the U.S. Government Printing Office, www.gpo.gov]

                                                                    ATTACHMENT 2

            Regional Outer Continental'Shelf
              Onshore Facilities Siting
                                 for West Florida

           f3

                                                                           SO,

                TD
                 195
                 E5
                C63
                1983

                          West Florida Regional Planning Council

                          WEST FLORIDA REGIONAL PLANNING COUNCIL

                               COASTAL-ENERGY IMPACT PROGRAM

                         REGIONAL OUTER CONTINENTAL SHELF ONSHORE

                         FACILITIES SITING STUDY FOR WEST FLORIDA

               The preparation of this  document was financed through a grant'
               from the Office of Coastal Zone Management, National Oceanic
               and Atmospheric Administration in conjunction with the Florida
               Department of Community Affairs.

                            Grant No. 82-CE-66-01- 0'0-21-015

                                      April 1983

                                           TABLE OF CONTENTS

                                                                                   Page Number
                 Acknowledgements    ..........................................         A-1

                  Introduction  ..............................................          A-5

                 CHAPTER 1 - Executive Summary and Recommendations
                                and Conclusions    ...............................      1-1

                                Recommendations  ..............................         1-3

                                A. Envir  onmental Resources Recommendations        ... 1-3
                                B. Industry Activity Recommendations        .........   1-6
                                C. Facilities Siting Recommendations        ..........  1-8
                                D. Public Policy Action Recommendations        ......   1-9

                                Conclusions   ....................................      1-11
                                Chapter 1 Footnotes*  .............................     1-21

                 CHAPTER 2      Assumptions For   Evaluating OCS Onshore
                                Impacts  .......................................        2-1

                                I. Assumption 1 - OCS Resource Estimate        ......   2-3

                              II. Assumption 2 -      Potential Resource    .........   2-4

                             III. Assumption 3 -      Potential OCS Hydrocarbon
                                                      kesource Sites    .............   2-6

                              IV. Assumption 4 -      Transportation of OCS
                                                      Reserves   ...................    2-7

                                V. Assumption 5 -     OCS Pipeline Landfall    ......   2-8

                              VI. Assumption 6 -      Timing of OCS Onshore
                                                      Activities   .................    2-12

                            VII. Assumption 7 -       Industry Onshore
                                                      Facilities   .................    2-13

                           VIII. Assumpti6n 8 -       Regional Resource
                                                      Committment   ................    2-15

                                Chapter 2 Footnotes   ...........................       2-1.6

                CHAPTER 3       OCS Study Met@odology    .........................      3-1

                                I. Literature Review and Background
                                   Research   ..................................        3-2

                                     Identification of Typical Oil Industry
                                     Onshore Facility Needs     ....................     3-2

                              III.   Evaluation of Regional Constraints
                                     For OCS Onshoro@ Facilities     ................    3-3

                                     A. Bays and Estuaries      ....................     3-3
                                     B. Large Land Areas In Single Ownership.. 3-4
                                     C. Major River Systems       ...................    3-5

                               IV.   Direct Technical Input     ....................     3-8
                                 V.  Regional Assumptions    ......................      3-9

                               VI.   Selection of Alternative Facilities Sites
                                     Based On Oil Industry Requirements        ........  3-9

                              VII.   Formulation of Socioeconomic
                                     Evaluation Matrix   ............... t ...........   3-10

                                     A.  Population    .............................     3-12
                                     B.  Local Employment    ......................      3-13
                                     C.  Local Revenue    ........................       3-13
                                     D.  Land Use   .............................        3-13
                                     E.  Access to the Gulf of Mexico       .........    3-14
                                     F.  Utilities   .............................       3-14
                                     G.  Availability of Support Services        ......  3-14
                                     H.  Access to Transportation Systems        ......  3-14
                                     I.  Traffic Flow    ..........................      3-15
                                     J.  Recreation and Tourism      ................    3-15
                                     K.  Conservation/Preservation Areas        .......  3-15
                                     L.  Ports  .................................        3-16
                                     M.  Facility Costs    ........................      3-16
                                     N.  Aesthetics  ....................     : .......  3-16
                                     0.  Navigation  .................... .......        3-16

                             VIII.   Formulation of Environmental Matrix        .......  3-17

                                     A.  Air Quality    ...........................      3-17
                                     B.  Water Quality and Water Supply        ........  3-19
                                     C.  Groundwater Quality     ...................     3-21
                                     D.  Water Supply    ..........................      3-22
                                     E.  Solid Waste   ...........................       3-22
                                     F.  Hazardous Substances     ..................     3-23
                                     G.  Wetlands/Marshes    ......................      3-24
                                     H.  Grassbeds   .............................       3-24
                                     I.  Noise  .................................        3-25
                                     J.  River/Stream Ecosystem      ................    3-25
                                     K.  Beach Ecosystem    .......................      3-2,6
                                     L.  Wildlife   ..............................       3-26
                                     M.  Endangered Species     ....................     3-27
                                     N.  Shell Fisheries    .......................      3-27
                                     0.  Fin Fisheries    .........................      3-27
                                     P.  Energy Consumption     ....................     3-28
                                     Q.  Dredging   ..............................       3-28
                                     R.  Oil Spill Impacts     .....................     3-29,

                               IX.  Evaluation and Assessment of the Roles
                                    of Federal, State, Regional and Local
                                    Regulatory and Policy Recommendations         .......  3-32

                               X.   Evaluation of Alternative Sites For
                                    Developmen   *t of Specific West Florida
                                    Recommendationg    ...................    **           3-32

                               XI.  Conclusions and Final Report.Preparation          .... 3-32
                               Chapter 3 Footnotes    ..............................       3-33

                CHAPTER 4      Oil and Natural Gas Industry Needs, Alternatives
                               and Impacts   .......................................       4-1
                               I. General Scenario of OCS Onshore Activity            .... 4-5

                                    A.   Pre-Ekploration Phase      ...................    4-6

                                    B.   Geological and Geophysical'
                                         1. Exploration Phase       ...................    4-6

                                    C.   Exploratory Drilling Phase      ..............    4-6
                                         1.   Exploratory Drilling Rig      ............   4-6
                                         2.   Temporary Service Base     ..............    4-7
                                         3.   Permanent Service Base     ..............    4-8
                                         4.   Supply Boats   ........................      4-10
                                         5.   Crew Boats   ..........................      4-11
                                         6.   Catering Services    ...................     4-11
                                         7.   Helicopter Companies     ................    4-12
                                         8.   Drilling Mud Companies     ...               4-13
                                         9.   Wellhead Equipment Companies      ........   4-13
                                    D.   Field Development Phase      .................    4-14
                                         1.   Permanent Service Base     ..............    4-14
                                         2.   Platform Fabrication Yard      ...........   4-14
                                         3.   Platform Installation Service Base..         4-15
                                         4.   Cement Companies    ....................     4-1.7
                                         5.   Pipelines  ........................      -   4-17
                                         6.   Pipe Coating Yards   .................     * 4-20
                                         7.   Gas Processing/Treatment Plants       .....  4-22
                                         8.   Natural Gas Compressor and
                                              Metering Facilities     .................    4-24
                                         9.   Oil Storage/Marine Terminal      .........   4-25
                                        10.   Refineries and Petrochemical
                                              1@acilities  ..........................      4-28
                                              a. Refineries    ......................      4-28
                                              b. Other Petrochemical Facilities... 4-31
                              Chapter 4 Footnotes     ..............................       4-33

               CHAPTER 5     Potential OCS Onshore Facilities Sites and
                             Antivipated Impacts      ..............................       5-1
                               I. Identification and Profile of Onshore
                                    Support Facilities    ..........................       5-1

                                    A. Service Base     ............................    5-2
                                        1. Characteristics of an Onshore
                                             Service Base For Exploration      ........ 5-4

                                    B.  Pipeline Landfall and Onshore Cor     ridor.. 5-6

                                    C.  Natural Gas Treatment Facility      ..........  5-15

                                    D.  Marine Oil Barge Terminal     ...............   5-23

                                    E.  Compressor and Metering Facilities       ...... 5-27

                              II.   Alternative West Florida Sites Considered
                                    For Onshore Natural Gas and Oil Facilities.. 5-29

                                    A.  Pipeline Landfall and Corridor      ..........  5-30

                                    B.  Onshore Service Base     ....................   5-37

                                    C. Gas Treatment Facility      .................... 5-41

                                    D.  Oil Barge'Terminal    ......................    5-47

                                    E. Compressor and Metering Station       .........  5-50

                             III.   Positive and Negative Impact Assessment
                                    of Potential Sites    ..........................    5-50

                             Chapter 5 Footnotes    ...............................     5-53

               CHAPTER 6     Regulatory Mechanisms Assessment      ..................   6-1

                             Federal Agencies Charged With Management
                             of the OCS .........................................       6-1

                               I. U.S. Department of the Interior        .............  6-2

                                    A. Minerals Management Servic     e  .............  6-2

                                    B. United States Geological Survey       .........  6-2

                                    C. Bureau of Land Management      ...............   6-2

                              II.   National Ocean and Atmospheric
                                    Administration   ..............................     6-3

                                    A. Office of Oceanic and Coastal Resource
                                        Management   ..............................     6-3

                                    B.  National Marine Fisheries Service     .......   6-3

                             III. U.S. Army Corps of Engineers       ................   6-4

                                IV. U.S. Environmental Protection Agency       ........  6-4

                                V. U.S. Department of Energy      ...................    6-4

                                VI. U.S. Coast Guard   ...........  ..................   6-4

                             VII. U.S. Department of Defense        ..................   6-5

                                    A. U.S. Department of the Air Force        ........  6-5

                                    B. @U.S. Department of the Navy      .............   6-6

                            VIII.   U.S. Fish and Wildlife Service      ..............   6-6
                                IX. -U.S. National Park Service..'    .................  6-6

                                X. U.S. Heritage Conservation and
                                    Recreation Service    ..........................     6-6

                             Federal OCS Related Regulatory Mechanisms        .........  6-7
                             General OCS Regulato*ry'Mechanisms      ..................  6-7

                                The Outer Continental Shelf Lands Act
                                Amendments of 1978 (P.L. 95-372)      ................   6-7

                                Submerged Lands Act (P.L. 83-31)      ................   6-10

                                Clean Air Act (P.L. 84-159)     .....................    6-10

                                Federal Water Pollution Control Act (P.L. 845).. 6-12
                                Marine Resources and Engineering Development
                                Act of 1966, Including Title III, Coastal
                                Zone Management Act of 1972 (P.L. 89-454)       .......  6-22

                                National Environmental,Policy Act of 1969
                                (P.L. 91-190)  ...................................       6-30

                                Coastal Barrier Resources Act of 1983
                                (P.L. 97-348)  ...................................       6-33

                                Solid Waste Utilization Act as Amended by
                                'the Resource Recovery Act of 1970     ...............   6-34

                                National 11istori c Preservation Act of 1966
                                (P.L. 89-665)  ...................................       6-35

                                Occupational Health and Safety Act of 1970
                                (P.L. 91-596)  ................ I ...................    6-39
                            Environmental L@gislation     ..........................     6-39

                                Marine Mammal Protection Act of 1972
                                (P.L. 92-522)  ...................................       6-39

                               Marine Protection Research and Sanctuaries
                               Act of 1972  .....................................      6-40

                               Migratory Bird Treaty Act    .......................    6-46

                               Endangered Speciea Act of 1973    ....... ; ..........  6-48

                               Mineral Leasing Act, Amended and National
                               Wildlife Refuge System Administration      ...........  6-51

                               .The Fish and Wildlife Coordination Act
                               (P.L. 73-121)  ...................................      6-53

                           OCS Related Transportation Regulatory Mechanisms        ... 6-  54

                           General OCS Related Mechanism     ......................    6-54

                               DOepwater Port Act of 1974 (P.L. 93-627)      ........  6-54

                               Port Safety and Tank Vessel Safety Act of 1978
                               (P.L. 95-474)  ....................................     6-58

                               River and Harbor Act of 1899     ....................   6-@O

                               Natural Gas Act of 1979    .........................    6-64

                               Natural Gas Pipeline Safety Act of 1968
                               (P.L. 90-481)  ...................................      6-67

                               Hazardous Liquid Pipeline Safety Act of-1979
                               (P.L. 96-129)  ...................................      6-68

                           OCS Pipeline Rights-Of-Way     .........................    6-69

                           Tanker Vessel Regulatory Mechanisms      ................   6-71

                           Ongoing Federal Mechanisms     .........................    6-74

                               Geological and Geophysical Surveys and
                               Analysis  ........................................      6-74

                               Intergovernmental Planning Program      ..............  6-74

                               Regional Environmental and Socioeconomic
                               Studies  .........................................      6-74

                               OCS Oil and   Gas Information Program    .............. 6-75

                               Land and Water Conservation Fund     ................   6-75

                               Marine Fisheries Management    ............... I ...... 6-76

                           Pertinent Proposed OCS Related Federal
                           Legislation   ........................................      6-77

                               Amendment to the OCS Lands Act
                               Amendments of 1978 and the Coastal Zone
                               Management Act of 1972     .........................    6-77

                            State of Florida Regulatory Mechanisms       ............  6-78

                               State of Florida Agencies Responsible
                               For Manageing OCS Impacts      ......................   6-78

                                    I. Office of the Governor     ..................   6-78

                                  II.  Florida Department of Community
                                       Affairs   ..................................    6-79

                                  III. Florida Department of,Environment.al
                                       Regulation   ..............................     6-80

                                  IV.  Florida Department of Natural
                                       Resources   ................................    6-80

                                    V. Northwest Florida Water Management
                                       District   .................................    6-81

                                  VI.  Florida Game and Freshwater Fish
                                       Commission   ..............................     6-82

                            Florida's  OCS Related Regulatory Mechanisms       ....... 6-82

                                    I. Dredge and Fill Permits     .................   6-82

                                  II.  Pollutant Spill Prevention and Control
                                       Act, Chapter 376, F.S     ...................   6-84

                                 III.  Energy Resources Part I, Regulation
                                       of Oil and Gas Resources, Chapter 377,
                                       F.S  .....................................      6-86
                                  IV.  Environmental Land and Water Management
                                       Act, Chapter 380, P.S     ...................   6-87

                                   V.  Local Government Comprehensive
                                       Planning Act, Chapter 163.3161,F.S       ...... 6-91

                                  VI.  Land Acquisition Trust Fund,
                                       Chapter 253, F.S    ........................    6-92

                                VII. Florida Industrial Siting Act,
                                       Chapter 288, F.S    ........................    6-94
                                VIII.  Easements, Chapter 704, F.S     .............   6*-96
                           General State. R@gulatory Mechanisms     ..... ; .........  6-96
                                  I. Miscellaneous Executive Functions,
                                       Chapter 23, F.S    .........................    6-96

                                  II. Beach and Shore Preservation Act,
                                       Chapter 161., F.S   ......................  00 6-97

                                III.   Intergovernmental Programs,
                                       Chapter 163, F.S    ........................   6-98

                                   IV.  State Parks and Preserves,
                                        Chapter 258, F.S   .......................    6-99

                                    V.  Florida Archives and History Act,
                                        Chapter 267, F.S ... i  ...................   6-102

                                   VI.  Game and Freshwater Fish,
                                        Chapter 372, F.S   .....* ..................  6-103

                                  VII.  Water Resources Act,
                                        Chapter 373, F.S   .......................    6-103

                                 VIII.  Water Resource Management-Act,
                                        Chapter 373, F.S   .......................    6-104

                                   IX.  Environmental Control,
                                        Chapter 403, F.S   .......................    6-105

                                    X.  Forestry, Chapter 589,.F.S     .............  6-106

                                   XI.  Air Pollution,.Chapter.17-2, F.A.C      ..... 6-107
                           Regional OCS Related Mechanisms      ...................   6-109

                                    I.  Regional OCS Gulf Onshore F    acilities
                                        Siting study for West Florida      .......... 6-109

                                   II.  West Florida Regional Planning Council
                                        Clearinghouse Review    ...................   6-109

                                  III.  West Florida Regional Planning Council
                                        Ongoing Planning Programs     ............... 6-110

                                   IV   Regional Issues Positions     ..............  6-111

                                    V.  Regional Goals, Objectives and
                                        Policies  ................................    6-112
                           Local GovernmeiAt OCS Related Regulatory
                           Mechanisms  ........................................       6-118

                                    I. Local Government Comprehensive Plans       ... 6-118

                                   II. Zoning   .................................     6-119

                                 III. Developments of Regional Impact        ........ 6-119

                                   IV. Local Pollution Regulations      ............  6-120

                                    V. Harbo  r and Port Controls    ...............   6-120

                                   VI. Areas of Critical State Concern       ........  6-121

                                 VII. Historic Preservation Districts        ........  6-121

                                VIII. Interlocal Coordination      ................ .  6-121
                            Local Government OCS Related Regulatory
                            Mechanisms  ........................................       6-122

                                   .I. Escdmbia County     ........................    6-122

                                   II. Santa Rosa Island Authority       ............  6-125
                                 III.   City of Pensacola   ......................     6-125

                                   IV.  Santa Rosa County   .......................    6-127

                                     V. Gulf Breeze   ............................     6-130

                                   VI.  Okaloosa County    ........................    6-1'33

                                 VII.   Fort Walton Beach   .............  o ........  6-135

                                VIII.   Mary Esther...   .........................     6-138

                                   IX.  Walton County   ..........................     6-141

                                     X. Bay County   ..............................    6-142

                                   XI.  Panama City   .............................    6-144

                                 XII.   Panama City Beach   ......................     6-146

                                XIII.   Mexico Beach   ............................    6-147
                                Chapter 6 Footnotes   .......... o  ................   6-149
               Bibliography   ..................................................       B-1
               Appendix A     Impact Evaluation Matrices    .....   ................

                                  LIST OF FIGURES AND TABLES

                                                                               Page Number
                FIGURE.A-1      OCS Leases OffshCre From West Florida      ........ A-10

                FIGURE A72      Eglin Coordor    ...............................    A-11

                FIGURE'A-3      OCS Resource Development Potential
                                From West Florida   ............................    A-14

                TABLE 2-1       Exploratory Wells Drilled In The
                                Destin Dome  ..................................     2-5

                FIGURE 3-1      Existing And Potential Industrial Sites      ...... 3-7

                TABLE 3-1       Causes Of Oil Spills Greater Than 50
                                Barrels Resulting From offshore Operations
                                On The Federal OCS   ...........................    3-30

                TABLE 471       Summary Of General Oil Industry Onshore
                                Facility Needs   ...............................    4-2

                FIGURE 4-1      Phases Of OCS Activity   ........I ...............  4-'3

                TABLE 4-2       Average Yield From One (1) Barrell Of
                                Crude Oil  ....................................     4-29

                FIGURE 5-1      Existing Facilities   ..........................    5-10

                FIGURE 5-2      Gas Processing And Treatment    .................   5-17

                TABLE 5-1       Estimates Of Air Emissions From Gas
                                Treatment Facility   ...........................    5-24

                FIGURE 5-'3     Alternative Potential OCS Onshore
                                Facilities Evaluated   .........................    5-31

               .FIGURE 5-4      Center Lease Blocks For OCS
                                Production Areas   .............................    5-33

                                     ACKNOWLEDGEMENTS

                   The literature review, evaluation of-oil industry facilities
              needs, regional onshore impacts.assessments and preparation of

              this document were the assigned work tasks of the environmental

              staff of the West Florida Regional Planning Council. The success
              of this.work is largely due to the input from the OCS Advisory
              Commitee and from technical representatives of the oil industry.

              A great deal'of assistance was offered by staff   representatives

              of the Florida Department of Community Affairs, Division of

              Local Resource management and the office of Planning and

              Budgeting, Office of The Governor.

                   The'"Planning Council staff extends its sincere thanks to

              these people who generously extended the staff the benefit of

              their time and expertise.

                   A list of the OCS Advisory Committee and other participants
              is included to recognize their helpful assistance.

                     Participant                           Representing

                Larry Anchors                      Okaloosa County
                Sydney Andrews                     Florida Dept. of Agriculture
                                                   and Consumer Services
                Arthur Apfell                      Minerals Management Service
                Micheelle Armstrong                Pensacola News-Journal
                Jim Barkaloo                       U.S. Fish and Wildlife Service
                Jon Barnes                         WKGC Radio
                Michelle Beale                     Getty. Oil Company
                Tom Bell, Jr.                      West Florida Homebuilders
                                                   Association
                Pat Blackshear                     Walton County
                William Blaskis                    City of Gulf Breeze
                Al Borchik                         Town of Cinco Bayou
                Sylvia Bourke                      Citizen
                Michael Burke                      Pensacola News-Journal
                Carolann Bowen                     Florida Dept. of Natural Resources
                R.J. Broussard                     Sohio Petroleum Company
                Gary Brown                         City of Niceville
                E.J. Burgin                        Florida Gas Transmission Company

                  Linda Carden                         Town of Jay
                  Jim Chitwood                         Destin Log
                  Louis Coakley                        University of West Florida
                  Judy Coe                             Sierra Club
                  J.0. Collis                          Exxon Company, USA
                  E.J. Cowan                           ASCS
                  Ted Czupryk                          City of Callaway
                  Grover Davis                         Marine Transportation Service
                  Gloria Dawson                        League of Women Voters
                  Howard.Demmig                        U.S. Air Force
                  Mark Dougherty                       WOWW Radio
                  Brian Doyle.                         Playground Daily News
                  James  Dyehouse                      Sierra Club
                  Bob Echols                           Northwest Florida Water Management
                                                       District
                  Ralph Edenfield                      Florida Division of Forestry
                  Pete Edwards                         Bay County
                  Sylvia Edwards                       DeFuniak Springs Herald Breeze
                  Patrick Emmanuel                     Citizen
                  Rudy Etheredge                       Port of Panama City
                  Gabriele Gaddis                      League of Women Voters
                  Dick Fancher                         Florida Dept. of Environmental
                                                       Regulation
                  John Farquhar                        Getty Oil Company
                  M. Fifield                           Pensacola News-Journal
                  Mike Ford                            Citizen
                  Virginia Foster                      Audubon Society
                  John R. Franklin                     City of Fort Walton Beach
                  Shirley Gade                         Audubon Society
                  Peter Gagnon                         Gulf Breeze Sentinel
                  Elizabeth Gauthier                   Office of The Governor
                  Jerry Gerde                          Citizen
                  Earl Gilbert                         City of Parker
                  Wayne Goodson                        City of Niceville
                  Gene Goslin                          Southern Natural Gas Company
                  Joe M. Gregory, Jr.                  Getty Oil Company
                  Philip Griffitts                     City of Panama City Beach
                  Paul Groom                           Saint Joe Paper Company
                  John Hair                            Reading and Bates Construction
                                                       Company
                  George J. Hall                       City of Lynn Haven
                  Alton Ray Hammond                    Town of Century
                  Virgil A. Harris                     Shell Offshore, Inc.
                  Richard Hatch                        U.S. Navy
                  Wilbur Howell                        Flori'da Division of Forestry
                  Charles V. Helton, Sr.               City of Freeport
                  Tom Herbert                          T.A. Herbert's Associates
                  Jon Herring                          Amoco Production Company
                  Cherie flicks                        News Herald
                  John Higgins                         Exxon Company, USA
                  Robert Holmes                        Pensacola Chamber of Commerce
                  Jennifer Hodnette                    City of Pensacola
                  Jim Howell                           Santa Rosa County

                                               A-2

                  Roy Hyatt                              Environmental Studies Center
                  Carlton Jackson                        Florida Pctrolcum Council
                  Terry Jernigan                         Florida Depart. of Community
                                                         Affairs
                  Glen Key                               Perdido River Soil and Water
                                                         Conservation District
                  Roy Kingsmill                          City of Callaway
                  James L. Kirkland                      United Gas Pipeline Company
                  Jeff Kiss                              Florida Dept. of Community
                                                         Affairs
                  Bob Koncar                             City of Valparaiso
                  Ingrid Kreis                           Destin Log
                  Ingrid Kristensen                      WFSH Radio
                  Linda Lampl                            T.A. Herbert's Associates
                  William Laseter                        City of.-Valparaiso
                  Timothy Leonard                        Five Flags Pipeline
                  A.C. Littleton,   Jr.                  City of Panama City
                  John C. McElhaney                      Five Flags Pipeline
                  W.M. McLean                            Walton County
                  Rick.McNutty                           Channel 6 TV
                  Rich McWilliams                        Northwest Florida Water Management
                                                         District
                  Delores Meleney                        QeFuniak Springs Chamber of
                                                         Commerce
                  Bill Metzger                           Escambia County
                  Mike Mitchell                          Okaloosa County
                  Jane Moore                             Preservation of Destin
                  James P. Morgan                        Citizen
                  F.D. Musson                            Mobil Oil Exploration and
                                                         Production Southeast, Inc.
                  Sally Patrenos                         Florida Petroleum Council
                  Philip Payne                           Citizen
                  Bill Peebles                           Okaloosa County
                  Cass Pentecost                         Town of Mexico Beach
                  Fred L .  Pryor                        Town of Mary Esther
                  Dick Radford                           Midway Water System
                  David Reinhart                         WJHG TV
                  Joseph Reynes                          City of Gulf Breeze
                  Bruce Richards                         City of Milton
                  Ola Richborg                           City of Laurel Hill
                  Billy Roberts                          Bay County
                  J.M. Ros                               Southwest Forest Industries
                  David Roundtree                        Pensacola News-Journal
                  Russell Rudd                           Soil Conservation Service
                  James Rueff                            U.S.S'. Lexington
                  Cynthia Russell                        City of Pensacola
                  Jack Salmon                            University of West Florida
                  David Schaller                         Port of Pensacola
                  Donald Setterberg                      U.S. Air Force
                  Thomas Serviss                         Florida Division of Forestry
                  John Seymour                           Southern Natural Gas Company
                  Jim Sheffer                            Santa Rosa Island Authority
                  Walt Sikes                             U.S. Navy.
                  Randy Smith                            WEAR TV
                  Sam Smith                              Okaloosa County Pollution Board

                                                A-3

                Karen Spence                        WFSH Radio
                Alice Stewart                       Citizen
                R.W. Thackery                       Gulf Islands National Seashore
                R. Thomas                           U.S. Navy
                R.F. Thomas                         Gulf Oil Company
                Marion Tidwell                      Farm Bureau
                Doug Topper                         Citizen
                Sid Verindex                        Minerals Management Service
                Robert Von Axelson                  Agricultural Stabilization
                                                    and Conservation Service
                William F. Wade, Jr.                Town of Cinco Bayou
                Muriel Wagner                       League of Women Voters
                Sally  Webb                         WJHG TV
                George W. Wheeler                   Town,of Shalimar
                Raymond Williams                    City of'Gulf Breeze
                Grey Wilson                         City of DeFuniak Springs
                Randy Wood                          WMBB TV
                Gerald Woolard                      Escambia County
                Erica Woolley                       Audubon Society
                Lewis E. Zangas                     Florida Marine Patrol

                 West Florida Regional Plannirig Council Staff Participants

                           Daniel F. Krumel       Executive Director
                           D.T. Raynor            Environmental Director
                           Michael Zeigler        Regional Planner
                           Helen Clarkson         Research and Clerical
                                                    Assistance
                           Leo Doidge             Research and Document
                                                    Cover Design

                 A special recognition is extended to Mr. Virgil Harris, Mr.

            Carlton Jackson, Ms. Elizabeth Gauthier, and Mr. Jeff Kiss for
            their attention and generous assistance during the completion of
              0
            this work.

                                             A-4

                                        INTRODUCTION

                    Energy requirements are increasing worldwide. Available
                supplies of natural gas and crude oil are being depleted at a
                rate which threatens acute shortages. Alternative sources of

                energy are being explored by government and industry, however,
                each alternative requires many improvements in technology to

                meet energy demands safely.

                    Current American energy  demands are met primarily by
                domestic and foreign fossil  fuels. More than one-half of our

                fossil fuels are imported.   In order for the United States to
                become independent of foreign  oil imports domestic energy
                sources must be further developed or alternative energy sources
                .must-be substituted. Continued dependence on foreign fuel
                imports will heighten the pre sent energy supply problems. The
                United States is one of the world's greatest producers and
                refiners.of crude oil and natural gas. Americans are the great-
                est consumers of these petroleum products. In 1978 the United
                States consumed approximately 6.9 billion barrels of petroleum,
                or approximately 29.6 percent of the total world demand. In
                1978, oil accounted for 48. 5 percent of American energy needs
                and natural,gas accounted for 25.6 percent. Coal and nuclear

                power contributed much less energy to meet the nation's demand.1

                    No expert can declare the actual origin of petroleum. The
                IforganicI" theory of petroleum's origin is the most widely
                accepted. This theory proposes that crude oil and natural gas
                are organic minerals formed by the decay and chemical alteration

                                            A-5

                of the remains of prehistoric flora and fauna.

                    Petroleum is most often discovered in sediments laid down

                in ancient oceans. These sediments contain the organic residue
                of decayed organisms settled ;nd accumulated in layers. As the
                layers formed they were compressed under the weight of the lay-

                ers above. Under this pressure, heat was generated which

                combined with chemical,-bacterial and radioactive factors to

                form the organic matter known as petroleum.

                    During the time petroleum was being formed loose sands,
                marine forms and sediments were being formed and cemented into
                sandstone, limestone and shale    Some sedimentary rock layers
                were too dense for petroleum or natural gas to migrate slowly
                through. Other rock layers were less dense and the petroleum

                and natural gas flowed upward toward the surface because the

                oil and natural gas are lighter and less dense than water.

                Wherever a formation of dense nonporous rock lay above a
                porous layer the upward migration was halted. Natural gas was
                trapped under the nonporous rock layer and petroleum was

                trapped beneath the natural gas.

                    Through the centuries the earth's crust has shifted   and

                folded breaking the sedimentary layers into irregular forms.
                Traps were created that collected migrating  natural gas and
                oil. Some of these traps are commonly called: faults,'salt
                domes and anticlines. Oil and natural gas are extracted from

                these traps.

                    Early oil explorers and geologists learned to closely

                survey the underground structures and, formations where oil and

                                            A-6

                gas were found. Today oil ge ologists and other experts use
                many technical tools to search and find buried petroleum

                deposits.
                    During the summer of 1970, oil was discovered near Jay in
                Santa Rosa County. Production  of oil in thethree (3) Jay
                fields accounts for more than 80 percent of Florida's oil
                produced. Experts have-estimated that the Jay oil fields may
                yield 340 million barrels of oil before depletion early in the
                twenty-first century.2
                    Development of the'Outer Continental Shelf (OCS) resources
                is intended to have a.positive impact on domestic oil and
                natural gas production to achieve United States energy indepen-'
                dence. By holding lease sales of OCS lands, the federal
                government (Department of the Interior) 'seeks to encourage
                domestic exploration, development and production of oil and

                natural gas.

                    Offshore operations of the-petroleum industry began as
                extensions of onshore exploration, drilling and production. In
                the late 1930's seismic surveyshad been conducted of coastal
                marshlands, bayous and shallow bays adjacent to the Gulf of
                Mexico. Most of the early oil industry activities in areas
                under water were to extend oil field boundaries and to recover
                oil from reservoirs already defined onshore.

                   As offshore operations move into deeper water and more
                hostile environments, all exploration and production costs
                increase. Larger petrole um. reserves must be discovered.to
                justify the development and production of a new discovery.

                                            A-7

                     Recent federal policy changes have been made to stimulate

                industry interest in development of the OCS. Under the Outer

                Continental Shelf Lands Act Amendments, the Department of the
                Interior, Minerals Management*Service (MMS) is charged with
                administering mineral resource development of-offshore areas

                under federal jurisdiction. The formation of MMS resulted

                from an effort by the Department of the Interior to improve
                royalty management of oil and gas lease receipts. MMS is
                charged with all leasing and resource management functions
                for the OCS. Some of these functions include: selection of

                areas for possible leasing, evaluation of potential resource
                volumes, supervision of exploration activities, management of
                lease sales, supervision of drilling and production activities
                and collection of lease royalties. The MMS is second only to
                the Internal Revenue Service among government agencies in
                revenue collected for the U.S.. Treasury.3
                     In July, 1981 the U.S. Department of'the Interior announced
                its intention to revise and "streamline" the OCS leasing process.
                The revision has been completed and provides for more OCS
                terrirory to be leased than ever before. A basic summary of

                the OCS leasing process includes:

                    1. the DOI identifies OCS areas which have hydrocarbon

                        potential;

                    2. DOI issues a.call for information and suggestions

                        from the oil and natura 1 gas industry for other

                        areas to be considered for lease;

                                           A-8

                      3.  DOI determines which areas are to be considered

                          in the supplemental EIS;

                      4.  DOI completes EIS focused on "potential environmental

                          effects of oil and gas activities in the area proposed

                          for leasing";

                      5.  DOI issues notice of a lease sale;

                      6.  the governor submits comments within sixty (60) days;

                      7.  bids for leases are submitted to.DOI;

                      8.  DOI releases a notice of sale and allows for

                          public comment; and,

                      9.  lease sale.

                      Regional and local agencies can affect a    lease sale very

                 little.  Local citizens become involved in the    OCS onshore

                 facilities siting process after a lease sale had been made and

                 after the oil companies have completed exploratory activities.

                 A summary of the historical OCS lease sales offshore from west

                 Florida is offered in Figure A@l.

                      Currently, one area of the OCS offshore from West Florida

                 is omitted from lease sales. This area is known as the Eglin

                 Corridor, offshore from Eglin Air Force Base. The area is

                 omitted to minimize military conflicts with OCS activities.
                 This 70 miles wide by 160 miles long area is used by the

                 military for research and testing of mis'siles and other

                 arament testing (see Figure A-2).

                      The OCS offshore from the WFRPC area had been a focal point

                 for significant oil industry interest since the early 1970's.

                 Exploratory drilling in West Florida and the frontier offshore

                 from West Florida has been a subject of public controversy

                                              A-9

            ALABAMA                                FLORIDA
            Baldwin     (Escambia     Wa Rosa   Okaloosa  >         Walton
                                                                                Washington

                                                                                  Bay

                                                Lea[ue

                               Ty1ree

                                          Pensacola Block

                                                                  7-

                                                                 Z.

                                         Destin Dome Block

                     Proposed Tracts for Leasing Sale No. 69

                     Expired or Relinquished Leases

                     Active Leases

                                       De Soto Canyon Block

            SOURCE:   Final Regional Environmental Impact                   FIGURE A-1
                      Statement, Gulf of Mexico. minerals           OCS Leases Offshore From
                      Management Service. January, 1983.                   West FLorida
                                                A-10

            ALABAMA                                 FLOR I DA
            Baldwin    (Escanibia  a a Rosa    Okaloosa            Walton
                                                                               Washington

                                                                                  Bay

                                               Lel-lc tic

                               Ty1rec

                                                                        FIGURE A-2

                                                                     Eglin Corridor

                                                                   Source:  Final Exivironmenta-;
                                                                            Impact Statement,
                                    EGLIN CORRIDOR                          Gulf of Mexico.
                                                                            MMS. January,1983.

                                               A-11

                 and concern. Local government representatives and citizens have

                 expressed apprehension concerning exploration and development

                 of the OCS offshore from this region. Major topics of local

                 concern include:

                       1. locations for oil industry support facilities, such

                           as pip eline corridors and gas treatment facilities;

                       2.  potential increases to population;

                       3.  changes in demand for public services;

                       4.  changes in demand for public facilities;

                       5.  changes in demand for housing;

                       6.  localized inflation rate increases;'

                       7.  impacts to fishing and tourism industries;

                       8.  impacts to the mission of the U.S. Air Force and

                           U.S. Navy in West Florida;

                       9.  risk of oil spills or blowouts;

                       10. impacts to west Florida's economy;

                      .11. environmental impacts, and

                       12.. impacts to public safety.

                       Three Mareas of the Gulf of Mexico OCS which may yield

                 oil and/or natural gas which could impact west Florida are:

                 Destin Dome Block, De Soto Canyon Block, and,the Pensacola

                 Block (see Figure A-1). Federal, state and oil industry
                 experts maintain that the,Destin Anticline and the sou,thwest

                 corner of the Pensacola Block are the most promising of these

                 areas (see Figure A-3). Various oil companies have maintained

                 exploratory interest in lease blocks offshore from West Florida
                 since the early 1970's.' Eighteen (18) exploratory wells have

                 been drilled within the Destin Dome area. Although none of these

                                             A-12

                                            FIGURE A-3

                                            (facing page)

                                 OCS Resource Deve-lopm'ent Potential'
                                    Offshore From TAbst Florida

                                                  Highest Hydrocarbon  Potential.
                         gn
                           5,noN.

                                                  Moderate 14ydrocarbon,Potentia.1

                       ...  ..........
                                                  Least Hydrocarbon Potential

                                                  Destin Anticline

                   Source: Final Regional Environmental Impact Statement,
                            Gulf of Mexico. Minerals Management Service.
                            January,.1983.

                                               A-13

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                                                                                                                                                                                                                                                               .A-14

                                                                                                                                                                                                                                                               @

                wells produced commercial volumes of petroleum or natural gas the
                MMS continues to judge that ageologic potential for hydrocarbons
                still exists. MMS proposes that 110 exploration wells may be
                drilled in the eastern Gulf o@ Mexico between 1984 and 1990 with
                five (5) production platforms and ninety (90) production wells
                during the period 1989-1996. Two (2) pipelines are proposed to
                landfall in Florida, one (1) is expected in the vicinity of

                                                                           4
                Pensacola or Panama City and the ot-her in'the Tampa area.

                      In consideration of the continued industry interest  in both
                lease sales and drilling operations it is evident,that local

                government representatives and citizens   within Region I should
                continue to consider the potential impacts that may occur from
                OCS activities. Using funds provided by the Federal Coastal

                Energy Impact Program (Section 306 of the Coastal Zone Manage-

                ment Act Amendments of 1976) in coordination with the Florida

                Department of Community Affairs, office of Federal Coastal

                Programs; the West Florida Regional Planning Council has
                completed this OCS Onshore Facilities Study (OCS Study) to
                evaluate the potential onshore impacts of OCS activities and to
                assist state and local government representatives and citizens

                to prepare for and manage any potential impacts. The objectives
                of this study are:
                     1.  To develop  local and regional expertise in understanding

                         and managing OCS facilities.

                     2.. To increase local and regional understanding of the OCS
                         process and opportunities for effective participation.
                     3.  To conduct assessments of possible impacts from OCS

                         activites offshore and onshore.

                                            A-15

                     4. To promote orderly OCS related development within the

                         region by selecting preferred oil industry facility

                          sites before OCS discoveries are made.

                     This study has been completed to help the state and local

                communities prepare to influence facility siting and management

                of impacts. This OCS onshore facilities siting study is not

                intended to  be a technical encyclopedia of every possible

                action that may.be anticipated, but it is intended to demonstrate

                the critical points that west Floridian's should be aware of

                regarding OCS oil and natural gas. Other documents are readily

                available which contain detailed technical information and
                possible i'scenarios" of what might happen. This document

                cannot serve as a handbook for local government or oil industry

                representatives to use to make every necessary OCS related

                decision. The recommendations are offered for events that may

                never occur, however, contingency plans need to be maintained

               .for any future proposals for onshore facilities.

                     Because of wide variations in oil and/or gas fields and

                the individual specific facilities, personnel and operations

                of thes e fields, the approach of this OCS Onshore Facilities

                Siting Study was not to produce a hard and fast output, but to
                offer quidelines for West Florida's citizens. Today, there

                is no mechanism to determine if hydrocarbon reserves are located
                in the OCS offshore from West Florida. The Minerals Management
               'Service's estimate of recoverable oil and natural gas is for

                the entire eastern Gulf of Mexico. Little disaggregation of this
                estimate is available for the subplanning areas of the Gulf. To

                                            A-16

                evaluate the possible onshore impacts of OCS acitivity it was

                necessary for the study staff to formulate a realisitc estimate

                of the hydrocarbon resource that could landfall in West Florida.

                The approach taken to estimate the resource volume was to

                determine the minimum volume find necessary to justify field

                development and production costs. This determination was based

                on oil and natural gas industry technical input.

                     A second assumption concerns the probability of what type

                of hydrocarbon reserves could be discovered. The MMS and oil

                industry technical input strongly indicates that natural gas

                discoveries are more likely than discoveries of oil.

                                          A-17

                                         CHAPTER 1

                                     EXECUTIVE SUMMARY

                                            AND

                              RECOMMENDATIONS AND CONCLUSIONS

                                         CHAPTER 1

                                     EXECUTIVE SUMMARY
                                            AND
                             RECOMMENDATIONS AND CONCLUSIONS

                     Because the worldwide demand for energy is steadily

                increasing and because the United States is determined to

                decrease its energy dependence on non domestic resources,

                it is inevitable that Florida's offshore Outer Continental

                Shelf (OCS) will be explored and developed. The nation's need

                to stimulate domestic production has accelerated the federal

                OCS leasing process which could accelerate the oil industry's
                activity in Florida's offshore areas. Although the Minerals

                Management Service (MMS) received no bids for lease blocks in

                the OCS areas offshore form northwest Florida in the 8 March

                1983 sale, the oil industry contends it does maintain its

                interest. Federal, state, regional and local concern over

                possible oil industry impacts in west Florida remain, and

                certain preparatory actions are needed before any oil or

                natural gas landfalls in Region I.

                     This OCS facilities siting study examined the potential

                impacts of five (5) likely types of OCS-related, onshore

                facilities and up to seven (7) alternative sites for each

                type of facility. Due to the proximity of the oil industry

                facilities in and around Mobile, Alabama, and in Mississippi,

                Louisiana, and Texas, there is a possibility that a resource

                discovery may not impact west Florida. This alternative was

                examined because oil industry technical representative input
                indicates its viability if a resource discovery is made in

                                           1-1

                 the southwest corner of the Pensacola Block or extreme

                 western magrin of the Destin Dome Block (see Figure A-1).

                       The West Florida Reg  ional Planning Council staff began
                 the contracted work using the approach developed by the New
                 England River*Basin   Commission, but found that the scenario

                 approach and format   was,not adequate for developing an

                 assessment of the potential OCS onshore impacts for West Florida.

                 The method used.for completing this OCS Study is basic and
                 relatively  uncomplicated. The process followed eleven (11)

                 basic steps/procedures.

                       1. Literature review/research..

                       2.  Identification of typical oil industry facility needs..

                       3.  Evaluation of regional constraints for OCS facilities

                           siting.

                       4.  Direct technical input from oil industry representatives

                           and public participants.

                       5.  Development of regional assumptions.

                       6.  Selection of alternative facilities sites based on

                           oil industry requirements and local suitability.

                       7.  Formulation of socioeconomic evaluation matrix.

                       8.  Formulation of environmental impact matrix.

                       9.  Evaluation and assessment of the role of federal,

                           state, regional and local regulatory and policy

                           mechanisms.

                     10..  Evaluation of alternative sites for development of

                           specific West Florida recommendations.
                      11.  Conclusions and'final report preparation.

                                              1-2

                    RECOMMENDATIONS

                           Due to a lack of any "real" information concerning the

                    location, type, or volume of a resource discovery, the West

                    Florida Regional Planning Council staff and OCS Advisory

                    Committee were not able to recommend actual sites for all

                    industry needs. However, recommendations have been developed

                    which will serve to assist any future siting decisions to be

                    made when further OCS exploratory activity yields more detailed

                    data. This combination of general and specific recommendations

                    are presented in four (4) different categories. Some recommenda-

                    tions are pertinent to more than one (1)               category. The

                    recommendation categories are:

                                A. Environmental Resources

                                B. Industry Activities

                                C. F   acilities Siting

                                D. Public Policy Actions

                           The. following recommendations have been developed to provide

                    a basis for decision makers to evaluate and permit OCS related

                    facilities to locat in this region.

                    A. Environmental Resources Recommendations

                          implementation of certain methods or measures are necessary
                    to minimize any environmental degradation or loss from OCS

                    onshore activities. The adoption and use of these recommenda-

                    tions is a function of the region's elected officials and the

                    staffs that support        local governmental processes.

                         1.    Efforts should bi@! made to employ an environmental quality

                                                       1-3

                     (air, water, and groundwater) and safety monitoring program

                     prior to and during the construction and operation of an

                     OCS facility site.
                2.   Facility sites should no@ be located in areas that are

                     environmentally sensitive, or where environmental quality
                     is stressed prior to an OCS facility siting.

                3.   OCS facility sites.should be located away from marine or

                     estuarine meadows.

                4.   Efforts should be made to retain natural vegetation,

                     where feasible, at an OCS facility site.

                5.   OCS facilities (service bases and pipelines) should be

                     installed with blowout or pressure activated shutoff

                     devices whereever located in or near environmentally

                     sensitive areas or populated areas.

                6.   Efforts should be made to minimize any oil industry

                     activity impacts in nearshore marine and estuarine areas.

                7.   Efforts should be made to.mitigate for any habitat loss by

                     reestablishment of a comparable habitat at an alternate

                     location.

                8. facility sites should contain an onsite stormwater/drainage

                     retention/detention area.

                9.   Any approved discharge from a retention/detention system

                     should be accomplished through natUral vegetated areas and

                     not directly into open estuarine or mai@ine waters.

                10.  Efforts should be made to employ the best practicable
                     technology to control dust or any other suspended particles
                     in the air during construction and operation phases of any

                     ocs onshore facility.

                                          1-4

                11.   Efforts should be made by all OCS vessels to operate

                      within defined navigation areas in a manner not to

                      generate wak es or otherwise increase turbidity or to

                      otherw ise impact shellfish beds, marine grass beds or

                      other sensitive estuarine areas.

                12.   Effort'should be made to employ sediment control

                      techniques and to avoid actions that,might promote

                      erosion.

                13.   All solid  waste products, domestic and industrial,

                      ,should be disposed of at approved, permitted solid

                      waste disposal areas or resource recovery facilities.

                14.   Any hazardous waste (chemical or physical) should be

                      disposed of at a authorized disposal site, and the

                      facility operator should be notified in advance of the

                      characteristics and composition of the waste and the time

                      of its transport.

                15.   Efforts should be made to eliminate any thermal discharge

                      to estuarine or other   temperature sensitive habitats.

                16.   Facility sites that will generate high noise levels should

                      be located, where feasible, in areas to minimize noise impacts.

                17.   Efforts should be made for facility related transportation

                      to avoid all noise sensitive areas..
                18.   High noise level activities should be limited to daylight

                      hours if surrounding land use will be impacted.
                19.   Any pipeline landfall should be made by horizontal drilling

                      so as to not disturb the beach dune system

                                             1-5

               B. Industry Activity Recommendations

                    When an industry establishes a facility onshore in west
               Florida certain measures'should be implemented to minimize any
               degrad  ing impacts due to facility operations. Necessary manage-
               ment measures.described prior to development are more readily
               incorporated.by the industry and therefore less costly to
               implement.

                    1.  OCS.faci-lity site construction should be staged to
                        minimize the amount of area under construction at

                        any one time.

                    2.  OCS facility sites that are related or complementary
                        ..should be located in close proximity to each other.
                    3.  Efforts should be made by industry representatives to
                        conduct ongoing technical and public presentations

                        to educate and inform about OCS activities and related

                        onshore operations.
                    4.  Efforts should be made by the OCS industry to provide
                        local labor training programs and to employ from the
                        existing labor force.

                    5.  Efforts should be made to maintain natural vegetation,
                        grass or other ground cover (e.g. mulching, sodding,
                        etc.), on any unused areas of an OCS facility site.
                    6.  Efforts should be made to preserve any wetland areas
                        that may be a part of or adjoining an OCS facility site.
                        these areas should be incorporated into the site's

                        drainage system.

                                            1-6

                     7. Efforts should be made to minimize dredging, bulkheading

                          or other engineered disturbance activities. Procedures

                          such as "jack and.bore" to cross roads and horizontal

                          drilling to cross barrier islands and rivers should be

                          emphasized to minimize dredging.

                      8.  OCS.facility site maintenance dredging should employ

                          turbidity devices and be conducted at a time when

                          impacts-to the surrounding environment will be minimized

                          (i.e., winter).

                      9.  OCS facility site operation.and maintenance procedures

                          should be conducted at times to minimize any negative

                                   to flora, fauna and environmental quality (i.e.,

                          cross rivers and streams during low flow).

                    10.   OCS facility sites should maintain a drainage system

                          for stormwater and for spillage that drains to an

                          onshore retention area.

                    11.   OCS facility sites should employ other best management

                          practices where onsite retention/detention is not viable

                          (e.g., grassed swales, grading, shallow depression

                          retention, rooftop retention, etc.).

                    12.   OCS facility sites for fuel servicing should include

                          fuel spill containment equipment to be used whenever

                          any fuel or product is spilled.

                    13.   Efforts should be made to insure that spill containment

                          devices are readily available at any product transfer-

                          site.

                    14.-  Any discharge or disposal from OCS facilty sites or

                                                1-7

                                vessels into estuarine or other nearshore waters should

                                be prohibited.

                         15.    Efforts should-be made to designate and use upland diked
                                disposal sites for ar@y spoil generated during maintenance
                                dredging needed for an OCS activity.
                         16.-   OCS facility sites should be as hurricane proof as possible.
                         17.    Facility sites for OCS crew and supply boats should be
                                designed to allow the vessels to.use onshore power
                                rather'than onboard generators a          t dockside.
                         18.    Efforts should be made to transport OCS products by

                                pipeline, where feasible.-

                         19.    Efforts should be made to incorporate blow out or

                                shutoff divices at product transfer points.

                         20.    Onshore facilities should be constructed with fan-cooled

                                equipment to minimize impacts on water resources.

                    C.   Facilities Siting Recommendations

                         Onshore facilities are necessary for OCS operations. Specific
                    methods and actions should be employed prior to and during con-
                    struction of any OCS facility to minimize any negative impacts.
                    Decisions for siting industry facilities should incorporate
                    issues of public concern regardless of an absence of existing
                    regulatory provisions. These recommendations should be considered
                    by all levels of government involved in.facilities siting, as
                    well as the oil industry'.

                          l.. OCS facility sites that are not water dependent should
                                be located as far as feasible from the region's

                                estuarine water      areas.

                                                      1-8

                    2. OCS facility sites should be located in areas where needs

                        can be accomodated by existing onshore facilities, where

                        feasible (e.g., existing docking facilities).

                    3.  OCS facility sites constructed in flood prone areas

                        should include provisions for accomodating hurricane

                        force wind and water surges.

                    4.  OCS facility sites should be located in areas that will

                        not impact rare, endangered or threatened species.

                    5.  OCS pipelines should be located away from environmentally

                        sensitive areas and be placed inpreviously disturbed

                        (e.g., rights-of-way).areas, where feasible.

                    6... OCS right-of-way areas should be no wider than necessary

                        to minimize impacts.

               D.   Public Policy Action Recommendations

                    Local elected.officials,.federal agancy personnel, state

               agency personnel and regional government officials must be

               involved in any onshore activities to support OCS development

               by industry. Representatives of governments and government

               agencies are charged with making the decisions that will

               ultimately determine what industry activities take place and

               what the subsequent impacts will be.

                    1.  Efforts should be made by federal, state, regional and

                        local governments to promote the development of OCS

                        resources in a coordinated, environmentally sensitive-,

                        and responsive mqnner.

                    2.  Efforts should be made by federal and state governments

                                            1-9

                        to promote research and development of techniques that
                        will further minimize the negative impacts of OCS related

                        activities.

                    3.  Efforts should be made by regional and local governments

                        to stay aware and become involved in OCS related real

                        issues affecting the regional and local environment and

                        economy.

                    4.  Efforts.should be made by state and local governments to

                        prepare for regulatory and fiscal needs prompted by OCS

                        onshore activities.

                    5.  Efforts should.be made by local governments to incorporate
                       -policies and provision s for OCS related facilities and
                        impacts into all comprehensive planning efforts.
                    6.  OCS onshore facilities should be considered to have
                        regional impact and should be reviewed and permitted by
                        reg ional and local clearinghouse procedures.
                    7.  Efforts should be made'by gas utilities in Region I to
                        guide development of OCS onshore facilities so that the
                        region's residents obtain optimum benefit from regionally
                        produced energy resources.

                                           1-10

                CONCLUSIONS

                    This OCS facility siting study examines probable industry

                facility needs and the impact!% that may be presented within the

                West Florida region and offers guidance for federal, state,

                regional and local decision makers to prepare for these impacts.

                During the preparation of this study certain conclusions were

                reached. Overall conclusions pertinent to this study are

                summarized-as follows.

                    Petroleum fuel (oil and natural gas) has been determined to

                be a resource of vital importance to the-United States and is

                therefore subject to national control. Federal government policy

                has established that domestic petroleum fuel reserves will be

                explored and developed to the greatest possible extent. The

                Outer Continental Shelf of the United States has been viewed

                for extensive and systematic resource development and is the

                subject of the U.S. Department of the Interior's OCS Oil and Gas

                Leasing Program.

                    Although the U.S. Department of the Interior Minerals Manage-

                ment Service and Geological Survey have been charged with

                estimating the oil and gas reserves in the OCS, including the

                Gulf of Mexico OCS; the reserves of naturalgas and oil are not

                known. Some technical sources report that the world is depleting

                its rapidly declining supply of petroleum fuels, while other

                technicalexperts claim that development of vast new reserves

                is imminent. The same disagreement occurs between experts.coft-

                cerning the resource reserves in the Gulf of Mexico OCS.

                   The State of Florida has maintained: "Florida supports OCS

                operations for leasing, exploration and production, providing
                that consideration is given to our unique coastal environment."1

                The state has pledged close supervision of any OCS activities

                and has.conscientiously fulfilled its pledge. Florida filed

                (14 September 1982) a petition for judicial review of Secretary

                of the Interior James Watt's approved Five-Year Outer Continental

                Shelf Oil and Gas Leasing Program. The petition was filed because

                the state was not satisfied that its "unique coastal environmentit

                has been adequately provided for in-the Department of the Interior

                leasing program.

                   Although there is a need to determine and prepare for OCS

                related facilities in west Florida there is an uncertainty about

                exactly when any such facilities may be expected to occur.   The

                U.S. Department of the Interior has streamlined the OCS federal

                lease sale process to promote and accelerate OCS exploration.

                However, at the same time the process was revised the worldwide

                supply of petroleum fuels was at a surplus level. The current

                surplus of petroleum fuels has precipitated a decrease in the

                price for the fuels. This surplus and reduced price combination

                has caused the oil industry to be less interested in OCS explora-

                tion. It is not cost effective for the oil industry to continue

                to spend funds for lease.options and expensive exploration

                activities at a time when product volumes are at a surplus level

                and when domestic supplies cost the same or more than foreign

                supplies. -Oil companies are interested in selling their
                product as soon as possible and maintain it is too costly

                                           1-12

                 to "sit on" a resource find while waiting for a more favorable

                 market.

                     Another factor that makes   it difficult to estimate when

                 onshore facilities for OCS activities will be needed is the

                 time pqriods.involved in the,lease sale process. Once a

                 leasing schedule has been developed by MMS, it requires two

                 and one-half years to three and one-half years to complete

                 the leasing process. After the lease process is completed the

                 lease holder has five to ten years to conduct exploration drill-

                 ing within a lease block.

                     Even if a lease block were.sold today, local     citizens and

                 government representatives would have ample time     to complete

                 any necessary planning efforts and to implement any necessary

                 regulations or management controls.

                     "Remaining recoverable reserves of oil and gas in the Gulf

                 of Mexico Outer Continental She  lf and Continental Slope have

                 been estimated to be 2.90 billion barrels of oil and 39.8
                 trillion cubic feet of gas,   as of December 31, 1981.,,2 MMS

                 further estimates that the recoverable oil and gas resources

                 of the eastern Gulf could be:

                     1. Most Likely Find:          123 Million Barrels of oil
                                                   157 Billion Cubic Feet of Gas

                                 OR

                     2. Maximum Find:              980 Million Barrels of Oil
                                                  1.26 Trillion Cubic Feet of Gas3

                 MMS states that "over 90%   of the gas resources are estimated to

                 be discovered in subplanning area E-1" which provides an estimate

                 of:

                                                1-13

                    1. Most Likely Find:             31 Million Barrels of Oil
                                                    147 Billion Cubic Feet of Gas

                                OR

                    2. Maximum Find:                242 Million Barrels of Oil
                                                    920 Billion Cubic Feet of Gas

                These MMS estimates have not been   disaggregated into subplanning

                areas which corresponded to the West Florida Regional Planning

                Counci 1 OCS facilities siting study boundary. Using input

                supplied by four (4) different oil industry repre,sentatives the

                study staff prepared an estimate of the minimum resource that

                would justify the cost of developing a production field in the

                OCS offshore from West Florida. This minimum volume is estimated

                as 100 million cubic feet of gas per day and 10 thousand barrel@;

                of oil per day.*

                    It has been concluded,  for this study, that two (2) areas of

                the OCS are more likely to  yield a resource find that could

                impact Region I. The two    (2) areas are:

                             Destin Anticline

                        2.   Southwest corner of the Pensacola Block

                             and western margin of the Destin Dome

                             Block (see Figure A-1) .

                The MMS has  determined that the only  'high resource   potential"

                in. the eastern Gulf of Mexico in an area south of Escambia and

                'Santa Rosa Counties. Currently there are seven (7) active leases

                in this area. It is likely that any resource discovery made in

                this area will be transported to Alabama rather than to Florida.

                *for a field life of seven (7) years.

                                             1-14

                      if a resource discovery is in the OCS offshore from West

                 Florida it is very likely that the product will be transported

                 to shore in a pipeline. The State of Florida has developed a

                                                0
                 stipulation that disallows any other transportation system

                 (e.g. barge or tanker ship) unless a pipeline is not economically

                 feasible. If a discovery is made that would yield less than 100

                 million cubic feet of gas per day or 10 thousand barrels of oil

                 per day, a.pipeline would not be cost effective, therefore,

                 another transportation system would be required. Oil produced

                 at a rate of less than 10 thousand barrels per day may be

                 tankered ashore, while gas produced   less  than 100 million cubic

                 feet per day might not be produced.

                      Based on input offered by three (3) oil company representa-

                 tives it has been assumed     that if a pipeline is to landfall in

                 West Florida it will be sixteen (16) inches in diameter. Such

                 a pipeline is designed to transport more than a minimum volume

                 discovery. Most pipelines that landfall on the Gulf Coast are

                 less than twenty (20) inches in diameter.

                      While it is not possible to detailexact locations for all oil

                 industry facility sites it is possible to offer seven (7)

                 potential sites for an OCS pipeline landfall. Related industry

                 facilities would be located in close proximity to a pipeline

                 landfall. The seven (7)    potential landfall sites are:

                           1. Al - Perdido Key (Escambia County) in the vicinity

                                    of Highway 292 and the Intracoastal Waterway

                                    Bridge (see Figure 5-3).

                           2. A2 -  Santa Rosa Island/Gulf Breeze (Santa Rosa County)

                                              1-15

                                  in the vicinity of the Santa Rosa County and

                                  Okaloosa County line (see Figure 5-3).

                        3. A6     Panama City Beach (Bay County) in the vicinity
                                  of the inter@ection of Highway 79 and U.S.

                                  Highway 98 (see Figure 5-3).

                        4. A7     Mexico.Beach (Bay County) between Tyndall Air

                                  Force Base and Mexico Beach (see Figure 5-3).

                     If two (2).resource discoveries were.made, one (1) close to

                Pensacola and one (1) close to Mexico Beach, it is possible that

                two (2) pipeline landfalls could occur, however, such an occurance

                is not an assumption for this study.

                     MMS and oil industry experts state  natural gas has been

                concluded to be the most likely resource find in the OCS offshore

                from West Florida. The resource finds in Jay, Florida and in Mobile

                Bay, Alabama have come from the geologic formation called

                "Smackover    This same formation is the likely source for any

                future find in the OCS offshore of Region I. The Smackover

                formation is producing "sour" natural gas or gas that contains

                hydrogen sulfide, therefore, a gas treatment facility will be

                necessary to remove the hazardous hydrogen sulfide. The most

                suitable sites for gas treatment facilities in West Florida

                are recommended as:

                         1. C1 - Southwest Escambia County (see Gigure 5-3).

                         2. C2 - Gulf Breeze Peninsula/Garcon Point

                                   (Santa Rosa County)(see Figure 5-3).

                         3. C3 -   Holley/Navarre vicinity (Santa Rosa County)

                                   (see Figure 5-3).

                         4. C6 -  West Bay (Bay County) (see Figure 5-3).

                                           1-16

                     The onshore support or service base is the first onshore

                facility that would be located to accomodate OCS activity in
                West Florida. Factors t hat are considered when locating an

                onshore support base include:

                         1. land availbaility and surrounding   land use;

                         2., waterfront access;

                         3. access to @he Gulf of Mexico;

                         4. access to rail and road transportation;

                         5. availability of support services, e.g. potable

                             water, fuel, and communication facilities; and,

                         6.  potential for flooding and hurricane damage.

                The most suitable sites for onshore support bases are recommended

                as:

                         1. Bl - Bayou Chico Industrial Park (Escambia County)

                                  (see Figure 5-3) .

                         2. B7 - Southwest Forest Industries (Bay County) (see

                                  Figure 5-3).'

                     Although oil is not likely to be discovered, another

                onshore oil industry facility that has been considered for

                West Florida is an oil barge terminal. Such facilities already
                exist and may be expanded or modified to accomodate hydrocarbons
                discovered in the OCS offshore from West Florida. An oil barge

                facility would be more likely to be needed if an oil find is

                made which would generate less that the minimum volume of oil

                to justify a pipeline. In such an event, oil would be loaded

                onto barges at the produption platforms and shipped to an oil
                barge terminal for storage and transshipment. Factors considered

                                           1-17

              hydrocarbon resources discovered in the OCS offshore from West

              Florida. An oil barge facility would be more likely to be

              needed if an oil find is made which could generate less than the

              minimum volume of oil to justify a pipeline. In such an event,

              oil would be loaded onto barges at the production platforms and

              shipped to an,oil barge terminal for transshipment. When sizing

              and locating an oil barge terminal factors examined are:

                            l.- rate of oil production;

                            2. size of barges to be used to ship oil;

                            3.  frequency of crude.oil deliveries to be made

                                from the term@nal to an oil refinery;

                            4.  crude oil storage capacity needed if barge

                                traffic is interrupted;

                            5.  flood and hurricane exposures;

                            6.  access to intracoastal waterway, rail and

                                road transportation;

                            7.  proximity to existing petroleum facilities;

                            8.  land availability, and surrounding land use;

                            9.  soil suitability for staorage tanks; and,

                            10. distance from oil and gas separation facilities

                                and crude oil refineries.

                  The sites evaluated to be most suitable in West Florida for a

              potential oil barge terminal are:

                            1. D2 - Pensacola Bay (Escambia County), and

                            2. D5 - St. Andrews Bay (Bay County)

               (see Figure 5-3).

                  The last type of onshore oil industry facility considered for

                                           1-18

               West Florida is a natural gas compress ion and metering facility.
               These facilitiesare needed to transport and measure any natural
               gas produced from the OCS. The need for and the size of these
               facilities depends on how much pressure the natural gas has at
               the OCS well, the distance from the production wells to the
               onshore interstate transmission pipeline and the pressure main-
               tained in the interstate Pipeline. These facilities will be
               located along the onshore pipeline corridor connecting the
               interstate transmission pipeline and the OCS submarine pipeline,
               therefore, the siting of these facilities is dependent upon where

               the pipeline corridor is constructed.

                   Two metering stations will be needed, one (1) on the offshore
               production platform and the other along the onshore pipeline.
               These facilities may easily be located at the points of inter-
               connection between the OCS pipeline and the onshore transmission
               pipeline. S ix alternative sites (El-E6) are summarized in Figure

               5-3.

                  Any needed gas compressor facility is likely to be sited at
               the gas treatment facility or at the point of interconnection
               between the OCS pipeline and the onshore transmission pipeline.
               The sites that have been determined to be most suitable for a gas
               compressor and metering station are (see Figure 5-3):
                       1. El - United Gas Pipeline Terminal (Escambia County)
                       2. E2 - Juniper'Creek Compressor Station (Santa Rosa

                                County)

                       3. E5 -  Choctwhatchee River Compressor Station

                                 (Washington County)
                       4. E6 - Connection to Panama City lateral pipeline at

                                           1-19

                                  Bayou George (Bay County)

                   OCS related oil industry facilities that were evaluated for
               this study, but have been determined to be unlikely to locate in

               West Florida include:

                              .1. drilling mud companies;

                              2.. wellhead equipment companies;

                              3.  platform fabrication yards;

                              4i  separate platform installation service base;

                              5.  cement companies;

                              6.  permanent pipe watering facility;

                              7.  marine terminal;

                              8.  oil refineries; and,

                              9.  petrochemical facilities.

                   The eastern portion of the Destin Anticline has been offered

               for leas e and exploratory wells have not discovered commercially

               producible volumes of hydrocarbons. Due to the U.S. Air Force

               mission at Eglin Air Force Base'an area of the Gulf of Mexico

               known as the Eglin Corridor has been excluded from lease sales.
               The Eglin Corridor exclusion has prevented any industry exploration
               of the western portion of the Destin Anticline. The U.S. Depart-

               ment of the Interior and the U.S. Department of Defense are

               currently involved in discussions to determine if the western

               portion of the Destin Anticline can be explored by using lease
               stipulations or other mechanisms to allow industry to explore.

                                          1-20

                                         CHAPTER 1

                                         Footnotes

               1. Graham, Robert, Governor, State of Florida. Letter to
                   Cecil Andrus, Secretary of the Interior. 7 September 1979.

               2. .*U.S.' Department of the Interior, Minerals Management.
                   Service. Estimated Oil and Gas Reserves, Gulf of Mexico
                   Outer Continental Shelf and Continental Slope. December
                   1981.

               3.  U.S. Department of the Interior, Minerals Management
                   Service'. Final Regional Environmental Impact Statement,
                   Gulf of Mexico. January 1983.

                                             1-21

                                        CHAPTFjR 2

                     ASSUMPTIONS FOR EVALUATING OCS ONSHORE IMPACTS

                                        CHAPTER 2

                    ASSUMPTIONS FOR EVALUATING OCS ONSHORE IMPACTS

                   Oil and natural gas discoveries in the eastern Gulf of Mexico
              have had.very little impact on any part of West Florida. Previous
              discoveries have produced onshore impacts in other states, but
              none in Florida's Planning Region I.

                   In the absence of discoveries of commercially producible
              volumes of hydrocarbons in the Destin Dome or De Soto Canyon, it
              has been impossible for the Mineral Management Service (MMS), U.S.
              Geological Survey (USGS) or oil industry experts to predict the
              potential. yield of the geologicalformations of the eastern Gulf
              of Mexico or the resulting onshore impacts.

                   The study is not able to offer exact figures for volumes of
              oil and/or natural gas finds nor exact numbers of jobs, or the
              exact number of dollars that may be spent locally by the oil
              industry.. For this study, onshote requirements for OCS development
              have been determined based upon existing, available data and

              certain assumptions.

                   The formulation of the basic assumptions for this OCS onshore
              facility siting study was done with direct input from ten (10)
              oil and gas industry representatives, and other pertinent input.
              Because there is no readily available or approved mechanism for
              communication between the oil companies and local public agencies
              attempting to project oil industry activity, the WFRPC staff set
              out to develop a mechanism to receive input from oil company
              representatives for this study. Fortunately, the oil industry

                                          2-1

                  representatives were willing to provide assistance to the staff
                  to complete this study. No oil industry was able to offer confi-
                  dential or corporate priority information, nor were the companies
                  willing to be quoted directly in this study.
                         The..WFRPC.was able to make contact and receive input from
                  key personnel.of the following representatives of the industry:
                              1. Amoco Oil Com'pany

                              2. Exxon Corporation

                              3. Florida Gas Transmission Company
                              4.   Getty Oil Company

                              5.   Gulf Oil Company
                              -6.. Mobil Oil Exploration and Producing, Southeast, Inc.'

                              7.   Shell Offshore Inc.

                              8.   Sohio Petroleum Company

                              9.   Southern Natural Gas

                              10.  United Gas Pipeline Company
                        Other pertinent input was received for these assumptions from

                  representatives of      :

                              .1.  Eglin Air Force Base

                              2.   Florida Department of Community Affairs

                              3.   Florida Petroleum Council
                              4.   Minerals Management Service of the U.S. Department
                                   of the Interior

                              5.   Office of tho Governor of Florida

                              6.   Port of Panama City

                              7.   Port of Pensacola

                              8.   Reading and Bates Construction Company
                              9.   St. Joe Paper Company

                                                      2-2

               I.  Assumption 1 - OCS Resource Estimate

                   One major assumption formulated for this study concerns

               the estimate of recoverable oil and/or natural gas in the eastern

               Gulf of'Mexico. In its Final Regional Environmental Impact

               Statement, Gulf of Mexico, the MMS offers two (2) scenarios for

               oil and gas finds in the eastern Gulf OCS: 1) most likely find,

               and 2) total find. The MMS estimates are:

                        l.. most likely find:  123 million barrels of oil
                                               157 billion cubic feet of gas

                                              and

                        2.  total find:        980 million barrels of oil
                                               1.26 trillion cubic feet of gas

               MMS projects that only twenty-five percent (25%) of the estimated

               oil deposits and ninety percent (90%) of the natural gas would

               impact Florida Planning Region I (West Florida). Therefore, the

               MMS estimate of the volumes of hydrocarbons that could offset

               West Florida is:

                        1. most likely find: .31 million barrels of oil
                                              147 billion cubic feet of gas

                                             and

                        2. total find:        242 million barrels of oil
                                              920 billion cubic feet of gas

                    The assumption of the volume of hydrocarbons to be discovered

               was further defined by considering a minimum volume find of oil

               and/or natural gas that would justify the oil industry's capital

               expenditures for development, production, transport and process-

               ing. The oil industry input agreed that a minimum volume of 100

               million cubic feet of gas per day and/or more than 10 thousand

               barrels of oil per day for a field life of seven (7) years would

                                            2-3

              be required to justify OCS development costs offshore from West

              Florida. Any smaller volume find might be taken, but would not

              be transported by pipeline.and therefore, would most likely not

              landfall in West Florida.

              II. Assumption  2 - Potential Resource

                   An assumption of what type of hydrocarbon resource may be

             'discovered offshore of Planning Region I is  based on the previous

              and continuing oil industry experience onshore and offshore of

              West Florida.

                   The Jay oil field is producin g oil and natural gas from a

              geological formation known as the "Smackover". The current oil

              industry activity in Mobile Bay has yielded commercially

              producible volumes of natural gas from the same geologic

              formation. The "Smackover" formation also extends into the

              Gulf of.Mexico. To date, eighteen exploratory wells have been

              drilled into the "Smackover" formation in the Destin Dome portion

              of the OCS (see Table 2-1). Each of these eighteen (18) wells were

              drilled to depths which would more likely yield natural gas than

              oil. If a hydrocarbon resource is discovered below 17,000 to

              19,000 feet it is generally natural gas because the temperature

              at that depth modifies oil into gas.

                   The natural gas discovered in the "Smackover" formation in

              Jay and Mobile Bay contain s hydrogen sulfide and is, therefore,

              said to be "sour". Hydrogen sulfide is corrosive and hazardous-

              which makes it less desirable and more costly to produce and

              transport than gas without hydrogen sulfide ("sweet" gas).

                                          2-4

                                          TABLE 2-1

                       Exploratory  Wells Drilled In The Destin Dome

                 Lease Block    Lease                                         Proposed
                     No.          No.      Operator     Well No.    NID*    Bottom Depth

                    617         2463       Zapata            1.,   4-76        10,500
                    360         2468       Gulf              1     1-75        21,000
                    250         2472       Exxon             1    12-74        11,000
                    251         2473       Chevron           1    10-74        12,000
                    205         2479       Exxon             1     6-74         7,000
                    207         2480       Exxon             i     6-74         7,000
                    162         2486       Exxon             1     6-74         7,000
                    162         2486       Exxon             2     8-74        12,00.0
                    162         2486       Exxon             3     3-75        19,000.
                    163         2487       Exxon             1     6-74         7,000
                    166         2490       Sun Oil           1     8-74        19,000
                    118         2492       Exxon             1     6-74         7,000
                    118         2492       Exxon             2    12-74         7,500
                    119         2493       Amoco             1    11-74        12,000
                    119         2493       Amoco             2    11-74        12,000
                      31        2502       Amoco             1     6-77            ?
                    529         3888       Shell             1    11-79        19,450
                    563         3890       Sohio             1     8-81        21,500

                *Notice of Intent to Drill

                Source: Mineral Management Service, Personal Communication

                                               2-5

                   MMS oil industry technicians and data from existing

              production wells indicate,that high sulfur, "sour" gas is more

              likely to be found offshore of Florida than   "sweet" gas or oil.

             III. Assumption 3 - Potential OCS Hydrocarbon Resource Sites

                   Based on.data. presented in the MMS Final Regional Environ-

              mental Impact Statement, Gulf of Mexico and-responses from the

              oil industry-it i's assumed that there are two (2) areas of the

              eastern Gulf of Mexico which are more likely to yield hydrocarbons

              thanother OCS areas offshore of West Florida. The-two (2) areas

              which are assumed to be potential locations of OCS resource dis-

              coveries..are:

                        1. Destin Anticline

                                 This area of the Gulf of Mexico OCS is located

                            approximately ninety-five (95) miles south of the

                            Okaloosa County community of Destin. This area is

                            in the Destin Dome Block of the OCS.

                        2. Southwest Corner  of Pensacola Block

                                One area that MMS has projected as having a high

                            resource potential for hydrocarbon reserves is the

                            area which includes the southwest corner of the

                            Pensacola Block and the westOrn margin of the Destin

                            Dome Block. The center of this area in the OCS is

                            located approximately thirty-five (35) miles south

                            of Gulf Breeze. There are currently seven.(7) active

                            active leases in this area of the OCS. Two (2)

                                            2-6

                            Unsuccessful explo i.-atory wells have beoii drilled

                            here.

               IV. Assumption 4 - Transportation of OCS Reserves

                    If a hydrocarbon reserve is discovered in the OCS offshore
               from West Florida there are assumed to be only two (2) likely
               transportation mechanisms for the resource to reach onshore
               facilities. 'The'two (2) mechanisms Iare:

                        1.  pipeline

                        2.  tanker vessel or barge

                    If more than a minimum resource find is made, it is assumed
               that industry will construct a sixteen (16) inch diameter pipeline
               to onshore facilities. The diameter of the pipe for the pipeline
               has been selected based on technical input from the oil industry

               representatives.

                    Oil industry representatives maintain that a sixteen (16)
               inch diameter pipeline would be adequate for the minimum
               discovery (100 million cubic feet of gas per day or more than
               10 thousand barrels of oil per day). Such an OCS pipeline could

               transport more than the minimum volume find.

                    There is a possibility that if a resource discovery is made
               in the western portion of area 2 of Assumption 3 that the resource
               would be transported to Alabama, therefor e, Florida would experience
               no onshore.impacts.

                    A second transportation assumption is that if a volume of'

               10 thousand barrels of oil*per day or less is discovered in the

                                           2-7

              OCS the cost of an OCS submarine pipeline would not be cost

              effective. In such a discovery   the oil would be loaded onto

              tanker vessels at offshore mooring sites and then shipped

              directly to a refinery. There are no refineries in West Florida

              and it is assumed there will not be any located here, therefore,
              tankered oil 'would not impact West Florida directly. Although

              the State of Florida has taken a posture that all OCS hydrocarbon

              reserves should be transported by pipeline, the state's trans-

              portation stipulation would permit surface tankering of oil if a

              pipeline is not cost effective.

              V.   Assumption 5 - OCS Pipeline Landfall

                   The determination of the actual route an OCS pipeline might

              follow to landfall is dependent on where the resource is

              discovered. The key determining factor for a pipeline route

              is cost. A sixteen (16) inch OCS pipeline costs 1.2 million
              dollars per mile.1 Due to this   high cost factor the oil industry

              seeks the shortest distance for  a OCS pipeline.

                   To propose OCS pipeline routes the study staff located

              potential landfall sites based on capital cost factors, environ-

              mental suitability and distance from landfall to existing onshore

              transmission pipelines.

                   Due to the natural function, environmental quality or

              physical character, five (5) areas of the coast of West Florida

              were assumed to be inappropriate or unacceptable for OCS pipeline

              landfall. These areas are@:

                                            2-8

                                          Perdido Key between the Florida/Alabama State Line
                                          and a point west of the Perdido Key Bridge on
                                          Highway 292

                                                This barrier island and the associated estuarine

                                          system is highly sensitive to disturbance. A
                                          pipeline route would involve approximately'fifty-
                                          three (53) miles from a point of landfall to an

                                          existing intrastate pipeline. If located in this

                                          area the pipeline would be required to cross Perdido
                                          Bay or an alternate route involving the crossing of

                                          several streams.

                                  ..2.    Perdido Key between the Perdido Key Intracoastal
                                          Waterway Bridge-and Pensacola Pass

                                                This portion of the barrier island is also

                                          sensitive to disturbance. A major part of this

                                          eastern end of Perdido Key is part of the Gulf

                                          Islands National Seashore and the site of Fort

                                          McRae, a historical and archaeological site. The
                                          distance for a pipeline to connect to a gas trans-
                                          mission facility is approximately twenty-four (24)

                                          miles.

                                   3.     Santa Rosa Island from Pensacola Pass to a point
                                          two (2) miles west of the Santa Rosa/0kaloosa
                                          Col

                                               North of this barrier island is the Pensacola

                                          Bay system and the Port of Pensacola. The bottom
                                          of the bay sy@tem contains hazardous substances

                                                                 2-9

                            and the bay receives  heavy waterborne traffic.

                            To route a pipeline across this bay system would
                            be very costly.

                        4.  The,Gulf Coast from a point approximately four (4)
                            miles eai@t of the Santa Rosa./Okaloosa County Line
                            eastward to the Walton/Bay County Line

                                North of'this area is the Eglin Air Force Base.
                            The Air Force has stated that only existing right-
                            of-ways may be used for a pipeline route and that
                            a gas pipeline would adversely affect the mission
                            of Eglin Air Force Base.2 A pipeline routed through
                            this area would require a submarine pipeline abross*

                            Choctwhatchee Bay.

                                The area between Choctwhatchee Bay and the Walton/
                            Bay County Line is the Point Washington Wildlife
                            Management area which may be crossed only if no
                            other alternative i8 satisfactory.3 If it was

                            necessary to cross the Point Washington Wildlifc
                            Management area; ten (10) major waterways, including
                            the Intracoastal Waterw*ay and the Choctwhatchee
                            River would have to be crossed by the pipeline.
                            These required crossings would be very  costly.

                        5.  The Gulf Coast from between Highway 79 in Bay County
                            and a poinL_approximately four (4) miles west of the
                            Bay/Gulf County Line

                                A pipeline route would have to cross the   Saint

                            Andrews Bay System and the metropolitan area  of

                                            2-10

                           Panama City. An alternate route through Tyndall

                           Air Force Base would adversely impact the mission
                           of the air bas.e.4

                   After the above areas were identified as unsuitable for a

              pipeline..landfall the staff examined the remainder of the-coast

              of Planning Region I for suitable landfall sites. Based on oil

              industry input it is assumed that four (4) pipeline landfall sites

              are suitable, The sites assumed to be serviceable are:

                       1. Perdido Key in the vicinity of the Perdido Key
                           Intracoastal Waterway Bridge and Highway 292

                               If a pipeline landfalls in this area there is a

                           distance of approximately fifty-three (53) miles

                           from the point of landfall to a connection with

                           Florida Gas Transmission Company's interstate gas

                           transmission system (see Figure 5-3).

                       2.  Santa Rosa Island in the vicinity of the Santa Rosa/
                           Okaloosa Count@in@e

                               A landfall for an OCS pipeline in this area would

                           be approximately forty (40) miles from Florida Gas

                           Transmission Company's gas transmission line. Such

                           a route for an onshore pipeline would require the

                           pipeline to be constructed through five (5) river/

                           creek crossings. A convenient connection point could

                           be made at F1 orida Gas Transmission Company's Juniper

                           Creek Compressor Station (see Figure 5-3).

                       3.  Bay County/Panama City Beach in the vicinity of
                           Tilghway 79 and Highway 98

                                            2-11

                               An OCS pipeline landfall in this area would

                            require a connecting onshore pipeline approximately

                            thirty-one (31) miles long to reach Florida Gas

                            Transmission i@ompanyls interstate gas transmission

                            system. This route would require  the industry to

                            cross two (2) creeks, the intracoastal waterway and

                            the Point Washington Wildlife Management Area along

                            the.right-of-way for Highway 79 (see Figure 5-3).

                       4.   Bay County, between Tyndall Air Force Base and the
                            Bay/Gulf County Line

                               To connect an OCS pipeline landfall from this

                            area to the Florida Gas transmission system would

                            require an onshore pipeline approximately forty-three

                            (43) miles long. An onshore pipeline following this
                            route would cross the Intracoastal Waterway (see Figure
                            5-3).

              VI. Assumption 6 - Timing ofOCS Onshore Activities

                   Any assumption of when OCS onshore impacts may be anticipated

              is dependent on the oil industry and the OCS Leasing Schedule.

              The oil companies ultimately determine which lease'blocks will be

              purchased and when exploratory drilling will be conducted because

              it is the oil industry's money that is being used. No federal,

              state or local government-agency can require an oil company to

              offer a bid during a lease sale nor insist exactly when an

              exploratory well will be drilled. Oil company interest in OCS

              leases is directly proportionate to the worldwide market for

              petroleum fuels and the status of surplus or insufficient fuel

                                            2-12

               supplies. The oil industry is not eager to conduc  t exp  loratory

               drilling for "sour" gas in the,OCS at a time when there is a

               surplus of natural gas throughout the world. At the time of

               this writing (April 1983) such a situation exists. However,

               based on oil industry input it is assumed that lease blocks in

               the eastern Gulf will be sold again during or before the

               November 1985 sale. If lbases are sold in 1985 then exploratory

               drilling activity will begin during or before 1988.

                    No leases were sold in the Destin Dome, Desota Canyon or

               Pensacola Blocks during the Spring 1983 sale. The next lease

               sale of leases in the eastern Gulf is  scheduled for November of

               1985.

                    Based on oil industry  input it is assumed that the oil

               companies will continue to  explore the OCS offshore of West

               Florida at present decreased levels in  the short term, but both

               exploration and development are likely  to increase over the long

               term throughout the Gulf of Mexii--o OCS.

               VII. Assumption 7 - Industry Onshore Facilities

                    To determine what facilities the oil industry may need to

               locate onshore in Region I if a resource discovery is made

               required an examination of available technical literature and

               direct input from MMS personnel and from oil industry representa-

               tives.

                    OCS onshore facilities range from a simple support service

               base for exploratory work to complex deep water ports and oil

               refineries. Based on available information it is assumed that

               the oil industry will not recreate the complex oil and gas

                                            2-13

              infrastructure that have been developed in Texas and Louisiana.

                   It is assumed that at least one (1) onshore service base

              will be located in Florida Planning Region I. All service for

              previous exploration activity offshore of West Florida has been

              conducted from Louisiana.and the Port of Panama City. The

              temporary service base established at the Port of Panama City

              generated very little local or regional impact. It is assumed

              that a larger service base would be necessary if a resource

              discovery is made. It is possiblethat one (1) service base

              could be established near Pensacola and one (1) near Panama City

              if discoveries were made in each of the two (2) OCS areas dis-

              cussed in Assumption 3.

                   It is assumed that drilling mud and cement manufacturing

              companies would not be built in Region I because it is cost

              effective to transport these necessary materials from already

              existing facilities in Texas or Louisiana or Mississippi. Storage

              space would be required to provide for holding the drilling mud

              and cement until used. It is also assumed that drilling tools

              and wellhead equipment would be transported to West Florida from

              existing manufacturing facilities.

                   It is assumed that established catering service companies

              could be employed to supply OCS activities offshore from West

              Florida. Local surveyors and local labor could provide any

              necessary support for catering service companies.

                   it is assumed that platform fabrication yards will not be

              located in West Florida. When field development begins it is

              assumed that development p latforms will be supplied by existing

              facilities.

                                           2-14

                    Permanent pipe coating yards may not be necessary in West
               Florida because the current facilities along-the Gulf Coast can
               cost effectively supply any necessary pipe to West Florida by
               barge or rail transport.

                    It is assumed that no refineries will be constructed in
               West Florida. Refineries are already operating in Mobile,
               Mississippi, Louisiana and Texas. However, it is assumed that
               one (1) or more natural gas treatment/processing facilities will
               be constructed in West Florida if a resource discovery of suffi-

               cient volume is made.

             VIII. Assumption 8 - Regional Resource Committment

                    The general requirements for land, water and labor are
               ass umed to increase only minimally or moderately. Air emissions,

               wastewater treatment and solid waste from OCS activities are

               expected to be manageable.

                    Analysis of the anticipated OCS onshore facilities
               indicates that it is unlikely that any community in West Florida
               will be subjected to an unreasonable rise in demand for housing

               or social services.

                                            2-15

                                         CHAPTER 2

                                         Footnotes

               1. "Oil and Gas Journal". November 1982.

               2. Eglin Air Force Base, personal communication.

               3. St. Joe Paper Company, personal communication.

               4. Tyndall Air Force Base, personal communication.

                                          2-16

                                         CHAPTER 3

                                   Ocs STUDY METHODOLOGY

                                        CHAPTER 3

                                  OCS STUDY METHODOLOGY

                    It was.very difficult to assemble a methodology of acceptable

               format to determine the OCS onshore impacts in West Florida. The

               staff examined seven (7) different study approaches. The seven

               (7) methodologies were developed by:

                        l.. New.England River Basin Commission;

                        2.  Roy F. Weston, Inc.;

                        3.  Conservation Foundation;

                        4.  Maryland Major Facilities Study;

                        5.  Texas Coastal Management Program;

                        6.  Alaska Division of Community Planning; and,

                        7.  Louisiana Coastal Resource Management.

                   At first, the New England River Basin Commission methodology
               was determined.to be the most appropriate. However, during the
               literature review process and during preliminary evaluation, it

               was determined that none of the previously developed methodologies
               were directly applicable to West Florida. The lack of adequate
               data pertinent to West Florida is a significant problem and
               required that a modified approach be developed.

                    The decision was made that any methods used to assess

               potential OCS onshore impacts and to determine suitable sites for
               oil industry needs would have to be as uncomplicated as possible.
               The approach was to aim for a plan which can be easily reviewed
               and modified as new data becomes available, but is also adequate

               for local West Florida citizens and elected officials to understand

                                          3-1

               potential OCS problems in order to formulate implementable programs
               to minimize any negative impacts and to maximize any positive
               impacts.

                    A basic, twelve (12) component program was formulated and

               executed. The twelve (12) components are described below.

               I.   Literature Review and Background Research
                    Throughout the entire study process the staff acquired any
               and all available pertinent literature. Documents were reviewed
               and evaluated for applicability to West Florida. Many excellent
               documents were reviewed and the findings have been incorporated
               into,this OCS study effort. A list of these works is presented
               in the bibliography of this document.

                    As previously mentioned, there is very little information or
               data that is directly relevant to the OCS offshore from West
               Florida nor about potential onshore impacts in this region. In
               an effort.to generate pertinent'input and to provide data, the
               staff established direct contact with oil industry corporate
               decision makers and oil industry technical representatives. The
               oil industry was found to bevery willing, helpful and capable.
               Much of the findings of this OCS study is based on the information
               and data shared by oil industry representatives.

               II. Identification of Typical Oil Industry Onshore Facility Needs
                    The staff devoted significant time and effort to learning.
               about and analyzing the types of onshore and offshore facilities
               that are common to the oil industry. Tours of existing facilities

                                            3-2

              were arranged to provide "first hand" experience co .ncerning the
              industry's onshore activities. Again, the oil industry was very
              cooperative and helpful as the staff learned about oil industry
              facilities. The input of the oil company representatives-combined
              with the information contained in the current literature served to
              provide an understanding of the oil industry's facility needs.
              Discussions of the indust3fy's-general facility needs is presented
              in Chapter 4..and.a discussion of the needs and impacts of the
              facilities which are likely to be needed in West Florida are
              discussed in Chapter 5

              III. Evaluation of Regional Constraints for OCS Onshore Facilitie*s
                    Public and elected official concern has been expresse d that
              certain environmentally, recreationally and aesthetically signifi-
              cant areas may be degraded or destroyed by OCS onshore activities.
              It was determined to be in the best interest of the state, region,
              local citizens and the oil industry that any critical or delicate
              areas should be identified and considered for protection. Public
              input, technical input and pertinent literature data, including
              the recent document The Sensitivity of Coastal Environment and
              Wildlife To Spilled Oil In West Florida, were evaluated to define
              the-areas that are unsuitable or only marginally suitable for OCS
              onshore facilities. Three   (3) exclusion considerations have been

              applied.

                   A. 8ays and Estuaries

                        The shallow depth.and activity levels of the bays and
                   estuaries of West Florida would require the oil industry to

                                            3-3

                     construct a submerged pipeline using the same techniques
                     used for OCS pipeline installation. The cost of a submerged
                     pipeline is five  (5) or six (6) times greater than an onshore
                     pipeline. Because bay crossings are relatively short in
                     length (three (3) to seven (7) miles) and it would require
                     great capital expense to transport a smaller lay barge (lay
                     barges used in the Gulf  of Mexico may be too large to
                     maneuver in'bayp)   into the region's bays; the cost of a
                     short, submerged, estuarine pipeline may approach $5 million
                     per mile. As a result   of this high cost, it is presumed that
                     a gas pipeline company  would avoid crossing major bays:
                     Perdido Bay, Pensacola  Bay, Escambia and East Bays, Chocta-
                     whatchee Bay, and the  St. Andrews Bay System.

                     B. Large Land Areas In Single Ownership
                        The- second exclusion consideration considered ownership
                     and use of large land areas.. Eglin Air Force Base is the
                     largest single bwnership, lan d area in West Florida (463,542
                     acres). The primary activity at Eglin is developing and
                     testing weapon systems, which requires use of explosives
                     on the military reservation. Such activity would preclude
                     construction of surface or buried petroleum facilities on
                     the reservation. Officials at Eglin have confirmed    that
                     the reservation should not be.considered as a potential site
                     for OCS onshore support facilities. Tyndall Air Force Base,
                     located in Ba y County, received the same consideration as

                     the Eglin Air Force Base reservation.

                        Another large land area under single ownership is the

                                             3-4

                    Point Washington Wildlife Management Area, owned by the

                    St. Joe Paper Company and managed by the Florida Game and
                    Freshwater Fish Commission. When briefed on the objectives
                    ok'this OCS Study, officials at St. Joe Paper Company stated
                    that proposals for outleases of the Point Washington Wildlife

                    Management Area would be considered on a case-by-case basis.
                    Proposals for construction of a buried pipeline may receive
                    favorable consideration, since the land may still be used
                    for wildlife management, except trees cannot be grown in
                    the right-of-way. Proposals for construction.of large
                    facilities will, according.to St. Joe Paper Company officials,
                    mos.t likely be denied. Therefore, the Point Washington Wild-
                    life Management Area is excluded from consideration for onshore

                    support facilities, except for a pipeline corridor.

                    C. Major River Systems

                       The third exclusion criterion involves crossing major
                    river systems. The water volume and flow rate of large rivers
                    ma kes dredging and turbidity control difficult. In addition,
                    large rivers usually have an associated broad floodplain and
                    wetland area. Crossing rivers and associated floodplains is
                    expensive,,since erosion and water turbidity must be con-
                    trolled. The potential for significant environmental damage
                    increases with river*system size. Because of the potential
                    for greater environmental damage and high cost (the more
                    expensive horizontal drilling process is recommended for
                    making river crossings), it is presumed that a gas pipeline
                    company would avoid crossing large rivers with gas pipelines.;

                                            3-5

                   The Choctawhat chee River delta, at the head of Choctawhatchee

                   Bay, is the largest area excluded for this reason.

                        The second proce ss of selecting alternative sites involves

                   matching petroleum industry needs with existing, compatible

                   facilities. In this process, locations of potential support

                   services were mapped and correlated with gas/oil industry

                   needs. The types of 'areas researched included:

                        l.. industrial parks (existing and proposed) and

                            industrially zoned land (see Figure 3-1).

                        2.  isolated, undeveloped land where an industrial site

                            and adequate buffer zone could be located;

                       ..3. areas with access to the Gulf of Mexico;

                        4.  areas with access to the Gulf Intracoastal Waterway

                            (GIWW);

                        5.  dredged, maintained navigation channels and improved

                            waterfront sites;

                        6.  existing rights-of-:way compatible with potential gas

                            pipeline'needs;

                        .7. existing petroleum fuels barge terminals; and,

                        8.  existing natural gas pipelines and gas facilities

                            (see Figure 5-1).

                        In addition to mapping and researching the above areas

                   and facilities, policies and regulations of federal, state and

                   local governments were compared with gas and oil industry needs.

                   Specifically, the following were considered:

                        1. existing regulatory authority (Chapter 6

                        2. Florida Coastal Management Program, laws and regula-

                            tions; and,

                                           3-6

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                                                                                                                  FIGUR"EE 3-1

                                                                          EXISTING AND POTENTIAL INDUSTRIAL SITES (20 acres or larger)

                       WEST FLORIDA REGIONAL PLANNING COUNCIL

                        3. local government comprehensive plans, ordinances and

                            regulations.,

              IV. Direct Technical Input

                  Perhaps 'one (1) of'the most significant components of the OCS

              Study process involved the staffs direct communication with oil

              industry technical representatives. These knowledgeable experts

              served as the only source of current, comparative data. The

              industry representatives which have been most cooperative, respon-

              sive, and helpful are:

                        1.  Shell Offshore, Inp.

                       ..2. Mobil Oil Exploration and Producing, Southwest, Inc.

                        3.  Southern Natural Gas

                        4.  United Gas Pipeline Company

                        5.  Florida Gas Transmission Company

                        6.  Florida Petroleum Council

                        7.  Exxon Oil Company

                        8.  T. A. Herbert and Associates(Environmental Consultant

                            to Getty Oil Company)

                        9.  Amoco Oil Company

                       10.  Gulf Oil Company

                       11.  Sohio Petroleum Company

                       12.  Getty Oil Company

                   The staff directed batteries of questions to the various oil

              companies and other oil industry representatives. Industry responses

              were compared and evaluateq for regional pertinence and consistency.

                                           3-8

              V.   Regional'Assumptions

                   During.the staff search for an applicable study methodology it

              was realized that the study effort could be unending and of little

              use unless some basic factors or assumptions were determined. After

              consulting technical representatives, MMS and State of Florida

              personnel, the,staff determined eight (8) assumptions for the

              evaluation of alternatives and preparation of recommendations. The

              assumptions involve:

                        1. OCS resource estimate;

                        2.  potential resource;

                        3.  potential hydrocarbon resource sites;

                       .A.  transportation of OCS reserves;

                        5.  OCS pipeline landfall;

                        6.  timing of OCS onshore activities;

                        7.  industry onshore facilities; and,

                        8.  regional resource committment.

                   The eight (8) assumptions are discussed in detail in Chapter 2'.

              VI. Selection of Alternative Facilities Sites Based On Oil Industry

                   Requirements

                   During the literature search data collection and direct

              communication with oil industry representatives, the staff listed
              and conducted preliminary evaluations of oil industry onshore
              facility ne eds. Each facility type was then evaluated for its
              specific requirements, characteristics, and for probability of being
              located in West Florida.  The results of the evaluation are contained
              in Chapter 4.    The types of onshore oil industry facilities and

                                           3-9

                    ancillary services examined include:

                                    1. temporary support or service bases;

                                    2. permanent support bases;

                                    3.    supply boats;

                                    4.    crew boats;

                                    5.    drilling mud companies;

                                    6.    wellhead equipment companies;

                                    7..   platform fabrication yards;

                                    8.    platform installation service bases;

                                    9.    cement companies;

                                  10.     catering services;.

                                  .11.    drilling rigs;

                                  12.     pipeline corridors;

                                  13.     temporary pipe coating yards;
                                  14.     gas processing/treatment facilities;
                                  15.     gas compressor and metering facilities;
                                  16..    oil storage/barge facility;

                                  17.     marine terminal;

                                  18.     refineries; and,

                                  19.     petrochemical facilities.

                   VII.-Formulation of Socioeconomic Evaluation Matrix
                           The selection of a technique to conduct an analysis of impacts
                   of potential onshore facilities in West Florida was of the most
                   difficult work tasks of this entire study. If the selected
                   technique was too complicated it might have been too complicated
                   for general use for the citizens and elected officials and if the

                                                                 3-10

             technique was over simplified it could have not been acceptable
             to evaluate impacts. The staff opted to employ an approach which
             has been a very successful technique for other  studies conducted
             by the West Florida Regional Planning Council staff.   It was.
             determined that.a matrix of impacts should be developed which
             could be used to evaluate all the potential facilities and which
             could record the assessmen@ of positive and  negative impacts in a
             way that would make a comparison of each alternative site and each
             potential facility possible. The matrix approach was used for both
             socioeconomic and environmental impact assessments.. The matrices
             were determined to be satisfactory and had the advantage of being
             serviceable as a public information device.

                  Seven (7) alternatives were evaluated for most of the five (5)
             facility types of OCS onshore support facilities. Each facility
             alternative was evaluated for fifteen (15) different socioeconomic

             parameters. The socioeconomic parameters/impacts evaluated are:

                       1. population;

                       2.  local employment;

                       3.  local revenue;

                       4.  land use;

                       5.  access to the Gulf of Mexico;

                       6.  utilities;

                       7.  availability of support services to a proposed site;
                       8.  access to transportation (water, rail and roads);

                       9.  traffic flow;

                       10. recreation/toprism;

                       11. conservation/preservation areas;

                                           3-11

                        12.  ports;

                        13.  facility costs;

                        14.  aesthetics; and,

                        15.  navigation.

                   An evaluation weight.scale  was used for rating  impacts. The

              scale ranges from a plus three  (+3), representing highly favorable
              impact to a minus three (-3), representing a highly unfavorable

              impact. Each impact for each alternative was carefully evaluated

              with attention for consistency. After each alternative for each

              facility had been rated individually, the total for each evaluation

              was calculated. If an alternative was evaluated to   have a positive

              impact it-was considered to be favorable for recommendation as a

              suitable site for an industry facility. The determining factor for

              a.final recommendation was the combined total of the socioeconomic

              and environmental matrices evaluations. The completed matrices are

              presented in Appendix A of this document.

                   It is.important to remember'that the alternatives evaluated do

              not represent every possible site for industry needs. As industry

              activities in the OCS offshore from West Florida increase there

              will be additional data which may modify the assumptions. At that
              time the matrices may be reevaluated and new alternative sites may

              be evaluated.

                   The approach taken to evaluate the previously mentioned
              impacts is summarized in the following discussion.

              A.   Population

                        Each alternative site was considered for the potential
                   impact it might produce to,the total population of the region

                                            3-12

                   and to the closest local population center. The distance to

                  ,a population center which could provide necessary service for
                   labor or which might 'serve as a source for workers was consid-

                   ered. Also each facility type was evaluated for the type and

                   number of jobs that could be generated. If the potential

                   pop ulated.areas were evaluated to be able to accomodate an

                   expanded population anid if these areas  could offer the type

                   of workers necessary for a potential industry onshore facility,

                   a positive weight was assigned. If an area was evaluated to

                   not be able to accomodate or offer adequate labora lower

                   weight was assigned.

              B.   Locai Employment

                        The alternative sites were evaluated for any impacts on

                   the local employment level. In every case it was determined

                   that if local jobs.could be added,a positive impact would

                   result.

              C.   Local Revenue

                        The impact of each alternative siteon the local economy

                   was evaluated. If a site was determined to bring additional

                   revenues to local businesses rather than add additional

                  .expenses to an area, a positive weight was assigned.

              D.   Land Use

                        The  land use demand and characteristics of each alternative

                   site was  carefully compared to adjacent and surrounding land
                   uses. If adequate lana use was available and if land uses were

                                             3-13

                   compatible, a positive weight was assigned. if property costs

                   were high and/or it was determined that a land use conflict

                   would resulta lower weight was assigned.

              E.   Access to the Gulf of Mexico

                        If a potential. industry onshore facility requires access

                   to the Gulf of Mexico.OCS a weight was assigned for each

                   alternative's proximity to the Gulf. If an alternative site

                   did not require access to the OCS (e.g. natural gas compressor
                   and metering facility) no weight was assigned. If an alte  rna-
                   tive was evaluated to have a serviceable ac*cess, a positive

                   weight was assigned.

              F.   Utilities

                        Each alternative site was examined and evaluated for its

                   proximity to existing utility service. If a utility service
                   was not located in the area of a potential facility site, a

                   low weight was assigned.

              G.   Availability of Support Services
                        The availability and proximity of support services (e.g.,
                   emergency and fire protection) was determined to be a positive
                   impact or asset for most of the alternatives examined. I  f a
                   potential site might locate in an area that has adequate
                   support services, a positive weight was assigned.

              H.   Acces s to Transportation Systems

                        Each alternative.was evaluated for its transportation
                   needs and then compared to the existing systems available in

                                             3-14

                   the adjacent area. If adequate water, rail and road systems
                   were available which did not require capital improvements to

                   accomodate a facility    it was determined to be highly favorable
                   and therefore was assigned a positive weight.      Lower weights

                   were.assigned if additional capital expenditures were needed
                   or  if a proposed site was distant from a needed transportation

                   system.

                   Traffic  Flow

                          If an alternative facility site was determined to have a

                   loading  or congesting impact on any transportation system, a

                   low weight was assigned.

              J.   Recreation and Tourism

                         Each facility site was evaluated for any potential impacts

                   to the region's vibrant tourism industry and recreational
                   facilities. If a facility might impact on existing recreation
                   areas or interfere with touri*st facilities, a low weight was
                   assigned. If a facility    was determined to be away from existing
                   recreation areas and was evaluated to be of sufficient size-to

                   draw visitors who may choose to recreate in West Floria, a
                   positive weight was assigned.

              K.   Conservation/Preservation Areas

                        Each alternative'site was considered for its proximity to
                   any significant conservation/preservation areas. Sites-that

                   are away from critical estuarine, wetland or historical areas

                   were assigned higher weights than areas which might generate
                   potential negative impacts-to a conservation or preservation

                   area.

                                              3-15

                   Ports

                        Because the two .(2) major ports located in West Florida

                   add so much to the region's economy, each alternative. was

                   evaluated for any potential impacts to the ports. If an

                   alternative facility site was evaluated to add, but not burden

                   a port's activity, a positive weight was assigned.

              M.   Facility Costs

                        It was determined that some sites would require the oil

                   and natural gas industry to expend higher capital funds than

                   ot her alternative locations. If an alternative site was

                   determined to be costly to develop or locate,a lower weight

                   was assigned.

              N.   Aesthetics

                        The aesthetic appeal of West Florida is one of the

                   regionts most valuable resources. If an alternative site

                   was determined to degrade the aesthetics of a significant
                   area, a low weight was assigned. It is unlikely that any
                   facility site would add to the local aesthetics, however, if
                   a alternative site is to be located away from recreation areas
                   it was determined to be less of a negative impact to the local

                   aesthetics.

             0.    Navigation

                        If an alternative facility was determined to have a
                   loading or clogging impact to navigation in the region's
                   intracoastal and other waterways, a low weight was assigned.
                   In many cases the alternative site would have no impact on

                   navigation.

                                            3-16

              VIII. Formulation of Environmental Matrix

                    The same approach selected for evaluating socioeconomic impacts
              impacts was applied to evaluating environmental impacts. Eighteen
              (18) different potential environmental impacts were evaluated for

              each of the alternative sites. The eighteen (18) impacts evaluated

              are:

                        1.  air quality;'

                        2.@ water quality;

                        3.  groundwater quality;

                        4.  water supply;

                        5.  solid waste,

                        6.  hazardous substances;

                        7.  wetlands and marshes;

                        8.  grassbeds;

                        9.  noise;

                       10.  riverine and stream systems;

                       11.  beach ecosystem;

                       12.  wildlife;

                       13.  endangered species;

                       14.  shell fisheries;.

                       15.  fin fisheries;

                       16.  energy consumption;

                       17.  dredging; and,

                       18.  oil spill impacts.

              A.   Air Quality

                        The air quality Of West Florida is considered to be good,
                   generally, with some ambient air quality standard violations

                                           3-17

                   in areas of-high population.  The major impact producing

                   factors on air quality-from OCS related activity are due to:

                             1. combustion of raw materials;

                             2. evaporative loss of hydrocarbons;

                             3. internal combustion  from on-site power

                                 generation; and,
                             4.  product processing techniques,1

                        The major impact producing factors from offshore and

                   onshore OCS related activities are:2

                             1. offshore

                                 a. catastrophic events

                                     1 - blowouts with fire

                                     2 - oil spil

                                     3 - escape of "sour" gas

                                 b.  operational emissions

                                     1 - exploration drilling

                                     2 - platform installation

                                     3 - developmental drilling

                                     4 - oil production

                                     5 - gas production

                                     6 - barge loading

                             2. Onshore

                                     1 -gas processing  plants

                                     2 - refineries

                        Air quality impacts generated by a OCS onshore facility

                   may have short term and long term impacts. Air emissions that

                   are characteristic of oil industry facilities are:

                                           3-18

                             1. Nitrogen Oxide;

                             2. Sulfur Dioxide

                             3. Carbon Monoxide;

                             4. Total Suspended Particulates;

                             5. Hydrogen Sulfide; and,

                            .6. Hydrocarbons (e.g., butane, propane and

                                 natural.gas).

                        During the study consideration of the air quality

                   characteristics of each facility alternative site, the staff

                   ev'aluated the types of air emissions,.both general and catas-
                   trophic; and the proposed facility site's proximity to

                   populated areas. If a facility was determined to have low

                   volume air emissions or not near a populated or conservation/
                   preservation or recreation area, a moderate or no weight was

                   assigned.

             B.    Water Quality

                       The quality of the surface and ground waters of West

                   Florida have been of major concern since the late 1960s. A

                   great deal of effort and money has been dedicated to study,
                   restore, and improve the region's water quality.
                       Potential water quality problems resulting from offshore
                   OCS activity can be attributed to several factors:3

                             1. resuspe'nsion of bottom sediments through

                                 exploration, development and pipeline

                                 construction activities;

                             2.  discharge of deck drainage;

                             3.  sanitary wastes;

                                           3-19

                             4. domestic wastes;

                             5.  discharge of formation and produced waters;
                             6.  discharge of drilling fluids and muds;
                             7.  accidental hydrocarbon discharge due to spills

                                 and blowouts; and,

                             .8. discharge of radionuclides.

                        OCS related onshore facilities may impact local onshore
                   and nearshore water quality by increasing the point and non-
                   point pollution sources. Increased runoff from facility sites
                   may increase the loading of:

                             1. particulates;'

                             2. heavy metals;

                             3. petroleum products and chemicals; and,
                             4. biological ozygen demand (BOD),

                   to the streams and estuaries of West Florida.

                       Offshore water quality impacts from OCS oil*industry
                   activities "are expected to be very low..." and "...impacts
                   to onshore water quality is expected to be very low." "The
                   total cumulative effect of OCS related and other activities
                   is expected to result'in a very low to moderate level of input
                   on regional offshore and onshore water quality.,,5
                        "OCS oil and gas related population and support facility
                   increases are expected to create a low to moderate impact on
                   regional water supplies. However, the overall cumulative
                   impact which includes the effect of projected population and
                   industrial growth is e'xpected to be high to very high."6
                       The evaluation of potential,water quality impacts for

                                          3-20

                   each alternative site considered in this study was a complex
                   process. The general and potential catastrophic discharges
                   of each facility type'were defined. Each site location was

                   examined in relation to the adjacent and surrounding water
                   quality se gments. The potential discharges were com ared to
                                                                         P

                   the segment's water quality as recorded in the 208 Clean Water

                   Plan for West Florida'. A determination of overall water

                   quality'and water supply impacts was made for each facility
                   site location. If a facility was determined to be located in

                   a critical water quality segment and if it was characterized

                   by a potentially hazardous discharge,  a negative weight was

                   assigned.

              C.   Groundwater Quality

                        The protection of the region's groundwater has  been
                   identified as a high priority goal in the region's comprehen-
                   sive plans. Any facility that may severely degrade groundwater
                   quality,in an area wouldrequire detailed analysis prior to

                   permitting.

                        Any discharge into West Florida's groundwaters is unlikely
                   to be permitted. Accidental discharge may degrade groundwater
                   in localized areas, however, long term impacts from continuous
                   accidental discharge could be significant.

                        Each facility type was evaluated and its potential dis-
                   charges were characterized. The products and any hazardous
                   materials for each facility were evaluated and a determination

                   of groundwater impact9 if the products or materials   reached

                   the local groundwater was conducted.

                                            3-21

                        The only OCS related onshore facility that is assumed

                   to locate in West Florida that has been evaluated to have a
                   potential impact on groundwater is a natural gas treatment
                   facility. Each alternative site could impact the groundwater
                   depending on the size and processes of the facility.

             D.    Water Supply

                        Most of the water for potable use in West Florida is
                   supplied by the Sand and Gravel aquifer and the upper Floridan
                   aquifer. These two (2) resources have had adequate capacity
                   to meet the region's needs until*recen'tly. -The.Northwest
                   Florida Water Management District has completed a regional
                   water supply study which identifies the future water supply
                   needs and recommends water resources to develop to meet future
                   needs. In the future, potable water will be available, but at
                   a higher.cost due to resource development expenses.
                       Each alternative was characterized for its specific
                   potable water needs and demands. Facilities that demand large
                   volumes of potable water were assigned a negative weight. Some
                   alternative sites were considered which are in areas that

                   presently have water supply problems and have, therefore,
                   assigned negative weights. An onshore support base was

                   determined to have the highest potable demand and therefore
                   the greatest impact on water supply of the five (5) types of
                   OCS related facilities that.are assumed to be most likely to

                   locate in West Florida.

             E.    Solid Waste

                       solid waste disposal and any potentially hazardous

                                            3-22

                  components of the solid waste are of significant concern in
                  West Florida. The State of Florida and each county permit and
                  and maintain sanitary'landfills for the disposal of solid
                  wastes. The types of general solid waste (e.g., paper, pack-'
                  ing material, metal and wood products,  cement) from OCS
                  related facilities have been determined to be compatible
                  for the landfills in West Florida. The extra tons of solid
                  waste from the facilities can be accomodated in most of the
                  region's landfills. None of the alternatives that have been
                  evaluated have determined to be likely to generate a volume
                  or type of solid waste that could not be disposed of using
                  current permitted procedures.

             F.   Hazardous Substances

                       Hazardous solid wastes are required to be disposed of
                  in a special permitted landfill. These landfills are prepared
                  to eliminate the pollutants from seeping into groundwater and
                  surface waters or from impacts to,air quality. The OCS
                  related substances that are hazardous that have been identified
                  during literature search and data collection are:

                            1. sludges;

                            2.  scums from settling ponds;

                            3.  oiled drilling muds;

                            4.  hydrogen sulfide;

                            5.  desicants from gas treatment facilities;
                            6.  degraded amine;

                            7.  gas trealtment process sludges;
                            8.  oiled cleaning materials and supplies; and

                                           3-23

                             9. hydrocarbon wastes and sludges.

                        Some potentially hazardous materials will be used during
                   the construction of OCS related facilities and during

                   specialized operations.

                        The alternative facility site s were evaluated for sus-

                   ceptibility to hazardous waste substance spills and for
                   proximity to permitted hazardous waste disposal sites.
                   Matrix evaluation weights were a*ssigned based on a site's

                   potential for generating hazardous materials and on its

                   proximity to highly susceptible conservation/preservation

                   areas.

              G.   WetlAnds/Marshes

                        Wetlands and marshes are prevalent all along the coast

                   of West Florida. These highly productive areas are some of
                   the most.valuable resources in the region. The wetlands and

                   marshes are rich nurseries and wildlife habitats and serve

                   as flood water storage areas. These areas also serve as

                   groundwater recharge areas.

                        Each alternative site was evaluated for any  potential
                   impacts on the region's wetlands and/or salt and   freshwater

                   marshes. If a facility would require dredging or waterfront
                   modification or could not be located.away from marsh areas,

                   a negative weight was-assigned.

             H.    Grassbeds

                        Marine and submarine grassbeds were once widespread
                   throughout West Florida. Increased stormwater runoff,

                                           3-24

                   improper land use, dredging and industrial discharges have

                   degraded many of the grassbeds in the region. These highly
                   productive areas serve as habitats and nursery areas for

                   shell and fin fish.

                       ..Any alternative site that was determined  to.be   likely
                   to disturb, degrade,.or destroy grassbeds was   assigned a
                   negative weight.*

                   Noise

                        Noise pollution is a more significant concern in populated

                   areas or in areas that already experience high noise levels.

                   Each alternative facility type noiselevels were characterized

                   and each facility site was evaluated for combined noise level

                   impacts. Some facilities produce high noise levels during
                   construction, but are characterized by   low noise levels during
                   operation. Some facilities, e.g., natural gas treatment

                   facilities, are always noisy and have unfavorable impacts in,

                   populated areas. Facilities with high noise levels or

                   alternative sites that may be adjacent to populated areas

                   were assigned negative weights.

              J.   River/Stream Ecosystems

                        River and stream ecosystems were examined for suscepti-

                   bility to OCS onshore facilities and also for the cost to the

                   industry if it becomes necessary to develop a facility in a
                   river or stream area    One recommendation of this study is.

                   that any crossing of a major river or stream system should
                   be conducted using directional or horizontal drilling under

                                             3-25

                  the stream rather than dredgin g of a space for the industry's

                  needs. A pipeline corridor passing through a stream ecosystem

                  was determined to be more costly and more likely to degrade

                  the ecosystem than a pipeline which did not require a major

                  stream crossing. Disturbances and dredging in river and

                  stream areas can generate turbidity and resuspension of

                  hazardous substances in some areas or may involve the disrup-
                  tion of.critical wildlife habitats. Any facility site that

                  was determined to have a potentially degrading impact on

                  river or stream integrity was assigned an negative weight.

             K.   Beach Ecosystem

                       West Florida's beach ecosystems are the regions most

                  aesthetically valuable and appealing resource to the tourism
                  industry. However, the region's beaches serve a highly
                  valuable.function as the primary defense mechanism against

                  any storm forces coming across from the Gulf of Mexico. The

                  beach ecosystem is highly. susceptible to oil spills and human
                  development processes.  Due to the dynamics and natural
                  functions of the West Florida,beach system, this study

                  recommends that any pipeline crossing through a Gulf front
                  beach be done using horizontal or directional drilling

                  techniques.

                       Any facility site that would require modification to

                  a beach ecosystem or that would have a long term impact on
                  the region's beaches, was assigned a negative weight.

             L.   Wildlife

                       The marine, estuarine and upland wildlife of West Florida

                                            3-26

                    have been determined to be valuable resources throughout the
                    region and have been identified in the local government

                    comprehensive plans to be subject to protection and prese   .rva-

                    tion because of their value.

                       -If a facility was determined to require the displacement

                    of natural animal species during construction or operation or
                    if wildlife could not'coexist at a proposed facility site,    a

                    negative score was assigned.

              M.    Endangered Species
                         No alternative facility site was  -determined to be proposed
                    for a known endangered specles site. However, most potential

                    sites could impact endangered Species. Without detailed field

                    survey data-of each sit e it is impossible to identify the

                    degree of potential impact on an endangered species, therefore,

                    all proposed facility sites were assumed to have the same

                    potential for impacting endangered species except sites that

                    are proposed for previously developed areas.

              N.    Shell Fisheries

                         The shellfish (e.g., shrimp, oysters and scallops) of

                    West Florida serve as a food source and add to the economy

                    in West Florida. Any facility that was determined to have

                    a degrading or harmfu 1 impact to shellfish and shellfish

                    habita ts was. assigned a negative weight during the matrix

                    evaluation process.

              0.    Fin Fisheries

                         Just as shellfish are a valuable resource throughout

                                              3-27

                   West Florida, so are the fin fish. Any alternative facility
                   site that was determined to potentially generate an impact

                   that would damage or -harm fin fish or fin fish habitats

                   was  assigned a negative weight.

              P.   Energy Consumption

                         The 'need for this work is based on the fact that the

                   world's energy supply has become degraded to a point that

                   energy conservation is necessary. It has been assumed that

                   any OCS onshore facility that is characterized by a high rate
                  @of energy consumption is 'only jus tifie*d because it may assist

                   in generating additional energy resources from OCS reserves.

                   If a  facility has been'determined to consume a great deal of
                   energy it was assigned a negative impact weight.

              Q.   Dredging

                         The modification of the waterways, estuaries and water-

                   fronts of West Florida by hydraulic dredge is energy intensive
                   and degrades environmental quality with increased turbidity

                   and resuspension of bottom sediments.

                         All proposed facility sites were evaluated for dredging
                   requirements. Facilities that require slight or no dredging
                   were determined to have no impact or only slight negative
                   impact. Facilities t  hat would require dredging during
                   construction and continued long term maintenance dredging,
                   were assigned impact weights to reflect their highly unfavor-

                   able impacts.

                                              3-28

                   Oil Spill Impacts

                        One potential environmental impact that is of primary
                   interest to the study staff, Advisory Committee and the
                   public is oil spills. it is known that there will be a
                   oil spill in the Gulf of Mexico, according to the MMS.7
                   When a spill will occur is unknown, however, the negative
                   impacts of an oil spill can be anticipated and can be
                   minimized with proper planning. MMS stated that there is
                   a three percent (3%) chance that an oil spill equalling or
                   greater than 1,000 barrels of oil from the OCS will reach
                   shore in Escambia County within ten (10) days  of a spill.8
                        The potential for an oil spill exists outside of an
                   OCS oil spill. If oil transported by oil barge to a terminal
                   in West Florida there is an increased potential for an oil
                   spill in the Intracoastal Waterway or other nearshore areas.
                   The pote ntial impacts of an oil spill in a nearshore area
                   vary in severity depending an the area that a spill might
                   occur. Containment of a  spill from a collision or during
                   an exchange operation (loading or unloading) depends on the
                   availability of containment equipment. The clean up of an
                   oil spill in a marsh area or in a grassbed area could be

                   disastrous.

                       There are fourteen (14) different causes of oil spills
                   from offshore operations on the OCS. A summary of OCS oil
                   spills*of greater than fifty (50) barrels is summarized in

                   Table 3-1.

                       There are many different causes of oil spills from a

                                            3-29

                                                TABLE 3-1

                          Causes Of Oil S2ills Greater Than 50 Barrels
                             Resulting From Offshore-Operations On-The
                                               Federal OCS

                                                           Number of           Number of
                       Cause"s of Spills                   Incidents        Barrels Spilled

              Blowouts                                         9                 63,582

              Fire                                             1                 30,500

              Collisions of Vessels                            4                  4,325

              Hurricanes and Storms                            7                 14,457

              Abandonment Process                              1                     500

              Barge or Marine Vessel Accident                  3                  7,265

              Tank, Separator, Sump Overflow                   8                  1,013

              Transferring Oil, Fuel Operations                7                  1,211

              Human Error                                      8                 55,316

              Equipment Malfunction                            12                11,190

              Pipeline Leak/Break (unknown cause)              13                14,158

              Pipeline Leak/Anchor Dragging                    6                 191,702

              Pipeline Leak/Shrimp Trawler                     1                  4,000

              Pipeline Leak/Mud Slide                          1                     250

              SOURCE: Final.Regional Environmental Impact Statement, Gulf of Mexico,
                        Department of the Interior, Minerals Management Service. January 1983.

                                                     3-30

                   pe trolcum pipeline. External corrosion from the sea, damage
                   from equipment such as ship anchors or fishing nets, defective
                   pipe seams, and human error are the most common causes of

                   pipeline oil spills-.

                        Alternatives for managing an oil spill after it   occurs

                   are to try to burn the spilled oil, allow it to sink  or add

                   chemicals to cause thb oil to sink; booms and other devices
                   to contain the oil spill, manually remo ve it and allow' the

                   spilled oil to remain. If a spill occurs far from shore and
                   if the sea state is harsh enough.a spill may disperse and be
                   subject to biodegradation before it can impact marine or

                   estuarine habitats and wildlife.

                        Detailed containment and clean up procedures are

                   developed and adopted in the National Oil and Hazardous

                   Substances Pollution Contingency Plan. The oil industry has
                   develope d a special oil spill clean up technology which is
                   effectively applied on an ag needed basis. The oil companies
                   subscribe to Clean Gulf Associates which develops a operation's
                   manual to guide in procuring for use oil spill equipment in

                   the Gulf of Mexico.

                        Each alternative site was evaluated for its potential to
                   be a site for an oil spill. Oil barge terminals have a
                   greater potential to experience an oil spill than any other
                   facility evaluated. If a facility does not service oil no

                   weight was assigned.

                                            3-31

              IX. Evaluation and Assessment of the  Roles of Federal, State,

                   Regional and Local Regulatory and Policy Mechanisms

                        An inventory of pertinent regulatory and policy

                   mechanisms was completed to allow an evaluation of the

                   regulatory.mechanisms with reference to future industry
                   facility siting and any subsequent impacts (see Chapter 6).
                   Some regulatory mecha'nisms have been determined to be compre-

                   hensive,while others are less comprehensive.

              X.   Evaluation of Alternative Sites For Development of Specific

                   Wes t Florida Recommendations

                      ..Each alternative considered was evaluated for consistenby
                   or compatibility with the existing regulatory mechanisms.
                   After an evaluation of the alternative and regulatory mechan-
                   isms was completed the staff developed a list of fifty-two (52)
                   policy and study recommendations intended to be considered and
                   implemented by the appropriate federal, state, local and

                   industry representatives.

             XI.   Conclusions and Final Report Preparation

                        Public and technical input was requested and assembled

                   throughout the entire study process. After the work tasks

                   And assessments were completed th e WFRPC environmental staff

                   summarized the conclusions of the work'and authored this

                   docume nt to record the results of the contracted work.

                                           3-32

                                            CHAPTER 3

                                            Footnotes

                1. Minerals Management Service. Final Regional Environmental
                    Impact Statement, Gulf of Mexico. January 1983.

                2.  Ibid.

                3.  Ibid.

                4.  Ibid.

                5.  Ibid.

                6.  Ibid.

                7.  Ibid.

                8   Ibid.

                                               3-33

                                          .CHAPTER 4

                            OIL AND NATURAL GAS INDUSTRY NEEDS,

                                  ALTERNATIVES,.AND IMPACTS

                                          CHAPTER 4

                              OIL AND NATURAL GAS INDUSTRY NEEDS,

                                  ALTERNATIVES, AND IMPACTS

                    The onshore industry facility needs for OCS development are
               dependent on the scale and timing of offshore activity. The
               volume of a resource find, the character  of the resource dis-

               covered, distance from existing industry  facilities, local social
               and economic conditions, legal controls,  existing land use, and

               characteristi cs of the land and marine environmentalists all
               combine to dictate what type of onshore development the industry
               will locate in West Florida. The time frame for any onshore
               development activity is flexible and can be changed or modified

               as the other listed factors become more defined.

                    The following summary approach is offered to provid e a

               general description of what types of facilitie*s could be antici-

               pated if different volumes of resources are discovered (see
               Table 4-1). No single combination of facilities is necessarily
               a description of what will happen in West Florida. However,
               this summary approach does provide a'basic de'scription of what
               facilities the oil and natural gas industry employs and, therefore,
               provides insight into what impacts can be anticipated.

                    Detailed descriptions of the facilities which are most
               likely to be located in West Florida are offered in Chapter 5.

                    QCS operations and associated onshore activities and
               facilities occur in six (6) phases. Each phase is characterized
               by specific requirements and activities. The six (6) phases are

                                           4-1

                                                                                                             TABLE 4-1

                                                          Summary of General Oil Industry onshore Facility Needs

                                                                                         Waterfront            Dock Space            Capital Cost              Construction             Operations Locating
                        Type of Facility                          Land Needed              Access            (Approximate)            (Approximate)                   Jobs                    Jobs            In West
                                                                                                               -                                               (Approx4--te)           (Approximate) 1.7lorida
                Temporary Support Base                                   2-10                                                                                                                                  ver-,,
                                                                       acres                   v es         100-200 feet               $150,000                       20-90                30-60              like-y
                Permanent Support Base                              less than                                                          $150,000-
                                                                    50 acres                   yes          100-200 feet               $1 million                     20@90                30-60              1-ik e I Y
                Supply Boats                                                                                                           $3.5-$4.25                                                              very
                                                                  dock space                   yes             200 feet                 million                       50-80                    14             like-y
                Crew Boats                                                                                                                                                                                     very
                                                                  dock space                   yes             100 feet                $850,000                       20-25                     8             likely
                Drilling Mud         Company                             1-2                                                                                                                                   ver-,,,
                                                                       acres              variable             variable                     I.I.*                      1.1.*                  5-10          unlikely
                Wellhead EVipment Company                                11-2                                                                                                                                  very
                                                                       acres              preferred            variable                     1.1.*                     20-100               10-100           unlikely
                Platform Fabrication Yard                             200-800                                                                                                                                  very
                                                                       acres                   yes             variable                     I.I.                       1.1.*              200-500           unlikeiv
                Platform Installation
                   Service Base                                                    same as permanentsupport                   base                                    15-30              variable           possi---le
                Cement Company                                            1
                                                                         acre             preferred            variable                     I*.I.*                     I.I.*               I.I.*            unlikely
                Pipeline Corridor                                 100 feet       wide                                                  $600,-000-$9.3                 15-25
                                                                       access                    no                   0                     rnilliQp               variable              variable             likely
                                                                                                                                            Der mile
                Temporary Pipe CoatingYard                          _10-20
                                                                       acres              preferred            variable                $1   million                    1.1.*               10-50            possi:--le
                Gas Processing/Treatment                               20-60                                                           $25-$100
                   Plant                                               acres              -no                                           million                      300-500               30-60              likely
                Gas Compressor and                                  less than                                                          $146,000-
                   metering Facility                                 1 acre                      no                                  $18 million                       I.I.*               I.I.*              like--y
                Oil Storage/Barge Facility                             10-50
                                                                       acres                   yes             variable                    variable                    I.I.*               I.I.*            possi.:-,le
                Marine Terminal                                        15-60                                                           $50-$100                                                                very
                                                                       acres                   yes             variable                 million                      500-800               20-40            unlikely
                Refinery                                          up   to 1,000                                                        $8-$800                                                                 very
                                                                       acres                     no                                     million                 1,500-3,000               400-600           unlikely
                Petrochemical Facilities                                                                                                                                                                       ver-.,
                                                                    variable              variable             variable                    variable               variable.             variable            unlikely

                             insufficient information available.

                identified as:l (see Figure 4-1)

                     1. Pre-Production Phase

                            This phase involves the oil industry"s preliminary
                         evaluation of existing or specifically generated data

                         to predict the potential for hydrocarbons from a

                         geologic formation.

                     2.  Geological and Geophysical Exploration Phase

                            Using the OCS lease schedule and information obtained

                         during pre-exploration the oil industry searches for

                         potential petroleum deposits by analyzing geologic

                         characteristics of the areas proposed for lease sale..

                         Geophysical survey data is collected and an assessment

                         of the potential for petroleum is conducted.

                     3.  Exploratory Drilling Phase
                            Exploratory drilling occurs after seismic data has been

                         evaluated and the oil  company te chnicians have located

                        .areas of potential for oil and/or natural gas in the

                         lease blocks leased by the company. The exploratory

                         drilling phase is the first phase that requires invest-

                         ments for OCS offshore and onshore facilities. The oil

                         company employs an exploratory drilling rig in the OCS

                         and a support or service base is located onshore for

                         the rig(s).

                     4.  Field DeveloRment Phase
                            Field development involves additional drilling by the

                         oil companies to-determine the limits of the field or

                         formation containing the resource. Construction of

                                             4-3

             ion                         M M M M M M M M M'M

                                                                Figure 4-1

                                                          Phases of OCS Activity

                         U.
                         E-

                         CL

                         >

                         t7

                         U.                        Development Phase
                         C -
                         C

                         C

                         U.
                         E-                                                 Procluct.
                                                                                   'on
                                                                                       Phase
                                    Exploration Phase

                                                                                                                Shutdown
                                              P e-Pr du tion an Geological Exploration Phases

                                     5          10          15          20         25         30         35          40

                                            Lease
                                            Sale                            YEARS

                       production platforms to extract the oil and/or natural

                       gas occurs during this phase. Extensive onshore

                       facilities are required to fabricate and service the
                       production platforms. The greatest amount of offshore
                       activity, and,therefore, the greatest potential for
                       onshore impacts is during the development phase.

                   5. Production Phase'

                          The production or extraction of hydrocarbons can last
                       for ten (10) to forty (40) years.. The average field
                       life is between twenty (20) and thirty (30) years.
                       During this phase the industry uses its production
                       platforms to capture or recover the hydrocarbons. It
                       is during this phase that OCS pipelines are developed
                       to transport the recovered resource to the onshore

                       treatment or refinery facilities.

                   6.  Shutdown Phase

                          After the industry has exhausted all techniques to
                       capture as much resource from a field as possible, the
                       established facilities are dismantled and removed to
                       other sites for continued use or decommissioned.

              I.   General Scenario of OCS Onshore Activity
                   The following description is based on the oil industry's
              trends and past accomplishments. The facilities referenced in
              this general description are characteristic of a commercially
              successful find. A low or moderate volume resource discovery
              would not involve the expensive and complex facilities and

                                           4-5

               associated impacts summarized below:

               A.   Pre-Exploration Phase

                       The facilities needed-by the oil industry'during pre-

                    exploration are only the office facilities that the

                    company maintains for analyzing data and decision making.

                    No permanent facilities are needed in the OCS on onshore

                    from the frontier area that is being-examined.

               B.   Geological and Geophysical Exploration Phase

                       As during pre-exploration, onshore activity is generally

                    minimal. A docking service facility to maintain exploration

                    vessels is the only new facility needed during this phase..

                    Seldom is a new or permanent facility constructed to

                    service seismic exploration activities. Representatives

                    of the oil industry and of the U.S. Department of the

                    Interior, Minerals Management Service discuss and negotiate

                    OCS lease activity during this phase. Bids are offered,

                    leases are purchased and permits are completed during this

                    phase.

               C.   Exploratory Drilling Phase

                       The exploratory drilling phase requires the first siting

                    and development of offshore and onshore facilities to support

                    the industry's exploration activities.

                    1. Exploratory Drilling Rig

                           Depending on the depth to the bottom of the OCS and the

                        sea state different types of drilling rigs are used to

                        search for hydrocbirbon reserves. The rigs used for

                        exploratory drilling are constructed onshore and floated

                                             4-6

                        or towed to the site for drilling in the OCS.  Mobiliza-
                        tion, positioning, and support requirements are important
                        considerations to the oil company when selecting what type
                        of drilling rig to employ. The most common rigs used are:

                                        1.  jackup rig

                                       .2. semisubmersible rig

                                        3. self propelled rig

                                        4. drillship
                          Jackup rigs are platforms with legs that can be moved up
                        and down. These rigs have drilled in water depths up to

                        350 feet and are commonly used in the OCS.

                           Semisubmersibles are mobile rigs that are towed or
                        self-propelled to a drill site and then stabilized in the
                        water by partial flooding of p<)ntoons and moved by seabed
                        anchors or by dynamic positioning using motor driven

                        thrusters. The ja ckup and semisubmersible rigs are

                        considered to be most likely for OCS use offshore from

                        West Florida by the oil companies contacted.

                   2.   Temporary Service Base

                          During the exploratory drilling phase a service base or
                        staging area is located. Exploratory drilling activities
                        in the eastern G.ulf of Mexico have been serviced from two
                        (2) different types of base. Some exploratory rigs have

                        been serviced from existing service bases in Louisiana and

                        Mississippi. Other exploratory wells have been serviced
                        from a temporary service base at the Port of Panama City.
                          The initial service base, temporary or permanent, is

                                           4-7

                        designed to support the exploratory drilling rig during
                        .its work. The main function of the service base is to

                        serve as a transfer point or station for materials and
                        crew necessary to install, operate, manage, and dismantle

                        an exploratory drilling rig in the OCS.

                          The service base must be located on a waterfront on two

                        (2) to ten (10) acres of land. Th-e base contains service

                        space for a docking facility for the supply boats and

                        crew boats,and for loading and unloading supplies and
                        materials for the drilling rigs. Other space is needed

                        for open storage area;*crew quartets; office space;
                        communications equipment; small warehouse; parking;
                        material processing/handling; and, often, for a helicopter

                        landing area.

                          Auxiliary facilities to support the service base and the

                        exploratory drilling ri:g include a food catering service,
                        equipment repair facilities, and warehousing.

                   3.   Permanent Service Base

                          After a commercial volume has been discovered, the

                        temporary service base may be expanded to serve as a

                        permanent service. Literature estimates of fifty (50)

                        to one hundred (100) acres for a permanent base are
                        inflated when compared to actual industry experience
                        on the Gulf Coast. The type of activity characteristic
                        of the permanent service base, however, the activities.
                        are more intense. During the development and production

                                           4-8

                        phases fifty (50) or sixty (60) wells may be drilled

                        and require servicing. Tons of   materials will need

                        to be handled, stored tind transported to the rigs.

                          Support bases.may be owned (or leased) and operated
                        by the oil company that possesses the OCS lease that
                        is being explored or may be managed -by an independent
                        gen.eral.shore support or oil field service company.

                          Support services for repair and maintenance may be

                        contained at the support base or@at a separate yard.,
                        General repair service's for vessels may be performed
                        at the service base, but major repairs would be likely
                        to be performed by a contracted repair service. Local

                        repair and maintenance work is one way that local
                        industries and employment may be involved in OCS support.

                        There are adequate repair and maintenance facilities
                        within the OCS study planning area to support potential

                        industry needs.

                           Other ancillary or general OCS support services that
                        may be supplied through the service base vary with the
                        phase of-OCS activity. During the exploration and
                        development phases drilling mud supplies are distributed
                        through the support base. Logging and perforating
                        companies for testing well tailings and drilling progress
                        are also conducte.d through the support base. Cement
                        supplies, wellhead equipment and any other activity
                        needed on an OCS rig or platform may pass through the

                                            4-9

                         support base.

                           A detailed explanation of potential service base
                         impacts in West FloricTa is offered in Chapte  r 5.

                     4. Supply  Boats

                           supply boats  a.re the vessels used to transport equipment
                         from the service base to the exploratory drilling rig.
                         These boats are the primary support mechanism for a rig.
                         Supply boats differ in size but most have drafts of less
                         than fifteen (15) feet. The dock space required for a
                         supply boat is dependent on the size of supply boat that
                         is being used. The average length for a supply boat is

                         two hundred (200) feet, therefore, a minimum of two

                         hundred (200) feet of dock space is needed.

                           The most common drilling supplies that are carried to
                         the'rigs during the life of an exploratory well are:2

                                 a. drilling muds          642 tons

                                 b. cement                 315 tons

                                 C. tubular steel pipe     455 tons

                                 d. diesel fuel          3,318 barrels

                                 e. fresh water           1.19 million gallons
                           Other supplies carried by supply boats include drilling
                         tools.and equipment, wellhead equipment, blowout pre-
                         venters, rental tools, offshore food, and housekeeping
                         supplies.

                          Depqnding upon the amount of exploration activity, the

                                            4-10

                        number of supply boats will vary, however, there are

                        usually two (2) supply boats per OCS drilling rig.

                    5. Crew Boats

                          Crew boats are the boats that transport personnel from

                        the service base to the OCS rigs and back. The crew

                        boats are crewed*twenty-four (24) hours a day and are
                        use.d on.an as needed basis. These-boats are generally

                        one hundred (100) feet long and require five (5) feet

                        of draft. Crew boats may be operated from the same

                        dock space as the supply boats or may operate from a

                        separate docking facility.

                    6.  Catering Services

                          Catering companies supply food and general housekeeping
                        services to offshore facilities. A catering service may
                        operate from one (1) central onshore facility that
                        services an offshore area or may be operated from various

                        separate local supply centers. Catering services that
                        service the Port of Panama City or the Port of Pensacola
                        may be able to provide OCS service. The catered supplies
                        could be delivered to the support base for transportation

                        to the OCS rig on an as needed basis.

                         Initially a new onshore catering service facility may not
                        be located in West Florida. Catering may be contracted
                        with local food duppliers. The type and magnitude of

                        catering service required is dependent on the volume of

                                            4-11

                        resource discovered.

                    7.  Helicopter Companies

                          Helicopters are used to transport crews,  deliver

                        supplies and provide emergency services to  offshore

                        rigs,and platforms. It is unlikely that a   local

                        helicopter compahy would be contracted for  helicopter

                        services due to the highly specialized service

                        required. Specilized helicopter service would be

                        supplied by a offshore operator experienced in OCS

                        activities. It is likely that one (1) helicopter

                       ..could be located in Region I if the resource find was

                        substantial enough. The helicopter company could

                        expand or relocate to service any OCS activity offshore

                        from West Florida.

                          As previously mentioned, a support base could include

                        a helicopter landing area. If needs for helicopter

                        service cannot be met at the service base a new facility

                        could be constructed. Such a helicopter facility would

                        require a landing area, a radio or communications tower,

                        repair and fuel storage area, office/communications

                        structure and parking area for employees and visitors.

                        A landing area for a helicopter requires one (1) acre

                        or less of land. The amount of land necessary to

                        ensure a clear flight path free from obstructions would

                        determine the amc;unt of land necessary for a helicopter

                        service area.

                                             4-12

                          Employees for helicopLer service would be supplied
                        by the helicopter service company and may range in
                        number from two (2) to twenty (20) depending on the
                        number of helicopters and the level of service needed..

                    8. Drilling Mud Companies

                          These companies supply drilling fluids to drilling

                        contractors. The facilities neede d to produce the
                        drilling fluids consist of office/sales space,
                        laboratory and mixing and storage space. Generally
                        on e (1) or two (2) warehouses are sufficient for the

                      ..drilling mud companies.

                          It is unlikely that a new drilling mud company
                        will locate in West Florida. Drilling fluids may be

                        transported to the support service base and then

                        transferred to supply boats for shipment to the OCS
                        rigs. It is not likely that drilling mud companie s
                        will employ local, West Florida workers.

                   9. Wellhead Equipment Companies
                          These companies produce the equipment used'to control

                        and operate the wells during drilling and production.
                        The facilities that manufacture wellhead equipment do
                        not need to be located onshore from the OCS activity.
                        If a substantial find is made, wellhead drilling
                        companies may loc'ate a regional sales office or a
                        temporary facility to assist-installation of equipment

                                           4-13

                        at the support base established by the OCS lease owner.
                        If a separate facility is located it will require office

                        space and storage space on one (1) acre of land. Ware-
                        house space may be needed if on-site storage of equipment
                        is necessary. Between two (2) and one hundred (100)
                        people could be employed at a wellhead equipment facility
                        depending on the-level of OCS drilling activity and
                        the. facility is prepared to perform maintenance service.

              D. Field Development Phase

                    As oil and/or natural  gas reserves are discovered, additional
                  OCS support services need to be supplied from onshore. The
                  services may be supplied from existing onshore facilities in
                  Louisiana, Mississippi and Texas or new facilities may be
                  constructed closer to the OCS resource discovery.

                  1. Perm anent Service Base

                        .The permanent service -base (discussed in Section C.3 above)
                      may be established during the exploration phase or during
                      the field development phase. It is likely that a temporary
                      service base will become the permanent service base if

                      there is adequate space to accomodate the.increased
                      activity which will occur as more levels are drilled to

                      define the resource find.

                  2.  Platform Fabrication Yards

                        Platform fabrication yards are large, waterfront facil'ities
                      consisting of warebouses, buildings and cleared land used
                      to construct the OCS platforms to support resource develop-

                                           4-14

                        ment and recovery activities. A platform yard does not

                        have to be sited onshore from the OCS lease area. It is
                        unlikely that the industry would spend the money to
                        develop a fabrication yard in Region I because unused
                       ..platforms are currently available and because platform
                        fabrication yards are already located in the Gulf Coast.

                        There are four     platform fabrication facilities in

                        Mis,sissip pi, nineteen (19) in Loui siana, and ten (10)  in
                        Texas.3

                          There are two (2) types of platforms-used in the OCS:
                        steel and concrete. The type of platform employed
                        depends on the field being developed, the mix of oil

                        and gas, sea condition, OCS bottom conditions and

                        number of wells to be drilled. Platforms are composed
                        of a superstructure called the jacket, and deck for
                        drilling operations. OCS- platform fabrication companies
                        have never located a new yard in a frontier area unless

                        a significant hydrocarbon discovery has been made.
                        Platform fabrication yards have the highest impact on
                        the economy and environment of any onshore facility
                        during the development phase.

                         Platform or platform sections'can easily be fabricated

                        at existing yards along the Gulf of Mexico and towed
                        from these yards to sites offshore from West Florida..
                        it is assumed that there will be no impacts in West
                        Florida from platform fabrication yards.

                                            4-15

                          I.Oor zi platloriii br@icoti-oii yard to locato thero are

                        certain requirements which must be met. Between 200

                        to 1,000 acres of land adjacent to navigable water
                        accompanied by a skilled labor force, transportation
                        access, and energy supply are needed. The required

                        water depth varies between 15 feet to 30 feet.

                          The impacts of a fabrication yard incl ude increased

                        employment, increased tax base, increased service

                        requirements, increased utility requirements, increased

                        raw material sales, increased water supply demand,
                        increased sewage efflue'nt loading, increased solid

                        waste disposal, increased stormwater runoff, increased

                        potential for dredging, increased potential for fuel

                        spills and displacement of fish and wildlife.

                   3.   Platform Installation Service Base

                         If new deep water platforms are needed they may be towed
                        and assembled on the OCS site. After a platform has been

                        .completed and towed to the OCS offshore site, one (1) or
                        two (2) derrick barges are required to lift, position,
                        and for the deck modules into the jacket. A temporary
                        service base may be needed while the platform is being
                        assembled. If such a service facility is needed  it is
                        likely that the service base established during the
                        exploration phase would be adequate.

                         Due to the conditions in the Gulf of Mexicooffshore from
                        West Florida and due to the availability of platforms in

                                              4-16

                       Texas and Louisiana it is assumed that field development

                       platforms will have very little impact in West Florida's

                       economy.

                   4.  Cement Companies

                         Cement companies provide highly specialized services for

                       OCS offshore operations. The cement companies produce

                       and supply bulk cement and additives and blends them in

                       proper proportions. Because the requirements for OCS

                       cementing operations are highly specialized the oil

                       cc mpanies and drilling,contractors purchase needed

                      ,.cement supplies from proven companies.

                         It is unlikely that a new cement fabrication facility

                       will locate in West Florida. A cement distribution

                       center may be located at the OCS support base or at an

                       adjacent site. The distribution center requires water-

                       front access and approximately one (1) acre of land or

                       less to store the product before shipment to the OCS

                       rigs or platforms. The only local employment that may

                       be derived from cement distribution is local manual

                       labor to load or unload the cement products.

                   5.  Pipelines

                         Marine/submarine pipelines are the primary transPortation
                       mechanism used to conduct OCS hydrocarbon resources to

                       onshore facilities. Pipelines connect the OCS platforms

                       to onshore facilities. The distance between an OCS

                                           4-17

                        platform and landfall site is generally the shortest

                        distance due to the high cost of constructing a

                        submarine pipeline. The decision to construct a

                        pipeline is influenced by the estimated volume of a

                        resource discovery, the rate of production, distance
                        from'the OCS site to onshore facilities, water depth,

                        bottom topography, type of OCS resource discovered and

                        the value of the resource found. In the Gulf of Mexico

                        most of the oil that has been produced has been brought

                        to shore by submarine pipeline. Virtually, all OCS

                        natural gas has been briought to onshore facilities by

                        submarine pipeline.

                          A pipeline system may include a pressure source, gathering

                        pipelines from scattered OCS production platforms, major

                        trunk lines, pressurebooster stations and a onshore

                        landfall connection to onshore pipeline.

                          The laying of a su bmarine pipeline is a technical

                        accomplishment and requires special techniques. The

                        pipeline is constructed using a "lay barge" supported

                        by pipe suppl y boats, tug boats and a bury or "jet" barge

                        which trenches and covers the pipeline on the bottom of

                        the OCS.

                          There are several different methods for installing  an

                        OCS pipeline. Commonly, the lay barge is used to weld

                        sections of pipe together and release the welded pipeline

                                           4-18

                        into the water. The pipeline is allowed to rest on the

                        bottom or is buried in a trench to prevent damage.

                          A second technique u-ses a reel barge. Long sections

                        of welded pipe are wound onto a large reel placed on a
                        reel barge and the pipeline is installed by unrolling
                        the pipeline from the reel and placing it on the,ocean

                        floor.

                          A third installation technique is to pull pipe assembled

                        onshore short distances from the.onshore facility using

                        pu 11 boats. This mechanism is not considered feasible

                       Jor laying a pipeline from the OCS of the eastern Gulf

                        of Mexico.

                          The possibility of a pipeline landfalling in West Florida

                        is likely if a resource find is made offshore from West

                        Florida.

                          During installatio n of a pipeline the industry must

                        locate a base to support the lay barge and other associated
                        vessels. Space is needed to service the lay barge, tug
                        boats, cargo barges and the jet or bury barge. It is
                        likely that the service base established by the oil

                        company during the exploration phase may be used to

                        support the pipeline installation activities.

                          The impacts from pipeline installation in West Florida
                        depend on pipelin& landfall and distance for the pipeline
                        to connect to a transmission.line or oil barge terminal.

                                           4-19

                        If a pipeline landfalls in Region I local jobs, goods
                        and services will be needed during the time of construc-
                        tion. The environment will be disturbed during
                        construction, but only in the pipeline corridor. The
                       ..degree of disturbance and any degradation of water quality
                        will.depend on the techniques used to install the pipeline.
                        If the pipeline is layed across th e coastline using a
                        dredge barge the potential for environmental degradation
                        is higher than if the beach is crossed using a horizontal
                        drilling procedure to drill.under the beach and install
                        th e pipeline by pulling it through the drilled hole.

                       -Increased turbidity, temporary destruction of wildlife
                        habitats, increased potential for spill of hazardous
                        materials (e.g., oil) are the major environmental concerns
                        generated by a pipeline landfall. After installation of
                        the pipeline and restoration of the corridor the impacts
                        of an OCS pipeline are minimized unless a blow out or
                        other catastrophe oc curs to the pipeline.

                         A detailed analysis of potential pipeline impacts in
                        West Florida is offered in Chapter.5.

                   6. Pipe Coating Yards
                         A pipe coating 'yard is a large facility designed to store
                        4nd prepare steel pipe for use in a submarine pipeline
                        The pipe is prepared for underwater use by applications
                        of concrete and as'phalt sealers for corrosion proofing

                                           4-20

                        the pipe and to help sink it during installation.

                          A pipe coating'yard is located in a frontier area,

                        such as West Florida, -only after contracts-are signed

                        and if a@large amount of activity is indicated. The

                        yard is only needed for a short period of time and is

                        only*used for on e season when coated pipe is needed.

                          It is.unlikely that a pipe coati ng yard will be located

                        in West Florida unless several pipelines are to be

                        installed. A temporary or portable facility may move

                        to this area for the duration of a season, or until a

                        particular pipeline is installed. Factors that determine

                        if a pipe coating yard will be established include: the

                        distance between the production platform and existing
                        pipe coating facilities; ability of existing yards to

                        mee t delivery schedules; expected quantity of work;

                        whether subsequent lease sales are made and if these

                        sales may also be se rved by a newly established facility;

                        and access to steel pipe and raw material sources. A

                        portable pipe coating facility requires between ten (10)

                        and thirty (30) acres on a waterfront with access to

                        overland transportation. If a significant discovery is
                        made the temporary facility can be made permanent. A
                        permanent pipe coating facility will be established only
                        when a long term contract or possiblility for large scale
                        business is determined. Pipe coating yards presently

                        located on the Gulf Coast vary from 75 acres to 200 acres

                                           4-21

                        in size. Existing pipe coating facilities include

                        administrative offices, pipe cleaning buildings, pipe

                        coating areas, cleared, open storage space, storage

                        buildings, rail terminal, marine terminal, and mainten-

                        ance facilities. It would be possible for coated pipe

                        to be shipped to West Florida from these existing

                        facilities rathet than locate a pipe coating yard in

                        Region I.

                          If a pipe coating facility is located in West Florida

                        most of the employees will be hired locally and trained

                        on-site. However, employment for this type of work is

                        generally temporary. It is customary for a pipe coating

                        company to relocate supervisory personnel to a temporary

                        pipe coating facility.

                          The environment adjacent to a pipe coating yard is

                        impacted by dust, stormwater runoff, and maintenance

                        dredging activity.  If a new facility is established

                        a large area of land will be needed and therefore an

                        increased potential for loss of fish and wildlife habitat.

                    7.  Gas Processing/Treatment Plants

                          Gas treatment facilities resemble gasoline refineries

                        are designed to removed impurities, valuable liquefiable

                        hydrocarbons such as butane and propane and other con-.

                        stituents from the raw natural gas stream. The gas

                        treatment plant removes all extra compounds before the

                                            4-22

                        gas en ters the gas transmission system. Although

                        industry representatives state that there are no

                        standard sizes or formats for gas treatment plants,

                        these facilities usually are located on fifty (50)

                       ..acres.or less. A gas treatment plant is designed and

                        operates for the life of production of an OCS find.

                          It is possible to construct the -gas treatment plant

                        on a platform in the OCS, however, such an action is

                        cost intensive. Also, there is available technology

                        to liquify natural gas using extremely-low temperatures

                        and then tanker the liquified gas to an onshore facility,

                        however, this process is prohibitively expensive and

                        hazardous.

                          The decision to locate a gas treatment plant is made

                        after the characteristics of the natural gas found are

                        identified. Factors that affect the siting of a gas

                        treatment facility are: size and quality of the find,

                        location of pipeline, location of pipeline landfall,

                        distance and location of a commercial transmission lines

                        and relationship to petrochemical development.

                          A gas treatment plant will contain refrigeration units,

                        compressors, powiz!r generators, contact towers, storage

                        tanks, flare stacks, control center, and sulfur recovery^

                        components.

                         Partial processing of the gas stream generally is performed

                                            4-23

                        on the OCS production platform. Water is removed from

                        the natural gas stream before it enters the pipeline.

                        Partial processing facilities may be located onshore

                        tather than on the offshore production platform.

                          During construction of a gas treatment facility as many
                        as 25'0-500 workers may be employed for approximately one

                        and one-half years. After construction approximately

                        35-50 employees will be needed.

                          Gas treatment facilities do not. need to be located on a

                        wa terfront and may be located up to ten (10) miles inland

                       ..from. the point of pipeline landfall. These facilities '

                        are noisy (80-100 decibels twenty-four hours a day, every

                        day) and generate air, water and solid wastedischarges.

                        The air emissions include hydrogen sulfide, sulfur dioxide,

                        various hydrocarbons, particulates, carbon monoxide and

                        nitrogen oxides. Wastewater may contain dissolved hydro-

                        carbons, acids and various heavy metal wastes.   Solid

                       .wastes generated include sludges, spent dessicants,

                        filttation media and oil absorbants.

                    8. Natural Gas Compressor and Metering Facilities

                          If natural gas is discovered offshore it must be metered

                        or measured to determine volume, flow rate etc., and

                        may need to be compressed to transport it in the OCS

                        submarine pipeline.

                          Two (2) metering facilities will be needed if natural gas

                                            4-24

                        is discovered.  One (1) metering facility will be
                        installed at the.OCS production platform and a second
                        along the onshore pipeline. The metering will record
                        the volume of gas produced and help determine if there

                        are any leaks in the OCS pipeline or onshore transmission

                        pipeline.

                          A compressor facility may be needed at the OCS production
                        platform if the natural gas being produced isn't under
                        sufficient pressure to move through the OCS pipeline.
                        A second compressor facility may be located at the gas
                        treatment facility or at the point of interconnection

                        between the OCS pipeline and onshore gas transmission

                        pipeline.

                         A more detailed discussion of natural gas compressor
                        and metering facilities is presented in Chapter 5.

                   9. Oil Storage/Marine Terminal

                          Some type of marine terminal is required whenever water-
                        borne shipments of crude oil are made. These facilities

                        may range in service from a small oil barge terminal to
                        a large deepwater port servicing "supertankers". Oil

                        storage terminals are generally sited on waterfront

                        property to minimize pipeline. distance. The decision

                        to site a marine terminal is made at the time that

                        production and transportation strategies are formulated.

                        If the oil discovered is in insufficient volume to

                                            4-25

                        justify a pipeline the product may be loaded directly

                        onto barges or tankers and transported to onshore

                        facilities6 If a minor oil find is made it is unlikely

                        that anything larger than an oil barge terminal will be

                        located in West.Florida.

                          A highly productive oil field less than 150 miles from

                        shore would very likely justify the construction of a

                        full marine terminal.

                          A full marine terminal.will contain large storage tanks

                        on approximately thirty (30) acres of waterfront land.

                        A depth of forty (40) to fifty (50) feet or mooring buoy

                        is needed to accomodate large tankers to service the

                        terminal. A terminal could also include equipment for

                        pumping and cooling equipment, pipelines and management

                        offices.

                        Different types of oil terminals include:

                        a.  Crude Oil Receiving/Storage Terminals   These

                            facilities are designed to receive crude oil from

                            OCS platforms by pipeline or by tanker. Often these

                            terminals are built near oil refineries to hold or

                            store crude oil until it isprocessed. The crude

                            oil is received, metered, evaluated and-stored.

                            These tank farms act to hold the crude oil before

                            it is processed or loaded onto tankers to be trans-

                            ported to othler facilities.

                                           4-26

                         b. Transshipment Terminals - A transshipment terminal

                             receives crude oil by pipeline from offshore platforms

                             and loads the crude oil onto tankers for processing

                             elsewhere.

                         C.  Product Terminals     These facilities receive refined

                             petroleum products by barge or tanker for storage

                             and subsequent delivery to regional or local markets.

                             Product terminals do not have a direct contact with OCS

                             activities. Several small product terminals exist

                             in West Florida; Pensacola, Freeport,'Eglin Air Force

                             Base and Panama City.

                            If a full marine terminal is located a large number of

                         jobs will be created for construction workers. The number

                         of jobs depends on the size of facility to be constructed.

                         To construct a facility to accomodate 250,000 barrels of

                         oil per day would require between 500 and 600 workers.

                         Many of the construction jobs could be offered to local

                         workers. However, a simple oil barge terminal is more

                         likely than a full marine terminal, therefore, fewer jobs
                         will be created to modify or expand existing storage

                         facilities.

                           Potential environmental impact  s may be produced by increas-
                         ed oil tanker and barge traffic; maintenance dredging; crude
                         oil or processed petroleum transfers; collision, spill,
                         fire or hurricane'hazards. The need for adequatechannels

                                              4-27

                        and turning basins at oil storage facilities may generate

                        increased dredging problems and subsequent turbidity.

                        Dikes will be required around a oil storage facility to

                        serve to minimize oil spill and flooding impacts.

                   10.  Refineries and Petrochemical Facilities

                        a. Oil Refinery

                            A modern crude oil refinery consists of a series of

                        processing units to chemically or physically process or

                        refine the crude oil into more useful petroleum products,

                        e.g.,, gasoline, fuel oil, and jet fuel. (se*eTable 4-2).

                        The size and type of facility to be located depends upon

                        the type and volume of crude oil to be refined. As the

                        percent of gasoline produced increases so does the com-

                        plexity of the refinery.

                            The actual crude oil refining process takes place by

                        fractionation or distilIation. A refinery includes

                        processing units, storage tanks, water treatment

                        facilities, offices, machine ship, storage space and

                        warehouse, electrical substation, fire equipment, pumping

                        station., truck loading areas, pipelines, rail spurs,

                        parking areas and a buffer area around the facility.

                            Oil refineries are generally located by market demand

                        rather than by proximity to OCS production area. Offshore

                        development does not dictate the site for a refinery.

                        Due.to the limited chance of discovery of oil offshore

                                            4-28

                                             TABLE 4-2

                      Average Yield From One (1) Barrel of Crude Oil

                         Product              Gallons/Barrel          % Yield

                Gasoline                             19.28               45.9

                Jet Fuel                             2.86                6.8

                Ethane                               0.04                0.1

                Liquified Gases                                          2.6

                Kerosene                             0.55                1.3

                Distillate Fuel Oil                  9.16                21.8

                Residual Fuel Oil                    3.65                8.7

                Petrochemical Feedstocks             1.26                3.0

                Special Naphthas                     0.34                2.8

                Lubricants                           0.67                1.6

                Wax                                  0.08                0.2

                Coke                                 1.18                2.8

                Asphalt                              1.55                3.7

                Road Oil                             0.08                0.2

                Still Gas                            1.64                3.9

                Miscellaneous                        0.21                0.5

                Processing Shortage                  -1.64              -3.9

                                          TOTALS    42.0              .100.0

                SOURCE: American Petroleum Institute.. 1974.

                                              4-29

                        from West Florida and the existing refineries west of

                        this region on the Gulf coast, it is unlikely that a

                        refinery or other petrochemica  1 facilitiy will locate

                        in West Florida., There,are three (3) refineries in

                        Alabama, twenty-five (25) in Louisiana, one (1) in
                        Mississippi and thirty-seven (37) in Texas-4

                        Refineries are g6nerally separated from other OCS
                        rel.ated-facilities and tend to be -sited in areas that

                        are acceptable to public opinion and away from environ-

                        mentally sensitive areas.

                             The capital cost to construct a-refinery can range

                        from eight (8) to eight hundred (800) million dollars.

                        A small portable facility may cost much less. During
                        construction between 1,500 and 3,000 jobs may be generated

                        to complete a refinery that canprocess 200,000 barrels

                        per day. Aft  er completion approximately 500-600 jobs are

                        created. Approximately ten percent (10%) are administra-
                        tive jobs and eighty percent (80%).involve operation and

                        maintenance jobs require skilled labor. Refineries

                        located on the Gulf coast have'annual payrolls averaging

                        approximately seven (7) million dollars.

                            if a refinery was to locate in West Florida a potable
                        water quantity problem could occur. Refineries require
                        large volumes of water to operate. Also, a refinery

                        generates air emissions that may degrade ambient air
                        quality. Anticipated air emissions include hydrocarbons,

                                            4-30

                        carbon monoxide, particulates, sulfur oxides, and.nitrogen

                        oxides.

                            Refineries are noisy and can generate between 90 and

                        100 decibels every  day of the year.

                            Wastewater impacts  may result from discharges of

                        metal fragments, hydrocarbons, particulates, alkaline

                        substances, and process chemicals.

                            Other environmental impacts that may be anticipated

                        if a refinery is located in West Florida include loss of

                        fish and wildlife habitat due to land clearing, thermal

                        pollution from cooling operations and aesthetic problems.

                        b. Other Petrochemical Facilities

                            These facilities are designed to manufacture chemicals

                        or products from refined petroleum products and natural

                        gas.. Two (2) basic petrochemical products are made;

                        ar omatics and olefins. The final yield of the petro-

                        chemical operations.include such substances as plastics,

                        paints, dyes, resins, fibers, textiles and rubber.

                            Petrochemical facilities can be as large as 400 acres

                        for large complexes or small for specialized products.

                        These facilities are costly, employ large numbers of

                        workers, have high energy use demands, many require large

                        amounts of water-and most generate air emissions.

                            As with a refinery, petrochemical facilities do not

                        directly connect with OCS activities and,therefore, do

                        not need to be located onshore from a OCS discovery.

                            Actual types of petroche.mical'pro duct determine what

                                            4-31

                       types of impacts will be generated. Some petrochemical

                       products are seen as "dirty" because hazardous substances

                       may be used or generated during processing. Large petro-

                       chemical complexes require detailed federal, state and

                       local permits for location, construction and operation.

                       Due to the limited oil and natural gas find anticipated

                       in the OCS offshore from West Florida it is highly unlikely

                       that any petrochemical facilities-will be located in

                       Florida Planning Region I.

                           As previously mentioned, adescription of the facilities

                       which are more likely to be located within the study area

                       considered in this document are offered in Chapter 5.

                                          4-32

                                         CHAPTER 4

                                         Footnotes

               1.  Tampa Bay Regional Planning Council. Coastal Energy  Facilit ies
                   Siting Study. December 1982.

               2.  New England River Bas*ins Commission. onshore Facilities Related
                   To Offshore Oil and Gas Development. November 1976.

               3.  Minerals Management Service. Gulf Of Mexico Summary Report 3.
                   August 1982.

               4.  Minerals Management Service. Gulf of Mexico Summary Report 3.
                   August 1982.

                                           4-33

                                         CHAPTER 5

                            POTENTIAL OCS ONSHORE FACILITIES

                              SITES AND ANTICIPATED IMPACTS

                                          CHAPTER 5

                             POTENTIAL OCS ONSHORE FACILITIES
                               SITES AND ANTICIPATED IMPACTS

                     In the event of a gas or oil discovery on the  Outer

                Continental Shelf (OCS) south of West Florida, this region could

                expect a range from "no impact" to the limited impacts of five
                (5) types of petroleum industry facilities. According to
                petroleum industry sources, the proximity (Texas a nd Louisiana)

                of a large, permanent oil and gas infrastructure to West Florida
                will prevent any major increase in manufacturing related supplies.
                Because petroleum industry employees work 7 days on - 7 days off,
                or simil,ar schedules, employees and dependents are unlikely to mbve
                into West Florida. Therefore, large scale impacts on schools,
                housing and municipal services will not occur.

                    The "No Impact Scenario" could result from onshore support
                facilities being located in Mobile and Baldwin Counties, South
                Alabama. There currently is active oil and gas production in
                Alabama, onshore and in coastal waters, and the petroleum infra-
                structure (pipelines, storage tanks and gas treatment facilities)
                is being constructed to support onshore and offshore production.
                Fifteen (15) active lease blocks immediately south of Mobile Bay
                and the Mississippi Sound are currently held by oil companies.
                There are only two (2) ac tive leases on the OCS south of West

                Florida. As the petroleum exploration and production infra-
                structure'in Alabama enlarges and spreads toward Florida waters,
                gas and/or oil activities south of West Florida could cost-

                effectively be supported entirely from Alabama.

                                           5-1

                    In the "Limited Impact Scenario", West Florida could re   ceive

               limited impacts from five types of onshore petroleum facilities.

               I.   Identification and Profile of Onshore Support   Facilities

                    The.,five (5) onshore oil and/or natural gas facilities which

               are expected to impact the West Florida region are:

                    1. an onshore supporit base;

                    2.   a pipeline landfall site and pipeline corridor connecting

                         an OCS production platform to an interstate gas trans-

                         mission system;

                    3.   a natural gas treatment facility;

                    4.  ..an oil barge terminal; and

                    5. a natural gas compressor and metering station.

                    These facilities would be expected during the t  hree (3) phases

               of drilling activity; exploration, development, and production.

               Descriptions  of the five  5) facilities have been collated from

               direct responses of oil and natural gas companies operating in or

               near the Gulf of Mexico. Because of the uniqueness of the Gulf,

               requirements for these facilities differ greatly from estimates

               presented in the  New Jersey Energy Facility Development Potential
               Studyland Onshore Facilit Iies Related to Offshore Oil and Gas
               Development - Factbook.2

                    A. Service Base

                             An onshore service base would be the first onshore

                    activity observed. A service base would be established prior
                    to transporting an ex'ploratory drilling rig to a lease site

                                            5-2

                     on the OCS. Factors to be considered when locat   ing an

                     onshore service base are:

                         a.  land availability and surrounding land use;

                         b.  waterfront access  and presence of bulkhead,   dock

                             and navigation channel;

                         C.  access to rail and to road transportation;

                         d.  access to the Gulf of Mexico;

                         e., availability of support servic  es, potable water,

                             fuel and communication facilities; and

                         f.  susceptibility to flooding and hurricane damage.

                         The initial service bas*e, used to support earl y 'explor-

                     atory drilling efforts, may be considered temporary. If

                     wells yield no commercially producible volumes of pe  troleum,

                     the service base may be in use for six (6) to twelve (12)

                     months,.then dismantled when the exploratory well is sealed

                     and the drilling rig is removed from the lease site.

                         The primary need for an onshore service base would be

                     for a location for crew changes, a supply point for food,

                     water, fuel, and small emergency supplies, and a point of

                     local communications. When an exploratory drilling rig is

                     transported to a drilling site from permanent fabrication,

                     launching, and mooring sites in Texas and Louisiana, it
                     usually is already loaded with drill pipe, well casing,
                     drilling muds, casing cement, and equipment required to

                     complete the proposed number of wells. Therefore, an

                     onshore service base'in West Florida will not act as a

                     major supply point.

                                             5-3

                   Characteristics of an onshore service base forexploration are:

                   a.   Land Area - 1.5 to 5 acres can support exploratory drilling
                        for as many as five (5) drilling rigs. The land would be

                        used for a mobile home, to be used as an office,   communica-

                        tions center and housing for the shore-base crew;   a

                        covered warehouse of 1,000-2,000 square feet; open storage;
                        a helipad, unless.an airport is nearby; and a parking lot

                        for -crew.members (35 to 40 persons).

                    b.  Docks - a dock length of 150-300 feet is required for crew

                        boats (90-110 feet each) and.supply barges..

                    c.  Wat er Depth - a navigable channel of 12 to 15 feet depth
                        and about 100 feet in width is required to operate barges,
                        crew boats, and work boats. Crew boats operating in the

                        Gulf are about 100 feet long and have a draft of 5 to 8

                        feet.

                    d.  Access to Gulf - a reliable channel (15 feet deep, 100 feet

                        wide, and does not require constant maintenance) to the

                        Gulf is required for access to the OCS. Distance from the

                        service base to the Gulf is important.

                    e.  Transportation - an onshore service base site would

                        ideally be served by water, rail and road transportation

                        systems.

                    f.  Water - exploratory drilling rigs require about 1,500

                        gallons per day of potable water for the crew and about.

                        12,600 gallons per day of freshwater for drilling and

                        washdown. Some OCS drilling rigs are equipped with
                        desalinators which produce potable water. Drilling  and

                                            5-4'

                        washdown water may be river water or highly treated

                        sewage effluent.

                    g.  Fuel - one (1) OCS drilling rig and a supply boa t require

                        approximately 2,450,000 gallons of diesel fuel per year.

                        Fuel is usually purchased locally and some fuel storage

                        tanks or a fuel,storage barge may be located at the

                        service base.

                    h.  Waste Disposal   crew boats return solid waste to the

                        service base from the rig. A waste contractor hauls

                        wastes to an approved sa nitary landfill site.

                    i.  Support Services - fire protection, security and

                        electricity must be available at a potential service

                        base. Food supplies for crew members will be purchased

                        and transported by the drilling company or by a caterer.

                    j.  Ac-cess to Machinery Parts and Maintenance Services

                        small repairs, replacement parts, and welding may be

                        purchased locally; availability of these services near

                        a service base is beneficial.

                    Little distinction is noticeable between temporary onshore

               service base for exploration and a long-term service base to

               support resource development phase and production phase activities.

               In most cases, a temporary service base may be enlarged to support

               production activities. There will not be a large increase in the

               movement of materials and equipment through West Florida, because

               there will continue to be supplied directly from Texas and

               Louisiana to the OCS site.* For example, Mobil Oil Exploration

               and Producing Southeast, Inc. (MOEPSI) originally established a

                                            5-5

                base of two (2) or three (3) acres to support exploratory
                activities in Mobile Bay,'Alabama. As the result of a large
                gas find, Mobil has proposed to-enlarge the.same site to four
                (4) to six (6) acres to support field development and production
                from five (5) production platforms and twenty (20). wells.

                B. Pipeline Landfall and Onshore Corridor

                   In the e vent of a commercial natural gas or oil discovery
                that meets the minimum resource specifications in the assump-
                tions @(Chapter 2 ), a pipeline must be constructed.from the OCS
                production.platform to an interstate distribution system. For
                this study, one pipeline landfall contain ing one (1), sixteen
                (16) inch pipeline is assumed to occur.

                    A pipeline is the preferred transportation method because
                it is safer,.presents less hazard for spills, and has a lower
                operating cost. Also, the State of Florida has adopted a
                transportation stipulation for OCS oil and gas leases off the
                coast of Florida, requiring product transportation to shore in
                a pipeline, unless a pipeline is not economically feasible.
                    In the unlikely event.of  a commercial oil discovery, the
                discovering oil company (producer) would construct an oil
                pipeline ashore, along with required facilities. In the event
                of a natural gas discovery, the producer usually sells the gas
                to a gas transmission company, at the platform, and the gas
                transmission company would construct a pipeline and associated
                facilities. While some offshore pipeline construction activities

                                            5-6

               may be supported through the onshore service base, most
               materials are expected to,be loaded onto the lay barge i'spread"
               before it departs the permanent pipe fabrication and pipe coating
               yards in Louisiana and Texas. Steel pipe and supplies for the
               onshore pipeline would be.transported by truck directly to the

               pipeline corridor.

                    Many factors are considered by oil and gas companies when
               selecting a.p'ipeline corridor:

                    1. total oil and gas reserves;
                    2. oil and gas composition (gas containing hydrogen
                        sulfide and carbon dioxide is more costly to

                       .-transport since pipe must be thicker and anti-

                        corrosion precautions must be taken);
                    3.  rate of production - determines pipe diameter;
                    4.  distance and route from production site to delivery

                        point;

                    5.  water depth;

                    6.  topography under water and on land;

                    7.  geology and soils;
                    8.  types and number of crossings (estuary and large
                        river crossings are expensive; road, rail, and

                        wetlands crossings add cost);
                    9.  land use within and surrounding proposed ROW
                        (laying pipeline on beachfront and waterfront ROW
                        is expensive because of the high cost of leases and,
                        while laying pipqline through urban areas is possible,
                        cost increases because of additional safety factors);

                                           5-7

                        10. proximity to existing ROW's;

                        11. environmental concerns about estuaries, wetlands, etc.;

                        12. capital cost of pipeline;

                        13. operating costs; and,

                       .14. revenue to be derived from sale of the petroleum

                            resource.

                        Offshore and subm*erged estuarine pipelines cost four (4) to
                    six (6) times as much as an onshore pip eline.3 Because of the

                    high cost of submerged pipelines ($600,000 to $9.3 million

                    per mile), oil and gas companies tend to construct offshore

                    pipeli nes to the closest.lan dfall and avoid crossing,sounds,

                    bays and large rivers. Also, the cost of a pipeline carrying

                    sour gas is considerably higher than the cost of a pipeline

                    carrying commercial gas. Therefore, gas i s usually treated

                    soon after making landfall.

                        When seeking a pipeline-corridor, the pipeline company

                    will seek the shortest acceptable route to an interstate

                    pipeline system. In West Florida, OCS natural gas would be

                    marketed through Five Flags Pipeline Company (a local pipe-

                    line); Florida Gas Transmission Company (an interstate

                    pipeline with major markets east of West Florida), or United

                    Gas Pipeline Company (an interstate pipeline which terminates.

                    in Escambia County, Florida).

                        An existing pipeline can be tapped at any.location,'

                    provided several general conditions are met. The conditions

                    are:

                        l.' The site must be accessible by land for routine

                                           5-8

                           operation and maintenance. The land area at the

                           point of interconnection ranges from virtually no

                           new right-of-way for a meter station and tap to

                           several acres if hydrocarbon liquids are to be

                           removed or if the gas must be compressed before

                           entering the pipeline.

                       2.  The existing transmission pipeline must have capacity

                           available to transport new gas.

                       3.  There must be a market for new gas.

                       The major pipeline systems involved in West Florida are
                    Florida Gas Transmission Co'mpany, United Gas Pipe Line Company

                    and Five Flags Pipe Line Company (see Figure5-1      Florida

                    Gas is currently involved in a project to remove a portion of

                    its existing system from gas service. One (1) of two (2)

                    pipelines will be converted to transport refined petroleum

                    liquids from Baton Ro uge refineries to south Florida. If the

                    remaining pipeline does not have adequate capacity for new

                    natural gas, Florida Gas could apply to the Federal Energy
                    Regulatory Commission (FERC) to divert an equal volume of gas
                    to an interconnecting pipeline west of Florida, thus, creating
                    pipeline capacity to receive new OCS gas in Florida.

                        The easternmost terminus of United Gas' system is located
                    in Escambia County, Florida. Therefore, United could probably

                    only purchase gas found south of Escambia and Santa Rosa

                    Counties. As with Florida Gas, United must also divert an
                    equal volume of gas f@rom its pipeline west of Florida, to

                    create capacity for new gas.

                                           5-9

                        If OCS gas production volumes are large and field

                    reserves indicate a long-term production forecast, then

                    connection to the Southern Natural Gas Company System or

                    to the South Georgia Natural Gas Company system might be

                    cost-feasible. All new major pipeline construction must be

                    approved.by FERC, so that existing pipelines may receive

                    maximum use. Southern Natural Gas.' main system is located

                    135 miles north from the West Florida'coast. South Georgia's

                    system is 40 miles north of St. Marks, Florida; however, it

                    consists of 6 to 10 inch lines,.which may not.be of sufficient

                    diameter to accept new OCS.gas.

                       ..Because Florida Gas Transmission Company's main pipeline

                    traverses the entire West Florida Region, it will be the

                    most likely destination for natural gas found on West Florida's

                    outer'continental shelf.

                        Laying an offshore pipeline begins at the production

                    platform. The lay barge "spread" (lay barge and two (2)

                    support barges) is the surface platform where pipe lengths

                    are welded together; inspected, then lowered to the seafloor.

                    A submarine pipeline ROW is about 200 feet wide.

                        At a water depth of 200 feet, in the Gulf of Mexico,

                    particularly where trawling and shipping activities are high,

                    the pipeline must be buried under the seafloor to prevent
                    fouling and rupture, caused by fishing gear and ship anchors.4

                    From the 200 foot isobath landward to the point of landfall,

                    a pipeline will be buXied. offshore, a dredging barge would

                    precede the point at whic h the pipeline being lowered would

                                           5-11

                    contact the seafloor. A trench would be cut in the bottom,

                    either by hydraulic dredge or by use of a jet sled, which

                    blows a trench in soft bottoms w ith.high-pressure water jets.
                    Aft'er the pipe is lowered into the trench, natural water

                    currents are usually allowed to cover the pipe. Other sub-

                   .marine pipeline laying techniques are in use, but this is

                    the most common method used in the Gulf of Mexico.

                        The.actual landfall may be made by one of two methods.

                    The lay barge will operate as close to land as water depth
                    permits. While final sections Qf the -offshore. pipeline are

                    being constructed, a bucket dredge excavates a trench behind

                    the..beach. In the final stage, the bucket dredge cuts

                    through the dune-beach system, creating a trench in which

                    onshore and offshore pipeline sections are joined. The

                    original beach topography and vegeta tion are reconstructed.

                        The second method of making a pipeline landfall is pre-

                    ferred and recommended in this study, because environmental

                    disturbance is greatly r educed. A drilling rig may be set,

                    either on the lay barge or on land, to drill horizontally

                    under the beach and dune system, so pipeline connections

                    may be made on land. If horizontal drilling is performed

                    from land, behind the dunes, the drilling rig may be

                    pivoted 1800 to drill 'Under Santa Rosa Sound and the Gulf

                    Intracoastal Waterway. The 16-inch pipeline would then be

                    pulled, from offshore, through the hole and connections made

                    to complete onshore and offshore pipeline segments. This

                    landfall method requires very little surface and bottom

                                            5-12

                     disturbance providing protection to the valuable, fragile

                     barrier island dune system.
                         Pipeline construction on land consists of clearing the
                     pipeline corridor, digging  a trench with equipment suitable
                     for the soils being moved,  assembling pipe sections along
                     one side.of the ROW, lowering the completed pipeline into
                     the trench, covering'with soil, and revegetating the ROW.
                     The ROW may-be used for agriculture, recreation, pasture,

                     etc., after completion of the pipeline. Because pipelines
                     are surveyed aerially and, for safety reasons, trees and
                     buildings cannot be located in the ROW. For a single, 16-
                     inch pipeline, the ROW could be asnarrow as 50 feet, or as
                     wide as 100 feet, depending on soils and topography.
                         Pipelines can safely pass through urban areas, but the
                     cost is higher because of added safety precautions. Pipe
                     wall th ickness is greater, more X-rays are taken, and the
                     pipe-casing is vented to pr'event accumulation of explosive
                     gases. Again, the ROW must be cleared of surface structures.
                         This report recommends that major river crossings be
                     horizontally drilled, to reduce environmental disturbances.
                     River crossings may also be dredged. Small streams may be
                     crossed by dredging,as long as adequate turbidity curtains

                     are used.

                         Road crossings may be made by cutting through the road
                     or using a procedure of boring under the road and pushing.
                     the pipeline through a hole casing (called "jack and bore").
                     Counties and the Flor*ida Department of Transportation

                                            5-13

                     strongly recommend "jack and bore".5

                         Two (2) methods are commonly used to cross wetlands,

                     depending on soil stability. In the "flotation method", a
                     floating dredge excavates a channel wide enough to float a

                     small lay barge through the wetland. The ROW is refilled

                     and revegetated. If soils will support a crane, the crane

                     excavates a ditch wiae enough for only the pipe. The pipe
                     section.s are welded either on a barge or on land, floats are

                     attached, and the pipeline is pushea/pullea through the ditch.
                     The ROW is leveled and revegetatea. This is the "push-pull"

                     method

                         Several other configurations of pipelines and transportd-
                     tion systems, other than a single gas pipeline from the OCS
                     production platform to an existing gas transmission pipeline,
                     are possible. If the discovered natural gas resource is less

                     than the minimum specification, it cannot be produced. Natural

                     gas can be tankered/barged 'only after it has been liquefied,
                     and offshore liquefactio n plants are more costly than a pipe-

                     line.

                         If a less than minimum oil discovery is made, oil may be
                     loaded on a tanker/barge at the production platform and
                     shipped directly to a refinery.

                         If sufficient quantities of gas and oil are found
                     together so that a pipeline is justified, oil, gas, and water
                     would be separated on the production platform, water discarded,
                     gas and oil dehydrated, then both products may be put into one
                     pipeline and transpor ted ashore. Onshore, at a gas treatment

                                            5-14

                    plant, oil and gas would be reseparated, oil piped to a

                    marine terminal for shipment to a refinery, and gas

                    treated and piped to an interstate pipeline.

                        Finally, in the event that gas found south of Pensacola

                    is transported to Escambia County and gas found south of

                    Destin is piped ashore in Bay County, it is remotely possible

                    that West Florida cotld experience two (2) pipeline landfalls.

                        Characteristics of potential West Florida pipelines are:

                    1.  construction time: depends on length; for the shortest

                        route of 35 miles offshore and 24 miles onshore, one

                        yea:r may be required.

                    2. labor requirements.: about 250 jobs, 20 percent of which*

                        may be local laborers.

                    3.  cost: 16-inch offshore pipelines average $1.55 million

                        per mile while onshore 16-inch pipelines average $275,000
                        per mile.6

                    4.  noise: localized along 1 to 2 mile sections of the

                        onshore segment; during construction, equipment would

                        generate about 86 decibels, 100 feet from the source;
                        no noise during operation.7

                    5.  energy: pipelines are the least energy-intensive trans-

                        portation methods; energy consumption is included in

                        the discussion of compressor stations.

               C. Natural Gas Treatment  Facility

                   Natural gas produced from the OCS south of West Florida is

               expected to contain hydrogen sulfide, a poisonous and corrosive

                                            5-15

               gas. Hydrogen sulfide and carbon dioxide, when combined with

               water, form acid compounds which corrode.well casing, processing
               facilities and the natural gas pipeline. The gas may be dry, or
               it may contain petroleum condensates or liquidssuch as propane,
               butane, ethane, and pentane, which have a higher energy content
               than natural gas (natural gas is essentially methane) and are

               usually separated from th@! gas stream and sold to industrial
               and chemical. markets. Therefore, a gas treatment, gas processing,
               and liquids fractionation facility will be required.
                    A typical gas treatment and processing flow diagram is
               illustrated in Figure 5-2.

                    When sour gas is discovered, the gas and gas condensates ard
               separated and dehydrated on the offshore production platform.
               Dehydration removes water vapor.and reduces corrosion and danger
               caused by hydrogen sulfide and/or carbon dioxide. Gas liquids
               are reinjected into the gas stream and both are piped ashore.
                    Onshore, natural gas enter,s*the gas treatment plant for
               removal of carbon dioxide and hydrogen sulfide, which is further

               processed to recover elemental,sulfur, which is sold to chemical
               markets.' Sweetened gas (gas with hydrogen sulfide removed) and
               condensates enter the gas processing plant (commonly called the
               11gas plant"), where valuable gas condensates are removed. Some
               condensates may be added to the gas to produce contract-specified
               energy content (usually about 1000 British Thermal Units per 1000
               cubic fee"t),.before gas enters an interstate gas transmission
               pipeline. If gas liquids are recovered at an economical rate,
               they enter the fractionation plant, where they are separated and

                                           5-16

                                                                    FIGURE 5-2

                                                   GAS PROCESSING AND TREATMENT

                                        PIPED70 S@icm                                              or jncinenfed
                                        T
                                        10 MAFII@JF_
                                        1&-4D/0P_ FERWei2!y             &A'5
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                                                               rl                                    Lves                    15ULFUK
                                                                                                 t od",  U'S
                                                           A5

                                         C
                                                              p L!Z                      Ppoce-                   FKACr10?4A-n
                                                              'a
                                              R4 F@ riA I

                                                                                                                   ;.quic* int,
                                 WATB@.-,
                                                                                       L
                                                                                             -3
                                            W_'T'                                 U)
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                                                                               :2 X
                                        IT15 F?DEN14TIOW                        'Iw

                                                                                                          <RAS TMNSMIsNotj
                                                                                                      LINP,
                                                                                                    - -----------------
                       PLA7i=0?_M
                       AcTrVMaS
                                                                                  ACT1V1T7eS
                                                                                                     red

                                                                                                                  Z"' E101@141101.4
                                                                                                                   S

                                                                                                                                   ;AA
                                                                                                                          4T,

                                                                               Li I

                    SOURCE:   -Onshore Facilities Related to Offshore Oil and Gas Development, Facthook.
                              New ;ng-Land River Basin Commission. Nove ier 1976.

               sold to distributors or consumers. If gas liquids are not present
               in large quantities, they may be stored prior to shipment to an
               existing fractionation plant.
                    This may be one opportunity where the St. Regis gas treatment
               facility, owned and operated by Exxon Company, USA, may be shared
               by oil/gas companies that may discover petroleum on Florida's OCS.
               The Exxon facility is designed to treat 90 million cubic feet of
               gas per day but currently processes only 70 million cubic feet per
               day. If OCS gas condensates are not of sufficient volume to
               justify a gas fractionation plant, these liquids could be trucked
               to the St. Regis facility, near Jay, for fractionation.
                    Three factors determining the location of a gas treatment
               facility receive high considerati on. If sour gas is transported
               ashore, the gas facility is usually located within five (5) to
               ten (10) miles of the landfall site, to eliminate the corrosive
               effects of carbon dioxide and hydrogen sulfide and reduce pipeline
               cost. A gas treatment facility should be located along the pipe-
               line corridor. Also, if gas and oil are transported in one
               pipeline, the gas treatment facility should be located adjacent
               to or near a waterfront.site suitable for an oil barge terminal.
                    Other factors determining the development potential for a

               gas.treatment facility are:

                    1. flood and hurricane hazards;

                    2.  land availability and cost;
                    3.  access to transportation routes (rail not required);
                    4.  proximity to the interstate gas transmission pipeline;
                    5.  surrounding land use and need for buffer;

                                           5-18

                    6. local air quality;

                    7. rate of gas production;

                    8. percent of hydrogen sulfide; and,

                    9.' flowing pressure of gas wells.

                    According to gas industry sources, the percent of hydrogen
               sulfide and well pressure are important factors in determining
               the location of a gas treatment plant. It   is not a gas industry
               practice to compress sour natural gas. Lubricants, equipment
               maintenance and a multitude of operational problems associated
               with the presence of hydrogen sulfid& make compression a very
               high risk process. Therefore, gas treatment plants must be
               located as close to the source as possible and, if well pressure.
               is insufficient to push gas ashore, the gas might be treated on
               the production platform, or a field platform. If well pressure
               is insufficient to push sour gas ashore, the discovered gas
               resource must show a large reserve to justify the large capital
               expense of building an offshore gas treatment facility.    A low-
               pressure sour gas find of 100 million cubic feet of gas with a
               seven (7) year reserv e would probably be uneconomical to produce.
                    The size of a gas treatment facility is dependent upon gas
               production rate and the chemical structure of the gas. Gas plants
               range in size and complexity from a small, dehydration tower,
               located at each well site-to treat sweet, dry gas, and requires an
               area about.25 square feet; to a central complex covering 65 acres,
               which separates gas and oil, dehydrates,both resources, remove's
               and recovers sulfur, sepatates gas liquids and fractionates gas

                                           5-19

               liquids into marketable components.

                    Separate gas treatment modules would be manufactured at
               existing sites in Texas or Louisiana, transported to West Florida,
               then connected on the site of a gas treatment facility.   The size,
               number, and types of modules assembled are dictated by OCS pro-
               duction rate and chemical composition of the product.

                    The land requirement for a gas treatment facility sized to
               treat 100.mi.llion cubic fee t of gas per day is 30 to 35 acres.

               For treatment of sour gas and abatement of noise, odor and

               aesthetics, an additional buffer zone of 200 to 400 acres may
               be purchase d or leased by a gas.company, makin g a total land
               requiremen t of 300 to 800 acres. For example, MOEPSI has

               purchased sufficient land in Mobile County, Alabama, to control
               850 acres; 33 acres of plant site, 120 acres of fenced area, and
               730 acres for residential buffer. Alternately, Exxon Company,
               USA, leases a treatment plant site of only 65 acres, which is
               located about one-half mile from theTown of Jay, Florida.
               Surrounding land is owned by St. Regis Paper Company and is
               plante d with pine trees, so the forested area creates a buffer.
               In both cases, land adjacent to the treatment plant is unavailable
               for residential or commercial development.
                    Hurricane and flood hazards are a priority concern of gas
               companies. High, dky sites are selected for gas plants.
                    Other pertinent characteristics concerning.a gas treatment
               facility 'Include:

                    1. Construction Time - Gas treatment facilities on the Gulf

                        coast have generally been completed in one (1) year.

                                           5-20

                    2. Labor Requirements - About 350 construction jobs are

                        generated when a gas treatment facility is under
                        construction. Approximately 225 of these jobs can be
                        jobs for local construction workers. After completion

                       ,.a gas.treatment facility will generate between 25 and
                        35 operations jobs. About half of these jobs can be

                        filled by West Florida workers.

                    3.  Capital-Cost - Previous gas treatment facilities have
                        ranged in cost between 50 and 60 million dollars, with
                        a monthly operating cost of.3.5 million dollars.
                    4.  Noise - Gas treatment facilities are noisy during
                       -construction and during the life of operation. During
                        construction the on-site noise level is estimated to be
                        between 74 and 98 decibels for approximately ten (10)
                        hours per day. If an adequate buffer zone surrounds

                        the construction site the noise level may be reduced
                        to nine (9) decibels above daytime background noise at

                        a distance of 3,000 feet from the site.

                            During facility operation, noise levels at the

                        facility range between 75 and 100 decibels. This noise

                        level would be continuous 24 hours per day, seven (7)

                        days a week.

                    5.  Water Consumption - The consumptive use of a gas treatment
                        facility may be minimized by the use of air-cooled or
                        fin-fan equipment. Water is needed for fire protection
                        and for domestic needs. Water consumption is approximated

                        to be 150,000 gallons per day, or less, if air cooled or

                                           5-21

                        fin-fan coolers are used. Where feasible, on-site

                        wells may provide water for fire protection and
                        associated needs and a municipal system could provide

                        the low volume of potable water needed for domestic

                        use.

                    6.  Energy Consumption - If a gas treatment facility to

                        treat 100 millioh cubic feet of gas per day is

                        con.structed the estimated electrical usage would be
                        approximately 750,000 kilowatt hours per month for the

                        sweetening, processing and fractionation operations.
                        Fuel consumption is estimated to be approximately 270
                       ..million cubic feet of natural gas per month. If the

                        gas treatment facility is located in an area which

                        already experiences a high level of industrial emissions,
                        it may be necessary to increase the use of electricity
                        to prevent additional loading to the ambient air quality.
                    7.  Air Emissions - For a proposed gas treatment facility
                        with capacity to treat 100 million cubic feet per day
                        of sour gas (six (6) to eight (8) percent of hydrogen
                        sulfide, by volume) sulfur dioxide and nitrogen oxide
                        emissions are of primary concern. Such emissions may
                        require the issuance of a federal Prevention of
                        Significant Deterioration (PSD) air permit and a
                        Florida Department of Environmental Regulation (FDER)

                        air permit.

                            Other potential air emissions include water vapor,
                        carbon dioxide, carbon monoxide, particulates, certain

                                           5-22

                         volatile organic compounds, and hydrogen sulfide.

                             If a leak of untreated natural gas, containing
                         hydrogen sulfide, occurred the gas flow would be
                         shunted to the flare stacks and burned. The hydrogen

                         sulfide would be converted to a less harmful sulfur

                         dioxide.

                             The specific*volume of air  emissions depends on
                         the. volume of gas treated and the hydrogen sulfide

                         content of the gas being treated. Table 5-1 records
                         the estimated air emissions from Mobil oil Company's

                         gas treatment facility proposed  for Mobile, Alabama.
                             Air emissions may be controlled by using the best

                         available control technology (BACT).

               D. Marine Oil Barge Terminal

                    In the unlikely event that a minimum volume of oil to justify
               a pipeline cost is discovered in the OCS offshore from West Florida,
               a submarine pipeline would be installed to transport the oil to
               onshore facilities. If a less than minimum discovery of oil is
               made, the oil would be loaded onto barges at the production
               platform and be shipped to a refinery.

                    If an oil pipeline is constructed in West Florida, a crude
               oil barge terminal with storage tanks would need to be located.
               There is only'one (1) existing petroleum li quid's pipeline in
               West.Florida. This sixteen (16) inch diameter oil pipeline
               transports crude oil from Exxon's St. Regis facility in Jay,
               Florida to Mobile, Alabama% Because of the lack of existing
               onshore oil pipelines in Region I it would be more cost effective

                                            5-23

                                            TABLE 5-1

                 ESTIMATES OF AIR EMISSIONS FROM A GAS TREATMENT FACILITY

                            Pollutant                            Amount
                 Sulfur Dioxide (S02)                       881 tons per year
                 Nitrogen Oxides.(NOX)                      2'98 tons per year
                 Carbon Monoxide (CO)                        29 tons per year
                 Volatile Organics (hydrocarbons)            17 tons per year
                 Particulates                                 7 tons per year
                 Hydrogen Sulfide (H2S)                       5 tons per year

               SOURCE:   MOEPSI. May 1982. Production   of Natural Gas from the
                         Lower Mobile Bay Field,-Alabama     Permit Applications.

                                           5-24

               for the oil industry to transport the crude oil from point of

               landfall through the Gulf Intracoastal Waterway on barges to

               existing refineries west of this region.

                    Factors which must be considered by the oil industry when

               locating.and sizing a oil barge terminal are:

                    1.  rate.of oil production;

                    2.  size of barges to be used at a terminal;

                    3.  frequency of oil shipments-to refineries;

                    4.  crude oil storage capacity required if barge transport

                        is interrupted;

                    5.  fl ood and hurricane exposures,

                    6.  access to intracoastal waterway, rail access and road

                        access;

                    7.  proximity to existing petroleum facilities;

                    8.  land availability, cost, and surrounding land use;

                    9.  soil suitability for storage tank foundation;

                    10. distance from OCS pipel:ine landfall; and,

                    11. distance from oil-gas separation facility.

                    Oil industry input indicates that an oil barge terminal in

               West Florida would include:

                    1.  To accomodate a potential OCS oil  discovery of

                        10,000 barrels of oil per day, a oil barge terminal would

                        require approximately four (4) to six (6) acres of

                        waterfront property.

                    2.  300-400 feet of dock space would be needed for servicing
                        crude oil barges'and associated tug boats.

                    3.  10-15 feet of draft with a 100 feet wide navigable channel

                                            5-25

                         connecting the docking facility and the Intracoastal,

                         Waterway would be needed.

                     4.  Tank storage capacity of about 100,000 barrels,
                         providing about a ten day'reserve. Tanks are used to

                         .meter.oil volume, to determine state and federal revenues.

                     5. Approximately one (1) year would be needed to construct
                         a new barge terminal. If an existing facility could be

                         modified the construction time coU ld be reduced to three
                         (3) months. A new facility could employ approximately

                         250 workers and have a capital cps t of 30.million dollars.
                     6.  After completion a crude oil barge terminal would employ

                         ..between ten (10) and fifteen (1 5) workers.

                     7. Noise levels could range from 85 to 100 decibels at the

                         facility if compressors or oil heating boilers are needed.

                         These noise sour ces would be intermittant and would occur

                         on an as needed basis.

                     8.  The energy requirement 'for a crude oil barge terminal may

                         range between 500,000 and one (1) million kilowatt hours

                         per year to operate the pumps, motors, yard lights, heat-
                         ing units, etc. An additional supply of 10   to 25,000
                         barrels per year of diesel fuel would be needed for tug

                         boats and'trucks.

                     9.  Depending upon the volume of oil  transferred through a
                         West Florida barge terminal, the predominant air
                         emissions would consist of evaporated hydrocarbons,

                         combustion emissi.ons (nitrogen oxides, sulfur oxides

                         and carbon monoxide) from tug boats, trucks and other

                                             5-26

                         on-site combustion engines. It is    estimated that

                         hydrocarbon emissions could be as high as 1.4 tons

                         per year.

                     For.comparison, Shell Oil operates an   oil barge terminal,

                near the mouth of the Mississippi River, which occupies 5.7 acres,
                contains a 450-foot dock, and has storage capacity for 272,000

                barrels of'orude,oil.

                     As previously discussed, it is conceivable that a small OCS

                oil find could be transported ashore.with,,natural gas. In this
                situation, the oil barge terminal would preferrably be located

                near the..gas treatment facility, since oil must be reseparated

                from gas and stabilized.

                     Oil storage tanks are constructed at an elevation to reduce

                flood hazards and oil facilities in coastal areas are constructed

                to withstand hurricane winds. oil facilities must have a spill
                containment dike or berm surrounding the site. Additional

                facilities and services are an office and communications center,

                control console, water for fire protection., domestic sewage and

                solid waste collection.

                E. Compressor and Metering Facilities

                    The requirement for compression facilities depends upon OCS

                well pressure, distance from wells to the interstate transmission
                pipeline,'and pressure in the interstate'pipeline. The Federal
                Energy Regulatory Commission usually requires pipelines to operate

                at no less than 60 percent of design capacity, therefore, the

                                             5-27

                need for compressors will vary with pipe diameter and rate of

                production.

                     According to oil industry sources, it is much easier to

                 push" gas through a pipeline, so compressors would   usually be
                located on the.production platform. However, it is    dangerous to

                compress sour.gas, so OCS geologic formation pressure must push

                gas through the gas treatment plant. Therefore, if compression
                of natural gas is required, compressors would.be located either
                at the gas processing plant (after sulfur removal) or adjacent to

                the interstate transmission pipeline,

                     A major compression facility could require up   to three (3)

                acres. However, if the compressor is located at the gas plant

                or adjacent to an existing compressor station or Florida Gas'

                Transmission Pipeline, very little new land would be required.

                     Characteristics of a.compressor station are:

                     1.  The landarea required depends on OCS well pressure,

                         production volume, distance from well to destination,

                         and pressure within  the interstate pipeline.

                     2.  The capital cost for construction is between $750 dollars

                         and $1,500 dollars per horsepower needed to operate the

                         compressor facility.

                     3.  Construction of a new compressor facility may provide

                         30 to 50 jobs fo r about four (4) months. There are no

                         on-site jobs generated'by a gas compressor station

                          uring operation.

                     4.  A gas compressor station must be accessible by road,
                         in order to conduct maintenance, as needed.

                                             5-28

                     5.  The compressor may be operated by electricity or natural

                         gas, depending upon ambient air quality. The energy
                         requirement is small, compared to treatment plan  ts or

                         barge terminals and is dependent on the size of the

                         facility and volume of  gas being transported.

                     6.  Compressor station compressor noises may be muffled so

                         that they produce 55 to 66 decibels at a distance of 800

                         feet. Noise is produced 24 hours.per day. Approximately

                         once per year, a high pressure pipeline is vented at the

                         compressor station, producing 85 to 140 decibels.

                     7.  Hydrocarbons and sulfur oxides are produced in a gas
                         combustion compressor.' The level  of emissions are small,

                         from 0.6 to 1.2 pounds of emissions per million cubic

                         feet of gas compressed.

                     Two (2) gas metering stations may be required;  one (1) on

                the production platform to determine the volume of  gas entering

                the pipeline, and one at the interstate pipeline to measure sales.

                Meteri ng facilities are important in detecting leaks.

                     Metering stations could cost between $100,000 and $750,000

                and require an area only 100 by 100 feet.square. Construction

                takes about four (4) months and would be  constructed concurrent

                wit h the compressor station. No on-site jobs are generated at a

                gas metering facility after construction.'

                II. Alternative West Florida Sites Considered for onshore Natural

                     Gas and Oil Facilities

                     For purposes of this Gtudy, up to seven (7) alternatives for

                transporting natural gas and/or oil ashore, providing treatment,

                                             5-29

               and marketing to an interstate gas system, were considered. At

               least one alternative in each of the five (5) coastal counties in
               Planning Region I was evaluated in detail and recommended.for oil
               industry and local consideration.

                    Using the information from the completed methodology described
               in Chapter 3 the OCS onshore support facility alternatives were
               developed. The alternatives are illustrated in Figure 5-3. Loca-
               tions for seven (7) pipeline landfalls and'corridors (Al-A7),
               seven (7) onshore service bases (Bl-B7), seven (7) gas treatment
               facilities (Cl-C7),five (5) oil barge terminals (DI-D5), and six
               (6) compressor -metering stations (El-E6) were chosen. A

               description of each considered alternative follows.

                    Because of the general nature of a OCS hydrocarbon discovery
               and due to a lack of detailed data, the sites selected and des-

               cribed are general areas. In some cases actual land owners have

               been contacted and specific sites have been named and described.

               A. Pipeline Landfall and Corridor

                   1. Alternative A-1 - The Perdido Key (Escambia County) landfall
                       is located in the vicinity of State Road 292 as it crosses

                       the Intracoastal Waterway. This route crosses the GIWW at
                       its narrowest point in Escambia County. The pipeline

                       corridor considered continues inland to the area of

                       U.S. Highway 90 at Bayou Marcus Creek, where the pipeline
                       could be constructed in an existing right-of-way of a
                       United Gas Company.pipeline. The considered OCS pipeline

                       corridor would continue northward and interconnect with
                       the United Gas Pipeline Company system, at the company's

                                          5-30

                          eastern terminal.

                             This corridor  would require crossing of the GIWW

                          (horizontal drilling recommended) and, as-with all
                          proposed corridors, se;Veral roads, streets' and streams.

                          The distance from landfall to destination is approximately

                          24 miles. The determination of distance from the OCS for

                          the alternative -submarine pipeline corridors was approxi-

                          mated starting from one (1) lease,block, each, determined

                          to be in the center of the productive areas of the Destin

                          Dome Block and the Pensacola Block (assumed to be the most

                          likely find areas). Block Number   144 was selected for the

                          Pensac ola Block and Block Number 995 was selected for the

                          Destin Anticline area (see Figure 5-4).

                     2.   Alternative A-2 - The Santa Rosa Island/Gulf Breeze landfall

                          (Santa Rosa County) is located approximately four (4) miles

                          east of Pensacola Beach. The pipeline corridor considered

                          crosses Santa Rosa Island to Range Point, crosses Santa Rosa

                          Sound to an area about three (3) miles east of Gulf Breeze,

                          crosses East Bay to Garcon Point, then continues inland to

                          an area west of Milton. This considered corridor crosses

                          State Road.87 between Milton and Naval Air Station Whiting

                          Field, and interconnects with the Florida Gas Transmission

                          Company interstate gas pipeline  at the Juniper Creek

                          Compressor Station.

                             This considered corridor requires a two (2) mile

                          crossing of Santa Rosa Sound and a three (3) mile cross  ing

                          of East Bay. Since both crossings are beyond the capabil-

                          ity limits of horizontal drilling, the pipeline must be

                                              5-32

                        ALABAMA                                           FLORIDA
             Mobile              B
                                  aldwin    lEscambia        a Rosa .1 Okaloosa            Walto
                                                                                               n      Washington

                                                                                                         Bay

                                                                      L   :ue

                                                    rllree

                                                                               995

                                                    144

       Ln
       I
       u,

                                                           FIGURE 5-4

                                                      Center Lease Blocks
             Mobile

                                                    For OCS Production Areas

                          must be buried by dredging. Both estuarine systems are

                          valuable and very fragile.

                             Further inland, the considered corridor crosses

                          Interstate Highway 10 and Pond Creek. The distance from

                       ..landfall to destination is approximately 44 miles.

                             If Getty Oil Company discovers natural gas in East Bay,
                          this pipeline corridor could be shared with Getty to

                          transport OCS and onshore generated natural gas.

                     3.   Alternative A-3  The Holley-Navarre pipeline landfall
                          (Santa Rosa County) is.located in the vicinity of the

                        .,Santa Rosa/Okaloosa County Line. The considered corrido*r

                          crosses a one (1) mile section of Santa Rosa Sound

                          (horizontal drilling is recommended), crosses U.S. Highway
                          98, and parallels State Road 87 and Okaloosa County Gas
                          District pipeline rights-of-way across Eglin Air Force

                          Base to U.S. Highway 90. The considered pipeline could

                          then follow State Road 191, or be constructed in a

                          straight line,to interconnect with the Florida Gas pipeline
                          at the Juniper'Creek Compressor Station.

                             This considered corridor requires crossing of two .(2)

                          major rivers, Yellow River and Blackwater River;. the second
                          of which may be performed by horizontal drilling. Distance
                          from landfall to de'stination is about forty-one (41) miles.

                             This potential corridor could be modified (Alternative
                          A-3A) as follows.. Near U.S. Highway 90, the OCS pipeline
                          corridor could turn west and follow the Okaloosa County

                                            5-34

                         Gas District pipeline right-of-way around Milton to the

                         vicinity of the intersection of County Road 187 and 194
                         (Sect-ion 32, Township 2N, Range 29W). Near this location,

                         an OCS pipeline could interconnect with the local Five

                         Flags Pipeline Company pipeline, which could market gas

                         to area industries in Escambia and Santa Rosa Counties,

                         or transport OCS'gas north to Jay, to an interconnection

                         with the Florida Gas Pipeline.

                             For Alternative A-3A, the distance from landfall to

                         destination is about 33 miles.
                             As in Alternative A2, this pipeline could potentially
                        ..be shared by Getty Oil Company and the OCS gas producer.

                     4. Alternative A-4 - The Destin landfall (Okaloosa County)

                         is located about two (2) miles west of the Okaloosa-

                         Walton County Line. The corridor crosses the peninsula

                         to Piney Point, crosses an eight (8) mile section of

                         Choctawhatchee Bay and Boggy Bayou, to meet and parallel

                         State Road 85 and Okaloosa County Gas District rights-of-

                         way across Eglin Air Force Base reservation. At

                         Interstate Highway 10 or U.S. Highway 90, the considered

                         corridor could depart State Road 85 and interconnect with

                         the Florida Gas pipeline northeast of Crestview.

                             This considered corridor requires one (1) major river

                         crossing; the Shoal River. The total distance from

                         landfall to destination is about 34 miles.

                    5. Alternative A-5     The Seagrove Beach Area landfall (Walton

                                            5-35

                         County) is approximately two (2) miles east of the

                         unincorporated community of Seagrove Beach. The

                         considered corridor continues northward to cross the

                         Choctawhatchee River delta, pass east of Freeport, and

                         interconnect with the Florida Gas pipeline east of

                         DeFuniak Springs.

                             This considered corridor requires crossing of a

                         major river delta, extensive wetlands, two (2) rivers

                         (Choctawhatchee and Mitchell), Black Creek and the

                         Intracoastal Waterway. The distance from landfall to

                         destination is approximately  31 miles.

                     6. Alternative A-6 - The Panama City Beach area    landfall
                         (Bay County),is near the junction of U.S. Highway 98 and

                         State Road 79. This is the only landfall considered

                         located within an urbanized area. However, the urbanized
                         area (residential and tourist attractions) along the  coast
                         is only one-half to one (1) mile wide, therefore, horizon-

                         tal drilling might be used to reduce any disturbances.

                             The considered corridor continues inland along State
                         Road 79, through West Bay to the vicinity of County Road

                         284, northeast of Ebro. The corridor continues north and

                         interconnects with the Florida Gas pipeline at the

                         Choctawhatchee River Compressor Station.

                             The only water crossing is the Intracoastal Waterway

                         at West Bay. The distance from landfall to destination is

                         approximately 33 miles.

                                            5-36

                     7. Alternative A-7    The Mexico Beach area landfall (Bay

                         County) is located between Tyndall Air Force Base and

                         Mexico Beach. The pipeline considered corridor extends

                         inland, either crossing or going around East Bay, parallels

                         County Road 167, and interconnects with the Panama City

                         Lateral of the Florida Gas Transmission system near U.S.

                         Highway 231 and County Road 167.

                             This considered corridor may require approximately

                         a three-quarter mile crossing of East Bay, with the exact

                         route determined by economic and environmental impacts.

                         The distance from landfall to destination  is about 23

                         miles, making this the shortest  considered onshore pipe-
                         lin.e alternative. However, the  offshore pipeline may be

                         too long, from production platform to landfall, to make

                         this alternative feasible.

                             The actual pipeline corridors that will receive

                         detailed analysis by a-gas transmission company will be

                         determined, in part, by the location of a petroleum

                         resource discovery in the Gulf of Mexico.

                B.   Onshore Service Base

                     1. Alternative B-1 - This considered base is located on the

                         eastern side of Bayou Chico (Escambia County) on 55 acres

                         of undeveloped industrial land. Surrounding land use

                         and zoning are industrial and the landowner has been

                         contacted and is receptive to leasing space for oil/gas

                         industry facility needs.

                                             5-37

                            All requirements for a service base could be met

                        with a minimum capitol investment. There is access to

                        support services, boat repair facilities, and parts

                        supplies.

                            The distance from this site to the Gulf of Mexico is

                        about eleven (11) miles.

                    2. Alternative B-2    The Port of Pensacola (Escambia County)

                        is an industrial area, which has all facilities to meet

                        the requirements for an onshore service base. However,

                        using this port to support OCS activities would cause

                        two (2) conflicts: the Port of Pensacola   is actively
                        using all land available, and accommodating OCS activities

                        would require the City of Pensacola to purchase additional

                        expensive waterfront property. Port of Pensacola

                        officials have stated that they prefer to use all

                        available facilities for the handling of rapid turnover
                        commodities, which produce more revenue than a long-term

                        .lease of space to an oil company. According to port

                        officials, as long as needed, suitable waterfront

                        facilities can be found elsewhere in the Pensacola Bay
                        vicinity, the Port of Pensacola will not consider leasing

                        space to an oil company.

                            The Port of Pensacola is approximately ten (10) miles

                        from the Gulf of Mexico.

                    3.  Alternative B-3   This considered site is located on

                        Blackwater Bay, between the community of Bagdad and the'

                                            5-38

                         City of Milton in Santa Rosa County. A grain elevator
                         is located in the area and a maintained navigation channel

                         and docks are present. Construction of an onshore service

                         base would require a large capital investment.

                             Drawbacks of this considered site are its distance

                         from.the Gulf (about 32 miles) and the surrounding land

                         use is primarily residential, creating a conflict with a

                         24-hour.oil industrial operation. Boat repair and

                         industrial services are also distant from the considered

                         site.

                     4. Alternative B-4    The Fort Walton Beach Industrial Park'

                         (Okaloosa County) is the fourth.considered service base.

                         This site is north of U.S. Highway 98, west of the

                         intersection of U.S. Highway 98 and State Road 189.

                         Hurlburt Field (U.S. Air Force facility) operates a
                         barge fuel dock on Santa Rosa Sound. An onshore support

                         base would more appropriately be located south of U.S.

                        ,Highway 98, on the Intracoastal Waterway.
                             There is one major obstacle to locating a service base

                         near the Choctawhatchee Bay area. The East Pass Channel,
                         conne cting Choctawhatchee Bay with the Gulf of Mexico,
                         shoals in to a four (4) to six (6) foot depth rapidly
                         after maintenance dredging. Therefore, this channel is
                         considered unreliable for OCS support vessel traffic,

                         and the next closest access to the Gulf is 40 miles, at

                         Pensacola Pass. If the Fort Walton Beach area were to

                                            5-39

                        be considered for a service base, the oil company and

                        taxpayers would be required to spend money for the Corps
                        of Engineers to maintain a reliable twelve (12) feet deep

                        channel at East Pass.

                    5. Alternative B-5-- The considered site of a petroleum fuels

                        barge dock in Frbeport (Walton County) is an industrial

                        site which contains the channel and shoreline improvements

                        required for a service base. The industrial site is about

                        15 acres.

                            The largest obstacle to locating a service base in

                        Freeport is the East Pass Channel, as discussed under

                        Alternative B-4. The distance to the St. Andrews Bay

                        channel is about 30 miles from Freeport.

                    6.  Alternative B-6 - The Port of Panama City (Bay County),
                        like the Port of Pensacola, has all facilities required
                        for a service base. The Port of.Panama City has one

                        advantage in that oil companies have previously leased

                         space for a service base.  Recently Standard Oil of
                        Ohio (SOHIO) leased space at the Port of Panama City
                        during the'drilling of an exploratory well on Lease Block

                        562.

                            Again, officials at the Panama City Port Authority
                        have taken the position that, as long as suitable water-

                        front sites can be found near Panama City, the-Port will

                        not serve as an onshore service base.

                                            5-40

                             This port is about six (6) miles from the Gulf of

                         Mexico.

                     7.' Alternative B-7   The area surrounding Watson Bayou,

                         Panama City (Bay County), is possibly the largest refined

                         petroleum products receiving terminal in West Florida.

                         Approximately si*x oil.companies operate fuel terminals

                         and.storage tanks with a combined capacity exceeding 1.5

                         million barrels of refined petroleum liquids. Southwest

                         Forest Industries also has a paper mill near this

                         location.

                             All requirements for an onshore service base could

                         be met in Watson Bayou, with minimum capital investment.,

                         There is a company that builds and operates crew boats

                         in the area. Boat repairs, industrial parts, welding

                         services, or even steel fabrication services would be

                         readily available in this area.

                             This site is about.nine (9) miles from the Gulf of

                         Mexico.

                C.   Gas Treatment Facility

                     A gas treatment, processing and fractionation facility would
                be located along the pipe line corridor. Because sour gas is anti-
                cipated, the proposed alternative facility sites are within ten

                (10) miles of the landfall site.

                     1. Alternative C-1 - There is adequate undeveloped land in

                         southwest Escambia County that may be used for gas treat-

                         ment facility with a controlled buffer zone. There are

                                            5-41

                        several industries in and north of Pensacola with air

                        emissions, however, southwest Escambia County is free
                        of industries and may allow sufficient dispersion of
                        air emissions; thereforej complex air discharge permits

                        may not be required.

                            The groundwater supply in southwest Escambia County
                        is adequate to supply the demand of a gas treatment
                        facility. Large portions of this part of Escambia

                        County lie within the 100-year flood hazard zone, there-
                        fore, the plant site must be carefully selected. Gulf

                        Power has a transmission substation within four (4) miles

                        of the proposed site and a 46 kilovolt (KV) transmissioh

                        line passes nearby.

                    2.  Alternative C-2 - A gas treatment facility along the

                        San ta Rosa Island/Gulf Breeze pipeline corridor
                        (Alternative A-2) might be located'on the Gulf Breeze
                        peninsula or on the southern tip of the Garcon Point

                        .peninsula, both in Santa Rosa County. A Gulf Breeze
                        peninsula location may create a serious land use conflict,
                        since this area contains residential subdivisions and the

                        Naval Live'Oaks portion of the Gulf Islands National

                        Seashore. Another significant point is that Getty Oil
                        Company has stipulated that, should natural gas be
                        discovered in East Bay, gas will not be transported to
                        the southern shore of East Bay. This stipulation
                        indicates that residents along the Gulf Breeze peninsula

                                           5-42

                         would not favor a gas facility in the area.

                             A Garcon Point peninsula location is more feasible

                         for hurricane and flood protection. However, prevailing

                         southerly winds may mix air emissions with the air

                         emissions of nearby industries, creating an air quality

                         problem and the need-for complex air discharge permits.

                         The Garcon Point:peninsula location is reasonably isolated

                         and a controlled buffer zone could be leased. This area

                         is served by county roads, which may require improvement

                         for heavy truck traffic. As discussed with pipeline
                         corridors, Getty Oil Company could possibly share a gas

                         treatment facility located on Garcon Point peninsula.

                             There is a Gulf Power transmission substation within

                         two (2) miles of a possible Gulf Breeze peninsula site

                         and a 110 KV transmission line traverses the peninsula.

                         The re are not adequate electrical facilities convenient

                         to a Garcon peninsula location.

                     3.  Alternative C-3 - A gas treatment facility along the

                         Holley-Navarre pipeline corridor could be located in

                         southeast Santa Rosa County, before the pipeline enters
                         the Eglin Reservation. A location adjacent to Eglin
                         Air Force Base could minimize the need to purchase a-

                         controlled buffer zone, since development is not per-
                         mitted on the reservation. Also, Getty Oil could share

                         gas facilities at this location.

                             There has been difficulty in obtaining groundwater
                         from the shallow sand-and-gravel aquifer in southeast

                                            5-43

                        Santa Rosa County. Several wells may be required to
                        fulfill the 150,000 gallon demand of a gas treatment
                        facility. Wells may be drilled into the Upper Floridan
                        Aquifer, or surface watermay be used.
                            Gulf Power Company has a substation within six (6)*

                        miles of this area and 230 KV and 110 KV transmission

                        lines pass withih four (4) miles of the area.

                    4. Alternative C-4 - For the Destin  pipeline corridor, a

                        gas facility must be located on the Destin peninsula,

                        because of insufficient available  land north of

                        Choctawhatchee Bay. Eglin Air Force Base officials

                        have stated that the Air Force would not outlease a
                        portion of the reservation for a gas treatment facility.
                            The Destin-Moreno Point area is currently undergoing
                        rap id residential and commercial development to accommodate
                        tourism andrecreation.' Removal of expensive land for
                        industrial use would be costly and in conflict with

                        surrounding land use.

                            Because the Destin peninsula is surrounded by salt-
                        water, obtaining adequate freshwater may overburden-the
                        groundwater aquifer and promote saltw ater intrusion.

                        Also, the area is subject to hurricanes.

                            There is a Gulf Power substation within four (4)
                        miles of the pipeline corridor and a 46 KV transmission
                        line traverses the Destin Peninsula.

                    5. Alternative C-5    A gas treatment facility along the

                                            5-44

                         Seagrove Beach area pipeline corridor would probably be

                         located north of the Choctawhatchee River delta (Walton

                         County). The only large land parcel, not in the Point

                         Washington Wildlife Management Area, south of the Gulf

                         Intracoastal Waterway, is adjacent to the Eden State

                         Ornamental Garden, at Point Washington.

                             The northern*location would be served by State Road

                         20,and U.S. Highway 331. This location is isolated and

                         distant from an urban area. As with Alternative C4, if

                         this gas facility were located adjacent to property

                         owned by St. Joe Paper Company or Southwest Forest

                       .,Industries, an additional controlled buffer may not be

                         required.

                             There is a Gulf Power Substation within five (5) miles

                         of the southern, Point Washington site, or with in thirteen

                         (13) miles of a site north of the Gulf Intracoastal Water-

                         way. Both 46 KV and 110 KV transmission lines pass within

                         one (1) mile and eight (8) miles of the respective southern

                        ,and northern locations.

                     6. Alternative C-6 - The only available large parcel of

                         private,land in southwestern Bay County not in the Point

                         Washington Wildlife Management Area is the area around

                         West Bay. This is in the vicinity where State Road 79

                         intersects the Intracoastal Waterway. This site has

                         been suggested by representatives of a gas transmission

                         company.

                                            5-45

                             West Bay is surrounded by water and the Point

                         Washington Wildlife Management Area, therefore, a
                         controlled buffer.may not be required. This con.   sidered
                         site is served by State Road 79 and is approximately 20

                        ..miles.from industrial centers in Panama City. Since this

                         portion of Bay County is undeveloped, the impacts of any

                         air emissions would be low.

                             West Bay is about four (4) miles from a Gulf Power

                         Substation, eleven (11) miles from the Lansing Smith

                         Generating Plant, and withip one-half mile of 230 KV

                         and 110 KV transmission lines.

                     7.  Alternative C-1 - A  gas treatment plant on the Mexico

                         Beach area pipeline  corridor could be located north of

                         Mexico Beach, in the southeasternmost corner of Bay

                         County. This area is 26 miles from an urban center, but

                         is not served by adequate electrical facilities. About

                         five (5) miles of improved, paved road must be constructed

                         to connect a plant site with U.S. Highway 98.

                             A more suitable location on this pipeline corridor

                         would be north of East Bay, in an area served by County

                         Road 187 and State Road 22    This location is about

                         fifteen (15) miles from Panama City and within three (3)
                         miles of a 230 KV electrical transmission line owned by

                         Florida Power Corporation, or within ten (10) miles of

                         a 110 KV line owned by Gulf Power Company.

                                            5-46

                D. Oil Barge Terminal

                    It is unlikely that an oil barge terminal will be located in
                West Florida, because an OCS oil discovery is not anticipated.
                However, in the event that a terminal is required, it could be
                located at numerous sites along the Gulf Intracoastal Waterway,
                since this route is used extensively for distribution of crude
                and refined petroleum products. Also, if oil and gas were to be
                transported,ashore in one (1) pipeline, the oil barge terminal would

                best be located adjacent to or near the gas treatment facility.
                    1.  Alternative D-1 - An oil barge terminal could feasibly
                        be located in the Big Lagoon area or along Perdido Bay
                        ..(Escambia County). A Big Lagoon site would create
                        serious land use and aesthetics conflicts. Two (2) Navy
                        airfields, Bronson and Saufley, located along Perdido

                        Bay, are not being used at original capacity. A portion
                        of either field could be converted to oil industry use at
                        a.moderate capital cost.' Negotiations with the Navy and
                        Department of Defense may require several years.

                   2.   Alternative D-2 - There are currently three (3) oil
                        companies which maintain refined fuel storage tanks and
                        barge docks along Pensacola Bay (Gulf, Chevron, and
                        Union 76). Belch er Oil stores Bunker C oil at the Port
                        of Pensacola. it may be possible that the oil companies
                        ma y be receptive to combining product distribution
                        services, then leasing excess barge terminal space for

                        use as an OCS oil barge te rm.inal.

                                            5-47

                             If this arrangement were negotiated, all facilities

                         would be available without major capital investment.

                         However, constructing a crude oil pipeline from southwest

                         Escambia County (gas treatment site) to the Pensacola

                         waterfront would require considerable expense.

                             If an oil.barge terminal were constructed along or

                         near pipeline co*rridor Alternative A-21, the most suitable

                         location may be on the Garcon Peninsula. Construction

                         of all barge terminal requirements, channel dredging,
                         constructing docks and -storage tanks, and providing

                         electrical service and support services, would be needed,

                         involving large capital expenditure.

                     3. Alternative D-3 - This site is on the south shore of

                         Choctawhatchee Day, near pipeline corridor Alternative

                         A-4   No facilities are available, therefore, all

                         facility requirements must be constructed.

                             A second terminal site in Choctawhatchee Bay may be

                         considered; the petroleum facility in Freeport. This

                         location is a short distance from pipeline corridor

                         Alternative A-5.

                     4.  Alter native D-4  A barge terminal could be located at

                         West Bay (Bay County), on the site of the gas treatment
                         facility (Alternative C-6'). While this site is adjacent

                         to the Intracoastal Waterway, all improvements-must be

                         developed.

                                            5-48

                            Other possible terminal sites west of Panama City
                         include the currently used military petroleum terminal

                         west of Lynn Haven (along North Bay), or a site adjacent
                         to the Gulf Power Company Lansing-Smith Power Plant, in

                         Alligator Bayou.(also on North Bay). Gulf Power main-
                         tains a barge channel and docks for barge shipments of

                         coal, so some fa-cilities may be available to service

                         industry needs. The Alligator Bayou site is about ten

                         (10) miles from a potential pipeline corridor (Alternative

                         A-6).

                    5...Alternative D-5 7 This location is within the existing
                         petroleum complex in Watson Bayou. All terminal facility
                         requirements, except storage tank capacity, can be

                         met without substantial capital investment. As in the
                         case with existing petroleum barge facilities in Pensacola,
                         there may be difficulty in constructing a crude oil pipe-
                         line from a gas facility location to Watson Bayou, since
                         an onshore pipeline must be constructed through an

                         urbanized area.

                            Another barge terminal site may be chosen in East Bay
                         (Bay County), near pipeline corridor Alternative A-7.

                         Eastern Marine, a boat building company, has a 130 acre
                         boatyard on Murray Point, in East Bay (Figure 5-3).
                         Additional industrial development is possible adjacent

                         to Eastern Marine. This site is adjacent to the Intra-

                         coastal Waterway.

                                            5-49

                E. Compressor and Metering Station

                    Any onshore compressors required could be located on the site
                of the gas treatment facility, causing little added impact on the
                region.. Another potential location would be at the  point of
                interconnection between the OCS pipeline and an onshore gas
                transmission pipeline. If a new compressor were located adjacent
                to an existing compressor@ station (El, E2, E5), additional impacts
                on land use,. noise, wildlife,'aesthetics, cost of facility, etc.,
                would be relatively small. If a new compressor station is
                constructed (E3, E4, E6), up to five (5) acres of land may be
                required, a new noise source would be created, and  all impacts

                would increase.

                     Two (2) gas metering facilities per pipeline are required;
                one (1) on the offshore production platform to measure gas
                produced and put into the pipeline (no impact); and a second
                onshore to meter gas sold to a transmission company. Metering
                stations are important for measuring gas volumes to determine
                leakage and revenue. The six (6) potential locations for onshore
                metering stations (El through E6) require small facilities with no
                impact on the region.

                III. Positive and Negative Impact Assessment of Potential Sites

                    The positive and neg ative impacts of seven (7) alternatives
                each for five (5) types of OCS onshore support facilities (total
                of 32 alternatives) were evaluated in the matrix, presented in.
                Appendix A. Each industry alternative was evaluated against
                fifteen (15) socio-economic impacts and seventeen (17) environ-

                mental impacts.

                                            5-50

                      As previously stated, the seven (7) alternatives presented
                and evaluated in this study do not represent every possible
                alternative for onshore oil and gas facilities serving OC   S
                activities. As industry activities offshore from West Florida
                increase and assumptions are changed to known factors, new
                alternatives may be developed by the oil and gas industry. The
                evaluation matrix may be*used to  select any alterna tive that is
                finally constructed.

                      As a result of these evaluation, the  recommended, most
                suitable OC S onshore support facility alternatives..are:
                A. Pipeline Landfall and Corridor:.
                    1.  Alternative A-1 - Perdido Key, Southwest Escambia County'
                    2.  Alternative A-3 - Holley-Navarre,   Santa Rosa County
                    3.  Alternative A-6    Panama City Beach, Bay County
                    4.  Alternative A-7    Mexico Beach, Bay County

                B. Onshore Service Base:

                    1.  Alternative B-1 -  Bayou Chico, Escambia County
                    2.  Alternative B-7 -  Watson Bayou, Bay County

                C.  Gas Treatment Facility:
                    1.  Alternative C-1 -  Southwest Escambia County
                    2.  Alternative C-3 -  Southeast Santa Rosa County
                    3.  Alternative C-6 -  Southwest Bay County
                    4.  Alternative C-7 - Southeast Bay County

                D.  Oil Barge Terminal:
                    1.  Alternative b-2 -'Pensacola Bay, Escambia County
                    2.  Alternative D-5 - Watson Bayou, Bay County

                                             5-51

               E. Compressor and Metering Station:

                    1. Alternative E-1 -  United Gas Pipeline Terminal,
                                         .Escambia County
                    2. Alternative E-2 - Junip-er Creek Compressor-Station,
                                          .Santa Rosa County
                    3. Alternative E-3 -  Choctawhatcheb River Compressor Station,
                                          Washington County
                    4.. Alternative E-6   Panama City Lateral at Bayou George,
                                          Bay County

                                            5-52

                                         CHAPTER 5

                                         Footnotes

                1.  Minerals Management Service. Gulf of Mexico Summary Report 3.
                    August 1982.

                2.  New England River Basins Commission. Onshore Facilities
                    Related to Offshore Oil and Gas Development - Factbook.
                    November 1976.

                3.  "Oil and Gas Journal". November 1982.

                4.  Minerals Management Service. Final Regional Service Impact
                    Statement, Gulf of Mexico. January 983.

                5.  Florida Department of Transportation. Utility Accomodation
                    Guide.

                6.  "Oil and Gas Journal". November 1982.

                7.  Mobil Oil Exploration and Producing Southeast, Inc.
                    Production of Natural Gas From the Lower Mobile Bay Field,
                    Alabama. May 1982.

                                            5-53

                                         CHAPTER 6

                             REGULATORY MECHANISMS ASSESSMENT

                                      "'CHAPTER 6

                            REGULATORY MECHANISMS ASSESSMENT

                   Identification of existing management, regulatory and policy
               mechanisms is.an important task if all impacts of OCS onshore
               activities are to be understood and prepared for. Mechanisms
               and regulatory structureb that might induce, constrain or
               influence the location of onshore facilities have been examined

               and summarized here. The agencies and mechanisms identified

               here have been compiled from existing works and from local

               government comprehensive plans and regulatory structures. The
               summary is arranged in the following order:

                            1.  Federal Regulatory Mechanism

                            2.  State of Florida Regulatory Mechanisms

                            3.  Regional Procedures and Policies

                            4.  Local Regulatory Mechanisms

               Federal level actions and regulatory mechanisms have a more

               comprehensive effect on OCS activity than any action of the
               other three (3) levels mentioned. Federal agencies are mandated

               to control any activity that occur directly on the OCS.

                      Federal Agencies Charged With Management of the OCS
                   Seventeen (17) federal agencies are directly or indirectly
               charged with the regulation and management of OCS resource

               exploration, development and production offshore from west

               Florida.

                                           6-1

               I-. U.S. Department of the Interior

                   Mineral resources are managed by the Department of the

               Interior (DOI) under the provisions of the Outer Continental

               Shelf Lands Act, which mandates orderly development of OCS

               resources.

                   A, Minerals Management Service

                       The Division of DOI that is directly responsible for
                   supervising  the exploration, development, production and

                   resource transportation in the OCS is the Minerals Manage-

                   ment Service (MMS). MMS is alsb responsible for collecting

                   royalty revenues from the oil industries for leases and

                   resource production.

                   B. .United States Geological Survey

                       OCS safety regulation issuance and enforcement, review

                   of industry exploration and development plans, drilling

                   permit issuance, OCS pipeline easements are some of the

                   responsibilities of the U.S. Geological Survey (USGS).

                   USGS has generated the estimates of OCS resource reserves

                   that are used for evaluating onshore impacts of OCS
                   facilities. The USGS is responsible for regulating air

                   quality from OCS activities.

                   C. Bureau of Land Management

                       An Intergovernmental Planning Program has been formed

                   to involve the different involved government agencies in

                   the OCS development 1@rogram. This unique program is

                                           6-2

                    managed by the Bureau of Lan Management (BLM). BLM.reviews

                    all industry exploration and development plans for lease

                    stipulations.

                II. National Oceanic and Atmospheric Administration

                    The National Oceanic and Atmospheric Administration (NOAA)

                is a branch of the U.S. Department of Commerce. NOAA is

                charg ed with a wide range of responsibilities including weather
                service, estuarine and marine sanctuaries, ocean surveys, deep
                sea bed mining and the Coastal Energy Impact Program (CEIP).

                CEIP funds  were used to fund this study effort.

                    A. Office of Oceanic and Coastal Resource     Management

                         This office of NOAA was previously named the Office of

                    Coastal Zone Management (OCZM) and is charged with asse    s.sing
                    environmental impacts of OCS activities and is responsible

                    for the protection of marine and coastal resources. OCZM

                    also reviews and offers comments for all industry OCS

                    exploration and development plans and environmental assess-

                    ment.

                    B. National Marine Fisheries Service

                        The National Marine Fisheries Service (NMFS) is charged
                    with the administrat.ion of sections'of the Endangered Species

                    Act and the Marine Mammals Act. NMFS also assesses the

                    environmental impacts of OCS projects on commercial fisheries

                    and other marine resources. NMFS reviews all industry plans

                    for exploration and development of OCS resources.

                                             6-3

               III. U.S._Army Corps of Enqineer's

                     The Army Corps of Engineers (COE) is charged with
               regulating any fixed structures on the  OCS. All exploration
               well platforms, field development and production platforms and
               product.pipelines are permitted by COE. The COE is assigned the
               permitting authority fo r any structure or modification procedures,
               in any United States navigable water.

               IV.   U.S. Environmental Protection Agency
                     The Environmental Protection Agency.(.EPA) has been charged
               by Congress to administer all federal laws for environmental
               quality protection. EPA has developed a system for permitting
               discharges into United States surface waters. This National
               Pollutant Discharge Elimination System (NPDES) is designed to
               limit the discharge of harmful substances. Exploratory drilling
               facilities are permitted by EPA as are discharges of drilling
               muds, drilling cuttings and other non-toxic discharges.

                       S. Department of Energy
               V*    U*

                     The use of petroleum fuel pipelines in the OCS is regulated
               by the U.S. Department of-Energy (DOE). DOE establishes the
               wellhead price of OCS produced natural gas and set the production
               rates for all federal leases and bidding systems to foster

               competition.

               VI.   U.S. Coast Guard

                     The U.S. Coast Guard (USCG) has many responsibilities

                                            6-4

               pertinent to OCS activity. The safety and prevention of oil

               spill pollution on the OCS is a major role of the USCG. USCG

               issues Aids to Navigation permits to mobile and fixed drilling
               facilities, establishes and en;orces safety regulations for

               drillships, platforms, and other fixed structures, enforces

               federal oil pollution laws in offshore waters, and shares

               responsibility with USGS'for oil spill prevention and cleanup.

               Procedures for the transfer of oil from vessel to vessel, between

               onshore and offshore facilities and vessels must be approved by

               USCG. USCG   conducts pollution surve.illance patrols in OCS

               waters. The USCG offers comments on proposed industry activities

               in the OCS as they relate to navigational safety and oil spill

               contingency plans.

               VII. U.S. Department of Defense

                     All U. S. military activities are directed toward protecting

               and defending the territories ahd allies of the United States.

                   -A. U.S.. Department of the Air Force

                          The United States Air Force (USAF) becomes involved in

                     the management process for the OCS because of the armament

                     testing mission of the Eglin Air Force Base      Eglin's

                     Armament Division is responsible for maintaining the

                     integrity of a portion of the OCS known as the Eglin

                     corridor for the testing of U.S. military armament devices.

                     This mission has prevented any leases from being sold in

                     the western portion of the Destin Dome Block.

                                             6-5

                     B. U.S. Department of the Navy

                         The United States Navy (USN) is involved in OCS.

                     activities only as the mission of the Navy is impacted
                     by any industry actions. The Navy's flight training

                     program based in west Florida directly involves the U.S.

                     Navy in the review and comment process for any OCS actions.
                     The Navy must insure'that the requirements for the missions

                     are considered when OCS leases and permits are issued.

               VIII. U.S. Fish and Wildlife Service

                     The U.S. Fish and Wildlife (FWS) provides biological

               assistance and comments for environmental assessments for lease

               sa les, explantion plans, development plans and production plans.

               Ix.   U.S. National Park Service

                     The U.S. National Park Service (NPS) offers comments for

               environmental assessments if any OCS activities are anticipated
               to impact any national parks.

               X.    U.S. Heritage Conservation and Recreation Service

                     The U.S. Heritage Conservation and Recreation Service offers

               comments on sections of environmental assessments that pertain to
               historical and archaeological sites on federally leased lands.

                                          6-6

                        Federal OCS Related Regulatory Mechanisms

                     Any OCS activity must comply with the federal regulatory
               process, however, the exa ct process or procedure for compliance
               depends on.the type and level of the activity that is proposed.
               The following federal statues and regulatory mechanisms have
               been identified as pertinent to the development of OCS resources

                            General OCS__Regulatory Mechanisms

               The Outer Continental Shelf Lands Act Amendments of 1978

               (P.L. 95-372)

               The 1978 Amendments to the 1953 Outer Continental Shelf (OCS) Lands
               Act provided new regulations for the management of oil and naturc@l
               gas resources on the-OCS by the Department of the Interior (DOI).
               The original act emphasized orderly, timely development of mineral

               resources; the protection of the environment; and the receipt of
               fair market value for resources of leased OCS lands. "In contrast,
               the amended act reflects additional concerns about offshore

               activities ... such as:

                     1. Preserving free competition;
                     2.  Encouraging development of improved technologies to
                         minimize human-and environmental damage;

                     3.  Assuring that states receive adequate data at the
                         earliest possible time in order,to plan for anticipated

                         OCS impacts;

                     4.  Assuring states an opportunity to participate in OCS.
                         policy and planning decisions;
                     5.  Minimizing conflicts between oil and gas development/
                                                                               10

                         production and other users of OCS resources;

                                           6-7

                     6. Establishing an oil spill liability fund; and

                     7. Establishing a fund to compensate fishermen for
                         damage to equipment caused by petroleum activities.(2)
              Major regulations which appear in the OCS Lands Act Amendments are:
              A. 43 C.FR 3320.2(d)    The Secretary of the Interior may cancel a

                   lease when:

                    .1. Continued actiVity pursuant to such lease would probably
                         cause serious harm or damage to life, property, any
                         mineral, national security or defense, or to the marine

                         coastal or human environment;

                     2.  The threat of harm or damage will not disappear or

                         decrease to an accept able extent within a reasonable

                         period of time; and

                     3.  The advantages of cancellation outweigh the advantages

                         of continuing such lease or permit in force.

              B. 44 CFR 7 6212 - USGS OCS orders regulate the following:
                     1.  Identification of wells, plat forms, structures, mobile
                         drilling units, and subsea objects;

                     2.  Drilling operations;

                     3.  Plugging and abandonment of wells;

                     4.  Determination of well producibility;

                     5.  Production safety systems;

                     6.  Well completioiy;

                     7.  Pollution prevention and control;

                     8.  Platforms and structures;

                     9.  Oil and gas pip6lines;

                    10.  Sulfur drilling;

                                           6-8

                    11. Production, rates, prevention of waste,, and correlative

                         rights;

                    12.  Public inspecti on of records;

                    13.  Product measurement and commingling; and

                    14... Approval or suspension of production.

                    The three significant programs established by the Amen  dments

               to the OCS Lands Act are the Offshore Oil Spill Pollution Fun  d,

               the Fisherman s Contingency Fund, and the OCS Oil and Gas informa-

               tion Program.

                    The offshore Oil Spill Pollution Fund is   composed of fees

               assessed per barrel of OCS prod uced oil (43 USC 1812(d)), and is.

               available for financing removal and,cleanup Of OCS related oil

               spills. The owner and operator of an offshore facility, including

               pipelines, is liable for all costs associated with removal and

               cleanup, and for damages up to $35 million. Additionally, the

               owner.of a pipeline must give evidence of financial res,ons   . bility
               sufficient to satisfy the maximum amount of liability 3

                    The Fisherman's Contingency Fund is a million dollar fund

               established to provide compensation to fishermen for damages

               incurred and profits lost, as a result of activities related to

               exploration, developme nt, or production of OCS oil or gas (43 USC

               1842). The Fund is maintained by fees collected from OCS lessees,

               holders of pipeline right's-of-way, and holders of exploration

               permits. Compensation from area accounts is available only for

               losses caused by OCS related activities within that particular

               area. if a financially responsible party is liable, the fund
                                                                      U
                                                                        1@o @ns
                                                                        '1

                                                                        3

               makes no payment.- However   if a fisherman suffers uncompensated

                                            6-9

               damage to either his vessel or gear, he may seek compensation from

               the Fund.

                    One of the more important compo nents of the Act provides that
               state and local governments have access to information relating to
               OCS activities and decisions at the earliest possible time so that
               they may effectively participate in OCS policy and planning
               decisions (43 USC 18U (5-)(6) (1978)). Accordingly, the Amend-
               ments established an OCS Oil and Gas-Information Program.

               Submerged Lands Act (P.L. 83-31)

                    This Act establishes state title to lands beneath navigable

               state waters and to the natural resources within such lands and

               waters. Florida's state boundary on the Gulf Coast extends three
               marine leagues (approximately 10.5 miles). Local governments in

               coastal areas should be aware that the term "natural resource.s"
               as it is used in this act "includes oil, gas, all minerals, and

               all marine animal and plant life, but does not include water
               power or the use of water for the production of powei,4 State or
                                                                     __j
               local water controls may be needed considering the high demands
               for water especially during OCS exploration. The Act also main-
               tains the right of the federal government to control these lands

               and waters for the production of power.

               Clean Air Act (P.L.,84-159, as amended by P.L.s 88-206 and 91-604)
                   This Act provides for air pollution prevention/control
               activities and is administered by the Environmental Protection'
               Agency (EPA). National Arhbient Air Quality Standards (Section
               109) have set permissible atmospheric levels for air pollutants.

                                           6-10

              These standards are divided into two categories: primary standards
              to protect public health,,and secondary standards to protect
              welfare, including property and aesthetics. Air emissions from

              certain stationary (industrial) and mobile (automotive) sources

              are also.specifically regulated.

                   Implementation Plans (Section 110) "provides that after June

              30, 1979, no major stationary source shall be constructed or

              modified in.any non-attainment area if the  emissions from such a
              facility will cause or contribute to concentrations of any
              pollutant for which a national ambient air quality,standard is
              exceeded unless ... the plan meets requirements rel ating to'non-
              attainment areas.rt@.@5
                   section 111 requires the EPA Administrator to set standards
              of performance for new stationary sources and revise them every
              four years. The New Source Performance Standards limit emissions
              from major new industrial sources. Also, if a new industry locates
              in a non-attainment area that industry must insure that a pre-
              viously existing industry reduces its pollution by more than the
              new'source will emit. This is known as offsetting and theoretically
              reduces emissions while adding industry. Section 112 requires the
              Administrator to establish national emission standards for hazard-

              ous air pollutants. The Act requires states to have a State
              Implementation Plan for achieving federal air quality standards
              and provides for Prevention of Significant Deterioration which

              prevents 1ndustries from moving out of developed areas to less.
              developed areas in order to avoid pollution control requirements.
                   Acid rain is a special problem in air pollution resulting

                                           6-11

               when sulfur oxide and nitrogen oxide emissions in the air are

               transformed into sulphuric and nitric acids and fall as rain.
               OCS storage facilities as' well as coal burning power plants con-

               tribute these pollutants to the air. OCS facilities and the

               additional electrical power they require to operate could worsen

               the already significant acid rain problem.

               Federal Water Pollution Control Act (FWPCA  or Clean Water Act

               (P.L. 845 as amended by P.L.s 579 and 660)

                    The objective of this Act is to restore and maintain the

               chemical, physical, and biological integrity of the Nation's

               waters. The Act directs  the EPA Administrator to establish

               Federal Standards of Performance for new source facilities and

               establishes the National Oil and Hazardous Materials Pollution

               Contingency Plan. Section 303 of the Clean Water Act establishes

               water quality standards. Sewage water contains large concentra-

               tions of organic matter, suspended solids and plant nutrients

               (nitrogen and phosphorus compounds) and is an excellent medium

               for the transfer of disease., For these reasons, sewage waste-

               water discharges are carefully regulated and treatment is

               required to allow receiving waters to continue to be utilized

               to support freshwater or marine aquatic life, swimming,  and

               shellfish harvesting.

                    An individual utilizes approximately 40 gallons of water

               each day to dispose of sewage wastes. It is evident that OCS

               related facilities which employ the largest number of workers,

               (e.g., refineries, petro-chemical plants, and platform fabrica-

               tion yards), are potentially capable.of causing the greatest

                                            6-12

               environmental impact from sewage discharges. Usually, the sewage
               will either enter an approved septic system or be discharged to
               a sewage system for treatment and disposal at another location.
               When sewage is properly treated prior to discharge, no appreciable
               harm should occur within the receiving waters provided that the
               effluent is discharged into receiving waters where disposal is
               permitted and dilution and dispersion can occur. However, should
               the receiving waters also contain high organic carbon concentra-
               tions, toxic levels of organic-chlorine compounds (e.g.,
               chloramines, chloroform) could be produced.
                   Marine terminals may generate the following types of waste-
               water: domestic (sewage); bilge; ballast; cooling; boiler; proce@;s;
               and runoff. Bilge water generated by tankers and tugs servicing
               a marine terminal is collected at the terminal and treated prior
               to discharge. Discharge of bilge will have minimal environmental
               impact if treatment includes the removal of toxic substances.
               Ballast water is taken on by tarikers after unloading to improve
               handling and is therein contaminated with oil. It also often has
               a high biological oxygen demand, a high concentration of fecal
               bacteria, and heavy metals. Ballast water can be toxic to aquatic
               life. Federal regulations require it to be treated prior to dis-
               posalf- if treatment facilities are available. Some new tankers

                                      n
               have separate ballast ta ks to avoid contamination.

                   Section 311 directs the President to.publish a National
               Contingen cy Plan for the removal of oii and hazardous substances
               and specifies liajbility and recovery of removal cost.
                   In addition, the Act provides control over thermal discharges
               to receiving waters. Partial oil/gas processing facilities in

                                          6-13

               combination with related marine terminal facilities may cause
               large net increases in receiving water temperature. These
               increases in water temper ature can kill aquatic 14 fe and may also
               increase the solubility of heavy metals and toxic substances.

                    Thermal discharges which will cause appreciable harm to,
               the balanced indigenous population of fish, shellfish, and
               wildlife in or on the receiving waters are prohibited. "The

               operator of,a marine terminal may be permitted however, to exceed
               federal standards if he can sh   that the heat discharge does not
                                             0 t
               harm receiving water organisms.@,6)
                    Section 402 of the Clean Water Act establishes the National

               Pollutant Discharge Elimination System (NPDES) program. This

               program regulates the discharge of pollutants from point sources
               (such as OCS facilities) and related activities into United States'

               waters. All such discharges or activities are unlawfu 1 without

               an NPDES permit. A permitted discharge that does not comply with
               the'terms.and conditions of the-permit is also unlawful. A dis-
               charge of a pollutant is defined as 1) any addition of any
               pollutant or combination of pollutants to waters of the U.S. from
               any point source, or 2) any addition of any pollutant or combina-
               tion of pollutants to the waters of the contiguous zone or the
               ocean from any point source other than a vessel or other floating
               craft which is being used as a means of transportation (40 CFR
               122.3). The last clause  is significant because it gives EPA
               jurisdiction over floating OCS facilities, since they are not
               being used as a means of transportation.

                   The NPDES program performs three basic functions. First,

                                           6-14

               it sets limitations, on discharges, based on the effluent guidelines
               developed by EPA for the.oil and gas extraction industry. Second,
               it outlines requirements for monit oring discharges, and reporting
               actual volumes discharged and any permit violations to EPA. Third,
               it imposes a schedule of compliance for the permittee to complete
               constructionor to install new pollution  control technology.
                    Discharges of ammoni ai heavy metals, suspended solids, oil
               and grease,.phenol and heat are regulated for each industry

               ca--egQry (such as petroleum refining) by the NPDES. In addition,
               quality standards for receiving waters have been set by individual
               states, with the assistance offederal water quality guidelines.
               Thes'e standards vary depending on whether the receiving water in'
               question is used for-public water supply, recreation, irrigation,
               fishing or.other uses. Discharges which threaten to increase

               pollutant concentrations in a body of water in excess of standards

               set by the state are prohibited. Therefore, although a discharge
               may meet the requirements stated in an NPDES permit, additional
               pollutants reduction may be necessary to ensure that the standards

               for the receiving water are not exceeded as a result of the

               chemically contaminated discharge. Cooling water from power
               facilities (marine terminals may generate their own electricity)

               must meet NPDES. discharge limits.

                   Brine water has a unique status under the Clean Water Act.

               The  term "pollutant" in the Act is defined to exclude "water
              -derived in association with oil or gas production and disposed.
               of in a well, if the well.is used either to facilitate production

               or for disposal purposes, is approved by authority of the state

                                          6-15

              in which the wellis located, and if the state determines that

              such injection or disposal will not result in the degradation of

              ground or surface water resources." Therefore, the disposal of

              brine from the crude oil stream by injection into a  well is

              regulated at the state level; disp osal into surface water requires

              a permit under the National Pollution Discharge Elimination System

              (NPDES).

                   Stormwater runoff from tank storage areas and process areas

              at a terminal is collected, stored, treated and discharged with

              the process water. Effluent stormwater runoff from.the storage

              areas may not exceed a concentration of 35 parts per million of

              total organic carbon or 15 parts per million of oil and grease

              when discharged (40 CPR 419.12(b)(3)(c)(1)).

                   A policy statement in the Federal Water Pollution Control Act

              of 1972 declared that no discharge of oil into or upon navigable

              waters of the United States, adjoining shoreline, or into or upon

              the waters. of the contiguous zone (12 miles out from shore) shall

              be allowed. Regulations, howeverf- apply only to harmful quantities

              of oil, defined as those which: 1) exceed.water quality standards,

              or 2) produce a sheen on the surface of the water or form an

              emulsion or sludge. The Oil Discharge Regulations (40 CFR 110)

              require.that discharges of this magnitude be immediately reported

              by the owner of the property from which the spill originated so that

              clean up activities both by the owner and others as necessary can

              proceed. This legislation applies to both point and non-point

              discharges.

                   Since OCS facilities  are not presently considered to be new

                                            6-16

               sources (40 CFR 122.66(a) and (b), EPA is no t required to prepare
               National Environmental Policy Act (NEPA) related documents in
               its review of a permit application except where rigs will be
               operating in areas which have @een designated "environmen.tally
               sensitive" by the Bureau,of Land Management (B LM) (45 Federal

               Regulation 68391, October 15, 1980    If the decision is to
               issue a permit, a draft permit is formulated specifying any limita-
               tions and requirements. A fact sheet or a statement of basis is

               prepared to accompany each draft permit and to explain the
               technical and legal basis for the terms of the permit (40 CFR
               1-24.7 and 124.8). A fact sheet presents this information in
               greater detail than a statement of basis and is prepared in cases
               of major discharges, widespread public interest, or where major
               issues are raised. An administrative record for each permit is
               available to the public for inspection and reproduction (40 CFR

               124.9).

                   Actually, most of the drilling currently done  on the OCS is
               done without an NPDES permit. EPA has sent most applicants
               letters of nonobjection. EPA sends the letters to operators
               within 30 days after receipt of a request for a permit. Permits

               are gnerally issued at a later date.

                   In cases of initial licensing, EPA prepares a draft permit
               and issues a public notic e (40 CFR 124.113). Any person may then

               request a panel hearing on the draft permit. The request must
               include ob jections to the draft permit and issues to be raised

               at the hearing. Denial of a panel hearing may be appealed to

               the Administrator.

                                           6-17

                    If EPA elects to hold the hearing, public notice of it is

               issued. Any person may request to participate (40 CFR 124.117).
               Thirty or more days before the hearing each party to the   'hearing
               must file comments on the draft permit. These comments@con-

               stitute evidence to be presented at the hearing (40 CFR 124.118).

               After.the hearing, the presiding officer prepares and files a

               recommended decision incl'uding any modifications on the permit
               .(40 CFR 124.,124). Copies of the decision are sent to each party
               and the Administrator. Unless the recommended decision is appealed.

               to the Administrat or, or the Administrator elects to review the

               decision, it becomes final once the time for filing any appeals

               has expired (40 CFR 124.127).

                    Any person may request an evidentiary hearing to contest the

               final permit decision (40 CFR 124.74(c)(8)). No issue may be

               raised at an evidentiary hearing that was not raised during the

               comment period on the draft permit unless good reason can be

               shown for the failure to raise it (40 CFR 124.76). Any person

               may submit a request to be admitted as a party to the hearing
               within 1.5 days after the public notice is issued. After expira-
               tion of the public notice period, any person may file a motion

               to intervene as a party, if certain requirements are met (40 CFR-

               124.79(b)). Such requests must specifically identify the issues

               which the requester seeks to address at the hearing (40 CFR

               124.79). After the hearing the presiding officer reviews the

               record and issues an initial decision. This decision becomes

               effective within 30 days unless an appeal is made to the Adminis-

               trator or the Administrator elects to review the decision.

                                            6-18

                    States can participate in the 402 program by establishing
               water quality standards (Section 303, Clean Water Act) granting
               or denying certification,of EPA's draft   permits wherever dis-
               charges occur within their territorial limits, or by sharing
               with EPA in the permit development process.
                    When a discharge occurs beyond the territorial limit, states

               may participate through:

                    1. Review and comment upon draft permits;
                    2.  Oral and/or written testimony at public hearings;
                    3.  Participation in evidentiary hearings;
                    4.  Appeal of decisions made at   evidentiary hearings or
                        denial of an evidentiary hearing   to the Administrator;
                    5.  Participation in initial licensing procedures; and
                    6.  Appeal of decisions made at panel hearings or denial of

                        a panel hearing to the Administrator.
                    Finally, states with approved Coastal Zone Management (CZM)
               programs,.such as Florida, may review draft permits for consistency
               with these programs. Section 401 of the Clean Water Act requires
               that anyone proposing to conduct any activity which may result in
               the discharge of a pollutant into waters of the United States

               must provide the permitting agency with a certification from the
               state in which the discharge originates. This ensures that the
               discharge will comply with applicable effluent limitations and

               water quality standards (33 USC 1341).

                    if th e state fails or refuses to act upon a request for
               certification within a reasonable period of time (three.months),
               the certification requirements shall be waived (33 CFR 325.2(b)(1)).

                                             6-19

               No license or permit shall be granted until the certification

               required by this section has either been obtained or waived.

               No license or permit shall be granted if state certification

               has been denied.

                    Section 304 of the Clean Water Act, Ocean Discharges, states

               that in.any event where insufficient information exists on any

               proposed discharge to make a reasonable.judgment on any of the

               guidelines established pursuant to Subsecti  on 304 (C)(2), no

               permit shall be issued.

                    Section 404 of the Clean Water Act rpgulates the discharge

               of dredged or fill materials  in.to the waters of the United States,

               including adjacent wetlands.   The program is administered by  the

               Army.Corps of Engineers (COE), which has primary responsibility

               for issuing discharge permits, while EPA holds veto power over

               the location of the disposal site. The disposal of dredged or
               fill material in wetlands/aquatic ecosystems may destroy or

               alter habitats, increase sediment loads and bottom sedimentation,
               and alter hydrologic patterns. The generalecosystem may also
               experience a reduction in species variety and productivity, depend-
               ing upon the type of wetland, the activities involved, and the

               volume and type of material used. The Section 404 program requires

               that adverse impacts be assessed prior to the discharge of dredged

               or fill material into waters of the United States. In addition

               to a public interest review by the COE prior to issuing Section
               404 permits, environmental and social factors, and the existence

               of alternate sites must be considered. Losses to the public as

               a result of damage to an aquatic ecosystem must be balanced against

                                            6-20

                the public benefits derived from a project.

                    Florida's role in the federal Section 404 program is limited

                to the following: Affected states receive public notice of all

                applications for permits and are invited to comment on proposed
                activities when circumstances warrant a public hearing (33 CFR

                325.3(c)(1)).. State certification and waiver conditions are

                the same as those described in the federal   Section 402 program.
                    Section 404''was the only water quality regulatory program

                under the 1972 Clean Water Act that was not originally intended

                to be.administered by state governments. ..However,.in 1977 Congress

                amended Section 404 to  allow the states, at their discretion, to

                assume responsibility for the administration of the Section 404

                regulatory program, including the issuance of general permits
                (33 USC 1344(g)(1)). Besides protecting wetlands and aquatic
                ecosystems within their borders, states can include regulation
                of wetlands use in their general planning for growth and develop-

                ment.

                    The  transfer of Section  404 program responsibilities to a

                state is subject to approval by EPA. This approval is conditioned

                upon the state's adoption of a program which assumes that dis-

                charges will comply with Subsection 404(b  ) guidelines. The 1977
                amendments also gave the EPA responsibility for overseeing state
                Section 404 programs. Fl.orida does not presently have a.state

                Section 404 program.

                    in t he absence of an approved state program the COE retains
                jurisdiction over the permit program. Since most pipeline

                construction is accompanied by discharge activities, the selection

                                             6-21

               of disposal sites must be consistent with guidelines developed by

               EPA in consultation with the COE. If EPA determines   that the

               proposed discharge will have an unacceptable adverse  environmental

               impact it is authorized to prohibit or restrict the activity

               (33 USC 1344 (c)).

               Marine-Resourc'es and Engineering Development Act of 1966,

               Including Title III, Coastal Zone Managemen-t Act of 1972 (P.L.

               89-454, as amended by P.L.s 89-688 and 92-583, respectively)

                    Title I of this Act provides for the accelerated development

               of marine resources and for the expansion  of knowledge concerning

               the marine.environment.

                    Title III of this Act is the Coastal Zone Management Act

               (CZMA) of 1972.. This Act, administered by the Department of

               Commerce (DOG), sets major goals for the following: protection,

               development,.and restoration of natural and historic resources;

               in creased recreational access and management of coastal development;

               and coordination/streamlining of federal and state decisions

               affecting coastal resources. The CZMA is a major tool which states

               can use to coordinate the many federal regulatory measures enacted

               during the 1970s, such as the National,Flood Insurance Progra m,

               the Deepwater Port Act of 1974, Fishery Conservation and management

               Act of 1976, and the OCS Lands Act Amendments of 1978. The CZMA

               allows affected states the opportunity to participate in and plan

               for the impacts on their coastal areas from oil and gas production

               in federal OCS areas. Also, the CZMA has the potential for use

               as a mechanism to delay oil and gas operations in federal

               territories.

                                             6-22

                    Each participating state is required to submit a coastal

               zone.management program to the DOC. States with approved programs

               have greater control over activity in the federal OCS.   If a state

               is not receptive to federal OCS development, it could delay OCS,

               activity.by requesting modification or denying certification near

               the end of its six month'time frame. This tactic could result in

               prohibiting any OCS oil and gas operations  from taking place,

               since the state review would allow another*six month period.

               However, if the affected state does not respond in some manner

               within three months after receiving a proposal,  it.is conclusively

               presumed that the state concurs.with the proposal.

                    Upon final approval of a state management program, which must

               provide adequate consideration of national interests in the siting

               of facilities, the state becomes eligible for grants under Section

               306 of the CZMA. These facilities would include energy production

               and transmission facilities, national seashores, military installa-

               tions, and interstate highways. There is some fear that the Act's

               language will compel states to locate facilities which might be

               detrimental to environmental protection in coastal areas. However,

               the CZMA regulations state that, "the requirement should not be

               construed as compelling the states to propose a program which

               accommodates certain types of facilities, but to assure that

               national concerns are included at an early time in the state's

               planning activities and that such facilities not be arbitrarily

               excluded from or unreasonably restricted in the management program

               without good and sufficient reasons."

                    The 1976 amendments to the Coastal Zone Management Act extend

                                            6-23

               the  federal consistency requirements to include Outer Continental

               Shelf (OCS) energy exploration, development and production.

               Spec ifically, federal agencies must "provide state agencies       with
               consistency determinations for all federal activities significantly

               affecting the coastal zone ... at the earliest practical time in the

               planning of the activity," according to federal consistency

               regulations.

                     Section. 307.of the act deals with in  ter-agenc.@, coordination

               and cooperation. Local governments must consider state and regional
               interests in exercising their regul    atory powers in the coastal tone,

               and federal actions within or directly impacting the coastal zone

               must be consistent with a state's program once that program has

               been approved by the Secretary of Commerce. However, should the

               state determine that a project is inconsis    tent with its program,
               it may request mediation efforts by the Secretary of Commerce-.

               If it is det ermined that the proposed federal action is consistent

               with the purpose of CZMA or nece@ssary in the interest of national

               security, the state's objection may be overruled. Confusion has
               arisen over the consistency Subsection 307(c)(1) phrase "directly
               affecting" the coastal zone in regards to prelease activities.

               Prelease activities include: 1) call for nominations and comments;

               2) tentative tract selection; 3) environmental statements; and 4)

               consultation with governors. The DOI has taken the position that

               prelease sale activities do not directly affect the resources in

               the coastal zone.

                     The state of  Californ ia contends that prelease activities     do
               directly affect the resources of the coastal zone because they

                                              6-24

               initiate a chain of impact-producing events. California is

               currently in litigation with the Secretary of the Department

               of the Interior over this issue. The language of Section 307

               (c) (1) is unclear and the act itself provides no definition of

               key terms. Therefore, the U.S. District Court in the State of

               California v. Watt (CV81-2080) had to turn to the Act's stated

               purposes, its legislativ6 history, and the interpretations of

               agencies charged-with administering the Act. The District Court

               determined in favor of California that decisions made during

               preleasing establish the timing of OCS development and production,

               and therefore, do "directly affect" the coastal zone. The Court's

               evaluation determined that the intent of the CZMA was to involve'

               states in the consultation process at the earliest time to prevent

               unnecessary losses in the coastal zone, and to encourage coopera-

               tion between federal, state and local governments rather than

               conflict. The case will go to the Supreme Court for a final

               determination.

                    Additionally, state agencies are required as part of their

               management program to develop a list for consistency review of

               federal permit activities which are likely to affect the coastal

               zone. If the state agency elects to review federal permits for

               activities outside of the coastal zone but likely to affect the

               coastal zone, it must generally describe the geographic location

               such activities (15 CFR 930.53(b)). The permit list may be

               amended by the state following consultation with the affected

               federal agency and approval of the National Oceanic and Atmospheric

               Administration (NOAA). Copies of the list and any amendments

                                           6-25

               shall be provided to federal agencies and the public by the state
               (15 CFR 930.53(d)). With the assistance of federal agencies,

               states are encouraged to mon itor unlisted federal permit
               activities and notify federal agencies and applicants of unlisted
               activities affecting the coastal zone which require state review.
               Monitoring can be undertaken through the use of the A-95 process,
               review of NEPA Environmental Impact Statements or by a Memorandum
               of Understanding-to ensure that the state has an opportunity to
               review any federal permit activity which can be expected to affect

               the coastal zone (15 CFR 930.54(a)).. If the state.believes that
               an unlisted activity should be @subject to state review, it must
               notify NOAA. Following notification to the federal agency by the
               applicant and NOAA, the federal agency may not issue a permit
               unless NOAA disapproves the state's decision to review the activity
               or certain requirements are satisfied (15 CFR 930.54(b)). The
               federal agency and the applicant must provide comments to NOAA
               within 15 days from receipt of the state agency notice. The basis
               for NOAA's approval or disapproval is whether the proposed
               activity-can reasonably be expected to affect the coastal zone
               of the state. NOAA's deci sion shall be issued, along with support-
               ing comments, within 30 days (15 CFR 930.54(d)).  In the event of
               serious disagreement between a federal agency and a state regarding
               whether an unlisted activ.ity is subject to consistency review,
               either party may request mediation by the Secretary of Commerce
               (15 CFR 930.55)).

                    When satisfied that the proposed activity is consistent with
               the provisions of the CZM program, an applicant for a federal

                                            6-26

               permit subject to state review must provide in the application

               a certif ication that the,proposed activity complies with and will

               be conducted in a manner consistent with the state's approved

               management program. A copy of the certification must also be

               provided-to the state along with supporting information (15 CFR

               930.57(a)). The supporting information shall furnish the state

               with a description of the-proposal adequate to permit an assessment

               of the probable  coastal zone effects, and a set of findings

               indicating that the proposed activity, its associated facilities,

               and their effects, are all consistent with the provisions of the

               management program (15 CFR 930.58 (a)).

                    State review begins when the state receives the applicant's

               consistency certification and the supporting information (15 CFR

               930.60(a)). The state ensures timely public notice of the pr   o-
               posed activity which must include a summary of the proposal, an

               announcement that public information subm itted by the applicant
               is available for inspection, and a statement inviting comments

               (15 CPR 930. 61 (b)

                    Federal and state agencies are encouraged to issue joint
               public notices and hold joint public hearings whenever possible
               to minimize duplication of effort and to avoid unnecessary delays
               (15 CFR 930.61(d) and 15 CFR 930.62, respectively).
                    At an early stage, t.h(@ state must notify the federal agency
               and the applicant whether it concurs with, or objects to, the
               consistency certification.   In the absence of an objection, con-

               currence by the state will be conclusively presumed six months

               after commencement of state review (15 CFR 930.63 (a)). If the

                                            6-27

               state has not issued a decision within three months following the

               revie w, it must notify the applicant and the federal agency of the

               status of the matter and the'basis for further delay (15 CFR 930.

               763(b)).

                    If the state objects to the  consistency ce rtification, it must

               notify the applicant! the federal agency and NOAA of its objection.

               The state must describe how the proposed activity is inconsistent

               with specific elements of the management program. A state objec-

               tion must also include a statement informing the applicant of a

               right of  appeal to the Secretary of Commerce (15 CFR 930.64)-.

               Following receipt of a state agency objection to a consistency

               certification, the federal agency may not issue the license or

               permit except as provided below (15 CFR 930.65):

                    1. The parties should consult informally to try to resolve

                         the matter. NOAA's Office of Coastal Zone Management

                         is available to assist the parties in discussions

                         (15 CFR 930.124).

                    2.   If there is still disagreement, the applicant may file

                        ,a notice of appeal with the Secretary of Commerce within

                         30 days of receipt of a state obje ction. Copies of the

                         notice and supporting documents must be sent to the state

                         and federal agency involved (15 CFR 930.125(a)).

                    3.   Upon receipt of the notice of appeal the state and the

                         'federal agency will have 30 days in which to submit

                         comments to the Secretary of Commerce. Comments are

                         forwarded to the.applicant and the agency within the

                         same time period (15 CFR 930.126(a)).

                                                 6-28

                   4. The Secretary of Commerce shall provide public notice

                        of the appeal in the immediate area of the coastal zone

                        which is li kely to be affected by the proposed activity

                        (15 CFR 930.127(a)).

                   5.   Following public notice, receipt of comments and possibly

                        a hearing, the Secretary of Commerce must determine if,

                        the proposal is bonsistent with the objectives of the

                        CZMA, or is necessary in the interest of national security

                        (15 CFR 930.130(a)). The Secretary of Commerce shall

                        issue a decision in writing.to the applicant, the state,

                        an d the federal agency.(15 CFR 930.130(c)).

                   6. .,If the Secretary of Commerce finds that the proposed

                        activity is either consistent with the objectives of the

                        CZMA or is in the interest of national security, the

                        federal agency may approve the permit activity (15 CFR

                        930. 131 (a)

                   7.   If the Secretary of Commerce does not make either of these
                        findings, the federal agency is prohibited from approving

                        ,the activity (15 CFR 930.131(b)).

                   Important sections of this Act in regard to funding include
              Section 308 which establishes the Coastal Energy Impact Program
              with grants for qualifying coastal states and Subsection 315(l)
              which provides 50 percent  federal matching grants for the acquisi-

              tion of estuarine sanctuaries for conservation and for use as

              laboratories for education and research. Five sanctuaries have

              been established. The federal share of any individual estuarine

              sanctuary cannot exceed two million dollars. In addition to these

                                          6-29

               funded sections, the CZMA includes grant provi-sions for interstate

               planning (Section 309), research, technical assistance and training

               (Section 310) and public access to beaches and other coastal areas

               of special value (Subsection 315(2)).

               The National Environmental Policy Act (NEPA) of 1969 (P.L. 91-190
              -as amended by'P.L.s 94-52 and 94-83

                    EPA requires that all federal agencies- proposing actions
               significantly affecting the quality of the human environment

               consult with other agencies having jurisdiction by law or expertise

               over such environmental concerns and prepare a detailed statement

               including:

                    1.  The environmental impact of the proposed action;

                    2. Any Adverse  environmental effects which cannot be

                        avvoided if the proposal is implemented;

                    3. Alternatives to the proposed action;

                    4.  The relationship between local short-term uses of man's

                        environment and themaintenance and enhancement of long-

                        term productivity, and;

                    5.  Any irrev ersible and irretrievable resource commitments

                        involved if the proposed action is implemented.
                    Copies of such statement and the comments of appropriate
               federal, state and local agencies shall be made available to the
               President, the Council on*Environmenta-1 Quality and to the public
               as provided by Section 552 of Title 5 USC, and shall accompany the
               proposal through the existing agency review processes (42-USC 4332).

                    In July 1979 the Council on Environmental Quality's regulations
               for implementing the provisions of NEPA (40 CFR 1500 et. seq.)

                                            6-30

               became effective. Federal agencies undertaking a major action

               must produce a public record indicating the manner in which the

               Environmental Impact Statement was utilized in the decision processf

               and which alternative's were considered in the EIS for minimizing

               environmental impacts.

                    40 CFR Section 1501 requires the integration of NEPA into

               planning at the prelimina:ry stages to ensure consideration of

               environmental concerns. Part 1501.4 outlines the criteria for

               determining if an activity is a major federal action requiring

               preparation of a full EIS.

                    Section 1502 of NEPA requires that an EIS be prepared as

               early as possible so that it can be included in recommendations

               on the final proposal.

                    Section 1504 establishes procedures for referring unresolved

               conflicts concerning propo sed federal actions to the Council on

               Environmenta 1 Quality. This procedure in effect extends the NEPA

               process, and the agency is precluded from taking any action on the

               proposal until the conflict has been resolved.
                    Section 1506 prohibits a federal agency from undertaking
               actions having any adverse environmental impact while the review

               process is underway. Subsection 1506.2 authorizes affected state

               and local governments to contribute to the preparation of an EIS.
               in order to eliminate duplicate EIS preparation.

                    section 1507 requires that all federal agencies comply with

               NEPA regulations and that environmental impact statements and

               comments on the statements be adequately prepared. In recent

               years court challenges contending that EISs were not prepared

                                            6-31

               by DOI in accordance with NEPA criteria have occurred in a   11 OCS
               areas. These have delayed OCS exploration, development, and

               production activity by three months to two years.

                    The construction of a pipeline requires that a   number of

               federal permits be obtained. For each permit, the agency     with

               the primary permitting responsibility is designated as the lead

               agency. Other federal agencies with jurisdiction over areas

               affected by pipeline activity are included*  in the NEPA process.

               All involved agencies, however,  may combine their procedures    to

               satisfy NEPA and other requirements simultaneously.

                    When the environmental review indicates that no significant

               impacts are anticipated, or when a project is altered to eliminate

               significant impacts, a Finding of No Significant Impact (FONSI) is
               issued. The environmental assessment shall be included as par    t of

               the FONSI.

                    Once a decision to prepare an EIS is made, notice of intent

               must be published in the Federal'Register and appropriate federal,

               state and local agencies must  be invited to participate in the

               scoping process. During this process, the range of actions,

               alternatives, and imp-acts is determined, and significant issues

               to be analyzed are identified.

                    An EIS is initially prepared and circulated for review in

               fraft form. Copies of the draft are submitted to the Governors

               of affected states, CZM agencies of states with approved CZM

               programs, and upon request,  to local government officials. The

               draft EIS is also availabl.e to affected federal agencies, and

               the public.

                                             6-32

                    The review period for a draft EIS is generally 45 days,

               although this is frequently extended for major pipeline projects.

               Interested parties are encouraged to submit written comments

               during this period. After evaluation of comments received, a

               final EIS is prepared which must list any mitigative measures

               necessary to make the recommended alternative environmentally

               acceptable. A decision on a proposed activity is usually made

               within 60 days after the release of the final EIS, though

               decisions on major projects may take longer. The lead agency

               prepares a concise public record of the decision and provides

               a monitoring mechanism to assure proper implementation of the

               decision..

               Coastal Barrier Resources Act of 1983 (PL,97-348)

                    The Coastal Barrier Resources Act prohibits federal

               subsidies for flood insurance, bridge construction, sewage treat-

               ment facilities and other construction on designated undeveloped

               barrier islands. The Coastal Barrier Resources Act:

                    1. Establishes a coastal barrier resources system

                        consisting of undeveloped barrier islands, beaches

                        and spits on the Atlantic and Gulf coasts;

                    2.  Prohibits new federal expenditures and federal

                        financial assistance within the-coastal barrier

                        resources system;

                    3.  Maintains federal assistance for energy facilities,

                        navigation channel maintenance, air and water naviga-

                        tion aids, and emergency disaster assistance; and

                    4. Preserves local zoning and permitting authority.

                                           6-33

               Solid Waste Utilization Act as amended by the Resource Recovery

               Act of 1970

                    This Act requires that EPA establish criteria for identifying

               hazardous wastes and a federal permit program (similar to the NPDES

               program) to regulate their handling and disposal).

                    In cases of specific hazardous toxic substances (such as

               cyanide), the federal goviarnment becomes involved in waste manage-

               ment. Generally, however, solid waste management is a state

               responsibility.

                    Solid wastes are generated by offshore oil operations and

               service bases. Offshore wastes are the more significant in terms

               of both quantity and environmental impacts. During drilling

               operations,. approximately six tons of solid wastes-will be

               generated per well per day. This includes drilling wastes, such

               as mud, mud additives, bit cuttings, sand and sludges collected
               in separatio n vessels and tanks; galley garbage; oily sludges;
               lubrication oils and waxes; ragg, packaging wastes; drums, spools,

               cables, and scrap metals; and human wastes. Some of this material

               is treated.and disposed of At sea, but a   large quantity is returned

               to shore through the service bases.

                    Offshore operators are not permitted to dispose of any oiled
               drilling mud and drill bit cuttings at the platform. Discharges
               of non-oiled drilling mud and cuttings are permitted in federal

               waters.

                    Since drilling wastes often contain hazardous materials,
               such as oil, acids or heavy metals, they must be disposed of in
               a special landfill site where there is not dan   ger of penetrating
               the ground water, running off into surface waters, or evaporating.

                                             6-34

               This may prove difficult in Florida due to its geology, soil

               and climate-conditions.

                    Less hazardous offsh ore wastes, such as scrap metal, paper,

               or wood products, are recycled or treated at the   service base

               before disposal in an  incinerator or sanitary landfill.
                    Solid wastes generated by service base operation include
               dunnage (material used to protect cargo) collected during boat
               unloading, garbage from supply and crew boats (approximately 6.5

               lbs. per person per day) and garbage/refuse from service base

               employees. These wastes can be incineratQd, disinfected and
               used as landf,ill or, in the case of garbage., ground up and.dis-
               posed of-with the sewage. Little adverse environmental impact
               is anticipated if these materials are disposed of in accordance

               with existing regulations.

               National Historic Preservation Act of 1966 (P.L. 89-665 as

               amended by P.L.s 91-243, 93-54, 94-422, 94-558 and 96-625 and

               Executive order (EO) 11593

                    The National Historic Preservation Act (NHPA) of 1966, as
               amended, authorizes the Secretary of the Interior to expand and
               maintain a National Register of districts, sites, structures,
               and objects significant in American history, architecture,
               archaeology, and culture. The Act provides for the nomination
               of properties of national', state, or local significance for
               placement.in the National Register but prohibits the listing of
               privately owned property when the owner objects in writing. The
               criteria for including pro'perties in the National Register

                                            6-35

               (36 CFR 60.2) provides the standard to judge whether a cultural

              .property is important enough to warrant special consideration
               during the planning of federal undertakings.
                    section 106 of the Act requires federal agencies to take
               into account properties listed in the National Register or that
               meet the criteria of the National Register during the early
               planning of federal proje'cts. The agency must allow the Advisory
               Council on Historic Preservation a reasonable opportunity to
               comment when cultural properties are affected by its project
               (36 CFR Part 800). The goal of Section 106 is to ensure that
               alternatives that avoid or minimize damage to significant cultural
               properties are examined in all federally supported actions. If
               the agency complies by considering Council comments, then it may
               proceed with any course of action thatit feels is justified.

                    Prior to approving any action that would foreclose.alterna-
               tives or the Council's ability to comment, the lead federal agency
               shall take the following steps according to EO 11593:
                    1. Identification of properties eligible for or listed in

                        the National Register

                        The agency official shall consult the State Historic

                        Preservation Office, the published lists of National
                        Register and National Register eligible properties,
                        public records, and experts in the field to determine

                        if there are any properties within the area of the
                        undertaking's potential environmental impact that

                        warrant special a.ttention.
                        If a property meets the National Register Criteria,

                                           6-36

                         or may mee t the Criteria, the agency shall request a

                         determination of.eligibility from the Secretary of DOI

                         (36 CFR 63). If the a          d the State Officer   agree
                                                .gency an

                         that no property within the area meets the Criteria, this

                       ..finding must be documented.

                     2.. Determination of effect

                         The agency and the State Historic-Preservation Office

                         must apply the Criteria of Effect (36 CFR 800.3(a) to
                         each National Register or National Register eligible
                         property within the area of-the undertaking's potential
                         impact. If both parties agree that the undertaking will
                       ..not affect the vital characteristics of the property, the
                         undertaking may proceed. In the case of an objection to

                         a determination of no effect,.the Executive Director of

                         the Advisory Council may review the determination and

                         respond to the objecting party within 15 days.

                    3..  Determination of no adverse effects

                         Determinations by the agency official and the Historic

                         .Preservation Officer must be documented and forwarded to

                         the Executive Director for review (36 CFR 800.6).

                    4. Adverse effect determination

                         If the agency finds that the undertaking will have an
                         adverse effect on the characteri stics of the property,
                         or if the Executive Director does not accept a determina-
                         tion of no adverse effect the agency shall: 1) prepare a

                         case report requesting the comments o f the Council; 2)

                         notify the State Historic Preservation Office of this

                                             6-37

                        request; and 3) proceed with the consultation process.

                    5.  Suspense of action

                        Until the Counci 1 issues its comments, good faith

                        consultation precludes a federal agency from making or

                      ..sanctioning any irreversible or irretrievable commitment

                        that.could result in an adverse effect on any property
                        eligible for or listed in the National Register (36 CFR

                        800.4 (a-e)).

                    The State Historic Preservation Officer may participate in
              the review process whenever it concerns an.undertaking located
              within the state's jurisdiction. Unless an extension is agreed

              upon, the..State Historic Preservation Officer may take up to 30
              days after receipt of a consultation request to respond. If the
              Officer does not respond within 30 days,. the agency may proceed

              with the review process.

                    State nominations need not be limited to state-held proper-
              ties. Federally owned properties may.also be nominated by a state.
              It is unclear, however, if this would include federal property
              outside state borders. In such cases, the State Historic Preserva-
              tion Officer shall notify the appropriate federal representative
              in writing before the nomination is forwarded to the National Park

              Service (36 CFR 60.11(d)).

                    To fulfill Section 101(b)(4) of NEPA regarding the preserva-
              tion of our national heritage, federal agencies should coordinate
              NEPA and Na tional Historic Preservation Act (NHPA) responsibilities
              to ensure that historic/cultural properties.are given proper

              consideration in the prepartation of environmental assessments

              and environmental impact statements.

                                          6-38

             occupational Health and Safety Act of 1970 (P.L. 91-596 as

             amended by P.L.s 93-237 and 95-251)

                   This Act protects workers from excessive, injurious noise
             and limits noise levels to 90 decibels for an eight hour day. It
             also stipulates.that the permissible exposure time.must be halved
             for every five.decibel increase. For instance, noise levels of.
             100 decibels are allowed for only two hours/ day. Noise will be

             produced during construction of OCS facilities and at marine

             terminals from compressors and boilers and to some extent from

             tankers and barges.

             ENVIRONMENTAL LEGISLATION
             Marine Mammal Protection Act of 1972(P.L. 92-522 as amended by
             P.L.s 93-205, 94-265, 95-136 and 95-316)
                   This Act (50 CFR Part 216) establishes a national policy
             designed to protect and conserve marine mammals and their habitats.
             The Act specifically prohibits the harassing, hunting, capturing,
             or killing of any marine mamma 1 unless otherwise exempted under its
             provisions. The Marine Mammal Commission is responsible for
             advising federal agencies on the protection and conservation of
             marine mamm als. The Commission has a Committee of Scientific
             Advisors to provide advice on actions needed to fulfill the purposes
             of the Act. Authority has  been delegated to the DOC, which is
             responsible for all cetaceans and pinnipeds (except walrus) and to
             the DOI, which is responsible for walrus, sea otters, manatees,.and
             dugongs. DOI is responsible for determining which OCS oil/gas
             activities will threaten marine mammal populations or violate

                                           6-39

             provisions of the Act.

                   Because certain species and population stocks of marine

             mammals are in danger of extinction'or depletion as a result of

             man's activities, the goal of this Act is to keep these species
             from diminishing,below their optimum sustainable population. The
             Act also calls for immediate measures to be taken to replenish any
             species or population stock which has already diminished below that
             population. Efforts are to be concentrated on the protection of
             rookeries, mating grounds, and critical habitat areas. Currently,
             knowledge of the ecology, reproduction., and,population dynamics of
             marine mammals is inadequate for their protection.

             Marine Protection Research and Sanctuaries Act of 1972 (P.L. 92-532

             as amended by P.L.s 93-254, 93-472, 94-62, 94-326 and 95-1523)
                   The purpose of the Marine Sanctuaries Program is to:
             1) identify distinctive areas in the ocean, from the coast to the

             edge of the continental shelf; 2) preserve and restore these areas
             by designat ing them as marine sanctuaries; and 3) provide appropriate
             regulation and management. Program emphasis is on the protection of

             natural and biological resources.
                   The presence of conflicts among existing or potential uses of
             a,candidate site is not, in itself, a basis for designation of a
             site as a marine sanctuary. Activities will be permitted within   a
             designated marine sanctuary to the extent that they are compatible
             with the purpose for which the sanctuary was established. This
             determination is "based on an evaluation of whether the individual
             or cumulative impacts of su6h activities (may) have a significant
             adverse effect on the resource value of the sanctuary" (15 CFR

             9 2 2...1 (c) ) .

                                            6-40

                   The Coastal Zone Management Office, within NOAA, administers

             the Marine Sanctuary Program which is coordinated with the Coastal

             Zone Management and Es tuarine Sanctuary Programs established under

             the Coastal Zone Management Act  of 1972.

                   The-Secretary of Commerce  is authorized to designate areas

             to be preserved-or restored for  their conservation, recreational,
             ecological or aesthetic values as marine san ctuaries. The

             Secretary of.Commerce also issues regulations to control designated

             activities within.each area. Activities occurring within the

             sanctuary may be authorized by other authorities, but are valid

             only if the Secretary of Commerce certifies that the proposed

             activity is consistent with the purposes of Title III of the Act

             and can be undertaken pursuant to the regulations established for

             the sanctuary (15 CFR 922.26(c)).

                   Any person may recommend that a site be considered for

             designation as a marine sanctuary  (15 CFR 922.20(a)). Recommenda-

             tions should be addressed to the Director of the Sanctuary Programs

             Office, Office if Coastal Zone Management, NOAA. Recommendations

             should be submitted as follows:

                   1.   Site recommended;

                   2.   Description of area;

                   3.-  Approximate coordinates;

                   4.   Area in square mi  les;

                   5.   Name of person/organization submitting recommendations;

                   6.   Principal contact;

                   7.   Detailed description of the feature(s) which make the

                        site distinctive;

                                            6-41

                       8. Data on the resources and site;

                        9. Summary of existing research to support description;

                      10.  Data deficiencies;

                      11.  Description of past, present and prospective uses of

                           site;

                      12.  Impacts of present and prospective uses of site and

                           its distinctive features;

                      13.  Probable effects of marine sanctuary designation and

                           recommended regulations;

                      14.  Present/future resource uses;

                      15.  Uses of adjacent onshore areas; and

                      16.  Summary of who should manage area and why and a

                           summary of activities which must be regulated to

                           ensure protection of distinctive  features.

                   Within three months of receiving a recommendation for any site,

              the Assistant Administrator shall review the site to determine if

              it should be placed on the List of Recommended Areas. The Assistant

              Administrator must notify the recommender of a site in writing of

              his determination. If the site is rejected, reasons for the rejec-

              tion must be indicated. Also, notice must be given that a

              recommendation may be resubmitted with additional information.

                   Eligibility criteria for the List of Recommended Are as

              (15 CFR 922.21(b)(1-5).and boundary guidelines (15 CFR 922.21(C))

              are discussed in the Federal Register (Vol. 44, No. 148, July 31,

              1979).

                   After a site has been included on the List of Recommended

              Areas, it may be considered for selection as an active candidate

              for designation as a marine sanctuary (15 CFR 922.23(a)). Prior

                                            6-42

              to selecting a site as an active candidate, the Assistant

              Administrator must consult.federal agancies, state and local
              officials, including port authorities, Regional Fishery Manage-

              ment Councils, and interested persons, including the recommender,

              to determine the nature of pot ential impacts in the area and to

              gain additional information. Selecti on of a site as an active

              candidate for designation'as a marine sanctuary shall be announced
              in the Federal Register (15 CFR 922.23(c))."

                    Within six months of selection as an active candidate, the

              Assistant Administrator must conduct at least one public workshop

              in the affected area. Based on the information obtained at the

              public workshop, the Assistant Administrator determines whether

              the site shall continue to be listed as an active candidate. The

              Assistant Administrator's decision shall be published in the Federal

              Register within 90 days of the last workshop (15 CFR 922.24(b)).

                    if the site continues to be an active candidate, the Assistant
              Administrator must prepare a draft Environmental Impact Statement
              (DEIS) containing a designation document and implementation regula-
              tions. Additionally, the Assistant Administrator must hold at

              least one public hearing on the DEIS in the area(s) most affected

              by the proposed designation (15 CFR 922.24(c)).

                    In response to comments received at the public hearing, the
              Assistant Administrator shall prepare a final EIS and file it with

              EPA. After consultation with appropriate federal agencies, the

              proposed designation shall be transmitted to the President for

              approval (15 CFR 922.26(a)).

                    The designation shall specify the geographic coordinates of

                                           6-43

             the sanctuary area, the distinctive features requiring protection,
             and the types of activities subject to regulation. In instances
             where immediate and irreversible damage might occur, activities
             other than those listed in the designation may be regulated on an
             emergency basis for up to four months. During this period, amend-
             ments to the de.signation terms may be initiated by following the
             same procedures taken for the original designation (15 CFR 922.26(b)).

                   If a proposed sanctuary falls within the territorial limits
             of a state, the Assistant Administrator must notify the designated
             Coastal Zone Management Agency of an affected state(p) with an
             approved Coastal Zone Management Program.   The Assistant Administra-

             tor must make every effort to cooperate and consult with  affected
             states throughout the entire review and consideration process.
                   In particular, the Assistant Administrator shall:
                   1. Consult with relevant state officials prior to selection

                       of an active candidate;

                   2.  Ensure that any state agency designated under Sections
                       305 or 306 of the Coastal Zone Management Act, and any
                       other appropriate state agencies are consulted prior to
                       holding any public workshop'or hearing; and
                   3.  Ensure that workshops and hearings include consideration
                       ofthe proposed designation's relationship to state
                       waters and-its consistency with the approved state Coastal
                       Zone Management Program (15 CFR 922.725(b)(1-3)).
                   The Governor of a state whose waters are included in the
             sanctuary may object to the terms of the designation if they are
             unacceptable. The Governor  may take up to 60 days following

                                            6-44

              publication of the designation to raise objections. Should this

              occur, terms and regulations of the designation shall not take
              effect for the.part of the sanctuary in state waters untilthe
              objection is withdrawn. If, in the opinion of the Assistant
              Administrator, subsequent,modifications of the designation terms
              no longer achieve the objectives of the Act, the designation may
              be withdrawn (15 CFR 922.26(e)).

                    In some cases, the  Sanctuary Programs Office has*consulted
              adjacent states prior to designation of a sanctuary in waters
              beyond state jurisdiction.
                    While the designation of an area as a sanctuary would allow
              oil and gas operations, two main proposed features could delay or
              prohibit those operations. First, permits issued prior to the area
              designation and effective date of regulations remain valid for one
              year. For those permits that expire after the one year period'and
              for all permit s issued after the designation and effective date of
              regulations, certification ws required by the Assistant Administra-
              tor. This could result in up  to a 120-day delay for the
              administrative processand might prohibit oil and gas operations
              in the event of an unfavorable decision. However, it is felt that
              where Bureau of Land Management (BLM) regulations.are adequate to
              provide safety in oil and.gas operations they will be used in lieu
              of new regulations.
                    Secondly, a large sanctuary might impede  recovery of hydro-
              carbon resources should,discoveries be made just outside the
              sanctuary and the reservoir.extend into the sanctuary. This has
            .not happened yet, but should it occur, the DOC officials intent

                                            6-45

             to permit oil and gas operations in the sanctuary provided the

             activity is consistent with any ongoing operations. However, if

             no ongoing oil and gas operations existed within the sanctuary,

             enough uncertainty might exist to'delay the decision   process.

             Migratory  Bird Treaty Act (MBTA)

                    The earliest of'the i4ildlife laws is the Migratory Bird

             Treaty Act (MBTA).(Ch. 128, 52, 40 Stat. 755) passed in 1916 to

             implement the terms of the treaties with Great Britain and Can  ada

             and in later years signed with Mexico.and Japan. This Act can be

             an effective weapon in the battle against destruction of habitat.

             Because it is based on treaties, it surpasses the importance of

             other statutes which Congress may enact. The basic ranking of

             legal importance in declining order is constitution, treaties, and

             statutes. This means that as long as it does not affect anyone's

             constitutional  rights, an expression of the MBTA will take  precedence

             over laws.. This make the MBTA a Very effective tool.

                    The MBTA, which construes the word "take" to mean "pursue,

             hunt, shoot, capture, collect, kill," or any attempt to do so, has
             -been used to prevent the baiting of fields in U.S. vs. Reese, 27 F.

             Supp. 833 (W.D. Tenn. 1939). and the use of lead shot in the hunting
             of migratory waterfowl (see 41 F ed. Reg. 31386, 28 iuly*1976). An

             act which prohibits any tak ing of migratory birds with no require-

             ment of "guilty knowledge" can be used to great advantage.

                    Guilty verdicts in the cases of the U.S. vs. F.M.C.  (a

             pesticide manufacturer charged with violation of the MBTA   for bird

             deaths from a contaminated company holding pond) and in the U.S..

                                             6-46

              vs. Corbin Farm Services (defendants charged with bird deaths as

              a result of pesticide field spraying) indicate that courts are

              willing to accept use of the.MBTA in cases where pollution has

              killed migratory birds without the intent or knowledge of the

              actors. Interpreted in this manner, d   egradation resulting 'from

              construction and channelization projects (if migratory birds will

              be harmed) could be a violation of the MBTA.

                    This new dimension to the MBTA provides an additional means

              to accomplish Fish and Wildlife Service (FWS) objectives in the

              coastal zone.   Also the Property Clause, U.S.C.A. Constr. Art.

              4.S3, Cl,.2, has recently gained greater efficacy in providing

              protection to federal projects. The Supreme Court in Kleppe vs.

              New Mexico held that a state agency acting in accordance with a

              New Mexico law could be prevented from removing wild burros from

              federal lands under the Property Clause. This line of reasoning

              was taken a step further in the U.S. vs. Brown (522 F. 2d. 817,

              1,977) where the court found that-the Property Clause permits

              Congress to enact legislation protection federal lands from "spill-

              over" effects from activities occurring on nonfederal public lands

              or waterS. State laws allowing hunting on waters within a National

              Park were overridden under the Supremacy Clause by federal

              regulations protecting wildlife and visitors on the land. If other

              courts  agree with the Brown reasoning, it is possible that activ-

              ities on public areas adjacent to refuges in the coastal zone can

              be prohibited if they have an adverse effect on the purposes for

              which the federal land is held.

                                            6-47

              Endangered Species Act of 1973 (P.L. 93-205 as amended by

              P.L. 94-325)

                    Under the Endangered Species Act (ESA), consultation

              authority is delegated to the Director of the Fish and Wildlife
              Service (FWS) and the Assistant Administrator for Fisheries,
              National Marine Fisheries Service (NMFS), both referred to as

              the Service.

                    The Secretary of Interior or Commercei and all federal

              agencies in consultation with them, are required  to ensure that
              any program authorized, funded or carried out by  a federal agency
              is not likely to jeopardize the existence of any  endangered or
              threatened species, or result in the destruction  or adverse

              modification of critical habitat.

                    This Act defines the terms "critical Habitat" and "endangered
              species" (Sect-on 3(5) and (6) and empowers the Secretary of the
              Interior to determine critical habitat boundaries and to specify
              species as.endangered or threatened. However, the Secretary of
              the Interior may not list, remove from any list, or change the
              status of any endangered/threatened species listed before enact-
              ment of this.Act without a prior favorable determination by the
              Secretary of Commerce (Subsection 4 (a)(2)(c)). An exemption for
              an agency action will not be considered a major federal action
              provided that an EIS discussing the impacts upon the endangered/
              threatened species or upon their critical habitats has been pre-
              pared previous to the action (Special Provisions, Section 7(k)).,
                    If the proposal is a major federal action significantly
              affecting the quality of th e human environment, the federal agency

                                            6-48

              or the designated representative shall request of the Service a
              list of species (listed and proposed) that may be in the action
              area. Within 30 days, the Service will respond with a species
              list. The federal agency or designated representative will then
              conduct a..biologic-al assessment to determine how the species in
              the action area will be affected. The federal agency will submit
              this biological assessment to the Service. If a federal agency
              determines that the action "may affect" listed species or critical
              habitats, either adversely or beneficially, they shall initiate
              Section 7 consultation with the Service. In addition,,if the
              federal agen cy determines that the action is likely to jeopardize
              the continued existence of proposed species or result in the
              destruction or adverse modification of proposed critical habitats,
              it shall confer with the Service.

                    The ServiCe will complete the consultation within 90 days
              and render a biological opinion. The biological opinion may
              include conservation recommendations.- If the biological opinion
              concludes that the action is likely to jeopardize a listed species
              or result in modification of a critical habitat, mutually agreeable
              and prudent alternatives will be included. During the consulta-
              tion process, no irreversible or irretrievable commitment of

              resources may be made which might foreclose the formulation/
              implementation of any reasonable alternative measures.
                    States now have, in addition to the inclusion of endangered
              and threatened plants under the program, an alternate set of
              requirements available to them to be eligible for a stateSection
              6 program. These requirements include:

                                            6-49

                    1. An appointed state agency with authority to conserve

                        resident species of fish or wildlife determined by

                        the state agency or the Secretary of Interior to be

                        endangered or threatened;

                    2.  A state agency authorized to conduct investigations to

                        determine the status and requirements for survival of

                        resident specie5 agreed upon;

                    3.  A state.agency authorized to establish programs, includ-

                        ing acquisition of land or aquatic habitat or interests

                        therein, for the conservation of resident endangered or

                        threatened species of fish or wildlife (but not for

                        plants); and

                    4. Provisions for.public participation in designating
                        resident species of fish or wildlife or plants as

                        endangered or threatened.

                    Whereas NEPA requires consideration of potential environmental
              hazards, the Endangered Species Act (ESA) mandates the preservation

              of endangered life.

                    The adequacy of DOI's consideration of endangered species in

              planning both Pacific@and Alaskan OCS lease sales has been chal-

              lenged. The most important court case involved Alaska's Beauf ort

              Sea-lease sale. The Court of Appeals held that DOI's leasing
              program is a continuum of planned events and that holding a lease
              sale does not, in itself, generate any irreversible or irretriev-
              able action that would jeopardize the endangered species.

                    The OCS Lands Act Amendments, NEPA, and ESA all insist on

              foresight when planning any proposed action. Since holding an

                                           6-50

              OCS lease sale is only one planned event, further consideration

              of these statutory goals m'st be addressed before exploration,
              development, and production.will be allowed. Theref.ore, if in

              any of these evaluations it is found that a lessee's OCS oil and

              gas explo.ration.plan will jeopardize an endangered species or its

              critical habitat, the proposal would not be allowed to proceed.

              Mineral Leasing Act (Section 28), Amended and National Wildlife

              Refuge System Administration, Amended

                    These Acts require approval by the FWS of rights-of-way for

              pipeline construction across national wildlife refuges and other

              federal lands under its control.

                    Title 50 incorporates the requirements of the Act to amend

              Section 28 of the Mineral Leasing Act of 1920, and the Act to amend

              the National Wildlife Refuge System Administration Act of 1974.

              The amendment to Section 28 establishes spe dial requirement for

              pipeline rights-of-way for oil, natural gas, synthetic liquid or

              gaseous fuels. The National Wildlife Administration Act, as

              amended, establishes criteria for granting rights-of-way across

              lands of the National Wildlife Refuge System.

                    Applications for all rights-of-way over lands administered

              by the FWS must be submitted to the Regional Director who deter-

              mines-if the right-of-way is compatible with the purposes

              established for units of the National Wildlife Refuge System

              (50 CFR 29.21-1(a)).

                    Applications must include an environmental analysis sufficient

              to enable FWS to satisfy NEPA and other cultural, historical and

              archaeological protection requirements (Hudson Canyon Transportation

                                            6-51

              Management Plan, Review Draft, Janduary 1981, pg. 136). The

              analysis must also include information concerning the impact of

              the proposed use on: air and water quality; scenic and

              aesthetic features; and wildlife, fish and marine life (50 CFR

              29.21-2).

                   If  the land administered by the Secretary of Interior through

              the FWS is owned in fee by' the United States and the proposed use

              is compatible with the objectives of the area, a permit may be

              granted by the Regional Director, generally for a term of 50 years.

              However, rights-of-way granted under the Section 28.for pipeline

              transportation, may not exceed 30 years in term nor exceed-50 feet

              in width (plus the area occupied by,the pipeline and its related

              facilities). The Regional Director may find  that a wider right-

              of-way is necessary for operation/maintenance, or to protect the

              environment or public safety (50 CFR 29.21-3(a)).

                    In instances where damage to a unit of the National Wildlife

              Refuge System may result,'the Regional Director may require

              mitigation measures to make the proposed use compatible with the

              purposes for which the unit of the system was established.

                    State involvement with respect to pipeline rights-of-way

              on federally-owned.offshore lands is limited to two forms. First,

              the Regional Director must offer state, local, other federal agen-

              cies, and the public an opportunity to comment on right-of-way

              applications. Notice of public hearings is published in the

              Federal Register (50 CFR 29.21-9(f)). Second, the Regional

              Director must consider, and basically comply with, applicable

              state standards for right-of-way construction, operation and

                                            6-52

              maintenance (5.0 CFR 29.21-9 (1)).

              The Fish and Wildlife Coordination Act (P.L. 73-121 as amended by

              P.L.s 732, 80-697, 86-624 and 89-72)

                    Under the.Fish and Wildlife.Coordination Act, any pipeline
              project that would affect a water body of the United States re-

              quires that the FWS and the NMFS recommend that wildlife

              conservation.receive equal consideration with other project
              features throughout the planning and decision-making process.
              The Secretary of the Interior is authorized to make.recommendations
              and issue reports on the wildlife aspects of proposed water-
              related projects. These reports and recommendations, and those
              of.the head of the state agency exercising authority over the
              wildlife resources of the state, are included in the final report
              by the responsible federal agency (16 USC 662(b)). Wildlife
              agencies can recommend that permits, including COE permits issued
              under Section 404 of the FWPCA, be denied. However, the COE is
              not required to heed the counsel of the wildlife agencies.

                   Thecoordination Act process begins when the FWS is notified
              of a federal permit application or of a proposed federal activity.
              The project is then reviewed for its impact on fish and wildlife
            .resources and recommendations are made to preserve, protect or

              enhance those resources.

                   The.Fish and Wildlife Service's goal is  the protection of
              fish and wildlife resources and their habitat. However, the
              ultimate determination regarding permit issuance rests with the
              permitting agency rather than with the wildlife agencies.

                                           6-53

                    Strengthening the Fish and wildlife Coordination Act would

              help protect coastal/wetland areas. The decision in the case of

              The Avoyelles Sportsmen's League Inc. vs. Alexander (C.A. 78-1428,
              W.D. la) held that the clearing of wetlands to convert bottomland

              into farmland is subject to permit under the FWPCA "even where no

              earth is moved". The Corpos had based its determination that no

              Subsecti on 404 permit was hecessary by invoking the normal farming

              exemption (Subsection 404 (f)(1)(A) and the fact that no earth was

              move d. The court ruled that the clearing of 20,000 acres of bottom-

              land to plant soybeans was not the normal farming activity

              contemplated by Subsection 404(f)(A) and that the clearing
              activities fall under.Sebsection 404(f)(2) which takes away the
              exemption for activities which change the use of the land. Those

              activities which would be exempted under Subsection 404(f)(1)(A)

              are denied the exemption if they are part of   an effort to convert

              a wetland area to another use which will reduce the reach, or
              impair the.flow or circulation of-the water     The Corps' argument
              was rejected in this case as an attempt to ignore the purposes     of

              the Coordination Act.

                     OCS Related-Transportation Regulatory Mechanisms

              A. General  OCS Related Mechanisms

              Deepwater Port Act of 1974.(P.L. 93-627 as   amended by P.L. 95-36)-
              This Act provides for licensing and regulation of any fixed or
              floating maninade structure, other than a vessel, located beyond
              the terri torial sea which i@3 to be used as a port or terminal for

              transport of oil to any state. This regulation-applies to all

                                             6-54

              associated equipment, pipelines, pumping stations, service

              platforms, and mooring buoys to the extent they are located

              se award of the high water mark.

                    The Act authorizes the Secretary of Transportation to
              grant licenses to construct and operate deepwater ports. Prior
              to issuing a license, the Secretary of Transportation must
              consider the recommendatiobs of EPA, the Federal.Trade Commission,
              the Attorney.General, the Secretary of the Army, the Secretary of
              Defense, the Governors of adjacent coastal states, and the general
              public*(33 USC,1503(c)). The Secretary of Transportation may
              grant licenses only if the applications are  consistent with the
              criteria and regulations of the Act. The  Act prohibits any person
              from transporting oil between a deepwater  port and the United
              States unless such a port has been licensed (33 USC 1503(a))..
                    Section 6 requires that the Secretary of Transportation
              establish env ironmental review criteria to be used in evaluating
              proposed deepwater ports. By amendment of Part 1, Title 49 CFR,
              this responsibility is delegated to the Commandant of the Coast

              Guard (49 CFR 1.46(t)).. The Coast Guard regulations apply to all
              United States deepwater ports regardless of location or design.
              During the license application review, each port is examined for
              its.potential environmental impacts and utilization of technology.
                    The Secretary of Transportation promulgate s regulation s which
              allow for cooperation with other federal agencies and with any
              potentially affected coastal states (33 USC 1504(a)). An "adjacent
              coastal state" is defined as any coastal state which would be
              directly connected by pipel ine to a port or would be located within

                                            6-55

              1.5 miles of such a proposed deepwater port. Upon request, the

              Secretary of Transportation may also designate other states as

              "adjacent" if it is determined that the risk of damage to.the

              coastal environment of that state is equal to or greater than

              the risk posed to a state connected by a pipeline. To obtain

              this designation, the state must make its request known within

              14 days of the Federal Register publication of notice for a

              proposed deepwater port. The Secretary shall make a determina-

              tion within 45 days after receipt of such a request by a state

              (33 USC 1508(a)).

                   The De partment of Transportation (DOT) must publish notice

              of receipt of a license application in the Federal Register. The

              application is reviewed by interested federal agencies and is

              sub ject to an Environmental Impact Statement review and a public

              hearing. At least one public hearing must be held in each adjacent

              coastal state  Any interested party may present relevant material

              at any hearing. If the Secretary'of Transportation determines

              that factual issue(s) exist wh ich may be resolved by a formal

              evidentiary hearing, at least one adjudicatory hearing shall be

              held. The record developed at any adjudicatory hearing will serve

              as the basis for the Secretary's decision to approve or deny a

              license. All public hearings on all applications within a desig-

              nated application area shall be consolidated and must be concluded

              within 240 days after notice of the initial application has been

              published.

                   State participation with respect to the Act ranges from

              receipt of notification of public hearing to collection of user

                                            6-56

               fees for the land-based facilities related to a deepwater port

               facility. The Coast Guard Commandant must issue a notice of

               public hearing to each applicant and each adjacent coastal state.
               The Governor of an adjacent coastal state may consult with the

               application  staf f concerning license'conditions that are under

               consideration.03 CFR 148.407). Should the Governor of an adjacent
               state notify the Secretar@ that an application is inconsistent with

               state programs relating to environmental protection, land and

               water use, or coastal management, then the Secretary of Transporta-
               tion shall condition any license granted so as to make it consistent

               with the state programs (33 USC 1508(b)).

                     Section 1508 further requires that the Secretary of Transp6rta-
               tion transmit a copy of all applications to the Governor of each

               adjacent coastal state. Prior to the issuance of a license, the

               Secretary must obtain the approval of the Governor of each of these

               states.

                     In summary, the proposed project must conform to approved

               state programs. The Governor of an "adjacent coastal state" can

               veto a proposed action if it is deemed inadvisable, and state
               participation is based on the provision that "the law of the
               nearest adjacent coastal state, now in effect or hereafter adopted,
               amended, or repealed, is decl ared to be the law of the United States,
               and shall apply to any deepwater port licensed pursuant to this Act,
               to the extent applicable and not inconsistent with any of the
               federal provisions (33 USC 1518(b))." The nearest adjacent coastal
               state is defined as that state whose seaward boundaries, if extended
               beyond three miles, would encompass the site of the deepwater port.

                                              6-57

                      Finally, any state which has land-based facilities directly

                related to a deepwater port is entitled to set "reasonable fees"

                for the use of such facil  ities. Fees may not exceed the econo   mic,
                environmental, and administrative costs inflicted upon a      state.
                All fees.are subject to approval by the Secretary of Transportation

                (33 USC 1504 (h) (y)

                Port.Safety,and Tank Vessel Safety Act of 1978, amending Ports and

                Waterways.safety Act of 1972 (P.L. 95-474)

                      This Act is important because it regulates designation of

                shipping routes on the'OCS and enforcement of safe access routes.

                There are two forms of official shipping lane designations; safety
                fairways and traffic separation schemes. Safety fairways are routes

                that have been established by the Corps of Engineers by means of

                denying permits for platforms within their limits (Section 10,
                River and Harbor Act of 1899, 33 USC 4,03). Traffic separation

                schemes establish directional lanes for vessel movement.

                      The 1978 Port and Tanker Safety Act amended the Ports an    d
                Waterways Safety Act (1072) and the Tank Vessel Act (1936). The
                Act authorizes the Secretary of Transportation (Coast-Guard) to
                designate port access routes for the movement of vessel traffic
                in-U.S. coastal waters ... and to designate necessary fairways and
                traffic separation schemes. Within the designated area-s, naviga-
                tion is to have "the paramount right over all other uses."
                Regulations for a specific designated port access route may
                prohibit or restrict placement of drilling or production platforms
                within or adjacent to vessel traffic lanes. Before a port access
                route can be designated, the Coast Gu  ard must study the need for

                                               6-58

               such routes. The Sec retary of Tra nsportati.on is forbidden to make

               a designation that would deprive a leaseholder of the effective

               exercise of a right granted by lease or permit, so long as the

               effective lease or permit date preceded the publication of the

               Federal Register notice announcing the undertaking of a study

               regarding potential vessel traffic density and the need for safe

               access routes (44 FR 22543, April 16, 1979)-.

                     The Secretary of Transportation is authorized to adjust the
               limits of fairways or traffic separation schemes as necessaryto

               accommodate the needs of other uses -,4hich'would.not be inconsistent

               with the purpose.for which the existing designation was made.

                     in-compliance with the Act, the Coast Guard initiated a

               Port Access Route Study.  Notice of the study appeared in the

               Federal Register on April 16, 1979.

                     The initial stage of the study evaluated existing,routes and

               determined where ship routing measures were needed to ensure safe

               access to and from United States ports. Required routing proposals

               may create new measures or amend existing measures relative to the

               study assessment.

                     In connection with any designation of fairways and traffic
               separation schemes, the Secretary of Transportation is directed to

               issue reasonable regulations for the use.of the designated area.
               Further, the Secretary of.Transportation,may make the use of fair-

               ways and traffic separation schemes mandatory for certain types,and
               sizes of vessels (the most direct route is generally the actual
               practice). Following completion of the Port Access Route Study,

               appropriate regulations will be issued.

                                             6-59

                     When appropriate, states may encourage the Coast Guard to

               adopt more rigorous protective measures for the transport of oil

               by tank vessel. The desig  nation of safe passage lanes over the

               OCS and the establishment of vessel traffic systems should be

               urged where necessary.

                     During the initial phase of the Port Access Route Study,

               the Governors of all coa.,@tal states were consulted for input

               relating to.commercial traffic routes, traffic concentration,

               and potential traffic density, fishing activity, recr   eational

               vessel traffic, and OCS resource development activities in the

               study area.

                     Also   prior to issuing,regulations, the Secretary of Trans-
               portation is directed to establish procedures for receiving further.
               input by officials from affected states (33 USCS 1223 (c)(3)(B)).

               The River and Har bor Act of 1899 (Sections 9 and 10 only)

                     This Act regulates permitting for any work in or affecting
               navigable waters of the United States. Section 9 specifically
               addresses permits for pipeline construction of elevated crossings

               over such waters.

                     Section 9 of the Rivers and Harbors Act prohibits construction

               of any dam or dike across any  navigable waters of the United States
               without congressional consent  and approval by the COE. Where the
               navigable portions of a water  body lie exclusively within the
               jurisdiction of a single state, the structure may be built under
               the authority of the state legislature if the plans are approved,
               by the COE.  Section 9 also applies to elevated bridges, causewayst

                                              6-60

               and pipeline crossings.   The Secretary of Transportation delegated

               authority with respect to elevated crossings to the Coast Guard

               Commandant. The Coast Guard's function in reviewing plans for
               pipelines across navigable waters (for the purpose   of this program)
               is to ensure that structures meet the requirements   of navigation.

                      If the District Commander's preliminary examination of the
               application suggests that the permit should be denied, he must

               notify the applicant of this determination and state the reasons
               for denial. If the'applicant desires that the application receive

               further consideration by the Commandant, the District Commander is
               required to give public notice that the applica  tion has been filed

               and proceed with  the case (CFR 115.60(b)).

                      Public hearings will be hel d only for cases where there  are
               substantial issues relevant to the effect that the proposed pipeline
               will have on the reasonable needs of navigation. Notice of the
               hearing is to be communicated to the applicant, state(s), county,
               and municipal authorities by mail.

                      Hearings are open to the public and conducted in an informal

               manner. Submission of written and oral statements is invited and

               encouraged.
                      the District Commander prepares a report reflecting the
               findings based on information obtained at the hearing and knowledge
               derived from his experience. The completed report is sent to the
               Bridge Division of the Office of Navigation. If the Commandant
               disagrees with the findings of the District Commander on a sub-

               stantive matter, he may return the case for reconsideration. If
               the Commandant decides not to issue the permit, he must inform the

                                             6-61

               applicant of the reasons for rejection and the modification of
               plans that would justify.reconsideration (33 CFR 115.60(e)(1)).
                     Generally, state participation in the review of Section 9
               permits takes three forms: (1) affected states receive notification
               of appli.cations.received and public hearings; (2) certification
               that the proJect meets with state water quality standards; and
               (3) where applicable, certification that the proposed project
               would be consistent with an approved state'coastal management plan.
               States are also invited to offer testimony at public hearings and
               to submit written comments to the District Commander.
                     Anyone proposing to condu.ct an activity which might result
               in any discharge of a pollutant into navigable waters must provide
               the Coast Guard with a certification from the state in which the
               discharge originates. This ensures that the discharge will comply
               with the applicable state effluent limitations and water quality
               standards (33 USC 1341).
                     If the state fails or refuses to act upon a request for
               certification within one year, the certification requirement will
               be waived. No permit may be granted until the certification require-
               ment has been obtained or waived. If state certication has been
               denied, no permit may be granted.
                     Finally, a state with an approved CZM program which includes
               the Section 9 permit, must also recieve the applicant's consistency
               certificatIe. If the state finds the proposed activity is incon-
               sistent with the CZM program, it can object to the issuance of.a

               permit.

                     Generally, a decision to issue a permit rests primarily on
               the effect of the proposed work on navigation. However, in cases

                                             6-62

               where the proposed structure is unobjectionable from the standpoint
               of navigation, but state or local authorities decline to give their

               consent to the work, it is unusual for the Coast Guard to issue a

               permit. In such cases the applicant is informed that the structure
               is unobjectionable from the standpoint of navigation and that the
               permit would be issued were the consent of the local authority also
               forthcoming (33 CFR 114.10(a)).
                     Section 10 permits are required    for all.structures or workin,
               or affecting, the navigable waters of    the United States, for work
               on artificial islands, and for all installations and other devices

               permanently or temporarily attached to the seabed on the outer
               continental shelf (Section,4(e), OCS Lands Acts of 1953, as amended).
                     To obtain a.permit an applicant must submit information.
               describing the project to the District Engineer of COE office having
               jusisdiction over the area in which work is to be performed.
                     Upon receipt of an application, the COE issues a public notice
               (wi thin 15 days) for the purpose  .of informing the public and
               soliciting comments. The notice is distributed to all levels of
               government, interested groups and indi  viduals, is posted in public
               places in the vicinity of the proposed work, and is occasionally
               advertised in local newspapers (33 CFR 325.3, 1979). The notice
               must include sufficient information on the nature of the proposed
               activity to generate meaningful comments.

                     Generally, the comment period is 30   days from the date the
               public notice is distributed.    In no case may it be less than 15
               days. All comments receive.d become part of the public record and
               are used by the District Engineer in determinin   g whether a public
               hearing is warranted.

                                               6-63

                    When structures on the OCS are to be constructed on lands

              under mineral lease from the BLM, that agency, in cooperation with

              other federal agencies, will have previously evaluated the potential

              effects of the leasing program on the total environment. COE,

              therefore., limits its evaluation of the proposal to its impact on

              navigation and national security. If state concerns and objections

              go beyond the questions of navigation and national sucurity, the

             ..COE will refer the matter to the Department*of the Interior.

                    Generally, Section 10 permits will not be denied, although

              modifications in timing and location may be required in the interest

              of navigation or national securi.ty. Notice must  be given to the

              COE prior'to the commencement of authorized work  even after a permit

              has been issued.

                    States will receive public notice of Section 10 permit

              applications and may submit written comments to the Distri  ct

              Engineer. In cases where all facilities and activities are

              located outside the state limits,' state concerns and objections.

              beyond the scope of national security and  navigation will be

              referred to DOI (NEABC-RALI Projects State Participation in OCS

              Development and Production Decisions, p. 3 5, July 1980).

                    A state with an approved CZM program (such as Florida) which

              has-included COE permits in its program lists will receive the

              applicant's consistency ce rtificate. If the state finds that the

              proposed activity is inconsi'stent with the CZM program, it can
              object to the issuance of the permit'.

              The Natural Gas Act of,1979

                    The Natural Gas Act authorizes the  federal regulation of

                                            6-64

              interstate transport of natural gas. The movement of natural gas

              from the OCS into any coastal state constitutes interstate trans-

              port. It is not necessary.that.a pipeline cross frQm one sta   te

              into another. Section 717(f)(c) of Title 15 U.S.C. states that

              no natural gas.company shall engage in the transportation or sale

              of natural gas, undertake the consturction or extension of any

             ,,facilities, or acquire or operate any such facilities or extensions

              without first obtaining a  Certificate of Public Convenience and

               ecessity from the Federal Energy Regulatory Commission (FERC).

                    The Act provides that the FERC-shall -fix charges and rates

              for the transportation and sale-of natural gas subject to its

              jurisdiction. The public convenience and necessity standard of

              Subsections 7(c) and 7(e) of the Natural Gas Act gives FERC

              authority over pipeline safety, including siting issues.

                    The requirements for certificate applications are outlined

              in 18 CFR 157. The required information is to be submitted through

              series of exhibits, the type, scope, and purpose of which are

              covered in 18 CFR 157.52 et seq. The guidelines set substantive

              requirements with respect to location and construction of a pipeline.

              The FERC guidelines are designed to avoid and mitigate adverse

              impacts on environmenta.1/scenic values and to require consultation

              with interested state and local officials.

                    FERC has also promulgated specific guidelines for the
              applicant's.environmental report. The applicant is expected to
              consult with appropriate officials at all government levels during

              the preliminary stages to assure that all environmental concerns are

              identified. The applicant must also cond  uct studies to determine

                                             6-65

               the impact of a proposed action on the environment and .to assess

               any measures which may be necessary to preserve the values of the

               affected area (18 CFR 2.82).

                     The FERC staff must review environmental reports and perform

               its own independent studies to determine whether the proposed

               licensing action is a major federal action significantly affecting

               the quality of the human'environment. If it is such an action,

               the FERC staff must prepare a draft EIS which is reviewed by the

               Council on Environmental Quality (CEQ), EPA, other appropriate

               agencies and the public. The public. has 45 days after publication

               of a notice of availabilityof the draft EIS to offer comment.

               After the expiration of the comment period, the FERC staff must

               consider all submitted comments and revise the draft EIS as necessary

               to produce a final EIS.

                     A public hearing may be held at the FERC's request or due

               to public obj ection. Any party whichmay be directly affected

               may file.a petition to intervene (15 USC 717n(a)). For a state

               to intervene, notice of intervention must be filed by a state
               commission or any regulatory body of the state having Jurisdiction

               to regulate rates and charges for the sale of electric energy or

               natural gas to consumers within the intervening state (18 CFR 1.8a

               (1)). This notice of intervention is not subject to the

               Commission's approval.

                     Petitions to intervene must clearly set out the grounds of
               the' proposed intervention, and the position of the petitioner in

               the proceeding,(18 CPR 1.8c).

                     The exercise by FERC of its authority to sanction interstate

                                             6-66

              transactions involving transmission,of natural gas by pipeline is
              not dependent upon approval by state regulatory commissions (Public
              Service.Commission of West Virgfnia v. Federal Powei' Commission,
              437 F.2d 1234 (1971)). The state can, however, exercise its
              influence by preparing comments on the draft EIS and by taking an
              active tole in'the hearing@s.

              Natural-Gas Pipeline Safety Act of 1968 (P.L. 90-481 as amended by
              P.L.s 92-401, 93-403, 94-477 and.96 129)
                    DOT is responsible for establishing federal safety standards
              for natural gas pipeline facilities. No permits are required, but
              all applicants for a certificate of public convenience and necessity
              under the Natural Gas Act must certify to FERC that applicable DOT
              safety standards will be satisfied (49 USC 1676). Safety standards'
              require that certain pipeline leaks and failure be reported to the
              Office of Pipeline Safety Operations (49 CFR 191)., Federal safety
              regulations contained in 49 CFR 192 cover design, construction,
              testing, operation, installation, inspection, replacement, and,
              maintenance of gas pipeline facilities.
                   The regulations focus on materials, maintenance and operating
              practices required to keep a pipeline functioning safely. While
              environmental protection is an incidental-result of these regula-
              tions, the principal objective is safety.
                   A Memorandum of Understanding (MOU) regarding pipeline safety
              regulations was signed in May 1976 between the Secretary'of the
              Interior and the Secretary of Transportation. This MOU specified
              each agency's responsibility as well as their joint responsibility

                                           6-67

              for inspection, enforcement and coordination.

                    The Act allows for federal regulation of those facilities

              used to transport natural and other gases in, or affecting, inter-

              state or foreign commerce. It  created exclusive federal authority

              over interstate. gas transmission facilities (49 USC 1671). Under

              no circumstances may states adopt standards which apply to such

              facilities.

                    The DOT also possesses overall responsibility forthe safety

              regulation of intrastate gas pipeline systems covered by the Act.

              However, states may assume safety regulatory jurisdiction over the

              intrastate systems within theirboundaries, so long as the concer  ned

              state agencies meet the certification or agreement criteria called

              for under 49 USC 1674.' Any state may adopt additional or more

              stringent safety standards for intrastate pipeline transportation,

              if such standards are compatible with federal standards (49 USC
              1672). With.respect to parti'cipati*on in DOT pipeline safety rulemaking

              actions, the state's participation is permitted in accordance with

              the Administrative Procedures Act (5 USC 551 et..seq.) and DOT's

              rules of procedure (49 CFR 5 and 106). In addition to administrative

              appeal procedures, any party adversely affected by DOT's pipeline'

              safety rulemaking actions is afforded judicial review in the Co urt

              of Appeals (49 CFR 1675(a)).

              The Hazardous Liquid Pipeline Safety Act of 1979 (P.L. 96-129

              (Title II))

                    The Hazardous Liquid Pipeline Safety Act (HLPS A) vests

                                             6-68

              responsibility in the DOT for establishing and enforcing minimum
              federal safety standards for hazardous liquid pipeline facilities.
              The Act extends to all hazardous liquids, including petroleum and
              petroleum products. As in the regulation of a natural gas pipeline
              (under the Natural Gas Pipeline Safety Act), DOT applies criteria
              to the design, inspectionj installation, construction, extension,
              operation, replacement and'maintenance of hazardous liquid pipeline

              facilities.

                    Like its gas counterpart, the Hazardous Liquid Pipeline Safety
              Act has no permit requirements. State/public participation in rule-
              making actions are to be in accordance with the provisions of the
              Administrati ve Procedure Act.

                    As in the case of the Natural Gas Pipeline Safety Act, states
              are not permitted to adopt or enforce safety standards applicable
              to interstate pipelines carrying hazardous liquids. A state may
              adopt additional or more rigorous standards for intrastate pipelines,
              provi ded these standards are compatible with the federal standards.
              To carry out such a programl a state must.submit to the Secretary
              of Transportation an annual certification that the state agency
              exercising regulatory jurisdiction over intrastate pipelines has
              adopted the Act'.s federal safety criteria, is enforcing these
              standards, promoting programs designed to prevent damage to pipe-
              line facilities and has a reporting and inspection program
              equivalent to the federal program (49 USC 2004).

              B. OCS Pipeline Rights-of-Way
                   BLM approves pipeline rights-of-way for all proposed trans-
              portation pipelines (as opposed to "gathering pipelines"). BLM

                                           6-69

               generally issues permits for the federal portion of common carrier

               pipelines used to transport oil and gas from the field to a shore

               facility or in some cases to a4 offshore facility where the resource

               is transshipped by barge or tanker. Transportation lines which are

               confined-to the tract(s) or unit(s) of a single lessee or,operator

               are granted.permits by th e USGA.

                     The BLM is responsible for conducting pipeline management

               studies to determine the best routing for pipeline placement and

               also collects rental fees for each mile of right-of-way and each

               pumping or support station.

                     The regulations of Title '43 CFR 3340 provide steps for grant-

               ing and administering rights-of-way for the transport of minerals

               by pipeline from the OCS.

                     By accepting a right-of-way grant an applicant agrees to

               comply with the regulations which the Secretary of Interior deter-

               mines to be necessary in order to conserve the natural resources of

               the OCS (43 CFR 3340.1(a)(1-12)). Included in these regulations

               is the requirement that right-of-way holders utilize the best

               available and safest technology that the Secretary determines to

               be economically feasible. Failure to comply with the Act, the

               regulations, or any conditions prescribed by the Secretary shall

               be grounds for forfeiture of the approval.(43 CFR 3340.1(b)).

                     In reviewing a right-of-way application, the authorized

               officer shall consider the potential effect of the pipeline on the

               human, marine, and coastal environments. The authorized officer

               shall prepare an environmental analysis, and may consider recommen-

               dations of appropriate federal agencies, hold public meetings

               after issuing appropriate notice, and consult with state agencies,

                                            6-70

              organizations and individuals.

                    As a condition of approval, stipulations may be attached

              to protect.the human,.marine and coastal environments, life

              (including aquatic life), and property and mineral resources,

              located on or adjacent to the proposed right-of-wdy. In approv-

              ing the pipeline right-of-'way, consideration shall be given to

              recommendations of the IPP (43 CFR 3340.2-2(a)).
                    if th'e.application is rejected, notification shall be made

              in writing and reasons for the decision shall be stated (43 CFR

              3340.2-2(e)).

                    once an application is approved, the holder of a right-of-

              way may take up to five years to construct  the pipeline. If

              pipeline construction has not been completed within five yearst

              the right-of-way grant shall be considered forfeited. Any

              deviation from the proposed plan prior to securing approval shall

              be at the risk of the holder (43 CFR 3340.3(a)).

                    Right-of-way grants shall be reviewed annually prior to

              commencement of pipeline construction. Significant changes in

              conditions subsequent to the grant of a right-of-way but prior

              to commencement of construction may be grounds for a request to

              alter the grant by the authorized officer (43 CFR 3340.21(b)).

                    Also, any changes made by the holder in the use of the
              pipeline or direction of flow.may be made only if approval is
              first obtained from the Department of Transportation and the

              authorized officer (43 CFR 3340.6(a)).

              C. Tanker Vessel Regulatory Mechanisms

                    State governments have retained only limited control over

                                            6-71

              oil.tanker operations. In the Supreme Court decision, Ray vs.

              Arco, 435 US 151 (1978), the Court ruled that the Port and Water-

              ways Safety Act (1972) preempted the field of tanker desig  n/

              operations except as to tug requirements, pilot requirements on

              vessels engaged in foreign trade, safety standards for "structures"

              in the waterways, and valid state regulation's concerning safety,

              and protection of the marihe environment.

                    Generally, the regulation of interstate commerce, such a

              tanker traffic, falls within the jurisdiction of the federal

              government, pursuant to powers derived from the U.S. Constitution

              (Article I, Section 8). State governments    are permitted to

              regulate onl y certain aspects of interstate  commerce, such as for*

              the protection of public health and safety. State programs may

              not conflict with or preempt federal laws. Particularly strict

              state regulations are subject to close judicial scrutiny to

              determine whether the resulting burden imposed on interstate

              commerce is legitimate. Regulations adopted in an arbitrary and

              capricious manner cannot be expected to withstand judicial

              challenge (Johansan, K. and Parrish, R., Oil Spills/oil Tanker

              Operations, Report 5: The Development of Petroleum Resources from

              the Outer Continental Shelf: Legal Management Problems and

              @Capabilities in Ore gon, Law Center, University of 01regon, p. 68,

              Jan. 1979).

                    Regulation of other  aspects of tanker design and operation

              for the safety and protection of the marine environment also appear.

              to be preempted by the Ports and Waterways Safety.Act (33 USCS 1221

              et seq.) Training specifications, inspection programs, and traffic

                                             6-72

              systems all fall under the exclusive jurisdiction of the Coast

              Guard. The Coast Guard exercises police powers over all vessels
              transporting OCS oil in coastal waters (14 USC 89(@) and (b) (1-

              2)). Accordingly, a state has only two* alternatives when seeking

              to protebt its marine environment from the adverse impact.of tanker

              traffic. First,, states may monitor and evaluate Coast Guard

              regulations applicable to oil tankers, and.'where necessary,,
              encourage the Coast Guard to adopt more rigorous protective

              measures. The designation of safe passage lanes over the Outer

              Continental Shelf and theestablishment of vessel traffic systems

              where needed, as well as improvements in recordkeeping and informa-

              tion dissemination should be urged. In addition, the Coast Guard

              should be encouraged to exercise its authority to deny port entry

              to vessels not conforming to federal standards for safety and.design.

                    Second, a state such asFlorida with an appro ved Coastal

              Management Program can require federally approved or funded

              activities affecting its coastal resources to be consistent with

              the objectives of the state Coastal Zone Management Plan (CZMP).

              Thus, the Coast Guard may not approve any activity described in

              the development/production plans affecting land or water use in a

              state unless that state concurs with the consistency certification

              that accompanies the plan. Federal permits for OCS activities

              affecting coastal resources mut be consistent with navigational

              safety (16 USCA 1456 (c)(3)). Proposed activities that might

              interfere with navigational safety could not be expected to receive
              the necessary consistency deitermination.

                                             6-73

                                Ongoing Federal Mechanisms

              Geological.and Geo2hysical Surveys and Analyses (30 CFR 251)

                    Industry data from tests is released ten years after the

              issuance of the permit under which they were collected. Deep

              stratigraphic tests are released 60 days after issuance of an OCS

              lease within 50 miles of the test site. States may review proprie-

              tary data submitted to the USGS Director at,locations designated by
              the Secretary of 'the Interior pursuant to S ections 26(d)(2) and

              205(g) of the OCS Lands Act Amendments of 1978. These sections

              require that an official be appointed by the Governor for inspection

              of.the information and-that th,e*state be subject to provisions of

              confidentiality.

              Intergovernmental Planning Program

                    The I ntergovernmental Planning Program (IPP) was impleme  nted

              in 1979.to provide formal coordination and planning for three OCS

              program elements administered by BLM: the leasing process; the

              Environmental Studies Program; and the transportation planning for

              OCS oil and gas. The IPP brings together government and private

              interests to provide analysis of areas that will be impacted by

              OCS development where residents are unfamiliar with such activity.

              The IPP has also established a Regional Technical Working Group

              Committee (RTWCC) for each leasing region to provide information

              and advice to DOI.

              Regional Environmental  and-Socioeconomic Studies (43 CFR 3331)

                     This BLM program was initiated in 1973 and serves to establish

                                             6-74

              environmental information for comparison with previously collected

              data to identify any significant changes in the human, marine, and

              coastal.environments.

              OCS Oil and Gas Information Program (30 CFR 252 and 43 CFR 3300.2)

                    Section 26 of the OCS Lands,Act Amendment establishes this

              program which requires the USGS Director to.'make available to

              affected states a regional summary report -to assist state and local

              governments in planning for onshore imIpacts of potential OCS develop-

              ment. The program regulations also require the USGS and BLM

              Directors to provide affected states with an index which lists

              the relevant programs, plans, reports, EISs and lease sale documents.

              The index summary reports and limited technical assistance are

              available from the OC S Information Office, U.S. Geological Survey,

              640 National-Center, Reston, Virginia 22092, (703) 860-7166.

              Land and Water Conservation Fund

                    The Land and Water Conservation Fund (L&WCF) is the major

              grants program instituted by Congress to assist the states in

              developing and acquiring outdoor recreation lands/facilities and

              comprehensive recreation planning. The L&WCF assists federal land

              managing agencies in purch asing recreation and endangered species

              lands throughout the country. Over $3 billion has been dispersed

              through the Heritage Conservation and Recreation Service (HCRS)  to

              states and federal land management agencies since the fund's
              inception in 1965. over 65' percent of these revenues were derived

                                           6-75

              from leases and royalties stemming from production of oil and

              natural gas on the OCS. A 1976 amendment to the L&WCF Act

              increased the annual L&WCF authorization ceiling from 300 to 900

              million dollars.

              Marine Fisheries Management

                    The Fishery Conservation and Managemen  t Act (FCMA) of 1976

              (16 U.S.C. 18@01-1882) established a 200 mile fisheries conservation

              zone off the coasts of the United States and its possessions,

              effective 1 March 1977. It also created eight Regional Fisheries

              Management Councils composed of fishermen, state representatives,

              and officials of federal agencies with responsibilities affecting

              commercial and recreational fisheries in the marine environment.

              This Act mandates a continuing planning program to be initiated by

              the Councils. A Fishery Management Plan based upon the best

              available scientific and economic   data must be prepared for each

              species (or related group of species) of fish harvested within each

              region.   Public hearings are held during the development of each

              plan, and approval by the Secretary of Commerce is required prior

              to the issuance of regulations to implement the plans. These plans

              generally regulate the level and method of catch by domestic and

              foreign fishermen, and may close areas to fishing. Closures concern

              only fis hing activities and not other uses of the OCS such as

              shipping of oil and gas. Given staff and funding limitations      some

              significant species may not have plans completed for five to ten-

              years or,more.

                                              6-76

                  Pertinent Proposed OCS Related Federal Legislation

             Amendment to the OCS Lands Act Amendments of 1978 and the CZMA

             of 1972, as amended (H.R. 4597)"

             The major provisions of the proposed bill are to:

                   1. Clarify wording in Title II of the OCS Lands Act

                       Amendments pertaining to the oil industry's liability

                       for oil spill damage. The amendment would.require the

                       owner or operator of a vessel or offshore facility to

                       be liable for damages and the cost of removal and

                       cleanup. The liability limit for a vessel is determined
                       by its size whereas the' liability for an offshore

                       facility is $75 million.

                   .2. Simplify the leasing, exploration, and development process

                       and attempt to provide industry with a more predictable

                       and.cost-effective lease sales process; and

                   3. Provide coastal states with a new.source of revenue for

                       coastal management and protection to replace funding

                       which is being phased out. The revenue potential of

                       this bill is especially important to the Tampa Bay

                       Region since the bill seeks to create an Ocean and

                       Coastal Resource Management Fund. The money in this

                       fund, not to exceed $300 million-during any fiscal year,

                       would be distribdted to all coastal states in the form

                       of a block grant. The distribution formula would be

                       based on OCS activity, coastal-related coal activity,

                       coastal-related energy facilities, miles of shoreline

                       and coastal population for each state.

                                           6-77

                          State of Florida Regulatory Mechanisms

                   The State of Florida'faces great potential effects from the

             U.S. Department of the Interior'-s Outer Continental'Shelf Oil and

             Gas Leasing Program. In consideration of this effect Florida's

             Governor Graham  has established a policy approach that unfounded

             or unreasonable regional objections should not override the

             national need to increase domestic energy supplies, but maintains

             that it is in' the national interest, as well as the interest of

             Florida and other coastal states, to minimize air and water

             pollution from OCS operations. Florida seeks to-control economic

             and environmental damage from oil spills and threats to marine and

             terrestrial wildlife from OCS related activities through its

             regulatory mechanisms.

             State of Florida Agencies Responsible for Managing OCS Impacts

             I. Office of the Governor

                  A. Office of Planning and Budgeting

                      The Office of Planning and Budgeting is the State of

                  Florida's designated agent for preparing State of Florida

                  policy for OCS related activities. The sta te contracts with

                  Dr. Murice 0. Rinkle to serve as the OCS Representative for

                  the state and Governor. The Office of-Planning and Budgeting

                  is:

                      1. responsible for preparing review comments for OCS

                          related activities;

                      2.  responsible for'establishing State of Florida policy

                          for OCS leasing, exploration, development, and

                          production activities;

                                            6-78

                      3. the designated representative for the Regional

                           Technical Work.Groups;

                      4. responsible for preparing State of Florida comments

                           for Environmental Impact Statements for MMS;
                      5.   responsible for development of OCS Transportation

                           Management Plans;

                      6.   responsible for preparing lease stipulations; and
                      7.   coordinating State of Florida OCS activities with

                           other states.

                   Florida Department of Community Affairs (bCA)-
                   A. Division of Local Resource Management
                       Coordination of OCS activities and planning programs between
                   the State of Florida, regional governments and local governments
                   is managed by the Division of Local Resource Management of the
                   Florida Department of Community Affairs (DCA). The Division
                   provides Coastal Energy Impact Program (CEIP) funds to the
                   Office of the Governor, Office of Planning and Budgeting to
                   conduct its OCS responsibilities. This OCS onshore facilities
                   siting study is founded, coordinated and managed through the
                   Division of Local Resource Management. This Division of DCA

                   serves to coordinate and educate Florida's citizens about
                   OCS activities and works to develop 'grass roots" OCS policy.
                       DCA's Division of Local Resource Management is also
                   responsi ble for administoring Florida's Development of
                   Regional Impact (DRI).program. As provided by Chapter 380
                   F. S. (Land and Water Environmental Management Act of 1972),
                   certain developments are presumed to have regional impacts

                                            6-79

                  and are required to complete a review process to evaluate

                  impact prior to construction. Under the same legislation,

                  DCA also@administe rs the Area of Critical State Concern

                  program. At the time of this study the southern portions

                  of Escambia, Santa Rosa, Okaloosa and Walton Counties are

                  the subject of a Resource Planning and Management Committee

                  which is charged with considering growth management issues

                  within the study area. Both the DRI process and the Resource

                  Planning and Management Committee conclusions could effect

                  the siting of OCS facilities within Region I.

                      DCA also coordinates and assists Florida's county and

                  municipal governments to prepare, adopt and amend comprehen-

                  sive plans ar required by the Florida legislature.

            III.  Florida Department of Environmental Regulation

                  Protection of Florida's environmental resources is the primary

            charge of the Florida Department o f Environmental Regulation (FDER).

            FDER has the responsibility of,monitoring and permitting activities

            in the waters of the state. All dredging fill activity, stormwater

            discharges, effluent discharges (domestic and industrial), air

            emmissions and waste disposal is administered by FDER. Any OCS

            onshore siting would be required to comply with the administrative

            rules of FDER.

            IV.   Florida Department of Natural Resources

                  The "administration, supervision, development and conservation

            of Florida's natural resources" is the legislative charge of the

            Florida Department of Natural Resources (DNR).

                                           6-80

                    A. Division of Beaches and Shores

                        This division of DNR administers a comprehensive program

                    for the protection of Florida's Atlantic and Gulf beaches.

                    P
                     ermits are issued for all construction seaward of the

                    established coastal control setback.

                    B. Florida Marine Patrol (Division of Law Enforcement)

                        This division is  responsible for enforcing state statutes

                    covering the state's  marine resources. The Marine Patrol

                    provides assistance in disaster situations including search

                    and rescue.

               V.   Northwest Florida Water Ma nagement District

                    The Northwest Florida Water Management District (NWFWMD) has

               been charged by the Florida legislature for the conservation,

               protection, management and control of the surface and groundwaters

               of west Florida. To accomplish this responsibility the NWFWMD

               performs:

                    1.  consumptive water use permits;

                    2.  regulation.of,the construction  of wells;

                    3.  regualtion of the construction  of dams and impoundments;

                    4.  permits artificial recharge of   groundwater, and

                    5.  preparation of water shortage plans.

                    The NWFWMD has completed a water supply development plan to

               insure that adequate potable water will-be available to me  et

               public demand in west Florida.

                    Any OCS related onshore potable water needs must be satisfied

               consist ent with the plans and authority of the NWFWMD.

                                            6-81

                VI. Florida Game and Freshwater Fish Commission

                     The Florida Game and Freshwater Fish Commission was formed

                to manage Florida's wildlife-and freshwater fish resources. The

                commission promulgates and enforces codes and regulations for the

                protection of these resources. The commission's Division of

                Fisheries works to improve sport fishing throughout the state.

                The Division of Wildlife,is charged withthe development and

                implementation of wildlife management practices and issues hunt-

                ing permits. The Division of Law Enforcement is responsible for
                protecting the state's wildlife and' fresIhwater aquatic life from

                abuse. The Office of Environmental Services reviews projects

                requiring dredge and fill permits, clearinghouse review and

                Development of Regional Impact (DRI).

                     The commission would be directly involved if a pipeline or

                other industry facility should locate in Florida.

                          Florida'a OCS Related  Regulatory Mechanisms

                     The State of Florida has assumed a position of supporting

                OCS resource development, but has made a statement that the

                state's environmental quality should not be unduly jeopardized

                during the resource development process. The necessary laws and

                agencies to administer these laws are in-place and are identified

                as follows:

                I.   Dredge  and Fill Permits

                     The regulation of construction, dredging and filling in

                Florida waters are the res@onsibility of the Florida Department

                of Natural Resources  (DNR) and the U.S. Army Corps of Engineers

                (COE). The DNR operates its program according to Chapter 16B-24,

                                              6-82

              FAC while DERs rules and regulations are contained in Chapters

              17-3 and 17-4, FAC. The rules and regulations governing the COEs

              permitting program are contained in 33 CFR 289.320.

                    The purpose of the DER permitting program that regulates

              dredge and fill and related activities is to maintain and, where

              appropriate, to improve the quality of waters in the state. The

              primary purposes of the DNR permitting programs are: 1) to manage

              and protect state lands; and 2) to control beach erosion. The

              primary purposes of the permitting programs of the Corps of

              En gineers are: 1) to restore and maintain-the integrity of the

              nation's waters; 2) to maintain.the navigability of waterways; and

              3) to protect ocean waters from pollutants dumped by vessels.

                    Unless specifically exempted, all dredging and filling

              activities that are to be conducted in or connected directly (as

              by way of an excavated water body) to certain waters  of the state

              require state and federal permits. Activities requiring a permit

              include, but are not limited to, the following: 1) the construction

              or emplacement of piers, wharfs, docks, dolphins, mooring pilings,

              riprap and revetments, retaining walls, groins, breakwaters,

              jetties, beach restoration, levees, wires or cables over or under

              the water, pipes and tunnels under the water, artificial fishing

              reefs, channels and upland  canals, intake and outfall pipes or

              structures, navigational aids, platforms,  ramps, signs, and fen'cesl

              2) excavation, clearing, and commercial sand and gravel dredging;

              and 3) filling, disposal of dredged material, and the transportation

              and deposition of dredged material in open water.

                                            6-83

              Ii.   Pollutant-Spill Prevention and Control Act, Chapter 376,

                    Florida Statutes

                    Subsection 376.021, F.S. of the Pollutant Spill Prevention

              Control Act acknowledges that the seacoast is a source of private

              and public recreation and, as such, should be protected.    In

              enacting this legislation, the legislature found that the transfer

              of pollutants between vessels, and between terminal facilities

              and vessels within the jurisdiction of state waters and pollutants

              occurring as a result of procedures involved in the transfer,

              storage and transportation of such products pose threats of danger

              and damage to the environment of.Florida. For purposes of the

              legislation, pollution was-defined as the presence of substances

              in the air or water in quantities potentially harmful to human

              welfare, animal/plant life.or property, or in quantities which   may

              unreasonably interfere with the enjoyment of life or property

              including outdoor recreation. Pollutants include oil or any kind
              and in any fo rm, gasoline, pestic'ides, ammonia, chlorine and

              derivatives thereof. With regard to storage facilities, the    Act

              provided that operation of terminal facilities shall require  an

              annual registration certificate and adhere to regulations formulated

              to govern the operation and inspection of such facilities. Sub-

              section 376.021(6) further declared that it was the intent of this

              legislation to support and complement applicable provisions of the

              Federal Water Pollution Control Act as amended. The Florida Depart-

              ment of Natural Resources was empowered to carry out the duties-

              and powers of this Act (Sub@;ection 376.051, F.S.).

                    Subsection 376.07(g), F.S. required that prior to being

                                             6-84

               granted entrance to any port in Florida, the master of a vessel

               shall report:

                     1. Any   discharge of pollatants the vessel has had since

                          leaving the last port;
                     2.'  Any mechanical problem on the vessel which creates
                          the possibility of a discharge; and
                     3.   Any denial of entry into any port-during the current

                          cruise of the vessel.

                     Fraudulent evasion of the provisions of Chapter 376 is a
               second-degree felony punishable as provided Subsections 775.082-

               .084, F.S.

                     Under the provisions of Subsection 376.11, F.S. the Florida
               Coastal Protection Trust F und was established. This fund provided
               a mechanism whereby financial resources are available f   or the
               cleanup and rehabilitation after a pollutant has been discharged,
               to prevent further damages, and to pay for those damages which
               have occur red. The Florida Coastal Protection Trust Fund is a
               nonlapsing revolving fund, which is maintained at a level of $35
               million fromexcise taxes on barrels of pollutant handled. Monies
               from the fund are disbursed for administrative costs, pollution
               discharge abatement, cleanup and rehabilitation of wildlife and
               natural resources, provable discharge damages, acquisition of
               spoil disposal sites and improvements to spoil sites.
                     Subsection 376.12, F.S. established limits on liability
               for prohibited discharges within state boundaries up to $14 million
               or $100 per 'gross registered ton for vessels in violation of
               Chapter 376, F.S. When the Department of Natural Resources (DNR)

                                             6-85

               can show that the discharge -was the result of willful or gross

               negligence or willful misconduct within the knowledge of the owner

               or operator, that owner/operatof will be liable for-the full amount

               of funds expended. When a discharge occurs from a terminal

               facilityl the liability is limited to eight million dollars,

               except in the case of neg@igence or misconduct, in which case

               the operator is liable for all costs. Additionally, any person
               claiming to have suffered damages as a result of a discharge of

               a prohibited pollutant may, within 180 days of the date of the

               discharge, apply to the DNR for reimbursement from the fund. This

               statute also prohibits a governmental agency from "holding
               harmless"" a vessel or terminal facility from liability for a

               prohibited discharge.

          III. Energy Resources Part 1, Regulation of Oil and Gas Resources,

               Chapter 377, Florida Statutes

                    Public policy, as defined in Chapter 377, F.S. is to conserve

               and control the natural resources of oil and gas in said state and

               the products made therefrom (Subsection 377.06, F.S.). The Florida

               Department of Natural Resources is responsible for governing all
               phases of the exploration, drilling and production of oil, gas,
               or other petroleum products in the state including exploration,
               drilling, and-production in the offshore waters of the state

               (Subsection 377.22, F.S.).  Subsection 377.24, F.S. mandates that

               a permit is.required prior to the drilling of an e'xploration well.
               No permit will be granted @o drill for oil or gas within the
               corporate limits of any municipality unless the governing authority

                                            6-86

               approves the application for such permit by resolution. No permit

               will be granted in tidal-waters within three (3) miles of a

               municipality or,county unless approved for permit by resolution

               of the governing body (Subsection 372.24(6), F.S.). Subsection

               377.242, F.S.-states that no structure intended for the drilling

               or production of oilmay be located within one mile seaward of

               the coastline of the state. No permit shall be granted within one

               mile inland-fromthe coastline unless it is determined that the

               estuaries, beaches, and sh ore areas of the state will be adequately

               protected in the event of an acciden*t. Under the provisions of

               Subsection 377.243, F.S. two conditions must be met prior to obtain-

               ing a drilling permit. These are: the ownership of a valid deed

               or lease which grants the right to explore for oil and/or gas; and,

               satisfactory evidence that the applicant will implement a program

               for the control of,pollution which may occur as a result of the

               activity. In order to protect the gas and oil fields in the state,
               Subsection 377.40, F.S. declared'it to be unlawful for any person

               to permit negligently any gas or oil well to go wild or to get out

               of control. The owner of any such well shall, after 24 hours w ritten

               notice by the Division of Resource Management given to'him or the

               person in possession of such well, make reasonable effort to control

               such well.

           IV. Environmental Land and Water Management Act, Chapter 380, Florida

               Statutes

                     The purpose of this Act is to develop growth and management

               policies to protect the natural resources, environment, and water

                                            6-87

               quality of the state which may be implemented to the maximum extent
               possible by local governments through existing processes (Subsection
               380.021, F.S.)'. Subsection. 380.05, FS. provides for the.designa-
               tion of areas of critical state concern by the Administration
               Commission (Governor and the Cabinet) if these areas contain or
               have a significant impact upon environmental, historical, natural
               or archaeological resources of regional or statewide importance.
               An area of critical state concern may be designated if it is
               affected by, or has a significant effect upon, an existing or
               proposed maj or public facility or other area of major public
               investment. Once an area is.designated, the Land Planning Agency
               may recommend specific principles for guiding the development of
               the area. The local government having jurisdiction over the land
               area designated has the opportunity to develop land use plans and
               regulations for these lands which are consistent with the specific
               principles established by the State Land Planning Agency. Develop-
               ment permits.issued for activities within these areas must be in
               accordance with these development plans and regulations.
                    Subsection 380.06(l), F.S. defines the concept of
               Developments of Regional Impact (DRI) to be any development which,
               because of its, char acter, magnitude, or location would have a
               substantial effect upon the health, safety, or welfare of citizens
               of more than one county. Proposals for DRIs must be reviewed   by
               regional planning councils (RPCs) which request comments from
               local governments as part of the review process and then make
               recommendations to local governments whether to approve, deny or
               approve with conditions the proposed DRI. Local governments are

                                           6-88

              responsible for implementing the recommendations made by RPCs-
              Chapter 27F-2, Florida Administrative Code contains the standards
              which identify developments presumed to be of regional impact.
              Industrial parks/plants must provide parking for more than 1,500
              vehicles or occupy a site greater than on square mile to be con-,
              sidered a DRI.. Petroleum storage facilities are assumed to be
              DRIs if the facility would be located within 1,000 feet of any
              navigable water and have a storage capacity of over 50,000 barrels
              or.if the facilities would have a storage capacity exceeding
              200,000 barrels (Subsection 2.08, Ch. 27F FAC). Therefore, it is
              probable that the only OCS facilities  that might be reviewed as
             .developments of regional impact would  be the petroleum storage

              facilities.

                    Further, Subsection 380.23, F.S. specifies the following
              projects which require a consistency review to ensure t hat activ-
              ities are in accordance with Florida's Coastal Management Program:
                    1. Federal development pr6jects which significantly affect
                        coastal waters and adjacent shorelands of the state;
                    2.  Federal assistance projects  which significantly affect
                        coastal waters and adjacent  shorelands of the state and
                        which are reviewed as part of the A-95 review process;

                        and

                    3.  Federal activities affecting land or water uses when such
                        activities are in or seawatd of the jurisdiction of local
                        governments re quired to develop a coastal zone protection
                        element and when such activities involve:

                                           6-89

                          a. Permits required under Sections 10 and 11 of the

                              Rivers and Harbors Act of 1899, as amended;
                          b. Permits required under Section 103 of the Marine

                              Protection, Research and Sanctuaries Act of 1972,

                              as amended;

                          C.  Permits required under Sections 201, 402, 403, 404
                              an d 405 of the Federal Water Pollution Control Act

                              of .1972, as amended, unless permitting activities

                              pursuant to such sections have been delegated to

                              the state;

                          d.  Permits required under  the Marine Protection Research

                              and Sanctuaries Act of 1972, as amended (33 U.S.C.

                              Sections 1401, 1402, 14-1-1421, and 1441-1444);
                          e.  Permits for the construction of bridges and.causeways
                              in navigable waters required pursuant to 33 U.S.

                              Section 401, as amended;
                          f.  Permits relating to the transportation and dumping
                              of hazardous substance materials which are issued

                              pursuant to the Hazardous Materials Transporta   tion
                              Act, 49 U.*S.C. Sections 1801-1812, as amended, or
                              33 U.S. C. Section 419, as amended;

                          g.  Permits and licenses required under 43 U.S.C. Section
                              717 for construction and operation of interstate gas
                              pipelines and storage facilities;
                          h. Permits required under 15 U.S.C. Section 717, as
                              amended, for.construction and operation of facilities

                              needed to import/export natural gas;

                                             6-90

                        i. Permits and licenses required for the siting/

                            construction of any new electrical power plants as
                            defined i n Subsection 403.503(7), as amended;
                        j.  Permits and licenses required for drilling and

                            mining on public lands;

                        k.  Permits for areas leased under the OCS Lands Act,

                            as amended,  including leases and approvals under
                            43 U.S.C. Section 1331, as amended, or exploration,

                            development, and production plans;
                        1.  Permits for pipeline rights-of-way for oil and gas

                            transmission; and

                        -M. Permits and licenses required for deepwater ports

                            under 33 U.S.C. Section 1503, as amended.

           V. Local Government_Compre'hensive Planning Act, Chapter 163.3161

              Florida Statutes

                    The Local Government Comprehensive Planning Act (LGCPA)
              requires all local governments to adopt a local comprehensive plan.
              It is the intent of the Act to encourage and assure cooperation
              between.municipalities and counties and to encourage coordination
              of planning and development activities between local governments
              and regional and state agencies. The direct effect of this Act on
              OCS onshore activity was stated in Subsection 163.3194(l), F.S.
              Once a comprehensive plan has been adopted, "all development under-
              taken by, and all actions taken in.regard to.development orders.by
              governmental agencies in regard to land covered by such plan or
              element shall be consistent with such plan or element as adopted."

                                           6-91

              This consistency also applies to local government zoning,
              subdivision, building, and construction, or other regulations
              controlling the development of land (Subsection 163.3194(2)(b),
              F.S.). It should be noted that Subsection 163.3177(4), F.S. calls
              for the local government comprehensive plan to be coordinated
              with the state comprehensive plan. Under the provisions of the
              Federal Coastal Zone Mana�ement Act, local comprehensive plans
              within a state participating in the coastal zone management
              program must be consistent with the state's coastal zone manage-
              ment plan. Because the Coastal Zone.Management Act.states that
              local governments cannot unreasonably restrict uses of regional
              benefit,..local governments would not, in all probability, be able'
              to prohibit onshore OCS development through provisions contained
              within their comprehensive plans.

          VI. Land Acquisition Trust Fund, Chapter 253, Florida Statutes

                  The Board of Trustees of the'Internal Improvement Trust Fund
              (BTIITF) of the state is vested and charged with the acquisition,
              administration, management, control, suspension, conservation,
              protection and disposition of all lands owned by, or which may
              hereafter insure to, the state or any of its agencies or depart-
              ments (Subsection 253.02(l), F.S).  Lands vested in the BTIITF

              according to Subsection.253.03, F.S. include all:
                  1. Swamp and overflowed lands held by the state;
                  2. Lands owned by the state by right of sovereignty;
                  3. Internal improvement lands;

                  4. Tidal lands;

                                           6-92

                  5. Lands covered by shallow waters of the ocean, gulf, or

                      bays/lagoons, and all lands owned by the state covered.

                      by fresh water;

                  6.  'Parks, reservations or lands/bottoms set aside in the

                      name of the state excluding held for road and,canal

                      rights-of-way; and

                  7.  Lands which may a6crue to the state from any source

                      excluding.road and canal rights-of-way or spoil areas/

                      borrow pits; or land which is or may become.vested in

                      any port authority, flood control,,navigation, or water

                      management district created by any general or special act.

                  The BTIIF may sell the land to private interests but must

              consult the Department of Environmental Regulation (DER) in the

              case of submerged tidal lands. The BTIFF.must be party to any
              action seeking to acquire*submerged lands or lands lying beneath

              navigable waters in the state through eminent domain proceedings

              (i.e. pipelines, etc.). Subsection 253.023, F.S. discusses the

              Conserva tion and Recreation Land Trust Fund whose purpose is the

              acquisition and protection of such lands.

                  If objections are-filed concerning the sale of state tidal lands,

              the BTIIF shall withdraw the lands from sale if it appears that the

              sale will:

                  16 Be contrary to public interest;

                  2.  Interfere with rip arian owners rights;,

                  3.  Result in a serious navigation impediment;

                  4.  Interfere with natural-resource conservation; or

                  5.  Result in destruction of marine productivity of habitats.

                                            6-93

                   Subsection 253.47, F.S. authorizes the BTIIF to lease or

               sell bottoms of state owned bay, lagoon, straits, etc. for

               petroleum purposes. No drilling or permanent structures can

                       'thin one-quarter of a mile of the shoreline of lands of
               occur wi

               an upland owner without the owners consent nor can private property

               be invaded. Purtherf Subsection 253.60, F.S. specifies that the

               development of lands leased by the BTIIF for the production of

               pil/gas will be in accord with Florida's conservation/control laws

               and in cases of conflict these  laws shall prevail. State permitting
               @agencies must obtain consent of the BTIIF,.before issuing permits

               over state lands post July 1980,

                   l.. Lan ds within a mun icipality's corporate limits except by

                        prior consent of the municipal governing authority;

                   2.   Tidal or submerged lands abutting or adjacent to the

                        corporate limits of a municipality or within three miles

                        of such corporate limits from the mean high tide line

                        into the waters except by prior municipal consent; or

                   3.   Lands on any improved beach located outside an incorporated

                        town or municipality or such lands in the tidal waters

                        abutting or adjacent,ot any improved beach.or within three

                        miles of,an approved beach from the mean high tide line

                        into-such waters except by prior consent of the county

                        commissioners.

          VII. Florida Industrial Siting  Act, Chapter 288, Florida Statutes

                   This chapter requires  Rrocedures to coordinate and facilitate

               state decisions relating to industrial plant siting and applies to

                                               6-94

                eligible oil and gas related onshore facilities. A person

                proposing construction within aquatic preserves may use the

                procedures established by this Act only if the construction is

                water-dependent and consistent   with applicable aquatic preserves'

                acts in.Chapter 288. @A person   proposing construction within any

                of the Outstanding Florida Waters may use this Act's procedures

                only if the construction is consistent with Chapter 17-3, Florida

                Administrative Code, as amended.

                    Subsection 288.505, F.S. states that no certification hearing

                for the construction of the facility.will.be held until local

                government approval has been received verifying compliance with

                Chapter '380 (if applicable); the local government comprehensive

                plan, zoning, land use and local pollution control ordinances.

                This local government ap  proval is effective for two years during

                which time the zoning and land use of the project may not be

                altered except with the applicant's agreement.

                    Under,Subsection 288.509(4),  .F.S.,  the Florida Department of

                Environmental Regulation is required to    conduct or contract for,

                studies of the proposed project including its:

                    1.  Environmental impact;

                    2.  Economic impact;

                    3.  Impact on publ  ic facilities including transportation

                        facilities;

                    4.  Impact on energy demand; and

                    56  Compliance with agency standards.
                    Studies must be comple.ted two months after their initiation.
                Certification is effective for seven years and constitutes the sole

                                                6-95

               license of the state and any agency as to the approval of the

               construction/operation of the proposed project. Additional rules

               by DER will become automatic modifications of the certification

               except.where specific variances/exemptions are included in the

               certification. Certification may be revoked or suspended pursuant

               to Chapter 120, F.S.

        VIII. Easements, Chapter 704, Florida Statutes

                   This chapter provides that state interest for easements preempt

               other rights of entry and that rights of entry for the purpose of

               mining, drilling, exploring or developing oil/gas, minerals or

               fissionable materials will be reserved unless those rights are

               excepted or not affected by the provisions of Subsection 712@03

               or Subsection 712.04, F.S.

                            General State Regulatory Mechanisms

           I.  Miscellaneous Executive Functions, Part I: State Comprehensive

               Planning, Chapter 23, Florida Statute s

                   Subsection 23. 0114, F.S. mandates the preparation of a state

               comprehensive plan by the Division of State Planning. The state

               comprehensive plan must be based on the best available data and

               must provide long range guidance for orde-rly social, economic and

               physical growth'of the st&te by setting forth goals, objectives

               and policies. Chapter 77-306, Laws of Florida mandate the State

               Coastal Zone Plan to become a part of the State Comprehensive

               Plan. The State Comprehensive Plan, once adopted by the Florida

                                             6-96

               Legislature, has the potential to indirectly manage most energy

               facilities which are likely to locate in the coastal zone since

               it will include the State  Coastal Zone Plan. The state and area-

               wide clearinghouse review  proposed federally sponsored activities
               for consistency with state/regional/iocal policies and objectives.

               Any energy facility relying upon federal assistance would be subject

               to an A-95 review conducted by a regional planning council.

                   Subsection 23.012, F.S. calls for the coordination of planning

               and programming among federal, state and local levels of government

               for a number of activities including., but.not limited to: economy;
               industrial development; commerce and trade; transportation and

               safety;.oceanic and water resources; pollution and environmental'

               health; and public utilities and services.

           II. Beach and Shore Preservation Act, Part I:,Regulation of Construction,

               Reconstruction and Other Physical Activity, Chapter 161, Florida

               Statutes

                   Part I of this law provides for the regulation of construction

               along the coast by the Division of Marine Resources, Department of

               Natural Resources (DNR). Subsection 161.041, F.S. provides for

               permits which are rquired for any coastal construction or recon-

               struction specifically undertaken for shore protection purposes,

               if upon lands of the state below mean high water line.

                   Subsection 161.051, F.S. declares that the state shall not be

               liable for nay damages arising out of construction, maintenance, or

               improvements of permitted.coastal works.

                   Subsection 161.052, F.S. establishers coastal construction

                                              6-97

               setback lines on a statewide basis. A 50-foot construction setback

               line from the mean high water line is established which prohibits

               construction seaward of the line without a waiver or variance

               approved by DNR. These setback requirements do not apply to

               coastal...locations having vegetative non-sandy shores. The DNR may

               authorize the.construction of pipelines or-piers extending outward

               from the shoreline, unles's it determines such construction would

               cause erosiQn'of-the beach in the area of the structure(s). Also

               the DNR may exempt portions of the coastline from the setback

               provision if, because of their natur.e, they are not subject to

               erosion of a substantially damaging effect to the public.

                    in Subsection 161.053, F.S. coastal construction is regulated

               on a county basis by DNR  by establishing coastal construction lines'

               following studies and a public hearing for each area involved.

               Control lines established under provisions of this section shall be

               subject to review at the discretion of the DNR after consideration

               of hydrographic and topographic'data. The aim is for local

               administration of coastal control lines through building and zoning.

               ordinances. However, if DNR determines the local program is inade-

               quately administered it has the power to revoke the authority granted

               to the county or municipality.

           III.-Intergovernmental Programs, Chapter 163, Florida Statutes

                   Enables counties and incorporated municipalities to plan for

               future development and to prepare, adopt and amend comprehensive

               plans to guide future development. Counties and incorporated

               municipalities of the state may adopt comprehensive plans, adopt
               and enforce zoning and subdivision regulations, land and water usel

                                             6-98

                as well as building, electrical, gas and sanitary codes.. Subsection

                163.180, F.S. provides for planning commissions. Subsection 163.185,

                F.S. charges planning commissions to review propose d activities or

                plans for conformity with a duly adopted comprehensive plan prior to

                construction or alteration. Performance standards for the use of

                property and.location of structures thereon may be regulated

                through zoning ordinances. Subsection 163.3167, F.S. directs each

                county and each municipality in this state to prepare and adopt a

                comprehensive plan as set out in this Act. F or those units of

                local government lying in part or in whole in the coastal zone, a

                coastal zone pro tection element shall be included. Also to be

                included is a utility element in conformance with the ten-year site

                plan required by the Florida Electrical Power Plant Siting Act,

                Part II, Chapter 403, F.S.

           IV. State Parks and Preserves, Chapter 258, Florida Statutes

                    Subsections 258.17-258.32, F.S. are known as the "State Wilder-

                ness System Act". The Depar tment of Natural Resources is directed

                to give early consideration to wilderness areas which:

                    1.  Are in close proximity to urban or rapidly developing areas;

                    2.  Are in imminent danger from some other source;

                    3.  Are designed to protect rare or endangered species or other

                        unique natural features; and

                    4.  Constitute the last vestiges of natural conditions within

                        a given region.

                    The following is a li.st of general management criteria for all

                wilderness areas.

                                              6-99

                      No alteration of physical conditions within a wilderness

                      area shall be permitted except to provide:

                      a. Minimal use facilities, such as hiking-trails, pit

                          toilets, manually operated water pumps, and primitive

                          camp sites; and

                      b.  Minimum management facilities, which may include

                          boundary fences and unimprovedvehicle trails for

                          control purposes and emergency access.
                  2.  The following are specifically prohibited activities or

                      uses:

                      a.  Dredging and dredge'spoil dumping;

                      b.  Artificial drainage or impoundments;

                      C.  Farming;

                      d.  Clearing of land;

                      e.  Dumping of wastes;

                      f.  Mining;

                      g.  Pesticide spraying, except emergency measures required

                          to protect public health and spraying for forestry

                          disease control;

                      h.  The,use of motorized vehicles on land or water, except

                          for emergencies or valid management purposes; and

                      i.  Removal-of timber, except to restore original plant

                                 'ties.
                          communi

                 .3.  All human activity within each wilderness area shall be

                      subject to special rules and regulations for implementing

                      the intent and purpose of Subsections 258.17-258.32 for the

                      particular area involved.

                                            6-100

                  4. Other uses of a wilderness area,  or human activity within

                      the area, although.not originally contemplated, may be

                      permi tted by DNR, but only after a formal finding of

                      compatibility made by DNR, and subject to regulation.

                  Subsections.2,58.35-258.46, F.S. are known as the Florida Aquatic

              Preserve Act of 1975. Section 258.16, F.S. establishes the Boca

              Ciega Bay Aquatic Preserve', Pinellas County, specifies its boundaries

              and prohibits.dredging, drilling, and excavation for minerals.

                  Subsection 258.391, F.S.-designates Cockroach Bay in Hillsborough

              County as an aquatic preserve for a p(@riodof 40 years under a lease

              with Tampa Port Authority and gives the exact boundaries.

                  Subsection 258.42(3)(a), F.S. limits dredging and filling in

              aquatic preserves to certain activities which require a permit.

              These include:

                  1. minimum dredging and spoiling as authorized for public

                      navigation projects;

                  2.  Minimum dredging and spoiling as authorized for the creation

                      and maintenance of mar inas, piers, docks, and associated

                      na.vigati on channels;

                  3.  Other maintenance dredging as required for existing

                      navigation channels;

                  4.  Reasonable improvements as may be necessary for public

                      utility installation or expansion; and

                  5.  Installation/maintenance of oil and gas transportation

                      facilities.

                  Subsection 258.42(3)(c), F.S. prohibits drilling of gas or oil

              wells within aquatic preserves. However, the state is allowed to

                                           6-101

              lease oil and gas rights and permit drilling from outside the

              preserve area. Subsections 258.42(3)(f) and (g), F.S. prohibit
              the discharge of excessive amounts of permitted wastes and of non-

              permitted wastes in aquatic preserves (amounts that would inhibit

              the accomplishments of the purposes of this Act).

                  No energy.facilities may be sited in state parks, wilderness

              areas, or aquatic preserve's without the approval of the Board of

              Trustees of the Internal Improvement Trust Fund, or for more
              routine types of construction, the Department of Natural Resources.
              All such construction as may be allowed must obtain.the necessary
              permits and must not pollute these areas sufficiently that deteri-
              oration of their natural qualities is noticeable. Certain types
              of energy transportation facilities are allowed within aquatic
              preserves, but oil and gas drilli ng within the preserves is

              expressly prohibited by law.

           V. Florida Archi ves and History Act,* Chapter 267, Florida Statutes
                  Subsection 267.061, F.S. states it is the policy of the state
              to protect and preserve sites and properties which have scientific,
              cultural or historical value or are of interest to the public.
              This Act provides for the acquisition and preservation of historic
              sites and properties and includes, but is not limited to fossil
              deposits, Indian habitations and sunken or abandoned ships. It is
              also state policy that treasure found on state lands (including
              submerged state lands) shall belong to the state. A permitting.
              process to regulate field i.nvestigation activities upon publicly
              designated archaeological sites is provided for in the law.

                                          6-102

               Subsection 267.11 provides a procedure for publicly designating
               and archaeological site. Once a site is so designated, no person
               may conduct field investigation activities without first s     ecuring
               a permit from the Division of Archives, History and Records

               Management.

          VI. Game and Freshwater Fish, @hapter 372, Florida Statutes

                   Subsection 372.85, F.S. prohibits contamination of fresh waters
               by the introduction of any substance in sufficient quantities to
               injure, stupify, or kill fish. Thus any drilling operations
               located on or near the fresh waters of the state must employ pre-,
               cautionary measures to prevent pollution of those waters as

               required by the Florida Game and Fresh Water Fish Commission.

         VII.  Water Resources Act, Part I: State Water Resources Plan, Chapte     r 373,

               Florida Statutes

                   The Florida Water Resources Act of    1972 covers all waters in

               the state unless specifically exempted    by general or special law
               (Subsection 373.023, F.S.). Subsection 373.016, F.S.      provides for
               the comprehensive management of water and related land use includi     ng
               but not limited to: the development of dams, impoundments,
               reservoirs and other works and to provide water storage for bene-
               ficial purposes; and to prevent damage from floods, soil erosion

               and excessive drainage.
                   Subsection 373.033,  F.S. establishes a procedure whereby a
               saltwater barrier line  is drawn. This could affect the construction
              ,of energy facilities since no deepening or widening of waterways

                                             6-103

               would be permitted that would allow further saltwater encroachment.

               Subsection 373.036, F.S.,mandates a state water use plan which must

               address the use and,quality of-water in the state bf Florida. This

               plan has the potential to preclude energy facilities for reasons

               relating to water consumption or water quality.

          VIII-Water Resource Management Act, Part II: Permitting of Consumptive
               Uses of Water, Chapter 373, Florida Statutes

               Subsection 373.219, F.S. sets forth the requirement for a permit

               for the consumptive use of water and imposes reasonableconditions

               to assure that the permitted use is consistent with the overall

               objectives of the water district or DER and is not harmful to the

               water resources of the area. No permit is required for domestic

               consumption of water by individual users. Subsection 373.223, F.S.

               sets forth the conditions for a permit. The use to which the water

               is to be put must be a "reasonable-beneficial" one. This means the

               use must be reasonable from the standpoint of other landowners and

               the public.

                   For the West Florida Region, consumptive use permits are

               required by the Northwest Florida Water Management District under

               the following conditions:

                   -1. If the withdrawal of water exceeds 1,000,000 gallons on any

                       given day or if the average annual daily withdrawal exceeds

                       or will exceed 100,000 gallons average a day on an annual

                       basis;

                   2.  If the withdrawal is from a well with an inside diameter

                       of six inches or more;

                                            6-104

                   3. If the withdrawal eqpupment or other facility has a
                       capacity of more than 1,000,000 gallons a day; and

                   4.  If the withdrawal is from a combination of wells or of

                       other facilities or of both, having a combined capacity
                       of more than 1,000,000 gallons a day.
                   Duri ng the.exploratory stage OCS facilities require approxi-
               mately 5,200,000 gallons o@ water per year per exploratory rig.
               In the permitting-of consumptive uses of water by energy facilities,

               states may develop performance standards or other reasonable

               criteria.

                   Subsection 373.590 has been called the Save   Our Rivers Bill.
               When adopted, this subsection increased the documentary stamp tax
               on deeds and other land transactions and deposited the increase
               into the Water Management Lands Trust Fund.- Floridals five (5)
               water management districts use the money to purchase interest in
               lands necessary for water management, water supply and the conser-

               vation/protection of water resourbes.

          IX.  Environmental Control, Part I: Pollution Control, Chapter 403,

               Florida Statutes

                   Subsection 403.021, F.S. declares that the pollution of the air
               and waters of the state constitutes a menace to public health and
               welfare and is harmful to industrial,  recreational and other
               beneficial uses of air and water. Parts II and III proclaim that
               it is the public policy of this state to conserve the air and
               waters of the state and to protect,  maintain and improve the quality
               thereof. The propagation of wildlife and aquatic life is protected

                                            6-105

              for domestic, agricultural, industrial, recreational and other
              beneficial uses. No wastes are allowed to be discharged into any
              waters of the state without.the necessary treatment to protect the
              beneficial uses of the water. Waters of the state include rivers,
              lakes, streams,and all other bodies of water such as saline,
              brackish and tidal waters. Subsection 403.088, F.S. mandates that
              permits are required*for s@-ationary installations which will

              reasonably be expected to be a source of air or water pollution.
              No di scharge into water within the state of any waste thatreduces
              the quality of the water is permitted.without authorization. Permits

              are to be denied if the discharge of waste will lower the water
              quality below established levels. Subsection 403.085, F.S. requires
              permits for ocean outfalls. Secondary treatment or other treatment
              as,may be required is necessary before the permit will be granted.
                  Subsection 403.061, F.S. grants authority for pollution control
              to DER, which must establish ambient air and water quality standards,
              determine sources of pollution and establish a permit system for
              operations or construction activities that may be a source of air
              or water pollution. Energy facilities that significantly affect
              the coastal zone may be regulated by the enforcement of performance
              standards relating to air and water quality.

          X. Forest:ry, Chapter 589, Florida Statutes
                  Subsection 589.011,,F.S. authorizes the Division of Forestry to
              grant easements for rights-of-way through state forest lands for
              the construction and maintenance of electric power lines and oil
              and gas pipelines under such conditions/limitations as the Division

                                          6-106

              may impose. The Division may be allowed t o lease its interest in
              oil, gas, and minerals within state forests under certain conditions.
              Actions of the Division of Forestry and the Board of Trustees of
              the Internal Improvement Trust ;und in administering this law
              frequently result in.rerouting of proposed pipelines/powerlines.
                  Although the law gives authority to the Division of Forestry
              of the Florida Department*of Agriculture and Consumer Services to
              grant easements through state forest lands for power lines and oil
              and gas pipelines, in fact, final approval is granted by the
              Governor and Cabinet sitting as the Board of Trustees of the
              Internal Improvement Trust Fund (Subsection 253.03(g), F.S.).

          XI. Air Pollution, Chapter 17-2, Florida Administrative Code
                  Chapter 17-2.03(4)(b), FAC, Prevention of Significant
              Deterioration, provides standards for determining when significant
              deterioration of air quality occurs in three specified types of
              areas, and.contains guidelines to prevent air quality from being
              degraded below significant levels. The rule states that each area
              of the state shall be placed in one of three specified deterioration
              classes. Aliowable deterioration of air quality in each class of
              area is estimated or measured from a 1974 air quality baseline.
              The-air quality areas are labelled Class I, II or III. Standards
              are established for maximum allowable annual increase in micrograms
              per cubic meter of particulate matter and sulfur dioxide in each
              area. Twenty-four hour maxima are established for both types of
              pollutants, and three hour maxima are -instituted for sulfur
              dioxide. Restrictions on increased concentrations of these
              pollutants are most severe with Class I areas; Class II areas

                                          6-107

              pollutants are most severe with Class I areas; Class II areas
              have moderate restrictions.on allowable increases in air quality
              degradation.; and Class IIIareas are least restrictive. The rule
              establishes no significant deterioration standards in any class
              of area for carbon monoxide, lead, nitrogen dioxide, or any known
              air pollutants.other than the two already mentioned. The West

              Region is a Class II area.

                  Procedures are also set forth in the,rule for either upgarding

              0
               r downgrading the classification of an area. The designated
              Clas,s I areas and any area exceeding,10,000 acres in sixe which is
              also a national monument, a national primitive area, a national

              preserve,..a national recreational area, a national wild and scenic
              river, a national wildlife r efuge, a national lakeshore, or a
              national seashore may not be downgraded to Class III areas.

                  Any energy facility that would emit sufficient amounts of
              particulate matter or of sulfure  dioxide to cause a cumulative

              reduction in air quality for the class of area in which it is
              located would have to use cleaner technology or it could not be
              built. Energy facilities cannot be located in any of the areas
              designated as Class I. Class II and III standards have little
              effect on energy facilities siting except in those areas where air
              pollution levels of particulate matter and sulfur dioxide are
              already high. Most of thses areas are found within metropolitan
              air sheds. In the West Florida Region there are no non attainment

              areas.

                                           6-108

                            Regional OCS Related Mechanisms

                  The West Florida Regional Planning Council (WFRPC), is an
              association of local governmente formed to provide citizens of
              the region with policies, plans and data to guide development and
              use of regional resources in Escambia, Santa Rosa, Okaloosa, Walton,
              Bay, Holmes and Washington.Counties, Florida (Planning Region I).
              The WFRPC serves in a advisory capacity andhas no regulatory
              authority. D ue to its unique format the WFRPC is in a .position
              to participate in any planning effort which has a regional or
              subregional scope.. The Planning Council conduct's several planning
              programs that may directly impact' any onshore OCS facilities

              within Planning Region I.

              I. Regional Outer Continental  Gulf Onshore Facilities Siting Study

                  for West Florida

                  The topic of this study is to evaluate the potential onshore
              impacts of OCS activities and to propse possible facility sites
              for oil and natural gas industry needs. The findings of this

              work are contained herein.

              II. WFRPC Clearinghouse Review

                  A. Development of Regional Impact

                      The WFRPC is the designated agency responsible for review-
                  ing and assessing the,potential impacts of any development
                  presumed to be of regional impact. The Planning Council staff

                  reviews proposed development plans and makes recommendations
                  to local governments and to the Florida Department of Community

                                          6-109

                  Affairs pertinent to the impacts of a Development of Regional
                  Impact (DRI)..

                  B. State of Florida Intergolrernmental Coordination and

                      Review Process

                      This review process replaces the review process established
                  by the U.S.' Office of Management and Budget as per Circular
                  OMR. The review process is designed to.teview and determine
                  the consistency of any proposed federal funding or rules
                  promulgation. The process is intended to insure the
                  evaluation, review and coordination of  any proposed federal
                  action at the regional and local levels. The WFRPC is the
                  designated regional.clearinghouse for this review process for
                  Florida Planning Region I.

                  WFRPC ongoing Planning Programs

                  A. Transportation Division

                      The WFRPC maintains a staff of transportation planners to

                  study, plan and propose so lution for the current and future

                  transportation needs of the region. The staff works through
                  metropolitan Planning Organizations (MPOs) for input and public
                  participation. Any long term transportation needs for OCS

                  facilities would be considered by the Transportation Division.

                  B. Clean Water Planning

                      The WFRPC Environmental Division has worked to prepare a

                  three (3) county plan for the restoration of clean water.    The
                  plan and its recommend .a'tions have been updated and expanded

                  annually since 1978. Any proposed onshore OCS activities

                                           6-110

                 within the region would be reviewed for consistency with the

                 208 Clean Water Plan recommendations.

            IV. Regional Issues Positions

                 The WFRPC has compiled a Regional Issues list that was prepared

             to assist'interested persons determine what the Council's positions

             are for'various' issues of regional significance in Planning Region

             I. The list is divided into seven (7) categories, each containing

             a statement of the Council's positions.

                     1.  Economy

                         Environment/Natural Resources

                         a. water quality

                         b. water quantity

                         C. other natural resources

                     3.  Public Support Services

                         a. potable water

                         b. wastewater treatment and disposal

                         C. drainage

                         d. solid waste

                     4.  Transportation

                         a. highways and roads

                         b. rail transportation

                         c. waterborne transportation

                         d. mass transit

                     5.  Housing

                         a. fair housing

                         b. land use

                                          6-111

                      6. Energy

                         a. energy generation

                         b. 6 nergy utilization

                      7. Government and Human Services

                         a. emergency and safety services

                         b.. education'

                         C. recreation and open space

              V. Regional Goals, Objectives and Policies

                  The WFRPC has prepared and adopted axegional goal of
              11achieve the highest long-term quality of life for all residents
              of the region, consistent with sound social, economic, and
              environmental principles through proper land development". The
              Council maintains its policy statements in twelve (12) different
              categories.. The Council policy categories are:

                    1.   Regional Residential Land Use Policies

                    2.   Regional Commercial Land Use Policies

                    3.   Regional Industrial Land Use Policies

                    4..  Regional Transportation Policies

                    5.   Regional Agricultural and Silvicultural Policies

                    6.   Re gional Air Quality Policies

                    7.   Regional Water Resources Policies

                    8.   Regional Wetland Policies

                    9.   Regional Topography and Soils Policies

                    10.  Regional Beaches and Dunes Policies

                    11.  Regional Natural Hazard Policies

                    12.  Regional Economic Development Policies

                                         6-112

                WFRPC policies which have a direct impact on the siting of

             OCS onshore facilities are:

                1.  Influence the timing, distribution, type, density, scale

                    and design of development through the coordination  of

                    land development pro posals with state and local comprehen-

                    sive plans and public investment programs to insure the

                    availability of adequate public facilities, services, and

                    other..resources.

                2.  Protect and maintain the desirable social and economic

                    characteristics and functions.of developed areas in a
                    manner consistent with the capabilities of the natural

                    and man-made systems of the are'a.

                3. Encourage the provision and maintenance of adequate

                    public facilities in already developed areas, and control

                    further growth and new development in areas where public

                    facilities and services overburdened.

                4.  Allocate to newly served developments an equitable share

                    of the cost of expanding public facilities.

                5.  Recruit industrial development at the regional level in

                    order to limit unnecessary counterproductive competition

                    between area local governments.

                6.  Encourage the establishment of tax incentives for new

                    industries which meet existing federal and state standards

                    and locate in appropriately designed industrial parks or

                    suitable sites.

                7.  Regulate industrial.development in the 100-year flood

                    plain in compliance with the requirements of the National

                    Flood Insurance Program.

                                          6-113

                     8. Discourage industrial development on soil.s and slopes
                         which are unsuited for the proposed use.
                     9. Discourage industrial development that would degrade
                         environmental quality    below that defined by Florida
                         and National laws and    regulations.,
                   10. The location of industrial development should be in
                         areas where air @ollution resulting from such develop-
                         ments will not sevely degrade the      air quality of

                         nearby residential areas.

                   11.   Protect estuarine areas and other marine habitats
                         .from adverse environmental impacts resulting from
                         .improper industrial development.
                   12. Provide industrial park locations in close proximity
                         to the Region's population and labor market centers.
                   13.   Incentives should be used to encourage the reservation
                         of prime industrial sites for future industrial use.
                   14.   Discourage industrial development in.areas not readily
                         served by public fac   ilities.
                   15.   Encourage the location of industrial parks near other
                         employment centers which have similar utility and service
                         requirements.
                   -16.  Encourage protection of industrial developments from
                         incompatible land uses.
                   17.   Industrial land use development should be compatible
                         with the local road and street system.
                   18.   The transportation system should be designed to support
                         planned growth and minimize conflicts w     ith other land

                         uses and the environment.

                                              6-114

                  19.  Encourage development of the road network in a manner
                       which affords access to areas where future development-

                       is desirable.

                  20.  Sufficient right-of-ways and building setbacks should
                       be reserved for future road construction and expansion.
                  21. Encourage the provision of adequate parking facilities

                       for proposed land developments.
                  22. Protectmajor transportation facilities from incompatible

                       land uses.

                  23.  Local streets and roads should be designed to be compat i-
                       ble with auto and truck traffic resulting from ma3or

                       -transportation facilities.

                  24. Utilizing the siting requirements and standards of the
                       Federal Clean Air Act and Chapter 17-2, F.A.C., insure
                       that stationary sources emitting air pollutants be

                       located and operated in such a manner as to:

                       a) Protect and enhance'the public health and welfare.
                       b) Prevent the significant deterioration of air quality.
                       c) Insure the attainment and maintenance of primary and
                          secondary ambient air quality standards.
                  25.  Discourage concentrations of wells which would produce
                       adverse drawdowns in the aquifer and allow saltwater

                       intrusion.
                  26.  Discourage individual disposal systems, such as septic
                       tanks, in urban areas and areas considered environmentally
                       sensitive.
                  27.  Encourage protection of groundwater supplies and aquifer

                                         6-115

                       recharge areas through surface water management,

                       regulation of development activities, and implementation

                       of 208 Clean Water Pian Recommendations.'

                  28.  Promote land use patterns and land development practices

                       which result in minimal non-point and point source dis-

                       charges into surface waters.

                  29.  Encourage the protection of lakes, streams and wetlands

                       as natural occurring water storage areas.

                  30.  Land development decisions should be based on the long

                       and short term capabilities of the hydrologic systems

                       to provide adequate suipplies of water.

                  31.-- Encourage the development and use of wetlands and

                       submerged lands only for purposes which are compatible

                       with their natural.values and functions.

                  32.  Discourage the discharge into wetlands and submerged

                       lands of pollutants or materials in amounts which

                       would destroy or significantly harm their value and

                       functions.

                  33.  Discourage the drainage and filling of wetlands and

                       submerged lands.

                  34.  Discourage commercial, industrial, residential develop-

                       ment and other developments, whtch by their general

                       purpose, are not-required to be located in wetlands or

                       submerged lands.

                  35.  Development in adjacent upland areas should be located

                       and constructed s6 as to minimize adverse impacts on

                       the values and functions of wetlands and submerged lands.

                                           6-116

                 36. Promote on-site erosion and sedimentation control

                      practices on land alteration projects.

                 37.  Encourage the use of beaches and dunes primarily.for

                      recreation oriented activities which do not alter or

                      ..disturb these resources.

                 38. Discourage urban, residential, or other development

                      along sandy beaches and dunes which,would threaten

                      the-inteqrity of the primary dunes and beaches.

                 39.  Encourage protection of estuarine beaches against

                      incompatible uses, and close regulation of-developments

                      which require locations on or near beaches and shores.

                 40.  .-Encourage regulation of flood prone areas for purposes

                      compatible with hydrological characteristics of the area.

                 41.  Ndn-residential and public facility development in the

                      100-year floodplain areas should be flood proofed.

                 42.  Flood flow ways-in riverine floodplains should be

                      protected from development which would impair their

                      normal capacity to discharge water from the 100-year

                      flood.

                 43.  Development below the 100-year flood level, in coastal

                      areas, should be.located above the mean high tide line,

                      adequately elevated and anchored, and designed to

                      minimize the impz!ct of abnormally high tides and/or

                      wind driven water.

                 44.  Adequate transportation facilities should,be provided.-

                      to enable prompt evacuation of people from hurricane

                      danger zones.

                                         6-117

                 45. Discourage increased urban and residential development

                      in flood hazard@areas which would require large

                      expenditure s of public. funds for flood control,-

                      through the use of non-structural flood controls.

                 46. -Encourage the utilization, preservation, and restoration

                      of natural resources so as to provide protection from

                      wind, wave, and water damage.

                  Local Government OCS Related Regulatory Mechanisms

                  The local governments of.the region m.ay be required to

             accomodate more onshore impacts of OCS oil industry activity than

             any other level of government. No local government has specifically

             addressed the onshore needs of the oil industry if a hydrocarbon

             find is discovered offshore from West Florida, however, certain

             OCS related regulatory mechanisms are in place. Local governments

             have been-granted authority or mandated by the Florida Legislature

             to accomplish certain activities that may impact OCS onshore

             developments. The general OCS related functions are summarized

             below.

                     General Local Government Regulatory Mechanisms

             I.   Local Government Comprehensive Plans

                  All local governments are required to adopt a local government

             comprehensive plan, as mandated by the Local Government Comprehen-

             sive Planning Act (LGCPA). These plans are intended to   serve to

             preserve and enhance the present advantages of Florida's resources

                                          6-118

              and to encourage and guide appropriate future use of each govern-

              ment's resources. Each comprehensive plan contains elements'

              determined, by the state, to be necessary for a comprehensive
              plan, Amendments to comprehensi  ve plans may be required to provide

              for onshore OCS facilities.

              II.  Zoning

                   Subsection 163.205, F.S. provides that zoning may affect the

              development of onshore OCS facilities in three ways. First,

              zoning defines permitted or prohibited uses in     the local govern-

              ments zoning districts. Secondlyr zoning ordinances define uses'

              permitted on particular parcels of land. Finally, zoning

              ordinances can  regulate onshore activities through the adoption

              of performance standards for particular districts or industries.

              Subsections 163.260-295, F.S     also afford local governments an

              opportunity to address the impacts ofonshore facilities. These

              include: 1) the control of the location and development of

              facilities through the emphasis of onsite requirements and/or.

              the division of lots into certain threshold sizes; and 2) building

              regulations which specifically address certai    n types of onshore

              activities.

             III. Development of Regional Impact

                   Local governments can directly affect onshore OCS faciliti.es

              siting through the Development of Regional Impact (DRI) process.

              Chapter 380, F.S. provides that certain developments are presumed

                                            6-119

             to have regional impacts and that the local government involved

             must issue a development order allowing the development after an

             impact assessment review has been completed. It is' not likely

             that any OCS onshore facilities would be presumed to be a DRI.

             IV. Local' Pollution Regulations

                  Subsection 403.182, F.S. provides that a county or municipality

             may establish and.administer an air and water pollution program.

             Additional provisions also allow for noise and odor pollution to

             be regulated. Under this statute, local requirements cannot be

             less stringent than those of the state. Thus, a local government

             might use these local pollution controls to regulate or discourag .e

             onshore OCS development by making the costs of pollution control

             prohibitive.

             V.   Harbor and Port Controls

                  Harbor and port regulations*are administered by various

             authorities. The latitude granted these agencies is dependent

             upon the authority contained in the appropriate local charter

             or special legislation. Activities at a port may be controlled

             by either port regulations or tariffs. Th  e use of these mechanisms

             allows the port manager extensive authority over what may enter the

             port. This includes the r  ight to accept or reject cargo considered

             to be dangerous. This could conceivably prohibit oil or gas from

             entering a port. Such action is highly unlikely in the Tampa Bay

             area due to the extent of petroleum imports.

                  If the port authority or district is autonomous, local land

             use controls may not apply. Therefore, a port may choose to develop

                                          6-120

              onshore OCS facilities despite municipal or county opposition.
              All of the ports in the Tampa Bay Region, with the exception of
              St. Petersburg, have established industrial zoning which would
              allow the development of OCS related facilities.

              VI. Areas of.Critical State Concern

                  Subsection 380.05(2)(c),'F.S., contains provisions whereby
              up'to five percent of the land within the state of Florida may
              be designated as areas of critical state concern. This designa-
              tion requires that protective development regulations be
              promulgated within one year. Such action would make the development
              of onshore-facilities in areas of critical state concern very
              difficult. It should be noted that local governments may nominate
              areas for this designation.

            VII. Historic Preservation Districts

                  Under the provisions of Subsection 267.0615, F.S., the
              Secretary of the Florida Department of State may establish a
              historic.preservation board for jurisdictions throughout the state.
              The purpose of such boards is to locate and identify through
              research all historic districts, sites, buildings, structures
              and objects of historical significance (Subsection 267.0615(3)
              (d)l, F.S.). By nomination of a local government, the establishment
              of a waterfront historic preservation district, if appropriate,
              may prevent onshore OCS facilities from developing in those areas.

            VIII. Interlocal Coordination

                  A decision to encourage or discourage development of onshore

                                         6-121

             OCS facilities by one jurisdiction may conflict with a decision

             by another jurisdiction. In order to avoid such instances,

             Subsection 163.3177(4), F.S. called for each comprehensive plan

             to include a specific policy statement indicating the relationship

             of the development of the area to the comprehensive plans of

             adjacen t jurisdictions, counties, regions, and the state.

             Additional provisions of the Florida Statues allows local govern-

             ments to coordinate with other jurisdictions in one of two ways.

             These are: 1) enter into interlocal agreements (Subsection 163.01,

             F.S.); and 2) form a council of local public officials,(Subsection

             163.02, F.,S.). Either method would allow for a unified position
             when dealing with the possibility of OCS onshore development.

                   Local Government OCS Related Regulatory Mechanisms

             I.    Escambia County

                   A. Comprehensive Plan

                       Policies which may impact OCS onshore facilities

                   siting are:

                       1. Develop a sound industrial base to attract new
                           industries compatible with existing and future
                          .planned land use.

                       2.  Encourage new industries to locate in suitable
                           areas served by utilities and transportation
                           facilities.

                       3.  Avoid excessive drawdown of subsurface water
                           supplies to prevent a saltwater intrusion.

                       4.  Discourage location of residential, commercial
                           and industrial land uses or other developments
                           in floodplains or wetlands by restricting
                           extension of public utilities and services.

                                          6-122

                        5. Dredge and fill activities should be prohibited
                           in areas designated as freshwater swamps and
                           wetlands.

                        6. Maintain and protect the primary dune systems and
                           the vegetation assbciated with marshes'and wetlands
                           on the barrier islands.

                       .7. The marshes and marine grass beds of the coastal
                           zone are considered vital to the maintenance and
                          .protection of the coastal and economic resources
                           of Escambia County, and as such, developments
                           which would degrade or minimize the natural
                           productive capacity of such areas are discouraged.
                        8. The white characteristics of the sands of the barrier
                           islands shall be retained through strict enforcement
                           of Escambia County Ordinance 74-2. All staining,
                           bleeding and leaching soils which would tend to
                           discolor the sands shall be strictly prohibited.

                           Activities or developments which cause or allow
                           saltwater intrusion into the freshwater lens of
                           the barrier islands are prohibited except as
                           autho rized through special review processes.
                      10.  Dredging, filling or activities artifically lowering
                           the water table of the barrier islands are prohibited
                           except as authorized through special review.
                      11.  Use the industrial development program to attract
                           industries requiring skills-that match those of
                           Escambia County residents or that residents can
                           easily acquire..

                      12.  Promote industrial development and guide it to
                           locations in planned parks or selected sites which
                           are economically sound, protect the natural environ-
                           ment and protect the health and safety of people.
                      13.  Encourage the executive and legislative branches of
                           of state government to take a positive attitude
                           toward new industry and promote industrial growth
                           which would meet federal and-state environmental
                           regulations.

                      14.  Encourage state legislation providing tax incentives
                           for new industries.

                      15.  Provide industrial parks designed to attract and
                           accommodate the type industries desired for the area.
                      16.  Cooperate with military authorities and congressional
                           representatives to maintain a strong military
                           presence in the County.

                                         6-123

                         17.  Cooperate with industries now located or planning
                              to locate in the County to develop a favorable
                              climate for compatible industrial growth.

                         18.  Increase employment opportunities in those
                              businesses and imdustries that are seasonally,
                              cyclically and structurally stable.

                         19.  Encourage industrial parks located with exposure
                              to major traffic arteries.

                         20.' Industrial parks not requiring direct surface
                              water access should be discouraged from locating
                              within the 100-year floodplain and encouraged to
                              examine alternative sites outside the floodplain.

                         21.  Adopt and enforce a local ordinance which requires
                              flood prevention facilities in all new and existing
                              industrial developmentin the 100-year floodplain.

                         22.  Discourage industrial development that would degrade
                              environmental qua'lity below that defined by Florida
                              and national laws and regulations.

                         23. Develop and adopt construction and     operating
                              standards to protect estuarine and    other environ-
                              mentally sensitive areas, from adverse environmental
                              impacts due to industrial development.

                         24.. Locate industrial parks and other industrial sites
                              away from sensitive estuarine/marine environments.

                         25.  Control stormwater through onsite development of
                              structures designed to minimize peak stormwater flow.

                         26.  Insure continued potable water availability by
                              preventing excessive withdrawals, particularly in
                              areas of known and suspected saltwater encroachment.

                    B.   Zoning

                         Escambia County has not adopted a county wide     zoning
                    ordinance. Only portions of the county are zoned       (City of

                    Pensacola, University of West Florida), however, a      zoning

                    ordinance is being drafted for the barrier island,      Perdido

                    Key which is consider6d as a possible landfall for      an OCS

                    pipeline.

                                              6-124

                   C. Site Plan Review Process

                       Escambia maintains a planning and engineering services

                   department which operates a site plan review process. Any

                   proposed OCS onshore development would be required to comply

                   with the county's review and building permit provisions.

                   D.  Sedimentation Control Ordinance (74-.6)

                       Escambia. County requires that stormwater volumes should

                   be retained on site or that stormwater discharges cannot be

                   any greater after development than before development.

             II.   Santa Rosa Island Authority

                   The Santa Rosa Island Authority was established by a special

             act of the Florida Legislature to serve on behalf of Escambia

             county to develop an d manage the Santa Rosa Island Development

             Code. The code is intended to insure that all development on

             Pensacola.Beach will be done in an orderly manner. The Authority
             is responsible for permitting*construction and leases to Pensacola

             Beach properties and would be involved in any discussions con-

             cerning a  possible landfall for a pipeline at Pensacola Beach.

            III.@ City of Pensacola

                   A. Comprehensive Plan

                       Policies which relate to OCS onshore facilities' siting

                   are:

                       1.  The City should promote industrial devel opment and
                           guide it to l6cations in planned parks or selected
                           districts or sites which are economically sound,
                           protect the natural environment, and protect the
                           health, and safety of people.

                                          6-125

                       2. Industry should be located near major transportation
                           nodes-to reduce travel time and energy consumption.

                       3.  The City should insure the:

                           a)   protection of industrial development areas from
                                incompatible uses,

                           W    establishment of land uses which are compatible
                                with industry types already located in the, area,
                           c)   adequate land adjacent to the site has been set
                                aside foi@ future expansion without encroaching
                                on land uses of an incompatible nature.
                       4.  Industrial land use development should be compatible
                           with the local toad and street system and should not
                           be located in areas where increases in traffic flow
                           will overtax the existing road system.
                       5.  Existing industrial sites which by nature of their
                           location constitute non-conforming uses should be
                           phased out.

                       6.  Highest priority must be given to water dependent
                           uses, particularly in those areas suitable for
                           commercial use including port and marine..faciliti-es,
                           recreation or resort areas.

                       7.  Development shall be compatible with adjacent land
                           and water uses to the maximum extent practical.
                       8.  Development in area8 adjacent to environmentally
                           sensitive areas are to be sited and designed to
                           prevent impacts which would significantly degrade
                           such areas.

                       9.  The City should continue to take whatever actions
                           are appropriate and within its jurisdiction to
                           mitigate the efforts of rail traffic within its
                           boundaries.

                       10. Minimize the relocation of existing transportation
                           facilities.

                   B. Zoning

                       The Pensacola City Council has prepared and adopted a.
                   comprehensive zoning ordinance. Any siting of OCS related
                   facilities would be in compliance with the City's ordinance.

                                           6-126

                   C. Site Specific Zoning

                       The intent of this ordinance is to allow more flexibility

                   and creativity in site planning, building arrangement, open

                   space and other site planning considerations.

                   D.. Site.Plan Review Process

                       The City of Pensacola maintains a planning department and

                   and eng ineering department to conduct the site plan review
                   and to insure any development is in compliance with existing

                   codes, plans and regulations,.

                   E. ..Erosion and Sedimentation Control
                       This City.runoff ordinanc-e establishes responsibility for
                   the alleviation of the harmful and damaging effects of on site
                   generated erosion, sedimentation, and runoff upon the developer.

                   F. Port of Pensacola

                       Pensacola's port is managed and operated by the City's
                   Port Director. All activities at the port must be consistent

                   with the goals and plans of the Port of Pensacola.

              IV.- Santa Rosa County

                   A. Comprehensive Plan

                       Policies which relate to OCS onshore facilities are:

                       1   Industrial development should occur in areas where
                           the terrain is well drained, free from flooding, and
                           has a good soil bearing capacity.
                       2.  Industrial development should provide a variety of

                                          6-127

                           desirable sites which are relatively level, regular
                           in shape, and provided with, or easily accessible
                           to, basic utilities such as water, sewers, and
                           electricity.'

                       3.  Industrial developfaent should be coordinated in
                           relative industrial complexes in areas large enough
                           to meet the needs of several types and varieties of
                           industrial activities.

                       4.  Industrial areas should have direct access to one
                           or more major transportation systems including
                           highways, railroads, airports, and,water facilities.

                       5.  Functional and related activities should be located
                           together in coordinated and compatible clusters of
                           development.

                       6.  The natural environment.shoul.d be conserved by
                           maintaining sensitivity to development in areas prone
                           to flooding and tidal action.

                      -7.  Compatible and coordinated development should be
                           facilitated by encouraging all development toemploy
                           good design and high standards as well as to utilize
                           the natural environment to its best advantage.

                       8.  Create an attractive and safe place to live.

                       9.  Preserve areas of critical environmental importance,
                           areas of high ecological sensitivity, and areas
                           containing unique natural features.

                      10.  Preserve and protect marine life in shoreline waters.

                      11.  Prevent atmospheric pollution of any type which would
                           adversely affect the environmental quality.

                      12.  Prohibitland and water use activities which lead to
                          ,a continuation of water quality problems in estuarine
                           bayous.

                      13.  Control and reduce the amount of effluent transmitted
                           to coastal waters from domestic, commercial, and
                           industrial sources.

                      14.  Promote the conservation of, marine life vegetation
                           and shoreline areas.

                      15.  Construction within the 100-year floodplain areas
                           should be limited to appropriate construction
                           techniques.

                                          6-128

                      16.  All new development whether residential, commercial,
                           or industrial should be designed to retain within
                           their boundaries the maximum quantity of rainfall.

                      17.  Natural upland vegetation removed for development
                           purposes should immediately be replaced with
                           vegetation indigenous to the area. By replanting
                           with vegetation characteristic of the area, main-
                           tenance and fertilization practices are reduced.

                      18.  Wetlands and tidelands should not be disturbed or'
                           altered in any way except'in cases of overriding
                           public inter6st where there is no other feasible
                           alte rnative.

                      19.  Submerged grasses should be preserved and not
                           modified except in cases of overriding-public
                           interest. If removal is required for a public
                           project, regrassing should immediately follow, if
                           practicable.
                      20.. No new'development'should be  permitted that would
                           threaten the stability of any beach area unless
                           proven otherwise by the developer.

                      21.  Industries and power plants should be encouraged
                           to employ recirculating water systems in their
                           production facilities in an effort to conserve
                           water supplies. Surface water supplies should be
                           utilized as an alternate source with the stipulation
                           that water quality will not be degraded.

                      22.. Insure that designated natural drainage corridors
                           are maintained in an open and unobstructed condition
                           in order to conserve their function and prevent
                           flooding.

                      23.  Discourage development practices which give rise to
                           overdrainage of land and soils.

                      24.  Require developers of industrial sites, subdivisions
                           and PUD's to provide stormwater retention systems
                           where determined feasible after engineering studies
                           to minimi.ze both flooding and non-point source
                           pollution.

                      25.  Preserve the County's beaches and estuarine system
                           through programs of erosion control, beach restoration,
                           marine life restoration, conservation, and polluti.on
                           control.

                                          6-129

                    B   Zoning

                        Santa Rosa County has not adopted a county wide      zoning
                    ordinance.- Only the'City of Milton and the Town of      Jay are

                    zoned.

                    C. Site Plan Review Process

                        Santa Rosa County  is engineering and   inspection department
                    reviews.proposed development plans for consistency with the
                    County's ordinances, regulations and plans.

                    D. Navarre Beach

                       ..Navarre Beach  is a portion of Santa   Rosa Island which

                    Santa Rosa County   leases from Escambia County. The Navarre
                    Beach Executive Director assists the Santa Rosa County Board
                    of Commissioners to insure development is consistent with the
                    plan for Navarre Beach development.

              V.    Gulf Breeze

                    A. Comprehensive Plan

                        1.  Secure the maximum physical, economic, and social
                            welfare for the community through the thoughtful
                            and planned use and development of land, buildings,
                            streets, public facilities, and natural resources.
                        2.  Preserve the quiet, residential atmosphere of the
                            City as a relief from the intense activity of its
                            neighboring large city.

                        3.  Provide a high quality natural environment.
                        4.  Minimize the impact of urban development on natural
                            environmental.systems of the locale and the region.
                        5.  Preserve areas of critical environmental importance,
                            areas of high ecological.sensitivity, and areas

                                             6-130

                           containing unique natural features.

                       6.  Limit population and development activity to a level
                           that will not place demands on the area's natural
                           resources by exceeding their practical capacity or
                           by causing a substantial decline in their quality.
                       7.  Protect and improve the natural distribution and
                           replenishment systems of the area's water resources.

                       8.  Preserve and protect marine life in shoreline waters.

                       9.  Prevent atmo@;phere pollution of any type which would
                           adversely affect environmental-quality.
                      10. 'Deve lop a transportation system capable of efficiently
                           moving people and goods within and through the
                           community.

                      11.  Ensure that all development within-the' city harmo-
                           niously fits into the existing natural environment.
                      12.  Encourage future growth to take place in compact
                           clusters supported by adequate transportation
                           facilities and related community facilities.
                      13.  Encourage all development to.employ good design and
                           high standard as well as to utilize the natural
                           environment to its best advantage;
                      14.  Nonresidential activities should be adequately
                           separated from residential areas by landscaping or
                           other appropriate buffering methods.

                      15.  Dredging and filling of any saltwater tidal marsh
                           or swamp area should be carefully considered in light
                           of many valuable benefits accruing to the area from
                           the presence of these land types.

                      16.  Principal natural drainage corridors should be
                           maintained in an,open and unobstructed condition
                           in order to conserve their function, prevent
                           flooding, and provide for the safety of area
                           residents.

                      17.  Control and reduce the amount of effluent transmitted
                           to coastal waters from domestic and commercial sources.
                      18.  Promote the conservation of tidal marshes and grass
                           beds in the shoreline areas.
                      19.  Prohibit all bonstruction within the 100 year flood-
                           plain unless adequate state approved construction
                           techniques are utilized..

                                          6-131

                      20.  Encourage site planning and design characteristics
                           which will minimize environmental damage by all new
                           developments in the City.

                      21.  Utilize, where possible and feasible, techniques to
                           minimize urban runoff, including the Vetention of
                           stormwater on site.

                      ..22. The natural pattern of drainage and vegetation
                           should be maintained as closely as possible to
                           achieve natural purification and to control the rate
                           of runoff.

                      23.  Shell, rock, or wood chips should be used in place
                           of-impervious surfacing materials. Surfaced areas
                           should be surrounded on as many sides as possible
                           by buffer vegetation to reduce runoff flow rates
                           and absorb pollutants where determined feasible by
                           engineering studies.

                      24.  Regulate development in flood prone areas so that
                           they adhere to Federal Flood Insurance guidelines..

                      25.  Keep low lying areas free from intensive urban
                           development to minimize flood.probelems.

                      26.  Encourage reduction of nonpoint source pollution
                           which results from drainage runoff.

                      27.- Wetlands and tidelands should not be disturbed or
                           altered in any way except in cases of overriding
                           public interest where there is no other feasible
                           alternative.

                       .28. Submerged grasses should be preserved and not
                           modified except in cases of overriding public
                           interest. If removal is required for a public
                           project, regrassing should immediately follow,
                           if practical.

                      29.  Bayous and wetlands should not be dredged, filled,
                           pre-empted, or.altered for nay reason other than
                           in overriding interest projects where there is no
                           other alternative.

                      30.  New development that would threaten the stability
                           of any beach area should be discouraged.
                      il.  Promote water conservation in all new or existing
                           developments.

                      32.  Assure effec@ive administration of solid waste
                           management practices.

                                         6-132

                   B.  Zoning

                       The City of Gulf Breeze has adopted and maintain a

                   active zoning ordinance. The City does  not encourage any

                   industrial or heavy development.

                   C. Site Plan Review Process

                       Gulf Breeze maintains a site plan review process to

                   insure consistency of new development*with the City's goals

                   and plans.

                   D. Erosion and Sedimentation

                      ..Gulf Breeze's runoff control ordinance insures that

                   runoff, erosion or sedimentation problems will be pre-

                   cipitated by new.development within the City's limits.

              VI. Okaloosa County

                   A. Comprehensive Plan

                       Policies of the Okaloosa County Comprehensive Plan which

                   could impact OCS onshore development are:

                       1.  A range of choic e in.land areas and locations for the
                           different types of industry should be provided to
                           meet the anticipated expansion of industry in the
                           County.

                       2.  Whenever possible, industrial plants should group
                           together in planned industrial districts on sites
                           capable of being expanded and developed in stages.

                       3.  Significant aquifer recharge areas should be
                           protected.

                       4.  The impacts of proposed developments on public
                           facilities should be predetermined.

                                          6-133

                       5.  In order to attain a state in the local economy
                           that is consistent with its growth management
                           objectives, Okaloosa County will direct its
                           economic planning efforts toward protecting and
                           enhancing employment opportunities in military,
                           tourism, construction, forestry and agricultural
                           industries.

                       6.  Environmentally acceptable industr ial and other
                           employment center development should be encouraged
                           to locate in suitable locations in the County to
                           diversify the economy and provide increased
                           employment opportunities to the residents of the
                           County.

                       7.  Industrial areas should have direct access to one
                           or more major transportation systems including
                           highways, railroads, airports and water facilities
                           for the transfer of its goods or services.

                       8.  Specific sites should be allowed in areas where the
                           terrain is well drdined, free from flooding, has
                           acceptable soil.bearing capacity and has direct
                           access to at least one major transportation system.

                       9.  Refine the growth strategy to guide future development
                           and to enhance the overall quality of the County,
                           maximize the-effective allocation of public and
                           private resources, provide increased opportunities
                           to the citizens of the County for personal betterment
                           and foster community identity.

                       10.. To reestablish the natural foredune environment in
                           increments, preventing sand damage to private property,
                           retarding erosion, and stabilizing foredune sand drift.

                       11. Ameliorate estuarine water quality by increasing
                           flushing, eliminating stormwater runoff, improving
                           point source discharge, increasing natural assimila-
                           tion of nutrients, and reducing turbidity.

                       12. Retard saltwater intrusion by reducing stormwater
                           runoff, reducing well water demand and inducing
                           groundwater recharge..

                   B. Zoning
                       Okaloosa County is the only county in Planning Region'I

                   that has'adopted and inaintains a county wide zoning ordinance.

                                           6-134

                    Any siting of OCS onshore facilities would be required to

                    be in compliance with the County's prescribed zoning.

                    C. Site Plan Review Process

                        Okaloosa County's engineering and      inspection.department

                    reviews proposed development plans to     insure consistency

                    with the County's ordinances, regulations and comprehensive

                    plans.

                    D. Erosion and Sedimentation Control

                        Okaloosa County has adopted a stormwater runoff control

                    ordinance to insure that any impacts of stormwater runoff

                    are abated by the developer prior to development.

             VII.   Fort Walton Beach

                    A. Comprehensive Pl4n

                        Policies of the Fort Walton Beach Comprehensive Plan

                    that may affect OCS onshore facilities siting are:

                        1.   Prohibit intense industrial development in the area
                             (should be located in Fort Walton Beach Industrial
                             Park).

                        2.   Discourage land and water use activities which lead
                             to continuation of water quality problems in
                             Choctawhatchee Bay and the Santa Rosa Sound.

                        3.   Encourage the maintenance of a quality environment
                             through the proper use and development of land.

                        4.   Encourage the minimization of the impact of develop-
                             ment on natural environmental systems of the area..

                        5.   Encourage any future development to see that it fits
                             harmoniously 'into the natural environment.

                                              6-135

                       6.  Promote the preservation of areas of environmental
                           importance, ecological sensitivity, and unique natural
                           resources.

                       7.  Encourage growth and development in areas in which
                           the resources*are tapable of supporting such growth.
                       8.  Discourage development in flood prone areas within
                           Fort Walton Beach.

                       9.  Discourage development in those areas which serve
                           to recharge the Floridan Aquifer.

                      10.  Discourage development in low lying areas free,from
                           intensive urban development to minimize flood problems.

                      11.  Encourage the preservation of the natural shoreline
                           in Fort Walton Beach.

                      12.  Promote the conservation of marine-life vegetation
                           and sho reline areas.

                      13.  Wetlands and tidelands should not be disturbed or
                           altered in any way except in cases of overriding
                           public interest. If removal is required for a public
                           project, regrassing should immediately follow, if
                           practical.
                      14.  'Marine grass beds should not be destroyed by dredging
                           .or any other modification except in cases of over-
                           riding public interest. In such cases, where marine
                           grass beds require removal during project construction,
                           replanting of the destroyed submerged grasses should
                           be included in the project design and undertaken as
                           soon as possible.

                      15.  The disposal of spoil in estuarine waters should be
                           eliminated in favor of open ocean disposal sites,
                           carefully chosen upland sites, or for use in the
                           creation of spoil islands.

                      16.  Wetlands and tidelands should not be dredged, filled,
                           preempted, or altered for any reason other than
                           overriding public interest projects where there  is
                           no-other alte rnative.

                      17.  Industries should be encouraged to employ recirculating
                           water systems in their production facilities in an
                           effort to conserve water supplies. Surface water
                           supplies should be utilized as an alternate source
                           with the stipulation that water quality will not be
                           degraded.

                                          6-136

                       18.  Encourage site planning and design characteristics
                            which will minimize environmental damage by all
                            new developments in the City.

                       19.  Discourage intensive development around creek
                            basins in both the! City and the fringe area.

                       20.  Utilize, where possible and feasible, innovative
                            design techniques to minimize urban runoff.

                       21.  Areas experiencing a drawdown in the groundwater
                            level should immediately begin studies to determine
                            if any surfaice water bodies in the vicinity can
                            supply sufficient potable water. Where possible,
                            potable surface fresh water sources should be used
                            as the primary source of water. The use of this
                            alternative source of fresh water would allow@the
                            aquifer time to replenish.
                       22.  The natural pattern of*drainage and vegetation
                            should be maintained as closely as possible to
                            achieve natural purification and control the rate
                            of runoff.

                       23.  All new developments whether residential, commercial
                            or industrial should be designed to retain within
                            their boundaries the maximum quantity of rainfall.
                            The quality and release rate of these waters should
                            be maintained as closely as possible to the natural
                            state. The indigenous vegetation and the original
                            soil type of the site should be replenished immediate-
                            ly following the completion of the project.

                       24.  Discourage all construction within the 100-year
                            floodplain unless adequate approved construction
                            techniques are utilized and development approval
                            is granted by the Fort Walton Beach City Council.

                       25.  Provide a compa tible network of streets linked in
                            accordance with proper use and scale so as to meet
                            existing and anticipated traffic needs.

                   B.  Zoning

                       The City of Fort Walton Beach has adopted a City wide

                   zoning ordinance. Any siting of OCS related onshore facilities

                   in Fort Walton Beach would be in compliance with the City's

                   zoning ordinance.

                                          6-137

            VIII. Mary Esther

                  Policies of the Mary.Esther Comprehensive Plan that relate

             to OCS onshore facilities siting are:

                  A. Comprehensive Plan

                      .1. Encourage the minimization of the impact of development
                           on natural environmental systems of the area.

                       2.  Require all development to fit harmoniously into the
                           .natural environment.

                       I.  Promote the preservation of areas of environmental
                           importance, ecological sensitivity, and unique natural
                           resources.

                       4.  Encourage a high level water quality in Mary Esther's
                           surface and groundwater resources.'

                       5.  Encourage the preservation of the natural shoreline
                           in Mary Esther.

                       6.  Protect the aesthetic value of the community in con-
                           junction with physical resources.

                       7.  Encourage orderly and planned growth and expansion
                           consistent with the protection of Mary Esther's
                           .natural-resources in areas which are capable of
                           supporting such growth.

                       8.  Promote and preserve the residential character of the
                           City.

                       9.  Encourage conse rvation oriented development techniques
                           which utilize land efficiently.

                      10.  Promote growth in areas where soils are suitable for
                           development.

                      11.  Encourage site planning and design characteristics
                           .which will minimize environmental damage by all new
                           development in the City.

                      12.  Discourage development in floo d prone areas within
                           Mary Esther unless adequate, approved construction
                           techniques are employed.

                      13.  Keep low lying areas free from intensive urban
                           development to minimize flood problems.

                      14.  Discourage intensive development around creek basins
                           in both the City and the-fringe area.

                                           6-138

                      15.  Future development should be discouraged in the
                           flood prone area east of Magnolia Avenue and south
                           of Highway 98. This site stands at the foot of a
                           corridor that channels significant amounts of
                           drainage runof f toward Santa Rosa Sound. Although
                           it should be left ts open space, the piroperty is
                           privately owned. Future use of this area should
                           be permitted only at low densities.

                      16.. Utilize the natural environment in such a way as
                           to provide less costly, non-structural solutions
                           to drainage problems.

                      17.  Properly regulate land development in flood prone
                           areas.

                      18.  Maintain and enhance coastal economic development,
                           public access, and recreational use consistent with
                           resource limitations;

                      19.  Specific vegetated areas  known to be inhabited by
                           endangered or threatened  species should not be
                           disturbed for any reason  other than overriding
                           public interest. This could.be accomplished through
                           the acquisition of this vegetated area by the s,tate
                           as a reserve for the propagation of the dwindling
                           species.

                      20.  Shell, rock or wood chips, where deemed feasible by
                          .a qualified engineering study, should be used in
                           place of impervious surfacing materials. Surfaced
                           areas should be surrounded on as many sides as
                           possible by buffer Vegetation to reduce runoff flow
                           rates and absorb,pollutants.

                      21.  Preserve and enhance the environmental and aesthetic
                           quality in Mary Esther.

                      22.  Reduce health hazards presented by the disposal of
                           garbage and other materials.

                      23.  Provide solid waste facilities to meet existing and
                           future demands.

                      24.  Ensure that surface and sub-surface water drainage
                           will not adversely impact land development, the
                           transportation system, or surrounding estuarine
                           bodies.

                      25.  Provide services at minimum cost to the environment,
                           minimum public cost, and at a rate compatible with
                           growth trends!

                      26.  Encourage the maintenance of a quality environment
                           through the proper use and development of land.

                                           6-139

                       27.  Assure current levels of water quality are maintained
                            or improved.

                       28.  Before a parcel of land is developed, the long term
                            effects of the structures and of the expected
                            inhabitants on the public works systems should be
                            examined. Development and the associated population
                            growth should not be allowed to exceed capacity of
                            public services.

                       29.  No dredging should be allowed in Class II waters
                            (approved for shellfish harvesting) except for
                            maintenance-dredging of existing public navigation
                            channels..

                       30.  Marine grass beds should not  be destroyed by dredging
                            or any other modification except in cases of over-
                            riding public interest. In such cases, where marine
                            grass beds require removal during project construction,
                            replanting of the destroyed'submerge(i grasses must be
                            included in the project design and undertaken as soon
                            as possible.,

                       31.  The-disposal of spoil in estuarine waters should be
                            eliminated in favor of open ocean disposal sites,
                            carefully chosen upland sites, or for use in the
                            creation of spoil islands.

                       32.  Wetlands and tidelands should not be dredged, filled,
                            preempted, or alter 'ed for any reason other than
                            overriding public interest projects where there is
                            no other alternative.
                    B. *Zoning

                        The Town of Mary Esther has adopted and maintains.a zoning
                    ordinance aimed at promoting'residential development and
                    discouraging industrial development. Industrial siting is

                    encouraged at the Fort Walton Beach Industrial Park. Any OCS

                    related facilities to locate in Mary Esther would be,in

                    compliance with Mary Esther zoning ordinance.

                    C. Site Plan Review Process

                        The Town of Mary Esther conducts a site plan review

                    process of all proposed development to insure consistency

                                            6-140

                     with the Town's ordinances, regulations and plans.

                     D. Estuarine Setback

                          Mary Esther had adopted a requirement that all development

                     on Santa Rosa Sound must be setback from the margin of the

                     Sound.

                IX.  Walton County

                     A.. Comprehensive Plan

                          The Walton County Comprehensive Plan contains the follow-

                     ing policies. that may affect OCS onshore facilities siting:.

                         ..l. Adopt and implement viable zoning ordinances and
                              subdivision controls designed to guide residential,
                              commercial and industrial development throughout
                              Walton County, consistent with goals and policies
                              of this plan.

                          2.  Encourage provision of public services as a positive
                              mechanism for guiding future growth to those areas
                              most suited for development.

                          3.  Preserve the.unique en   vironmental, aesthetic, and
                              recreational features associated with Walton County's
                              coastal   zone.

                          4.  Provide for the preservation of ecologically fragile
                              and unique open space areas"within Walton County.

                          5.  Guide future growth and development to areas
                              consistent with resource limitations and constraints.

                          6.  Encouragesound land development practices which
                              minimize negative impacts upon natural coastal zone
                              features.

                          7.  Promote the wise and prudent use of the County's
                              coastal resources as a means for enhancing the
                              economic well being of Walton County residents.

                     B.   Site Plan Review

                          The Walton County   planning And inspection department

                                               6-141

                   reviews proposed development plans for consistency with
                   the County's ordinan.ces, regulations, codes and plans.

              X.   Bay County

                   A. Comprehensive Plan

                       Policies contained in the.Bay County Comprehensive Plan
                   which could affect the location of OCS onshore facilities

                   are:

                       1.  Adopt a model zoning ordinance.

                       2.  Activities and developments shall not.diminish
                           existing water qualities-

                       3.  Develop and utilize the County's natural resources
                           and man-made infrastructure for the economic and
                           social benefit of the County's residents.
                       4.  Expand appropriate economic opportunities in order
                           to curtail out-migration.

                       5.  Activities and developments in the Hurricane Flood
                          .Zone should occur in a manner that does not jeopar-
                           dize public safety or welfare-
                       6.  Activities and developments should be designed and
                           constructed to protect against the statistical one
                           hundred (100) year storm-

                       7.  Activities and developments in other flood zones
                           should occur in a manner that prevents runoff and
                           erosion, and allows the free flow of water that can
                          .be expected to incur at intervals and during wet
                           seasons*

                       8.  Natural vegetation should be preserved to the maximum
                           extent possible, to prevent or reduce erosion and
                           runoff, and to protect the natural beauty of flood
                           zones,

                       9.  Prevent surface and storm drainage of contaminants
                           and pollutants.

                       10. Ensure that dredging and filling occur only when in
                           the overall public interest-

                       11. Any activity or development on either barrier island

                                          6-142

                            In Bay County shall be carried out with minimum risk
                            to the safety and welfare of prospective residents
                            on the island, and of citizens on the mainland.

                       12.  No activity or development shall be permitted which
                            will reduce the ability of either barrier islands
                            to absorb high waters and hurricane winds.

                       13.  Ensure that no contaminants or pollutants may be
                            discharged into the waters of the lake or its
                            tributary creeks.

                       14.  Port facilities are important and should be maintained,
                            provided always that the associated activities do not
                            diminish existing water quality below the DER
                            standards.

                       15.  Any proposal to dredge channels or berths to serve
                            Port Panama City should be approached with an open
                            mind, and judged on its merits, with the benefits to
                            be fairly compared with the costs of any such proposal.

                       16.  Consider noise levels in decisions regarding public
                            services and facilities, including location, site
                            preparation, orientation (design), and building
                            materials.

                    B.  Zoning

                        Bay County has adopted a County wide zoning ordinance.

                    C1. Site Plan Review Process

                        Bay County conducts a site plan review process of all

                    proposed development to insure consistency with the County's

                    ordinances, codes, regulations and plans.

                    D.  Proposed Ordinances

                        The Bay County Comprehensive Plan contains a list of

                    ordinances that could impact OCS onshore facilities, if

                    adopted. These proposed ordinances are:

                        1.  Zoning Ordinance
                        2.  Industrial Waste Ordinance
                        3.  Flood Hazard'Ordinance
                        4.  Erosion, Runoff and Sedimentation Ordinance
                        5.  Beach Setback Ordinance

                                           6-143

              XI. Panama City

                   A. Comprehensive Plan

                       Policies which may impact OCS onshore facilities siting

                    are:

                       1.  Maintain, restore and enhance the overall quality
                           of the coastal zone environment.

                       2.  Utilize coastal zone resources in accordance with
                           conservation principles.

                       3.. Employ ecological planning principles to determine
                           suitability of permitted development.

                       4.  Preserve endangered living and non-living coastal
                           zone resources.

                       5.  Guard against resource commitments of an irreversible
                           nature.

                       6.  Encourage and promote the development of presently
                           defined industrial areas such as the port, railroad
                           industrial park, and airport industrial park.

                       7.  Industrial uses should be located so as to have good
                           frontage and adequate access to major arterial
                           streets, rail or port facilities.

                       8.  Light industrial areas or activities (wholesale
                           warehousing, commercial) should be well served by
                           rail or truck transportation. Such areas and
                           activities may he able to be located near residential
                           uses if properly screened, buffered and access.
                           provided.

                       9.  Discourage land development in areas which have been
                           designated for preservation or conservation by
                           limiting transportation services to those areas.

                       10, Encourage and strengthen the commercial business and
                           employment opportunities for area residents.

                       11. Provide acceptable access as needed by motor freight
                           carriers.

                       12. Conservation areas should be utilized as passive
                           recreation facilities, such as picnicking, hiking,
                           nature study.and bike trails.

                       13. Areas of poor soils and potential flood hazards

                                           6-144

                            should be considered areas of conservation.
                            Development may take place but only after more
                            thorough study and special precautions are taken
                            to minimize potential problems.

                      .14.' All development adjacent to areas of Class IT
                            waters (West Bay), marine grass beds, and selected
                            coastal marshes, should be carried'out with caution
                            and all reasonable attempts should be made to
                            contain all wastes generated by the development
                            .on site; control runoff and nutrients, and prevent
                            sedimentation.

                       15.  The development of selected freshwater swamps should
                            be-prohibited or discouraged for all but the least
                            disruptive uses. These areas have a high water
                            table, poor drainage and support extensive stands
                            of water-tolerate vegetation. Such areas serve as
                            valuable resources for.surfa.ce water.storage and
                            are unsuited for intensive land development without
                            major alteration.,

                       ..16. All new development within the Hurricane Flood Zone'
                            or 100-year flood line should be required to
                            minimize flood damage by building the groundfloor
                            elevation above the level subject to flooding or
                            flood proof to those elevations.

                       17.  Unless water access is required, development in flood
                            ?lains should be prevented rather than later attempt-
                            ing to protect such investments through construction
                            of flood control Structures at public expense.

                       18.  Natural vegetation in flood plains should be
                            preserved to the maximum degree possible to prevent
                            erosion, retard runoff and protect the natural beauty
                            of the flood plains.

                       -19. All activities in flood plains should consider their
                            potential detrimental effects on water quality,
                            downstream resources, allow for the free flow of
                            water and take adequate measures to prevent these
                            effects.

                       20.  Flood damage prevention facilities should be
                            incorporated in all flood plain development.

                       21.  Natural vegetation along existing drainage channels
                            and inIlood plains should be preserved to prevent
                            erosion, retard-runoff, and preserve natural beauty.
                       22.  Marsh areas 'of greater than forty acres should be
                            placed off limits to development that would
                            significantly alter their character.

                                           6-145

                     23. Marine grass beds (along West Bay) are particularly
                         sensitive to increased turbidity that may result
                         from development activities in adjacent areas.
                         Special attention should be given to control of
                         runoff and introduction of nutrients into such areas
                         in order to preverft increased water turbidity.

                     24. Marine grass beds should not be modified except in
                         cases of overriding public interest.

             XII. Panama City Beach

                  A. Comprehensive Plan

                      Policies of the Panama City Beach Comprehensive Plan

                  which may affect OCS onshore facilities siting are:

                      1.  To promote.and enhance the resort character of the
                          City of Panama City Beach while protecting
                          residential neighborhoods and environmentally
                          sensitive areas.

                      2.  To evaluate during the land development review
                          process the impact of all new land development
                          projects on the natural systems of the City,
                          including soils, vegetation, and water resources.

                      3.  To design, construct, and maintain the stormwater
                          drainage system to protect property from hazards of
                          flooding, preserve'adequate water quality, and
                          maximize the use of the existing natural system
                          in order to minimize stormwater drainage problems
                          and improve overall water quality.

                      4.  To encourage the preservation of marginal lands in
                          their natural condition.

                      5.  To protect, maintain, and develop the variety of
                          natural resources found in.the coastal zone and
                          the hurricane flood zone through coordinated
                          management and regulation..

                      6.  To discouraqe development on properties designated
                          as "marginal land".

                      7.  To discourage future development between Front Beach
                          Road and the Gulf.

                      8., To require a11 development to connect to the waste-
                          water collection system.

                                        6-146

                        9.  To require all new development to be connected to
                            the central water system.

                       10.  To require new development to pay the cost of
                            extending service to the development site according
                            to City stand'ardseand then dedicate the improvements
                            to the City'.

                       .11. To require land development designs and construction
                            that retain the first one-inch of stormwater runoff
                            on-site or discharge it to regional stor mwater control
                            areas that have been determined to have capacity to
                            accommodate*flows from the development.

                       12.. To require land development designs and construction
                            that maintain stormwater runoff flow quantities,
                            peaks, and velocities at or below levels that
                            existed prior to development.

                       13.  To ensure that new development does not adversely
                            impact surrounding properties by altering drainage
                            patterns and water storage capabilities.

                    B. Zoning

                        The City of Panama City Beach has prepared and adopted a

                    zoning-ordinance which required that any new development be

                    in compliance with the City's plans for future expansion and

                    growth.

                    C. Site Plan Review Process

                        Panama City Beach reviews all plans for proposed new
                    development to insure*compliance with the Cityls ordinances,

                    codes and plans.

              XIII. Mexico Beach

                    A. Comprehensive Plan

                        Mexico Beach's p6licies that could affect OCS onshore

                    facilities sit ing are:

                                            6-147

                        1.  Identify the impacts of new developments on
                            environmental and community systems.

                        2.  Minimize excessive public costs of providing
                            facilities in areas with low suitability for
                            development.

                        3.  Provide for restricted building heights along
                            the beach..

                        4.  Eliminate surface drainage runoff and erosion
                            problems along the beach.

                        5.  Protect and enhance the beaches and lowland
                            areas by the use of proper development techniques.

                        6.  Preserve and enhance the residential character of
                            Mexico Beach.

                        7.  Encourage industrial development in the areas
                            compatible with residential development.

                        8.  Utilize coastal zone resources in accordance with
                            conservation principles preserving endangered
                            living and nonliving coastal zone resources.

                        9.  Allow a consumptive use that will diminish a
                            particular resource only after there has been
                            full disclosure to the Town Council and to the
                            public of the short term and long term costs and
                            benefits, so that a wise decision may be made.

                    B. Building Inspection'

                        Mex ico Beach requires that any development be inspected

                    to insure compliance with existing codes and ordinances.

                                           6-148

                                         CHAPTER 6

                                         Footnotes

                1.  Ta'mpa Bay Regional Planning Council. Coastal  Energy Facilities
                    Siting Study, Technical Appendix. September     1982.

                2.  Comptroller General of the United States. Report to   the
                    Congres@_of the United States: Impact of Regulations - On
                    5uter Continental Shelf Oil and Gas Development. 27 February
                    1981-

                3.  New England River Basins Commission. State Participation in
                    OCS Transportation Decisions. July,   1981.

                4.  U.S. Geological Survey and Bureau of  Land Management.
                    Compilation of Laws Related to Mineral Resource Activities
                    on the Outer Continental Shelf, Volume II. January, 1981.,

                5.  U.S. Geological Survey and Bureau of Land Management.
                    Compilation of Laws Related to Mineral Resource Activities
                    on the Outer Continental Shelf. Volume II. January, 1981.

                6.  New England River Basins Commission. Onshore Facilities
                    Related to Offshore Oil and Gas Development Factbook.
                    November, 1976.

                                            6-149

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               West Florida Regional Planning Council. Land Use Policy Guide.
               1978.

               West Florida Regional Planning Council. 208 Clean Water Plan.
               1978.

                                       APPENDIX A

                              IMPACT EVALUATION MATRICES

                                                                   @n

                                                w in               0                 0           0 ri)                 0           t1d
                                                                   1-1               (D
                        0                               (t
                                                        0          0                                                   z           Ft                         rt
                        rt            F,                rt         @_<               rt               rt               (n                                     M
                                      0         n (D               rt                H_          0 0                   11-1
                        @:00          0         0                  0                 @j          0                                 Oj
                                                r.      @d         @:$                           M                                 0
                                                        0                                                                                                     Ct
                        V.,                                                                                            rt,

                                                                                                 0                                 k<
                                                        z                                                                                                     Cn
                        M                               0          @3@                           ::%  0
                                                                                                 rt,  0                M                                      (D

                                                                   H.                                 rt,
                                                                                                 t-4 k<                n
                                                                                                                       0

                                                                                                                                                                                                                          En

                                                                                                                                                                                                                Cn
                                                                   cl                0                0                            0             Population                                                     0         ftj
                                                                                                                                                                                                                0         t-1
                                                                                                                                                                                                                H         0
                                      +                 +          +                 +                +                +           +             Local                                           0 >            0         w
                                                                   H                 H                F-                           H                                                             "a   -         M         H                             I
                                                                                                                                                 Employment                                      0              0         U
                                                                                                                                                                                                 U) 10          0         :r'O
                                                                                                                                                                                                                  4
                                                                                                                                                 Local                                                "0        0
                                      +                 +          +                 +                +                +           +                                                                  (D        1@4
                                      F-J                                                                                                        Revenfie                              H         s-@  F@        F-I
                                                                                                      H                F'          F1
                                                                                                                                                                                                                          0
                                                                                                                                                                                                      (D
                                                                                                                                                                                                 En
                                                                                                                                                                                       1-3       rt 0
                                                                                                      F_               F-                        Land Use                                                       w
                                                                                                                                                                                       En        H 0            0
                                                                                                                                                                                                      @i        C44
                                                                                                                                                 Gulf
                                                                                                                                   >             Access,
                                                                                                                                                                                                      0
                                                                                                                                                                                                                H
                                                                                                                                                                                                 F-
                                                        F                                             F-               H                         Utilities                                       H                        G)

                                                                                                                                                                                                                0         0
                                                                                                                                                 Support
                                                                                                                                                 Service
                                                                                                                                                 Availabi
                                                                                                                                                                  s
                                                                                                                                                                    lity
                                                        +                                             +                            +             Transporta-
                                                        F@         H                 H                H                                                       Access

                                      0                 0          0                 0                CD               CD          CD            Traffic Flow

                                                                                                                                                 Recreation/
                                                        F@                                            H                H                         Tourism

                                                                                                                                                 ConservatiorV
                                                        H                            Ili                                           H             Preservation
                                                                                                                                                 Areas

                                                                                                                                                 Ports

                                   C)                   +                            I                +                            +             Facility-
                                                                                                                                                 costs

                                   F@                   H        @_j                 Fj                                                          Aesthetics

                                                                                     I
                                                                                     NJ                                                          Navigation
                                                                                                                                                 Sto@ to t a- 1-
                                   Ln
                                                                                     Nj

                                                           WEST FLORIDA REGIONAL PLANNING COUYCIL

                                                                 ENVIRONMENTAL RESOURCE IMPACTS

                                                                         A. Pipeline Corridor-
                                                                   (Proposed Industry Facility)

                                                                                     IMPACTS

                                                                 >1
                                                                 4J
                                                           V          w              4J     m                                                                        0
                                                           "q         4j             w    w 0)   N,       w           14                                             .,1
                                                           @4                 02     to   :30    m        ra          -0               W   $4                 0)     41    M
                                                                         >1   (0     X      r.   10 0     w           W 4J       4J    44  IDw                -rq    C4    r.
                                                                         4-3                                          N                                       14                 4J
                                                                                                                                                     $4
                        Alternative Sites                        54   5: -4   $4     ra   w .0   (a .0    m              >1   4  >1    r-1           0        0                  0
                                                                 0    :1 H    w      -A   (dm    H  w     m      w    1 0     a  0     ro            .0       4    $4      10    4J
                                                           $4    lu           4J     H    N I    V $4     Cd     -rf >        0  0     r-4           w     9: w    0 r.    0
                                                           -H    (a                                                           0            r.        -4   .'j -4   r.0     w
                                                                      0       @mc    WO   ='dw   3T)9     OW     ZO   V w     m  M)    '52C rA En             44           Am    W

                                                                                        I
                    1. Perdido Key                         0     -1      0    0      .0     1      -1     0      -1   '-1     -1         1   -1     0         0    *-2       0      10

                    2.* GINS/Santa Rosa                    0     -2      0    0      0     -1      -3     -3     -1   -1      -1       -1    -1     -2 -2            -3    -1  1  -22
                                  County
                    3.    Santa Rosa C3./
                          Okaloosa County                  0     -1      0    0      0     -1      -1     0      -1 -1        -1                    0         0      -2      0 1  -10
                          Line                                                                                                                                                 1
                    4.    Destin                           0     -3      0    0      0     -1      -3     -2     -.1  - 1.    -1                    -1 -1            -3    -17--20

                    5.    Grayton Beach                    0     -3      0    0      0     -1      -3       0    -1   -3      -1                    0       0      -2      -1 -17
                          Vicinity                                           I
                    6.    State Road 79,                   0     -1      0    0      0     -1      -1       0    -1   -1      -1         1   -1     0       0                0 -10
                          Bay County                                         I
                    7.    Mexico Beach                     0     -1      0    0      0     -1      -2       0    -1   -1      -1       -1    -1     0       0        -2      0 -12
                                                                                                                                                                          @0

                    *NA    Not Applicable

                                                    WEST FLORIDA REGIONAL PLANNING COUNCIL

                                                          SOCIOECONOMIC RESOURCE IMPACTS

                                                               B. Onshore Sui@port Base
                                                             (Proposed Industry Faclii-f-y7--

                                                                            IMPACTS

                                                                                                                      0      0             0 0
                                                                                                                                           -H r4                     W     0
                                                                                                                1     '00    -rZ4, 0       4J   V                    0     0
                                                                                                            M r4    W 0,                   0    0                    rq    -H     @4
                                                                             4)     th             r4                                                       V        -P    -P     to
                     Alternative Sites                      Cd                      :D      M      4J     4ki 100                  (d (A                    P4       0     to     V
                                                            H        0    -4                W      -14      -1  r-4 W        44    4) -r4                   1-4 M          a,     0
                                                            0     03 H    (d        to    440      rq       >   ..q r. C:    44    W                   4J   -H  4J         -H     4J
                                                                                    r.    r-4a     H        54 go   0 0                                $4                  >
                                                                                                          9:1a      W .14
                                                                                          :3              :34
                                                                                                                A                                      0    (0'8           z (n
                                                                             A                            M En                     9  9    8    A1'4 $44 Ad A

                                                                                                                                                     ........................
              1. Bayou Chico                                0     +1      +1      +1       +3      +3       +3       +3      -3    -1           0      01 1  +3      0     -1     +13

              2. Por-E'of Pensacola                         0     +1      +1      -3       +3      +3       +3      ..+3     -3    -1        -1       -1     -3      0     -1     +1

              3. Milton/Bagdad                              0     +1      4-1     -1       -2      -2       -2      .+2      -1       0         0      0     -2      -2.     0    -8

              4. Fort Walton Beach                          0     +1      +1      +1       -3      +3       +2       +2      -3    -1           0      0     -2      0     -1     0
                     Industrial Park

              5.     Freeport                               0     +1      +1      -1       -3      -1       +1       -2               0         '0           -2      -1      0    -9

              6.     Port of Panama City                    0     +1      +1      -1       +1      +3       +3       +3      -1 -1           -1       -1     +1      0 -1 +

              7.     Southwest Forest                       0     +1      +1      +1       +1      +3       +2       .+3     -2       0         0      0     +2                   +10
                     Industries                                                                                                                                           L-2
              *NA     Not Applicable

                                                          WEST FLORIDA REGIONAL PLANNING COUNCIL

                                                               ENVIRONMENTAL RESOURCE IMPACTS

                                                                  R - Onshnrl        @u]2p!Qrt Base
                                                                 (Proposed Industry Facillt@y

                                                                                  IMPACTS

                                                               V
                                                               r4                 -W       W                                                                        0
                                                                    4J            W     m  0                                                       m      m
                                                                                                                                                          0         V   tm    r-q
                                                                       >4   ca                     m    0                    4J   44    4) W       .,4    -H            r.    (d
                       Alternative Sites                  0    &    a  4J                       r. 0    .0            W      W    "q    V% 0)      $4     W             -H    4-)
                                                          04   W       -rq  $4    rO    54 -W   Cd 4    m     4)   $4' >4  4 >4   H     9  rq   f-4W      a)            01    0
                                                               W    0 -4    W     -r4   (d W    VA LQ   V)    W    4) m    0 W    rd       0    @4 4      4         W   10    4J
                                                          $4   4J      M    -P    H     N  .0   -W W               >  0    Cd0    r4       W    0  W      W     0   r.  'W              E-
                                                                            cc    0     (d      a)                 .,4 rj  W D    -H    0  04   4  -H  -A .14   r:  0   W               0
                                                                       &          W        En   @c      0                                                      94 U     0     (n        E-

               1. Bayou Chico                             0    -1      0   -2     -1     -1        0    0     -1    0        0      0      0       0     0          -2  -1    -9      +4

               2. Port of Pensacola                       0    0       0   -2     -1     -1        0    0     -1    0        0      0      0       0     0          -2  -2    -9      -8

               3. Milton/Bagdad                           0    0       0   -2     -1     -1     -1      0     -1    0        0    -1               0   -1           -2  -1     11     -19

               4.      Fort Walton Beach                  0   -1       0   -2     -1     -1        0    -1    -1    0        0      0      0       1   -1           -2  -1 -12        -12
                       Tndustrial Park                                                                                                         I-
               5.      Freeport                           0    1       0   -2     -1     - 1 -1         -1    -1   -1        0    -1       0    -1     -1           -2  -2 -16        -25

               6.      Port of Panana Cit                 0    0       0   -2     -1     -1        0       0  -1    0        0      0      0       0     0          -2    0 -7          0
                                               Cit

               7.      southwest Forest                   0    0       0                   1       0       0  -1    0        0      0      0       0     0          -2    0 -7        +3
                       Industries

                  *NA = Not Applicable

                                                                                                        WEST FLORIDA REGIONAL PLANNING COUNCIL

                                                                                                                      SOCIOECONOMIC RESOURCE IMPACTS

                                                                                                                               C. Gas Treatment Facility.
                                                                                                                                                                                                    - T --
                                                                                                                            (Proposed industry FaC111EyT--.

                                                                                                                                                              I1,1PACTS

                                                                                                                                                                                                                                                I M
                                                                                                                                                                                                                                                                   0                             0 0
                                                                                                                        Z                 4j                                                                                                         w             V-1          r.               rj    .,1                                              0
                                                                                                                        0                                                                                                                            w             P4           0                V     4J                                               U           0
                                                                                                                        44                                                                                                                           0                          H                'd    g                                                rf          -H         @4
                                       Alternative Sites                                                                4J                                    0                                            H              4J    W                                  .0           V                                                                       4J          V          0
                                                                                                                        (d                k                   .:1                                          V              $4    0                                  H            fd                                                                      4)          fa         41
                                                                                                                        r-1         eq    0          rq                                      M             -f-f                 H    r-1                           44           9)                                       0          r-4   M                         0,         0
                                                                                                                        :j           fd   V-4         rd                                  %4 4)            -4                        V4              9             44           $4               U)    W A               V          -H    V                         -H         V
                                                                                                                        04           0    R           0                                   f-40             -H                                        0             (d                                  0 w               k          0     to            M
                                                                                                                        0                                                                 :j 0             V                    w              k     -4            $4                                                    0          0     0             0
                                                                                                                                          W                                               0  sc            Z)             V3    (n            E-1    V             E-4                           8     Pt   4'           04         44    U             4           z          U)
                         1.            Southwest Escambia                                                             +1               +1               +2                  -1            -NA              -1                   -1                   -1            -1              -1               0                NAO!              +1               -1          NA      -2
                                       County

                         2.            Gulf'Breeze Peninsula/                                                         +1               +1               +2                  -2            NA               +1                   -1               .+l               -1              -2               0                NA                                 -1          NA      -2
                                       Midway/Garcon Point

                         3.            Holley/Navarre                                                                 +1               +1               +2                  -1            NA               +1                   -1                   +1            -1              -1               0                NA                +1               -1          NA      +2

                         4.            Destin                                                                         +1               +1               +2                  -3            NA               -1                   +1                   +1            -1              -3               0                NA                -3               -3          NA      -8

                         5.            Southeast Walton                                                               +1               +1               +2                  -1            NA               -1                   -1                   -1            -1              -2               0                NA                -1               -1          NA      -5
                                       County                                                                                                    I
                         6.            West Bay                                                                       +1               +1               +2                  -1            NA               +2                   -1                   +1            -1                  0            0                NA                +1 ,             -1          NA      +4
                         7.            mexico Beach                                                                   +1               +1               +2                  -11           NA               -3                                                                          0            0                NA                   1             -2 NA               -6
                         *NA       = Not Applicable

                                                                           WEST FLORIDA REGIONAL PLANNING COUNCIL

                                                                                  ENVIRONMENTAL RESOURCE IMPACTS

                                                                                    C. Gas Treatment Facility
                                                                                    (Proposed Industry Facility)

                                                                                                           IMPACTS

                                                                                                           4J                                                                                                     0
                                                                                        4J                 W                                                                                                      r4
                                                                                                     :1              0                               4J                   0                             0)        4j      01     rq
                                                                                            >1                                          w                                 44                            -ri               r.     fu
                             Alternative Sites                                              _P                                   4)     A                          0      rq    V1  0           W       W                 rq     4J
                                                                                                     k     a     W   4J    fd    .0                                >1           r. -4       r-4 0)      4)                       0
                                                                                                     W     _r4
                                                                                                                 0 W       r_1 W        0     W      4)  W       0 0      ra    (a U        r_1 @4      4                 ra     4J
                                                                                  43        fd       4J    1-f   N   9     4J    $4     (d    r4     >   0       0 0      r_4   ro  W,      0 W      r. W      Q  0       4)
                                                                                                     to    0     (d        W                             0       0 0      'H    V.  04      4 "1     'H 'rl    9: 0       W                   0
                                                                                                           to        U)    @c                            C4      M W      3:    P4  En      U)  rZ.,  rX4 rZ4  94 (1      Q      rn

                                                                                                                                                                                                  f
                               Southwest                                                                                                                                                                        0-3       NAi-15 -17
                      1-       EscarrLbia County                         -2       -1        -1         1     1     - 1           0      NA       3       0         0       -1 -1            NA        NA

                               Gulf Breeze
                      2-       Peninsula/Midway                          -2       -1        -1         1   -1      -1            0      NA -3            0         0       -1 -1            NA        NA          -3      NA!    -15 -17
                      3.       Holley/Navarre                            -3       -1        -1       -1    -1      -1            0      NA.-3            0       .0        -171             NA        NA          -3      NA)-16 -14

                      4.       Destin                                    -3                                        -1            0      NA -3            0       -2        -1 -1            NA        NA          -3      Nk.    -18 -26
                      5.       Southeast Walton                          -2       -1        -1       -1    -1      -1            0      NA -3            0         0       -1 -1            NA        NA          -3      NJ -15 -20
                               County                                                                          I                    I
                      6.  1    West Bay                                  -2       -1        -1       -1    -1      -1            0      NP. -3           0         0       '71 -1           NA        NA          -3      NA -15 -11

                      7.       Mexico-Beach                              -3       -         -1       -       1     -1            0      NIZ -3           0         0       -1 -1            NA        NA        .-3       NA -15 -

                                                                                                                                    T_
                      *NA        Not Applicable

                                                     WEST FLORIDA REGIONAL PLANNING COUNCIL

                                                            SOCIOECONOMIC RESOURCE IMPACTS

                                                                D. Oil Barge Terminal
                                                              (Proposed Industry Faciri-EY-3-

                                                                              I-
                                                                                1-1PACTS

                                                                                                                 4J   I M      0              0  0                      w
                                                             Z       V                                           rf   0 M      9-4   0        rq
                                                             0                                                   r-4  4J 0)    ru    0        4J 4J                     0     0
                                                             -H                                                rh -H  $4 0                    (a (d
                                                             43                                             4) 0)                       r:3
                                                                              4)                                      & @      _4    4J Ca                                    V    to
                      Alternative Sites                      to      k        .1      Z)      M      4j     w  0                     Id                                 4)         41
                                                              I    r-40    r-4                ri)    -V4       ri F-4 M        44    4) -4    a) 0)M     0)    1-1 M               0
                                                             :3    (d r-4   to        TO    44 0)              >   4  r. 0     44    $4 k                4J    -H  4J         -4   4.)
                                                             04    0        0 >       r.      U             !104 * w  (0 0     (d    0  -:j              $4     0             >
                                                             0       p        0       (a    I U      4j        4)     $4 -4    $4                14 $4
                                                                     w        04'     $4                    w W          V                    8                               zo   Cn

                      Perdido Bay/Big Lagoon                 0      +1      +2      -1      NA       -1      +1          +1    -1    -1                  0              -11-1       -3
               2.     Pensacola Bay                          0      +1      +2      -1      NA       +2      +2          +2    -1    -1          0       -1  1  +1      -11-2       +3

               3.     Choctawhatchee Bay                     0      +1      +2      -2      NAr      _1      +1          +1    - 1.  -1          0       0      -2      -1 1        -4

               4.     West Bay                               0      +1      +2      -1      NA       +1      +1          +1    -1    -1        -1        0      -1      -1 -1       -1
               5.     St. Andrews Bay                        0      +1      +2        1     NA       +2      +2          +2    -1    -1        -1               +1      -1 -21      +2

                       --t Anolicable

                                                                    @',TEST FLORIDA REGIONAL PLANNING COUNCIL

                                                                           ENVIRONMENTAL RESOURCE IMPACTS

                                                                           D. Oil Barge Terminal
                                                                             (Proposed Industry Facii-,H@y

                                                                                                  IMPACTS

                                                                           >4
                                                                           4J
                                                                           .,4
                                                                                  0               4J       m                                                      ru                             0
                                                                    .H     r-4    4j                    m
                                                                                           2      m        0)      1@       m            14
                                                                                           :3           :1 0                10           41                                                      4j     01     rq
                                                                                           U)                                               4.)      4.)    (W    0  m          -H      r4                     fa
                          Alternative Sites                                       5                                                                               t7l 4)        W       $4                     4J
                                                                           &      a 4J                     (0         4)    .0              (a       m      .,q                                       @ .,4
                                                                           54     r. -r4   W      ra    $4 4J      0  A     U)    4)     '4 >1    4  >1     f-i   r. -rq    r-1 4)      a)              t7%    0
                                                                           4)     0 @4     4) .   -H    0  m       r4 m     (n    rn     4) m     () U)     ro    (13 0     r-1 4       .9    W  U)     a      41
                                                                    $4     4J        10    43     @j    N  g       4J 54    0            >  0     .0 0      H     10 0)     Q)  tQ   9: Ell   4) 0      4)     Q
                                                                                                                                                                                                                           L
                                                                    "q                                                            z                                                                                        0
                                                                                    &      (a     0     Cd         4)       $4    0      r4 u     4) E)     -H    r. 04     4   -H      H     C: 0      W      :3
                                                                           :3:                    m     m: En      @c       0               ra    co W      3:    W U)      m 44    W 44      K                W

                    1. Perdido Bay/                                 -1            NA     -1       -1    -2         -1      -2     -2     NA        -2        -1     -1          2     -1         -2     -2     -22 -25
                            Big Lagoon
                    2. Pensacola Bay                                -1     -2     NA     -1       -1    -2            0     0     -2     NA        -1        -1     -1          0     -1         -2 -li-16 -13
                    3. Choctawhatchee                               -1 -1         NA     -1       -1      2           2     -1    -2     NA        -2        -1     -1          0     -1         -2 -21        -20 -24
                           Bay
                                                                                                                                                                                                            7-
                    4. West Bay                                     -1 -1         NA     -1       -1 2             -1       -1    -2     NA        -2        -1     -1      -1        -1         -2 -21-20 -21
                    5. St.. Andrews Bay                             -1 -1         NA -1           -1 -2            -1       -1    -2     NA        -1        -1     -1      -2        -1         -2 -21-20 -18

                    *NA       Not Applicable

                                                                    WEST FLORIDA REGIONAL PLANNING COUNCIL

                                                                                SOCIOECONOMIC RESOURCE IMPACTS

                                                                                E. Gas Couresser/Metering:Station
                                                                                (Proposed Industry racii-if-y-j--

                                                                                                      I!-!PACTS

                                                                                                                                                 >4
                                                                                                                                                 43       1m          0                .0 0
                                                                                           43                                                    .,1       w          r-1              H   .'4                          m       r-
                                                                                0                                                                rq        0)         P4    0          4J  4J                           0       0
                                                                                -4                                                               -r4      @40               r4         0   9                V           rq      -4    @q
                                                                                V                     40      w                    -@f    4J  0                       0     4J   S                                      V       4j
                            Alternative Sites                                   0          k   -      .0                 m         V      $4  U  .2                   H     to   m         $4               r4          0       0     403
                                                                                r4    r-4  0    14    1z                 0         -H         H  @4                   44    w    -H    0   0 m              1@1m                tP    0
                                                                                :j    (d   @4    0           ro      44  0         rq         >  -1       9: r:       Im    w          V)  w (a      41     "1 4J               -H    4J
                                                                                                                                          I                                            r             $4     a  w        m
                                                                                                                                          0.  $4 0        (d0                          Z   0 w                                  >
                                                                                0                     :>                 ri                   0           14                               w $4      0                          0  '
                                                                                11,                                                                       EA                           8 A. .4       -                          z
                                                                                                                                                                      E-1                                   08          0
                1. Escambia. County,                                            0     +1              +1       0        NA         +3         +3          +3          0          0         0         IjA       +3       -1
                         Southwest of Cantonment
                2.       Santa* Rosa County,                                    0     +1              +1       0        NA         +3         +3          +3          0          0         0         NA        +3       -1      NAJ +1-
                         East of Jay

                                                                                                                                                                                                                        -2      NA -8
                3.       Okaloosa. Countyl                                      0     +1              +1     -1         NA         -1         -1                                 0         0         NAJ       -3
                -        Northwest of Crestview

                4.       Walton County
                         East of DeFuniak Spring                                0     +1              +1     -1         NA                                                       0         0                            -2      N@ -8
                         Washington County,
                5.       East of Choctwhatchee                                  0                     1      0            A        +3         +3          +3          0          0         0         NA        +3
                                                                                      +1              +                 N                                                                                               -1.           +1
                6.       Bay County - U.S. 231,                                 0     +1              +1     -0         NA         -1         +1          +1      -1             0         0         NA        -2       -2      T3
                         Near Deer Point Lake

                   *NA        Not Applicable

                                                             THEST FLORIDA REGIONAL PLANNING COUPCIL

                                                                 ENVIRONMENTAL RESOURCE IMPACTS
                                                                 E. Gas Compressor/Metering:Station
                                                                    (Proposed Industry Facility)

                                                                                    IMPACTS

                                                           >1
                                                           4j                       41      m                                                                       0
                                                                      V
                                                                                                                                                                    H
                                                                                                          ro        4J                0   $4         4)     0)      V     0
                                                                         >1                                                           44  W. m       rq     "q      04    r.
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                   1.     Escambia County,
                          Southwest of                    -1     NA     NA     0    -@l     1      0      NA   -1     0      NA       -1    -1   NA       NA 71           NA     7     6
                          Cantonment                                                                    I                                                               I
                   2.-    Santa Rosa County,              -1     NA     NA     0    -1     -1      0      NA   -1     0      NA       -1 -1      NA       NA       -1     NA!-7        6
                          East of Jay

                   3.     Okaloosa County,
                          North of Crestvi&v              -1     NAI    NA]    0    -1     -1             NA   -21    0      NA         2  -1    NA       NA       -1     NA!1-9 -17
                                                                                        1          0                                                                         i
                  4.      Walton Countyr                                                                                                                                     I
                          East of DeFuniak                                                         0                                                                         1
                          Spring                          -1     NA     NA     0   F 1      1             NA   -21    0      NA         2    1   NA       NA       -1     NA;    -9 -17
                  5.      Washinqton Count
                          I
                          East of ChoctwhN"'              -1     NAI    NA"    0 -11       -1      0                                  -1   -1
                          chee Bay                                                                        NA   -11    0      NA                  NA       NA       -1     NA     -7      6
                  6.      Bay County, U.S.
                          231, Near Deer
                          Point Lake                      -1     N@     NA     0 -11       -1      0      NA   -2     0      NA       -2  -1 NA           NA       -1     NA     -91 -12

                   *NA     Not Applicable

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