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COASTAL ZONE INFORMATION CENTER 011 and Gas Activities Affecting California's Coastal Zone: A SUMMARY REPORT DECEMBER 1988 TN 872 .C3 .B63 1988 CALIFORNIA COASTAL COMMISSION L) -T/v OIL AND-GAS ACTIVITIES AFFECTING CALIFORNIA'S COASTAL ZONE SUMMARY REPORT CALIFORNIA COASTAL COMMISSION December 1988 Prepared by: Billie C. Blanchard, Project Manager Mark A. Bachels. Intern Assistant Jonathan Van Coops, Staff Cartographer under the supervision of Susan M. Hansch, Manager Energy and Ocean Resources Unit First Edition June 1987 Second Edition December 1988 Acknowledgements .California Coastal Commission Staff Energy & Ocean Resources Unit Cartography Cartography by Robert Bathrick, Emily Schwalen Stephen Skartyedt, and Edward Wade, working under the direction of Jonathan Van Coops Drawings Word Processing Erin Caughman Nancy Padula Kristin Bergstrom Guy Waters Dena Bergstrom Report Duplication Grace Alfaro Contributors The following public and private agencies provided information and review comments on the report: ARCO Oil & Gas Company; California Coastal Operators Group; California Division of Oil & Gas; California Energy Commission Staff; California Local Government Coordination Program; Exxon U.S.A.; State Lands Commission Staff; Minerals Management Service; Phillips Petroleum; Port of Richmond; Port of Los Angeles; Port of Long Beach;-San Francisco Bay Conservation and Development Commission Staff; Santa Barbara County Energy Division; UNOCAL; Western Oil & Gas Asso0ation Tab-le of Contents Page Summary of Statistics ix Introduction I 1. Regulation of Californials Oil And Gas Resources 2 Ii. Tract Leasing in Pacific OCS and State Tidelands 3 A. Summary of California OCS Lease SaIe Activity 4 B. Summary of California State Tidelands Leasing 7 Activity III. Pacific OCS and State Offshore Exploration/Development Plans 24 A. Consistency Certifications of Pacific OCS Plans of Exploration through December 1988 29 B Consistency Certifications of Pacific OCS Plans of Development and Production through December 1988 29 C. State Tidelands Exploration/Development Wells and Platform Reviewed by the Commission from January 1981 to December 1988, 30 D. Summary of Existing, Approved, Proposed, and Hypothetical Platforms in the Pacific OCS And State Ti delands 30 E. Existing Platforms on Pacific OCS Active Leases as of@ 31 December 1988 F. Approved/Under Construction Platforms on Pacific OCS Active Leases as of December 1988 33 G. Existing State Tidelands Platforms and Artificial Islands As of December 1988 34 H. Proposed State Tidelands Platforms as of December 1988 35 IV. OCS and State Oil Production in California 46 A. Current California and U.S. Oil Production in 1987 46 B. Agency Projections for Oil Production in Barrels per day 47 Page V. Revenues from Pacific OCS and State Leases 48 A. Revenue from U.S. OCS Oil and Gas Operations 1 954-1986 49 B. Revenues from Pacific OCS Oil and Gas Operations off California 1963-1987 49 C. Revenues from Onshore and Offshore California State Lands Oil and Gas Operations 1929-1987 49 Vi. Existing And Approved Marine Terminals in California 50 A. Existing And Approved Marine.Teminals for Crude and Petroleum Product Transportation as of December 1988 56 V11. Pacific OCS and State Pipel.ine Systems 64 A. Existing, Approved, and-Proposed Pacific OCS Offshore Ipipelines as of December 1988 68 B. Existing'Major Onshore Crude*Oil Pipeline Systems in California as of June 1986 71 C. Existing Onshore Pipelines carrying Pacific OCS production as of December 1988 in Ventura and Santa Barbara Counties 73 D. Approved/Under Construction and Proposed Onshore Pipeline Systems as of December 1988 in Santa Barbara and San Luis Obispo Counties and to Los Angeles and Texas 76 E. Existing, Approved/Under Construcfion, and Proposed - State Offshore Pipelines from Platforms/Islands, and Subsea Well Completions in California as of December 1988 80 VIII. Oil and Gas Separation/Treatment And Gas Processing Plants 82 in California A. Existing, Approved/Under Construction, and Proposed Separation and Treatment And/Or Gas Processing Facilities in-Santa Barbara, Ventura, and San 'Luis Obispo as of December 1988 IX. Refineries in California 88 A. Pacific Coast Active Refineries as of January 1, 1987 89 iv op Page X. Crew and Supply Bases in California for Offshore Oil 93 X1. Areas off Limits to Oil and Gas Development in California 95 XII. KaJor Coastal Act Is.sues 14entified-Retative to Offshore Oil and Gas Develoownt 99 XIII. NaJor Conditions or ProJect Changes Resulting from the Coastal Commission's Review of Onshore and Off-sham Oil and Gas Development 100 XIV. Major Results of Coastal Comnission Review of Offshore Oil and Gas Development 102 XV. Glossary of Terms 103 XVI. Contacts .111 XVII. Bibliography 114 List of Fioures Figure 1-4 Active OCS Leases 9-12 5-8 Active State Leases 13-16 9(a)(b)(c) Proposed Final Five Year Program 17-19 OCS Oil and Gas Leasing 10(a) Lease Sale 91 20 10(b) Lease Sale 95 21 10(c) Lease Sale 95 MMS Supplemental Call for Information and Nominations 22 10(d) Lease Sale 119 MMS Call for Informati on 23 and Nominations 11 Types of Exploratory Drilling Rigs 26 12 Development and Production Platform 27 13 Gas Subsea Completion 28 14-16 OCS Platforms and Pipelines 36-38 Figure Page 17-23 State Platforms and Pipelines 39-45 24 Fixed Pier Tanker Berth 51 25 Sea Island Tanker'Berth 52 26 Single Buoy or Single Anchor 53 Leg Mooring (SALM) 27 Elevation View of.SALM 54 28 Multiple Buoy Mooring 55 29(a)(b) Marine Terminals-Northern/Southern California. 62-63 30 Offshore Pipeline-Construction 65 31 Onshore Pipeline Construction Spread 66 32 Existing Major Pipeline Corridors 72 33 Onshore Pipelines and Facilities-Ventura County 75 34 Onshore Pipelines and Facilities -Santa Barbara And San Luis Obispo Counties 78 35 Proposed Routes for Crude Oil Pipelines 79 36 Separation, Treatment, And Gas Processing Facilities 87 .37(a)(b). Active Refineries 89-92 38 Crew and Supply-Bases 94 39-40 National Marine Sanctuaries 96-97 41 State of California Coastal Oil and Gas Sanctuaries 98 Vi- List of Tables Table Page 1. Summary of California OCS Lease Sale Acti4ity 4 2. Summary of California State Tideland s Leasing Activity 7 3. Consistency Certifications of OCS Plans of Exploration through December 1988 29 4. Consistency Certifications of OCS Development and Production Plans through December 1988 29 5. State Tidelands Wells and Platforms Reviewed by the Commission from January 1981 to December 1988 30 6. Summary of Existing, Approved, Proposed, and Hypothetical Platforms in the Pacific OCS and State Tidelands as of December 1988 30 7. Existing Platforms on Pacific OCS Active Leases as of December 1988 31 8. Approved/Under Construct-ion Platforms on Pacific OCS Active Leases as of December 1988 33 9. Proposed Platforms on Pacific OCS Active Leases as of December 1988 33 10. Existing State Tidelands Platforms and Artificial@ Islands as of December 1988 34 11. Proposed State Tidelands Platforms as of December 1988 35 12. Current California and U.S. Oil Production in 1987 46 13. Agency Projections for Oil Production in Barrels Per Day 47 14. OCS and State Tidelands Revenues 49 15. Existing and Approved Marine Terminals for Crude and Petroleum Product Transportation 56 16. Existing, Approved, and Proposed OCS Offshore Pipelines as of December 1988 68 17. Existing Major On shore Crude Oil Pipeline Systems in California by Capacity and throughput as of June 1986 71 Vii- Table Page 18. Existing Onshore Pipelines Carrying OCS Production as of December 1988 in Ventura and Santa Barbara Counties 73 19. Approved/Under Construction and Proposed Onshore Pipeline Systems as of December 1988 in Santa Barbara and San Luis Obispo Counties and to Los Angeles and Texas 76 20. Existing, Approved/Under Construction, and Proposed State Offshore Pipelines from Platforms/Islands and Subsea Well Completions as of December 1988 .80 21. E.xisting, Approved/Under Construction, and Proposed Separation and Treatment and/or Gas Processing Facilities in San Luis Obispo, Santa Barbara, and Ventura Counties as of December 1988 83 22. Pacific Coast Active Refineries and Their Operable Atmospheric Crude Oil Distillation Capacity on January 1, 1987 89 Appendices Appendix I Undeveloped California OCS Active Leases*as of December 1988 116 Viii SUMNARY OF STATISTICS 0 Leasing in Pacific OCS and State Tidelands December 1988 Total OCS Tracts Offered ------------------------- 1,691 Total OCS Tracts Leased ------------------------ 369 Active OCS leases ------------------------ 135 Tracts Reviewed by Coastal Commission ------ 1,220 OCS Tracts with Coastal Commission Recommendation for Objection ------------------- 251 State Tidelands Active Leases ------------------ 50 0 Consistency Certifications of Pacific OCS-Exploration/Development Plans Reviewed by Coastal Commission - December 1988 Plans of Exploration by Le ases/Tracts ------ 161 OCS Plans of Exploration ------------------------- 129 OCS Plans of Development and Production 13 0 State Tidelands Wells and Platforms Reviewed by the Coastal Commission from 3anuary 1981:to 1988 State Tidelands Exploration/Development Wells 164 State Tidelands Platforms ---------------------- I o Developmint/Production Platforms in Pacific OCS December 1988 Existing ---------------------------------------- 21 Approved/Under Construction -------------------- 5 Proposed. --------------------------------------- 1. Hypothetical ----------------------------------- 10 0 Development/Production Platforms in State Tidelands December 1988 Existing ----------- 8 Platforms 6 Man-made Islands Approved/Under Construction -------------------- 0 Proposed --------------------------------------- 5 Hypothetical ---------------- -------------------- 16 0 Pacific OCS and State Tidelands Oil Production Pacific OCS 1987 production --------------------- 31,100,000 bbI State Tidelands 1987 production ---------- - 30,300,000 bbl 1999 OCS Peak Production for Santa.Barbara Channel/Santa Maria Basin ---------------------- 247,600 bbl/d 0 Revenues from Pacific.QCS and State Lands Pacific OCS from 1963 to 1987 ------------------ $5,400,314,000 Onshore And Offshore State Lands from 1929 to 1987 ------------------------------------------- $4,917,993,255 0 Existing And Approved;. 44arine Terminals for Crude/Petrole=:Product Transportation in California ------------------------------------- 70 0 Pacific OCS and State Tidelands Piveline Systems Miles of Pipeline installed on Pacific OCS ------- 164 Miles of Pipeline approved/under construction in Pacific OCS -------------------------------------- 101.5 Miles of Pipeline proposed in Pacific OCS -------- 6 Miles of Pipeline proposed in State Tidelands 43 Miles of Pipeline approved and proposed in San Luis Obispo and Santa Barbara Counties and to Texas ----------------------------------------- 3180 0 Existing, Approved, & Proposed Separation and Treatment And Gas Processing Facilities in San Luis Obispo, Santa Barbara, and Ventura Counties ------------ 19 0 Active Refineries in California -------------- 36 0 Existing Crew and Sugply Bases for Offshore Oil Tn-Southern California -------------------------- 8 INTRODUCTION California is a major U.S. oil and gas producer. California ranks fourth in overall oil production and second in OCS production among the oil producing states. The California Coastal Commission and numerous other federal, state, and local agencies are involved.in planning and regulating oil and gas development along the California Coast. This Summary Report provides available current statistical information on onshore and offshore California oil and gas activities. It is intended to be used as a background document for Coastal Commissioners, interested public, and other public agencies in their planning and regulation of ongoing energy development. Commission staff will update and revise the report on a regular.basis. Proposed revisions and changes will be solicited from interested parties and public agencies. The report.focuses on oil and gas development in the Pacific Outer Continental Shelf (OCS), State tidelands, and onshore coastal locations. These areas are all within the review authority of the California Coastal Commission by virtue of the California Coasta-1 Act of 1976 and the Federal Coastal Zone Management Act of 1972. This document is divided into fourteen topical areas which cover leasing activities; offshore and onshore oil and gas exploration and development; oil production and revenue figures; onshore and offshore support facilities; processing facilities; oil and gas sanctuaries; and the major concerns and requirements of the Coastal Commission under its review authority. Section One gives an overview of the regulation of California oil and gas resour'ces. Section Two provides backgroWd information on tract leasing in the Pacific OCS and State Tidelands. It includes the history and process of OCS and State leasing, as well as the present number of active leases off California. Section Three discusses onshore and offshore oil and gas exploration, development, and production Activities. It provides an historical summary of exploration and development plans reviewed by the Commission, as well as the number of existing, approved, proposed, and projected hypothetical platforms in the OCS and State Tidelands. Section Four outlines present and projected oil and gas production in California. Revenue figures on OCS and State tidelands development are provided in Section Five. Sections Six, Seven, and Eight focus on oil and gas facilities including existing, approved, and proposed marine terminals, pipeline systems, and separation/treatment facilities. The refinery process and the number of.operating refineries in California are discussed in Section Nine. The number and location of crew and supply bases in California are addressed in Section Ten. Section Eleven discusses oil and gas sanctuaries which prohibit oil and gas development in California. Section Twelve, Thirteen, and Fourteen outline the Coastal Commission major concerns with oil and gas development, major conditions required by the Commission's review authority, and positive benefits resulting from Commission review of these activities. A glossary of terms is provided in Section Fifteen. It lists numerous definitions for terms used in the text of this report in order to further the reader's understanding of oil and gas terminology.' -2- 1. REGULATION OF CALIFORNIA'S OIL AND GAS RESOURCES Energy development beyond the state three-mile limit on the Outer Continental Shelf (OCS) is regulated by the federal Department of Interior (DOI) Minerals Management Service (MMS) through the Outer Continental Shelf Lands Act (OCSLA) as amended and reviewed by the California Coastal Commission (CCC) thro*ugh the consistency process established by the Federal Coastal Zone Management Act (CZMA). Under the California Coastal Act of 1976, the Coastal Commission exercises direct coastal permit authority over energy development within the three-mile state tidelands area and onshore to -the coastal zone boundary. Where local government has a certified Local Coastal Program (LCP), the local government. assumes this permit authority in the onshore areas of the coastal zone subject to the Coastal Commission's review of appeals. Other state and federal agencies also have review authority over energy development. These agencies, include but are not limited to, the Minerals Management Service (MMS); the State Lands Commis@ion (SLC); the Division of Oil and Gas (DOG); the Department of Fish and Game (DFG); the Regional Water Quality Control Boards (RWQCBs); the Air Pollution Control Districts (APCDs); the Environmental Protection Agency (EPA); the U.S. Coast Guard;, and the U.S. Army Corps of Engineers. II. TRACT LEASING IN OCS AND STATE T-IDELANDS OCS Leasing,- Five-Year Leasing Programs The first step involved in developing offshore oil and gas resources.is carrying out a leasing program and sale. The OCSLA requires the Secretary of the Department of Interior (DOI) to develop a five-year schedule for leasing areas or tracts in the OCS for oil and gas exploration and development. At the Call for Information stage, the DOI requests information from industry, government agencies, and the public on offshore areas that either should or should not be considered for lease. The oil industry submits information on areas which it believes may contain oil and gas, and the State and other parties submit nominations and information within areas where oil and gas development would pose problems. The DOI then selects blocks for further study and consideration for sale, prepares an Environmental Impact Statement (EIS) on those tracts, and holds public hearings on the EIS. After public comment, a final.EIS is written and the Secretary of the Interior decides which tracts will be offered for sale. Since 1963, there have been nine lease sales and one re-offering sale in the Pacific OCS offshore California, and one lease sale offshore Oregon and Washington. As of 1988, there are still 11.4 active OCS leases off the California Coast (see Figures 1-4 and Appendix 1). Table 1 provides a summary of California OCS lease sale activity. In addition to the formal comment process mandated by Congress under the OCSLA, the State of California formerly took the position that offshore oil and*gas lease sales required a consistency review by the Coastal Commission under the provisions of the CZMA. However, in January 1984, in the Secretary of the Interior et al. v. California et al the U.S. Supreme Court held that a lease sale does not require a consistency determination because the sale of OCS oil and gas leases is not an activity "directly affecting" the coastal zone within the meaning of Section 307 (c) (1) of the CZMA. Thus, the state's participation is limited to Section 19 of the federal OCSLA, under which the Governor may submit recommendations on the lease sale. The Coastal Commission has submitted recommendations to DOI on the most recent Lease Sale to be held (Lease Sale 80 in southern California) and has submitted comments on proposed Lease Sales 91 (Northern California), 95 (Southern California), and 119 (Central California). concern over oil development impacts on sensitive coastal areas led Congress to impose a moratorium from 1982 to 1985 restricting leasing in key areas. The moratorium covered the four northern basins, waters offsh 'ore Santa Monica Bay, and waters offshore Newport Beach to San Diego. The Coastal Commission supported'the moratorium in a formal resolution to Congressional leaders. DOI has adopted a new Five-Year Lease Program for the period covering mid-1987 through mid-1992 which includes leasing areas off 'most of the California coast. (see Figures 9a, 9b and 9c) On April 10, 1986 and reaffirmed on February 24, 1987, the Commission recommended that DOI not carry out the Five-Year lease program due to unacceptable impacts on coastal resources, the lack of an overall energy policy which precludes rational planning for such lease sales, and the absence of an adequate EIS. The program is outlined on page 5. Table 1 Summary of California OCS Lease Sale Activity December 19UU Lease Sale Tracts Tracts Offered Tracts Tracts Leased Active Sale Date Offered with CCC Objection* Leased with CCC Objection* Leases pi** 05/14/63 129 57 0 P3** 12/15/66 1 1 0 P4** 02/06/68 110 71 24 35** 12/11/75 231 56 48 06/29/79 148 0 54 0 10 53 05/28/81 ill 29 60 19 39 68 06/11/82 140 24 29 0 15 RS-2 08/05/82 27 0 10 0 2 73 11/30/83 137 137 8 8 4 80 10/17/84 657 61 (plus deferral 23 17 19 91 Pending of all tracts 95 Pending in the S.B. Channel) 119 Pending Totals 1,691 f5_1 369 44 114*** Based on the Supreme Court case (Secretary of Int. vs. California et al.), the Commission has made only recommendations on Lease Sales 80 and 91. These are Lease Sales which occurred either before the establishment of the Coastal Commission in 1972 or the approval of federal consistency jurisdiction in 1978. See Appendix 1 for list of undeveloped California OCS active leases. (Sources: MKS, Pacific Summary Report 1987; California coastal commission files; and California Coastal Comission April 1986 staff reports on Call for Information for Lease Sale 91 and the Doi Proposed Five-Year Lease Program.) M MPM M M M M M laws M M -5- 1. Plan@inq Areas: The Pacific OCS previously had two Planning Areas. In the Final Five Year Program the DOI reconfigured these into three Planning Areas: Northern California California/Oregon border to Mendocino/Sonoma County border Central California Mendocino/Sonoma County border to Monterey/San Luis Obispo County border Southern California Monterey/San Luis Obispo County,border to California/Mexico border 2. Lease Sales: 5 OCS lease sales are proposed for the California Planning Areas: flanning Area Call for Information Lease Sale Issued to be Held 91 Northern Calif. Feb 1986 Oct 1989 95 Southern Calif. July 1987 April 1990 119 Central Calif. Nov 1988 March 1991 128 Northern Calif. Jan 1990 Feb 1992 138 Southern Calif. May 1990 June 1992 Lease sale dates are based on the DOI Final Program. The date for Lease Sale 91 had been delayed to August 1989 pending review by the Bush administration. Both the House and Senate have passed amendments to the DOI.'s budget extending Lease Sale 91 to October 1989. The final size and location of each lease sale will be determined through a two-year planning process that begins with the. Call for Information and Nominations and ends with'the leEkse sale. 3. Subarea Deferrals: DOI proposes to defer nine areas from any leasing during the new Five-Year Program: (Figures 9a, 9b and 9c indicate specific locations) Northern California Areas of Special Biological Significance (ASBS) Pt. Reyes Wilderness Pt. Reyes - Farallon Islands National Marine Sanctuary Offshore San Francisco Bay Offshore Monterey Bay Offshore Big Sur Santa Barbara Ecological Preserve & Buffer Zone Channel Islands National Marine-Sanctuary San Nicolas Basin Buffers around San Clemente and Catalina Islands -6- OCS Lease Sale 91 Northern California On February 13, 1986, the Department of Interior issued the Call for Information and Nominations for Lease Sale 91 (see Figure 10a). Lease Sale 91 is included in the Final Five-Year Oil and Gas Leasing Program for 1987-1992. Proposed Sale 91 includes an area from 12 miles south of Point Arena, north about 75 miles to Point Delgada offshore Mendocino County, and an area offshore the City of Eureka and Humboldt County. The Call area covers 229 blocks totaling 1.3 million acres. On 'April 10, 1986 the Coastal Commission recommended to 001 that no areas be ]eased under Lease Sale 91 due to unacceptable impacts on coastal resources, the lack of an overall energy policy which precludes rational planning for such lease sales, and the absence of an adequate EIS. The Draft EIS document was released December 1987 for public review and comment. Hearings on the document were held in Eureka on February 1, 1988 and in Fort Bragg on February 3, 1988. The hearings were well attended, with over 2,000 people at the hearing in Fort Bragg. The overwhelming majority of testimony pointed to deficiencies in the document and expressed opposition to the Lease Sale which has now been delayed until October 1989. The Commission staff submitted comments on the Draft EIS to the Department of the Interior which identified numerous deficiencies in the document. OCS Lease Sale 95 Southern California On July 9, 1987, the DOI issued a Call for Information and Notice of Intent. (NOI) to prepare an EIS on Lease Sale 95 offshore Southern California (see Figure 10b). It consisted of 1,375 blocks located from 3 to 130 miles offshore San Luis O.bispo, Santa Barbara, Ventura, Los Angeles, Orange, and San Diego Counties. The Coastal Commission staff commented to DOI that proposed Lease Sale 95 would pose unacceptable risks of oil spills, visual and air quality degradation, marine resource impacts, commercial fishing conflicts, And continued impacts on the state's vital tourism indii-stries. On November 17, 1988, the 001 issued a supplemental Call for Information for Lease Sale 95 to add 17 blocks to the sale totaling 76,335 acres offshore Camp Pendleton and the cities of Oceanside, Carlsbad, and San Clemente in San Diego County. (see Figure 10c). On December 14, 1988, the Commission adopted comments opposing the proposed action because of the reasons stated above, and the fact that the Supplemental Call is not authorized under the existing Five Year Program. OCS Lease Sale 119 - Central California On November 10, 1988, the Department of the Interior submitted a Call for Information for the offshore oil and gas Lease Sale 119 (see Figure 10d). This call covers 1.7 million acres, from 3 to 45 miles offshore, affecting Mendocino, Sonoma, Marin, San Francisco, San Mateo, Santa Cruz, and Monterey counties. The Commission is on record objecting to leasing in this region of the Outer Continental Shelf in its March 31, 1981 comments on Lease Sale 53, and in its April 10, 1986 comments on the Five Year Oil and Gas Leasing Program. On December 14, 1988, the Commission adopted comments opposing -7- Lease Sale 119, stati.ng that the sale poses unacceptable risks of oil spills; visual, recreational, and air quality degradation; marine resource impacts; commercial fishing conflicts; and continued impacts to the state's vital tourism industries. Further, the lack of an overall comprehensive policy for energy supply for this nation precludes rational planning for such lease sales. The Commission went on to find.that the EIS for the Five Year Program does not adequately,identify or discuss the impacts of these proposed sales. State Tidelands Leasing The area off California from the mean high tide line seaward to the three-nautical mile boundary is under the jurisdiction of the State of California as a result of Public Law 31, the Submerged Lands Act (SLA), passed by Congress in 1953. The State Lands Commission (SLC) has title to all tidelands and submerged lands with the exception of certain government land. Since 1938 the SLC has issued state leases for offshore oil and gas leasing by competitive' bid and collected royalties for oil and gas production in state waters. The last state offshore lease sale was held in 1968. Another sale. that was scheduled to be held in November 1983, offering eight parcels from Point Arguello to Point Conception, is not currently being proposed by the State Lands Commission. As of 1988, there are.50 active leases in California State Tidelands. (see Figures 5-8) Table 2 lists each lease number with the respective operator and issue date. Ta-ble 2 Summary of California State Tidelands Leasing Activity December 1988 Lease Parcel Tracts Leased - 50 Commission Numbers Operator Issue Date 91 SWEPI 5/21/43 129 ARCO 1/27/44 145 Energy Dev. Cal. 7/3/44 163 SWEPI 11/15/44 186 Exxon 9/24/45 208 ARCO 1/18/46 308 ARCO 3/4/47 309 ARCO 3/4/47 392 SWEPI 9/26/38 410 Bush 4/17/29 421 ARCO 10/22/29 425 SWEPI 1/10/50 Lease Parcel Commission Numbers Operator, Issue Date 426 SWEPI 2/10/50 .427 Mobil 5/19/30 429 Bush 4/21/31 1466 Bush 8/29/55 1824 Chevron 1/10/57 2199 Chevron 7/21/59 2206 Texaco 7/25/68 2725 Texaco 5/4/61 2726 ARCO 5/4/61 2793 ARCO 10/26/61 2879 UNOCAL 4/22/62 2894 Chevron 6/28/62 2920 SWEPI 8/28/62 2933 10/25/63 2955- Phillips 10/20/62 2991 UNOCAL 2/28/63 3004 UNOCAL 4/Z5/63 3033 UNOCAL 7/25/63 3095 Chevron 10/30/64 3120 ARCO 4/8/65 3133 Exxon 5/28/64 3150 Chevron 7/28/64 3184 Chevron 9/29/64 3242 ARCO 4/24/64 3314 SWEPI 7/2/65 3403 Chevron 11/18/65 3413 UNOCAL 12/1/65 3455 (Tract,2) City of Long Beach 3/11/66 01 -9- co S Active OCS Leases Santa Maria Basin Morro Bay 47.3-@ -3.74.. '.375 Son Luis Obispo Av a eac Pt. an Luis Pismo Beach Grover City 3. Son Luis Obispo Co. a 50 Santo Barbara Co. Santo 4. ...... . Maria QjS #09@. 05 Pt. Sol 414.*. 41.5'.. .41.6*. @4 06 @4' 2'0' 421 .22. 42.5 426 424* 4.27 @@424 43-b 431' 4m - .433j.4 4:37@j A-18. 34- -.435.. Lease Parcel N&ne Numbers 49 50OV/ -.440 4Al.' Lompoc LS 53 (373-453) .443. Pt. Arguello El RS-2 (499-500) .445, 44.6.-1.- 44,71- 4443 LS 73 (504-506) 44 .415.2. 451 .453, ........... NeAfow MD" Source: MMS, 8/88 Statute be" dwctfol cowrtak cowftswn Figure cartow-00'y Sockku Active OCS Leases-Santa Barbara Channel Area - - Gavlota 111@6 51 1 1 318 Pt. Conception Santa Barbara Cal 512 Ventura Co. ,31 0 Three 459 Santa Barbara Ellwood Goleta 89 4@6 0 2 1197 i", '1@95 188 @187 464 ..... .. .... 1.94 V329 AHD' Corpjnterlo@ 61 46 w511.84 1831i, 2 1@1. i-80 ........ .......... .240. 2 X X 46 Z@4 2.3-3. .38 34/6 Ventura 232 231 46 XT52@ 4 47 )8,. 217, '21.6,12.1.5. jj Oxnard Richardson .210' 209' - 34 Port Hueneme Rock 112 527 __rZDfl@ @6@ @iO4 Three Son Miguel 1. AnaCGP a Santa Rosa Sot) ta Cruz Island rT Lease Name Parcel Numbers N P 3 - (166) E]P4 (167-241) LS 48 (315-369) LS 68 (456-490) 0 Noulical Mon la Ven ra, 'u xn, rd Port Huene !08 k 202 a LS 80 (511-535) 0 Statute Moes 10 Source: MMS, 8/88_1 dec.11form CQ4916t cohmss" Figure 2 [email protected] to.-bm Active OCS Leases-Long Beach Area El Segundo Los Angeles Go. Orange Co. Long Beach San Pedro 7hree Mile Huntington Beach Mewport Bay .300. 301 Dano Pt. C, C,/% Lease Parcel N Name Nurnbers 0 Nouticd MMs 10 Ito Lj LS 35 (296-306) Statute Matte Source: MMS, 8/881 Figure 3 Eartography S@%@ -12- Active OCS Leases C/I West of Son Diego 0 -LT Lease Parcel Name Numbers LS 68 (489-490) LS- 80 (533-535)' 0 Nowlicd Min 10 statuto Mike Source: MMS, 8/88 Santa Oceanside Catalina Son Wand Clemente' Son Diego U. S. xieo . ....... .. ............ Area. 0 25 .............. San Diego .......... Miles 4 53 ......... Location Map dwI-I. coastal COPWASSM Figure 4 caruw4ww sectias Status of State Leases South Central Coast. 101 Santa Barbara Co. Hollister Ranch Gavioto Pt. Conception 2933 4 01 0. . . ....... a les 2 /27 3.1 2 20 1 2207 72 .1 Iz. z Ellwood 15791 '2205* . ...... .....- ......... 0 Coal Oil Pt. W Mile ... 12 4001 4002 Three 3 4 3499 30 91 Barbara 3498 Santa Active Lease N El Qu.itdaim (Lease Abandoned) V87/ 5 Statute Mae* Source: State Lands Commission, 6/88 Figure 5 Status of State Leases Santa Barbnra Co. arpinteria I / ) South Central Coast Ventura Co. ,J Rincon Pt. ........... .. ....... Punta Gorda ........ . .... 429 427 410 4000 3.84 3 0 Ventura ;6 q-,.i Vaniura Harbor Active Lease 735 El Quitclaim 33 4.1 Oxnard .(Lease Abandoned) 0 Statute Wds Source: State Lands Commission, 6/88 Fiaure 6 Status of State Leases South 'Central Coast xnard' Ventura County Port Hueneme ... .. ... .. ..... ...... ............ ..... .......... ................... ........... .... . . . ......... ........... . ....... . ............. ... ................... .... .. ........ .. ...... .............. - ........ . ... . ............ ....... .... ........ .. .. .... ... ....... Ln Pt Mugu rL. A. I Co. S UR Pt. ,6q Active Lease LI/-A Quitclaim (Lease Abandoned) L statut@ Wes Source; State Lands Commission, 6/88 Fiqi-we 7 Status of State Leases L.A. Cb. South Coast Ora. Co. Los Angeles Long Beach U a t Sunset Beach 0 5 Bolsa Chico State Beach Three 3455 MTV- .. . .......... ...I.......... . ..... .. ... .......... San Pectro 341 4 9 4% Huntington Beach 4 0 Newport Beach Active Lease N N, El ()uitclaim (Lease Abandoned) Statute MUe3 Source: State Lands Commission, 6/88 dt'llfarlda Coastal Commievian Figure 8 MMMM MMMM MGM MMMMMM4rM ............. Oregon . ................. .................. ........ ..... ........... .... ........................ ... ......... California ............. ...... .. ... .... .... ............. .............. . ......... . ............ . ................. ... ..... ...... Del Norte Co. ............ ............................... ..... - @. I. .. ........... . ........... ... ....... .... ............ ............... .................... ... ........ .......................................... .. . .......... .. ..... .... . ......... ................ ....... ....... ..... . .......... .................. ..... . ... V. ................ ....... ........ ............. .... ......... ............. ................. ......... . ...... ... .......... Humboldt Co. < ................... .............. . ......... ... ........... ...... .......... Cn ...... E- ....... .... ... .. .... . ..... ....... .................................... ........ ............. ....... .. .... ...................... . ........................................................................ CL ........................ .......................................... ................ ...... .............. ....... ... .. ...... 0 ............ ...... .......... ...... ........ ......... ......... . ........... ....... 0 . ........ . ................................. ...... .............................. I..... .. I .............. ................. *... ... .......... . ..... ...... .......... ....... ............. *- ....................... Mendocino Co. ...................... .......... ..................................... ..................... . .. . . . .................. ...... ..... .... .... ..... .... ...... ......... ........... .................................. - - I............ ........... ... ...I. . ... ......... . . ........ ... . .... -4 . .. .. ..... ................................................. . ...... ...................... . ........................... .............. . ......... .............. ...... ... . ......... .. . ....... . ...... ....... Sonoma Co. D-0-1- 5. Year OCS Lease Program Northern Californio Location Map Wah"ton r7l Areas Open for Leasing Oregon Lj Deferred Areas Note: Track outline shown for Lo illustrative purposes only. 0 25 .Source: MMS, 8/88 Statute Mdes drCoAlforma Coastai Commission Figure 9a Cartography Sectmv, Nam m m =.=4r m ................ ................... .............. Sonoma Co. .......... ... ................ ........... ..... . ... ......... ................................ . ..... . .. ......... .......... .. ...... ...... ...... .. .. ................. ... ... .. .... ....... . ........ Morin Co. . . ....... ... .. .............. ........... ......... . .. .. ............ ......... .... ............ San Francisco Co. @Tarallon Is" .............. .. ... San Mateo Co. .......... ... Santa Cruz Co. ....... . ..... .............. ... ................ . ...... ........ . ... ... .. ....... .. I .. :.. .......... .....-............... .... . .... ...... . ........ .......... . ......... ....... .............. Monterey Co.. . .............. .......... . ... ... .... ...........I... . ........ ......I... 00 ....... . .... ........ ..... . ........... ............ ........................ . . . ..................... ....... . .. ..................... . . .... ....... V- ............ .............. ... ...I.... ....... . . . ......... .. ........... ... ........... . . . ..... .......... .... .. ... .... ...... ........ ............ ...... D. 0. 1. 5 Year .. ... . ... .................. OCS Lease Program OCS planning re-a dy. Central California Locatlan Map WaShW1910" Areas Open for Leasin g r -.-I Deferred Areas Li Note: Tract outline shown for Illustrative purposes only. 0 25 50 Source: MMS, 8/88 Statute Miles MCatifarn'a Coastal Cordvssion Figure 9b Monterey Co. ................................ ...... . ....... . ....... .. . ..... ............. .. ........ .................................. Son Luis Obispo Co. ............ ............... .. .. ............ ........ .......... ........ ... ... ..... ... .............. I.% ............ . .. ....... ....... Santa Barbara Co. .. ..... ..................... ............... . ............ ** ....................... ... .. ... ... . ... ... ..........I................ .................I ........................ ...... . . ....... .... ... .................... V.... "' Ventura Co. ........ ... ................ OCS Planning ........... ..... ........ Los Angeles Co. . .. ... ..... ........... ...... Orange Co. 4!:. ........................... . .............. ......... San Diego Co. ............. ...... ............ --- ...... ...... ................ ........ ....... .. .. ............... ............... .... ....... ......... ..................... ........... .... ............ ............ ... . .. ... .... ...... ....................... ..... .... .. .. ... ..................... ....... . .......... ... ......... .... ...... Area B Y. us N. ........... ........... Baja D.O.I. 5 Year ............. .......... California OCS Lease Program . ... .. ............... ......... ..... -1-1.1 ......... Southern California ....... .. ............. ........ ... ..... L@U- Mp .... .. . ..... ..... ................. Wa*ftgtOn N Areas Open for Leasing E].Deferred Areas C*If@b .Note: Tract outline shown for illustrative purposes only. 0 2-1 L Statute Moss Source: MMS, 8/88 drC.t1fo-to C ... tai Figure 9c C-t.qr.phy K-tI. -20- Oregon . I Del Norte Co. Crescent City Lease Sale 91 Proposed Sale 91 Area Humboldt C a. Deferred Areas NOTE: Tract' outlines and boundaries shown for 'illustrative purposes only. Arcata Eureka 0 140UWCO MRM 0 statute Millm Mendocino Co. Ft. Bragg Mendocino Location Map Sonoma Co. olow SS MQrln Co. Source: MMS. 8/88 drCantalInts caa@W Figure 10o Monterey Co. Lease Sale 95 Southern California .... ........ Son Luis Obispo Co. .................... ................... EJ.Proposed Sale 95 Area . ......... Santa Barbara Co. .... .... .. Ventura Co. N Los Angeles Co. ... ....... .................... ............. ............... . ..... 11 21, so Orange Co. statuto Miles 'Sdn Diego Co. ................ .................. ................... Channel Islands .......... .... ........... .......................-......... i VD ........................... B 'a J'a California ................ Note: Tract outline shown for illustrative purposes only. See Figure 10c Source: MMS, 198a de Figure 10b -22- nc Point -MMS Supplemental San t 0. Call for Information C(emen e @Z%- and Nominations LEASE SALE 95 Southern California N Camp Pendleton 0 5 Nautical Miles 2524 Oceanside 25:25 2423 '2426 2 425 2424. - . ........ . . ......... q. .............. 12a27. @26 2@24 2@23 .. ............ ........... ........ ...... 2222 2227 2225 222-C 2223* Carlsbad /G/ Cc& Area ,D1&177e17 Location Map En c i in i to s Note: Lease block numbers shown. San Clemenle Source: Minerals Management Service, Nov. 1988 11/88'1 MCQ1,1fornts Coostzk Comission Certoorophy Section Figure 10--- -23- mms Call 'for Information Mendocino Co. and Nominations Central California Sonoma Co. LEASE SALE 119 Area of Marin Co. &M Ibuo Son Fronciscc Co. Farallon I Son --- Mateo Cc _4 Son to Cruz Co. Lmation Mcp VA Monterey Co. AT 0 25 5 I 1 10 Statute Miles Source: MMS. 11 /86 Note: Tract outlines shown for illustrative purposes orly.@ ditcatiforrO coastat C"Sswfl Figure 10d 24- III. PACIFIC OCS AND STATE OFFSHORE EXPLORATION/DEVELOPMENT PLANS Once a company has leased an offshore parcel in the OCS or state tidelan ds, it is required under lease provisions to proceed with exploration (single or multiple wells) and development plans within a two to ten year period. An exploration plan outlines the timing and activities of an exploratory-rig in a specific statetidelands or OCS location. A development plan.outlines all proposed development and production activities in a specific state tidelands or OCS location. It generally includes,a proposed offshore oil production platform, pipelines, and associated onshore facilities such as processing plants, transportation pipelines, and storage tanks. In the case of OCS 'plans, the lessee or operator must generally submit the exploration plan to the Minerals Management Service (MMS) before the end of the second year of a Five-Year lease or within the time specified in a 10-Year lease. As stated in Section II, the MMIS along with other federal agencies, has regulatory authority beyond-the State three-mile limit. However, since 1978 when the Coastal Commission's Coastal Management program was. certified as consistent with the federal Coastal Zone Management Act, the Commission has also had,consistency review authority over Plans of Exploration (POEs) and Development and Production Plans,(DPPs) in the OCS as well as any associated facilities in the state tidelands and onshore (i.e., pipelines, processing . facilities, storage tanks) with respect to those activities directly affecting land and water uses of the coastal zone. A permit from MMS cannot-be granted'...for' a plan without Coastal Commission concurrence that the project is consistent with its federally approved coastal management program. Concurrence can be presumed if the Commission does not act within six months of receiving a plan from MMS. If the Commission objects, it must give detailed reasons why it objects and how the project could be altered to be consistent with its coastal management program. Failure of a company to submit information which the Coastal Commission determines necessary for'a complete and proper consistency review is also grounds for an objection to an OCS plan. The Secretary of Commerce can override an objection if necessary in the interest of national security or the proposed project is found to be consistent with the objectives or purposes of the Coastal Zone Management Act of 1972. Under the Coastal Act of 1976, the Commission exercises direct coastal permit authority over plans of exploration and development which are within the three-mile offshore state waters boundary and onshore to the coastal zone boundary. Where local government has a certified Local Coastal Program (LCP), the local government assumes this permit authority in the onshore areas of the coastal.zone, subject to the Commission's review of appeals in certain geographic areas and for certain types of development. Local coastal permits on all major energy projects are appealable to the Commission. Plans of Exploration (POEs) or Development and Production Plans (OPPs) for state tidelands must also be reviewed and approved by the State Lands Commission. In addition, in State Tidelands the Division of Oil and Gas (*DOG) issues permits to drill. DOG establishes engineering standards, and inspects operations of all wells drilled both offshore and onshore. Other agencies -25- that have some responsibilities and control of exploration and development activities in state waters include the Department of Fish and Game, the Regional Water Quality Control Boards, and the Air Pollution Control Districts. With the approval of an OCS or state exploration plan by all required agencies, the company can proceed-with exploratory drilling at the proposed well location(s). Brill ships,.semi-submersibles, and Jack-up rigs are generally used for exploratory drilling off California (see Figure 11). Exploratory programs may propose the drilling of single or multiple wells. The average length of time for an exploratory operation is three months, which includes active drilling, evaluation and abandonment, and moving off the site. If any oil and/or gas discoveries warrant development and-the OPP has been approved by all applicable agencies, the company will proceed with development and production. Steel template, pile founded platforms are generally used in oil and gas development and production offshore California except for some man-made islands and gas subsea completions in state tidelands (see Figures 12 & 13). Platforms are fabricated at one or more onshore facilities and towed to their offshore installation site. A development drilling program is designed for each platform to bring the oil and gas discovery into production. Development drilling on the platform usually occurs for 3-10 years. Large platforms are typically equipped with two rigs for drilling wells. After the completion"of development wells, the production phase begins in which well fluids are brought to the surface, separated, measured, stored, and piped to shore to be further processed and transported-to other oil and gas related facilities. Tables 3-5 show the total number of POEs and DPPs that have been reviewed by the Coastal Commission under its consistency review and coastal permit authority. In additi,on, Tables 6-11 indicate the number of existing OCS and state platforms, approved platforms under,construction, and the number of platforms proposed in the future. Figures 14 through 23 show the-location of existing, approved, and proposed federal and state platforms and offshore pipelines. -26- Types of Top of Drill Rig Exploratory Drilling Rigs Drill Rig Waste NEEEEM G4s Rare Equipment & Materials Storage S i bmersible / . .11111 Heliport emisu Maindeck Lifeboat Lower A Hull Deck Ballad ond Storage Drill Rig Drill Ship Work Cranes 59m Heliport SHp Hull .-Dril Rig Heliport 127 m Hull Ja ck-up Rig -dl-- Jack-Up Leg rL -LI t L:@@ I H.3 rn =sE@a e Helipc@rt @@@@@@Work @Cranes 14.6 rn- Source: Adopted from Chombers Consultants and Planners Drawing for illustrative purposes only. drCiWrarrda CoastaL r Figure 11 -27- Development and Production Platform Drilling Rig Crone Decks 'Flare BOOM Drill Slots Water Level Jacket Pilings u L U cean Bottom Source. Adopted from A.D. Little Drawing fDr illustrative purposes only. coastu COMMUM Figure 12 cartaw-*P@ UCV" a, Gas Subsea Completion Spools -----Safety Joint ZSled Wellhead - Flowlines 'N@ 14 V Flotation Devices (Removed After Flowline Installation) 0 @O @@O Clamp Safety Joint Cl I af =_ J. Sled, Source: Adaptod from Shell Callfornla Productlon. Inc. Drawing for IllustratIve purposes only. l1kcallfor"la Ccmvtal Commiswan Figure 13 Cortoartmh. -29- Table T.- Consistency Certifications of OCS Plans of Exploration (POEs) through December 1988 Reviewed 120 Concurred with Project Modifications 107 Partial Concurrence* 6 Objected To** 7 Tracts 161 Wells Proposed 520 Wells Concurred With 476 (*Approval/disappro val of certain wells on a POE) (**Two of these objections were overturned by the Secretary of Commerce on Appeal) Table 4. Consistency Certifications of OCS Development and Production Plans (DPPs) throuqtt December 1988 DPPs Reviewed 13a DPPs Concurred 12b OPPs with Partial Concurrence I (Exxon) DPPs Objected To* 2c Tracts 15 Platforms 15 Well Sl'ots 807 a - includes'15 tracts and 15 platfo s b - includes Platforms Gail and Julius c - includes Platforms Gail and Julius (*Platform Julius was originally objected to by the Commission in 1985 and later approved in 1987. Platform Gail was installed under a settlement agreed to by Chevron, the Minerals Management Service, and the Commission.) (Sources: the MMS, the State Lands Commission, the Coastal Commission, and A. D. Little) -30- TabLl e 5. State Tidelands Wells and Platforms' Reviewed by the Commission From January 1981 to December 1988 Proposed Approved Denied Withdrawn Exploration wells 52 42 2 8 Development wells* 112 112 - - Platforms** 1 1 Includes existing islands and subsea well completions@ Platform Esther approved to replace an existing man-made island. Table 6e Summary of Existing, Approved, Proposed and Hypothetical Platforms in the Pacific OCS and State Tidelands December 1988 Pacific OCS* State Tidelands Existing/Installed 21 8 Manmade Islands 0 6 Approved/Under Construction 5 0 Proposed 1 5* Sub Tota-1 27 19 Hypothetical thru 2000** 10 16 Total 37 35 'ARCO includes 3 platform complexes'each having 2 platforms with a revised OPP for Holly A/B, Heron, and Haven. The two other platforms are Hayley and Hercules. **@Projected hypothetical platforms in the Santa Barbara Channel and Santa .Maria Basin through the year 2000. (Sources: the MMS, the State Lands Commission, the Coastal Commission, and A. D. Little) Table 7 Existing Platforms on Pacific OCS Active Leases as of December 19W installation Number of Water Required Platform Operator Lease OCS-P Unit/(Field) date well slots depth (ft.) commission approval (Lease Sale) Edith Chevron 0296/(35) Beta/(Beta) 1983 72 161 + Ellen SWEPI 0300/(35) Beta/(Beta) 1980 80 265 -Ellyl SWEPI 0300/(35) Beta/(Beta) 1980 - 255 Eureka SWEPI 0301/(35) Beta/(Beta) 1984 60 700 + Gina UNOCAL 0202/P4) (Hueneme) 1980. 15 95 + Gilda UNOCAL 0216PPO Santa Clara/(Santa Clara) 1981 96 205 + Grace Chevron 0217/(P4) Santa Clara/(Santa Clara). 1979 48 318 Hogan Phillips 0166/(P4) (Carpinteria Offshore) 1967 66 154 Houchin Phillips 0166/(p4) (Carpinteria Offshore) 1968 60 163 Habitat Texaco 0234/(P4) Pitas Point/(Pitas Point) 1981 24 290 + Hermosa Chevron 0316/(48) (point Arguello) 1985 48 603 + Harvest Texaco 0315/(48) (Point Arguello) 1985 50 675 + Irene UNOCAL 0441/(53) Point Pedernales/. 1985 72 242 (point Pedernales) Table 7 (continued) installation Number of Water Required Platform operator Lease OCS-P Unit/(Field) date Well slots depth (ft.) Commission approval (Lease.Sale) Henry Sun 0240/(P4) (carpinteria offshore) 1979 24 173 Hillhouse Sun 0240/(P4) (Dos madras offshore) 1969 60 190 A UNOCAL 0241/(P4) (Dos Cuadras Offshore) 1968 57 188 UNOCAL 0241/(P4) (Dos Cuadras O@fsfiore) 1968 63 190 C UNOCAL 0241/(P4) (Dos Ojadras offshore) 1977 60 192 Hondo Exxon 0188/(P4) Santa Ynez/(Hondo) 1976 28 842 Gail Chevron 0205/(P4) Santa Clara/(Sockeye) 1987 36 739 + Hidalgo Chevron 0450/(53) (point Arguello) 1986 56 430 + Platform Elly is a production platform from which no wells are drilled. only initial treatment and storage is done on the platform. Not applicable (source: MMS, r=rt, 1987) R:= MMS tS 4/88 Table 8 Approved/Under Construction Platform on Pacific OCS Active Leases as of December 1988 Installation Number of Water Required Platform operator Lease OCS-P Unit/(Field) date well slots depth (ft.) Commission approval Harmony Exxon 0190/(P4) Santa Ynez/(Hondo) 1989 60 1,200 + Heritage Exxon 0182/(P4) Santa Ynez/(Pescado) 1989 60 1,075 + Heather Exxon 0193/(p4) Santa Ynez/(Secate) 1997 28 620 + Julius SWEPI 0409/(53) (San Miguel) 1989 70 478 + Lo Iris UNOCAL 0440/(53) Point Pedernales/ 1991 60 285 + (Independence) (Point Pedernales) (Source: MMS, Summary.Report, 1987) MMS Review Comments, 4/88 Table 9 Proposed Platforms in Pacific OCS Active Leases as of December 1988 (not yet approv-e-dT Requires Installation Number of Water Commission Platform Operator Lease OCS-P Unit/(Field) Date well slots depth (ft.) Approval Hacienda Chevron 0451/(53) Rocky Point/(Rocky Point) + (Source: MMS) M Mir M Table 10 Existi92 State Tidelands Platforms and Artificial islands as of December 1988 Lease-State Water Well Date of Required Name Operator county PRC Depth + Ports Installation Comission Approval Platform Hazel Chevron Santa Barbara PRC 1824.1 100, 25 8/0/57 Hilda Chevron Santa Barbara PRC 1824.1 1061 24 8/24/60 Aminoil orange PRC 425.1 411 30 .4/12/61 Eva UNOCAL orange PRC 3033.1 581 .30 1/30/64 LO Hope Chevron Santa Barbara PRC 3150.1 1401 60 9/24/64 Heidi Chevron Santa Barbara PRC 3150.1 1281 60 5/27/65 Holly APM Santa Barbara. PRC 3242.1 2111 30 4./28/66 Esther Chevron orange PRC 3095.1 351 128 5/28/64 + (modified from an island to a platform)* Artificial islands Belmont Exxon orange PRC 186.1 421 70 10/27/48 Rincon Norris Oil Ventura PRC 1466.1 451 68 3/11/57 Grissom 224 White ci ty of Los Angeles Granted 351 176 6/4/64 Long Beach tidelands 401 (enactment of Freeman 181 chapter 138) Chaffee 261 (Source: State Lands Oommission) Table 11 Proposed State Tidelands Platforms As of December 1988 (not yet approve Requires coastal Platform operator County Lease Water Depth Well Ports commission approval served Heron ARCO Santa Barbara 309 2201 84 + Haven ARCO Santa Barbara 3120 2201 84 + I + 11 Holly A B ARCO Santa Barbara 3242 2201 84 un Hercules SWEPI Santa Barbara 2920 2371 55 + Hayley UNOCAL Santa Barbara 2879 2951 48 + (Source: State Lands commission) -36- OCS Platforms and Pipelines Santa Maria Basin Pt. San Luis Pismo Beach 7- Grover City Ej San Luis Obispo Co. r--- t-"'S a n t aBarbara "C@@O:@ 2W Pt. Sal 1-30 Santa Mcric 4[] 5D 6[j Lompoc PLATFORMS NAMES AND TRACTS 7& Existing 1. Future #1 0396 2. Julius 0409 9E] Pt. Arguello Approved 3. Future #3 (Sun) 0415 4. Future #4 (Sun) 0422 Proposed 5. Future #5 Shell 0427 15[:] Hypothetical 6. Future #8 Rhell@ 04-34 7. Iris 0440 PIPELINES 8. Irene W1 11E@ 9. Future #6 (Chevron) 0443 13 Pt. Conception Existing 10. Hi ddgo 0450 - - - Approved 11. Hacienda 0451 Proposed 12. Harvest 0315 13. Hermosa 0316 14. Future #7 (Conoco) 0322 14[:] N- 15. Future #9 (Chew-on) 0446 0 N3uftd mow 10 stcftto maw 10 Note: Platform and Pipeline locations ore approximate. Source: MMS 'and A.D. Uttle, 8/88 ftl.@ cassw Figure 14 Pt. Conception Govioto OCS Platforms and Pipelines Copiton Santa Barbara Channel Santa Barbara re, Mile 19 2 22 El Ventura 28 32 30 Richardson Rock Limi .31 3 Channel Islands San Miguel 1. Cruz Santa Rosa Anocopa 1. Island Marine Sanctuary PLATFORMS NAMES AND TRACTS ix ExIsting 16. Heather 0193 25. Henry 0240 Nautical Approved 17. Heritage 0182 26. Houchin 0337 Proposed . 18. Harmony 0190 27. Hogan 0166 19. Hondo 0188 28. Habitat 0234 F1 H)potheflcol 20. Future #2 0467 29. Grace 0217 Ar 21. C 0241 30, Gilda 0216 PIPELINITS 22. B 0241 31. Gail 0205 Exis.ting 23. A 0241 .32, Future #1 0469 Approved 24. Hillhouse 0240 33. Gina 0202 Nwitical Mile@ 10 @r@P I @Concep@lllon @Gov@iola re, Note: Platform and Pipeline locations are approximate. 0 Slatu,te Wee 0 Source: MMS and A.D. Little, 8/88 4weautorrda coa" contralwillon cartoomphy section Figure 15 OCS Platforms and Pipelines El Segundo Long Beach Area 0-1 0- Long Beach Son Pedro Huntington Beach 34J Arewpl;irt Bay 3 3-56% M37 00 ree Dona 'Pt. PLATFORMS NAME M TRACTS Existing 34. Edith 0296 Approved 35. Elly 0300 @Slx 36. Ellen 0300 proposed 37. Eurqka 0301 E] Hypothetical PIPELINES N Existing 0 Nautical Was 10 Approved Statute MUOO Note: Platform end Pipeline locations are approximate. Scnjrce: MM and A.D. Little, 8/88 IMCatifornia coastat commission Figure 16 C4M-tog@*Phy Section Son Luis Obispo CO.,b-. /,- State Platforms and Pipelines onto Barbara Co. -A Sonto Maria Southern Santa Maria Basin ussel Pt. Sal El C41 F1 urisirna Pt. 0 El Proposed State Lease El Hypothetical Platform Estimated location based on general geologic info. Surf Note: No pipelines from hypothetical platforms in this area are proposed as of this time. Lompoc 0 M189 10 0 15 t' Arguello Source: State Lands Commission, 1986 Mcelifornis coostat covusnimion Figure 17 Cartograpby Section m ohm m m m m m State Platforms and Pipelines Pt. Arguello Pt. Arguello to' Pt. Conception Vandenburg Air Force Base Mile 3 OceQ 2Z Pt. Conception Proposed State Lease F1 Hypothetical Platform Estimated location based on general geologic info. Note: No pipelines from hypothetical platforms in this area are proposed as 'of this time. 0 2 0 3 ISource: State Lands Commission, 1986 IwC*UfbrTJ* Ca"W Coutagmion Figure 18 Cartoomphy Sfttian State Platforms and Pipelines Pt. Conception Area San Augustine Pt. Conception 2725 2726 2206 2207 El 2879 4001 Ha@ey Pe Proposed State Lease j3 CLrb 0,'rO' PLATFORMS PIPELINES N Existing Existing S Approved Proposed Mugs IBProposed SUBSEA WELLS 2725 Hypothetical 0 Abandoned *Estirnoted location based on general geologic info. Soijrce: OPR. 1977, and State Lands Commission, 1986 dwcamryda C@taj coumbalon Ficitire 19 Cartaampby 9@ti= State Platforms and Pipelines Gaviota Area- 101 a Iguas Drake Gaviota 2199 2920 2933, -/"2206 2793 2894 2198 Hel-en 4,ercules F] 4001 4002 Mile Three Santa Barbara Channel PLATFORMS PIPELINES 0 Existing - Existing Q Approved ----- Proposed N Proposed SUBSEA WELLS Hypothetical (D Active Removed 0 Abandoned *Estimated location based in general geologic Info. 0 2 Source: OPR, 1977, an d State Lands Commission, 1986 0 KDometers OwCaMmia COM" Gauunh6m Figure 20 ftrtopsphy go-Alm M MGM M M M M M M Los Flores Canyon State Platforms. and Pipelines 101 Coal Oil Point Area 2991 2205 Naples 3004 Ellwood Deve7vaux IJ Lagoon 3120 Pcoal Oil Pt. 3242 308 Haven Holly 309 Holly A&B -Heron PLATFORMS PIPELINES Existing Existing 6j Approved Proposed ffl Proposed SUBSEA WELLS E] Hypothetical* A,tive N Removed 0 Abandoned Mae* *Estimated location based on general geologic info- 0 2 KIlomet" Source: OPR, 1977, ond State Lands Commission, 1986 Fiaure 21 Cartogrophy Secton SU Merland State Platforms and Pipelines Carpinteria Area 1824 Carpinteria Hilda Santo azel Barbara Co. r Ventura Co. 3133 Punta Gordo 6Q 1466 Rincond Hope Heidi &Q; '16 4000 PLATFORMS PIPELINES ISLANDS 0 Existing Existing A Existing 3084 Approved Proposed Proposed SUBSEA WELLS Hypothetical* Active N Removed 0 Abandoned *Estimated location based on general geologic info. Surnmerland mnw 2 0 -Source: OPIR, 1977 decaufamift COMW conwAftslon Figure 22 caetagmpby saouan State Platforms and Pipelines Long Beach Area Los Angeles Long Beach Co. Grissom Orange Wh i t e Co. Freeman Chaffee THUMS Tract I Belmont Esther 186 3095 3119 Pedro 3177 Huntington Beach 163 Mile Lirnit I (ee 3413 426 392 PLATFORMS PIPELINES Ar 0 Existing Existing Eva Emmy W Approved Proposed 425 [B Proposed ISLANDS Hypothetical 33 Existing Removed Source: OPIR, 1977, and State Lands Commission, 1988 acelifornia Coantai COM=18dan Figure. 23 CarWgmphy Sectloo -46- IV.' PACIFIC OCS.AND STATE OIL PRODUCTION IN CALIFORNIA California has been producing onshore and offshore oil since the late 1800's. As of 1987, California ranks fourth among the oil-producing states behind Texas, Alaska, and Louisiana. Total Santa Barbara Channel and Santa Maria Basin OCS Production may peak in. 1999 at about 247,600 barrels per day of oil. tables 12 and 13 indicate: 1) current annual U. S. and California production; 2) projected production; 3) percentage of total U.S. production in California; and 4) percentage of California production from offshore waters. It must be noted that different state agencies have varied figures on production projections with different time scales, different area coverage, and the inclusion of new production and/or current production. According to SLC the differences in the oil production forecast by DOG and SLC for a given field are in both estimated production rates and timing. The difference in production rates are the result of methodology with DOG's analog analysis2 as compared with the operator's projections based on production test data from exploratory wells in the specific field. The sequencing of projects under DOG's forecast is again based on analog data, wherein past platform construction, drilling and production schedules were used in timing of the new field developments.- State Lands, in contrast, has used the schedules submitted with the respective development plans (A.D. Willard, SLC Memorandum, October 2, 1985). Table 12 Current California And U.S. Production in 1987 (in barrels) % of CA % of US % of US 1987 Total OCS To-tal Total CA Onshore 335,600,000 85% - CA State Waters 30,300,000 7.63% - 1.0% CA OCS 31,100,000 7.83% 8.49% 1.0% CA Offshore Total 61,400,000 15.46% - 2.0% CA Total* Production 397,000,000 - 13.0% US OCS Production 366,141,709 12.1% US Total Production 3,034,000,000 - Total refers to offshore and onshore oil production (Sources: DOG and MMS) 10 SOURCE: CALIFORNIA COASM COMISSION, COASTAL ENERGY DEVELOPMEFIT, 1981. Onshore Production Facility 57 SOO 7m M-FI-111; SOURCE: CALIFORNIA COASTAL CMIMISSION, COASTAL EUERGY DEVELOPMENT. 1981., Offshore. Production Facility -47- Table 13 AGENCY PROJECTIONS FOR OIL-PRODUCTION IN BARRELS PER DAY State Onshore And Offshore Production Projections 1990 1995 2000 2005 1,064,000 1,064,000 1,031,000 968,000 (Source: Ca. Energy Commission, Biennial Fuels Report September, 1986) State Offshore Peak Production For Western Santa 8arbara Channel in State Waters 1991 1992 1995 - 1998 2000 .2003 70,000 45,000 63,000 15,000 70,000 45,000 (Source: SLC March 1985 estimates from Goleta to Santa Maria River) Current and New Production for Onshore and Offshore California 1987 1992 Onshore And Offshore 1,087,588 1,170,000 State Waters 83,013 65,600 OCS Waters 85,123 229,000 (Source: DOG, July, 1988) Pacific OCS Current and New Production for Southern California Planning Area 1987 1988 1990 1992 85,000 104,000 169,600 186,300 1994 1996 1998 1999 2000 184,000 182,900 224,200 247,600 .233,500 (Source: MMS, July 15, 1988) _48- V. REVENUES FROM OCS AND STATE LEASES Oil and gas leasing and production in OCS and state tidelands has generated considerable revenue for the federal government and the State of California. As of 198'7, OCS revenues to the federal government from California have totaled over 5 billion dollars. From 1929 to 1987, California tideland revenues have totaled over 4 billion dollars. Within the OCS, companies acquire rights to develop OCS lease tracts from the federal government in exchange for certain biddable and fixed payments. The OCS Lands Act (OCSLA). of 1953, and Amendments of 1978 and 1985 established a number of leasing systems which have included cash-bonus bidding with fixed royalty rate; cash-bonus bidding with sliding scale royalty rate; cash-bonus bidding with fixed net profit share; royalty-rate bidding; work-commitment bidding; and net profit-share bidding. Cash bonus payments are lump sum, non-refundable payments made at the time the lease is issued. Royalty payments are based on future production as.a percentage-of the gross revenue from the tract. Net profit share is contingent on future productionwith percentage of the net revenue. With work-commitment bidding, the lease is awarded to the company which pledges to undertake the greatest dollar amount of exploration on the lease. The lessee submits the cash value of the bid, or a performance bond for the same amount at the time the lease is issued. Prio r to 1979, cash bonus bidding (fixed or sliding scale royalty rate), was used almost exclusively as the bid variable. The 1978 OCSLA Amendments have required the use of the four other above alternative methods for no less than 20 percent and no more than 60 percent of all leases offered for sale in a five year period. (Head et al., March 1984) Only cash bonus bidding with fixed royalty bidding systems were used in the two FY 1987 sales. DOI has discontinued the use of the alternative bidding systems (MMS, Oil and Gas Leasing/Production Program, March, 1988). Revenues generated.from OCS development are deposited into the U.S. Treasury General Fund. Some of the OCS lease revenues are credited to the Land and Water Conservation Fund and.the Historic Preservation Fund. Current legislation requires that the Land and Water Conservation Fund be credited with $900 million annually. Transfers to the Historic Preservation Fund have amounted to $150 million annually since 1980. Under Section 8(g) of the OCSLA Amendments of 1985, the federal government is required to distribute twenty seven percent of the receipts from OCS leasing areas within a three-mile zone adjacent to State Lands. (43 U.S.C. Section 1337(g)]. In April 1986, the U.S. Congress determined-that Coastal states would receive 27% of the 8(g) income held in escrow ($6 billion), with the remaining 73% going to the federal government (MMS, POCS Current Events. April 1987).. Historically, the State Lands Commission has leased parcels in state waters with cash bonus bidding and a fixed or sliding scale royalty. In accordance with Public Resources Code Section 6217, the revenues derived from State Lands leasing are utilized for refunds, State Lands Commission expenditures, specified payments'to local governments, California Water Fund; Central Valley Water Project Construction Fund, and public and private higher education. -49- Table 14'provides the latest detailed revenue figures from OCS and State tidelands oil and gas development. Table 14 OQ ANIVSTATE TIDELANDS REVENUES Revenue from U.S. QCS Oil and Gas-Operat-ions 1954-1987 Oil and Gas Ro yalties, $33,051,164.,026 Bonuses 53,397,247,006 Rentals 615,842,712 Other Categories (Minimum 73,493,911 royalties, shut-in gas etc.) $87,137,747,655 (Source: MMS, Mineral Revenues: The 1987 Report on Receipts from Federal and Indian Leases, 1988) Revenues from Pacific OCS Oil and Gas Operations off California 1963-1987 Bonuses $3,916,123,323 Minimum Royalties 2,656,765 Rentals 32,908,482 Royalties 1,052,626,135 $5,400,314,000 (Source: MMS, June 1988) Revenues from Onshore and Offshore California State Lands Oil and Gas Operations 1929-1987 Oil and Gas Royalties $1,224,666,750 from State Lands Bid Bonuses on Oil Leases 189,910,958 from State Lands Long Beach State Share 3,502,793,211 (Net Profit arrangement) Oil And Gas Royalties 622,336 from School Lands (onshore) $4,917,993,255 (Source: State Lands Commission, Historic Revenue Information, Corrections included as*of June 30, 1987. Best available figures for historic revenue.) -50- VI. EXISTING AND APPROVED MARINE TERMINALS IN CALIFORNIA As an alternative to offshore, and/or onshore pipelines, marine terminals can be used to load/unload crude oil or other petroleum products for transport by tankers. Terminals generally consist of onshore tank storage farms, offshore mooring stations for the tankers, onshore and offshore pipelines, and tankship fleets. Marine terminals are used to: 1) load crude oil from production for delivery to refinery centers, 2) unload crude oil for delivery to refineries, and 3) load and unload refined petroleum products. Marine terminals have four basic types of berthing and mooring arrangements: fixed berth, sea,island (offshore pier), single buoy, and multi.ple buoy (see Figures 24.through 28). The Coastal Commission and Santa Barbara County have encouraged the use of pipeline transportation of oil, instead of using marine terminal facilities, when the environmental impacts of pipelines were determined to be less. In most instances, pipeline transportation results in less risk of oil spills and fewer air quality emissions. Table 15 indicates the number of existing marine terminals in California, including one in the OCS which also treats and stores crude oil, and marine terminals that have been approved by the Coastal Commission but are not yet under construction (see Figures 29(a) 29(b) for locations). W, SOURCE: CALIFORNIA COASTAL CMMISSION, COASTAL ENERGY DEVELOPMENT 1981. Marine Terminal Facility -51- Fixed Pier Tcnker Berth ..................... -- .. ........... .*...... ..................... ....... ............ .......... ...................... .......... ............ .................... Shore Line Moorinq Buoy Area 0 100' Depth Contour 'Spill Boom .......... ....... 100' 120' Depth ......... Contour ........... joTVI\ . .......... ............. Loading platform Source: Adopted from ERT Drawing for illustrative purposes only. laratifor"a catgut cor"Ossion Figure 24 carltow-60hy Sectm -52- 10 Sea Island Tanker Berth ........................................................... ....... ...........I ......... . . ... ........... .. .. .............. .. ................ ....... ........... .... .............. .. ............ ........ ........... Shore Line Moorlng 8uoy Area 1A Subsea Pipelines To/Frorn Sea Islands 100' Depth Contour Spill Boom ..... 100' 120' Depth ......... . Contour ....... ..... .. ......... OP ............. .......... . . ......... Loading Platform so rce: Adopted from ERT Drawing for Mustrative-purposes only. Oftcallform Co&wt*L cOr5M Figure 25 carlovap%y sect" -53- 10 Single Buoy or Anchor Leg Mo oring (SALM) Onshore Processing Facility ........... Shoreline Submarine Pipeline Corridor SALM Fixed Mooring Swing Radius 1500 Feet Source: Adopted from ERT Drawing for illustrative purposes only. llw,tfarm Caustal Commsm Figure 26 C.-tow-00j'y S-tw. Devotion View Of Single, Anchor Leg Mooring (SALM) Mooring Rope Pick- Up Buoy _-.-@Sea Level Mooring Buoy 16" Vapor Return Hose Fluid Swivel Assembly 2-20" Crude Oil Loading Hoses Ln Riser Shaft Subsea Pipelines oring Bas [Mo el Sea Bottom Submersible Pump Condensate Tank @_Pipeline Anchoring Base ISource: Adopted from ERT Drawing for illustrative purposes only. Figure 27 CorloGrophy Section Multiple Buoy Mooring 15 Ton Anchor 360' '2 3/4" Chain 8 Ton Anchor Ships Anchor 1\ #6 1400 500' 1115@ From Ship N Ton Anchor Marker End of Ln Pipeline Ships Anchor IS N, 66, 10 Ton Anchilir #2 0. 15 Ton Anchor 8 Ton Anchor 8 Ton Anchor Source: PG&E Drawinq for illimfirrifivo- m, dmCdIffornia Coasta( Copirission, Figure 28 Cartography Section -56- Table 15 Existing And Approved Marine Terminals for Crude and Petroleum Product Transportation as of December 1988 Northern California County Location Terminal Operator Function/Status Humboldt 1. Port of UNOCAL Product 1 Humboldt Bay 2. Port of Oregon Coast Product 1 Humboldt'Bay Towing Co. 3. Port of R.A.Knapp Product 1 Humboldt Bay (Chevron owned) 4. Port of Crown-Simpson Productl Humboldt Say Pulp Co. Contra Costa 5. City of Chevron Unloading crude Richmond Long Wharf and load product 6 Davis Pointt UNOCAL Unloading crude Rodeo and load product 7. Selby Wickland Oil Unloading product 8. City of Shell Unloading crude Martinez and load product 9. City of Landsea,Tosco Unloading crude Martinez area Terminals 10. Point Molate U.S. Navy Productl 11. Point San U.S. Navy Pr oductl Pablo 12. Point Petrol Mark Productl Richmond 13. Richmond UNOCAL Productl Harbor Channel 14. Richmond ARCO Productl Harbor Channel -57- County Location Terminal-Operator Function/Status 15. Richmond Texaco Productl Harbor Channel 16. Richmond Castrol Productl Harbor Channel 17. Richmond Time Oil Productl Harbor Channel 18. Point Orient Chevron Productl Solano 19. Benicia Port Benicia Terminal Unloading Terminals (Exxon Refinery) Crude 20. Benicia Port Huntway Refinery Unloading Terminals product San Francisco 21. Pier 70 PG&E Unload product for Potrero Power Plant San Mateo 22. Port of Pilot Productl Redwood City Oil Southern California Monterey 1. Moss Landing PG&E Multi-point mooring for loading product oil with onshore storage facilities San Luis 2. Estero Bay Chevron Loading Crude Obispo 3. Estero Bay Texaco Loading Product 4. Estero Bay U.S. Navy Unloading Product 5. City of PG&E Unloading product Morro Bay 6. Port San Luis UNOCAL Loading crude _58- County Location Terminal Operator Function/Status Santa Barbara 7. Cojo Bay (Pt. UNOCAL Loading crude Conception) 8. Gaviota Texaco Loading crude (constructed as interim terminal) 9. Ellwood ARCO Loading crude 10. Carpinteria Chevron Loading crude and unloading product but not since 1983 and 1985 respectively 11. El Capitan Exxon Not operating 12. Las Flores Exxon Approved but not yet constructed consolidated marine terminal w/SALM offshore for loading 140,000 B/d 13. Las Flores/ Exxon Treatment/storage/ El Capitan SALM for transport- OS&T ing processed crude Ventura 14. Ventura Texaco Loading OCS and River (Formerly Getty) other crude and product 15. Ventura UNOCAL Loading OCS and other crude 16. Mandalay Southern Cal Unloading product Beach Edison Unloading fuel oil 17. Port Hueneme Port of Hueneme Unloading fuel So. Ca. Edison oil at Wharf 1 Ormond Beach (but not since- Power Plant 1982) -59- County Location Terminal Operator Fuhction/Status Los Angeles 18. El Segundo Chevron Unloading crude (4 terminals) loading product 19. Port of LA U.S. Navy Loading and unloading petroleum products 20. Port of LA UNOCAL Unloading crude oil 21." Port of LA GATX Unloading petro- Terminals Corp. chemical and petro- leum products 22. Port of LA Pennzoil Unloading lube oil 23. Port of LA Chevron Loading and unloading bunker fuel, diesel and lube oil 24. Port of LA GATX Terminals Loadi'ng and Corp. unloading petroleum products 25. Port of LA- BP No. America Loading and Trading unloading diesel fuel oils 26. Port of LA Western Fuel Loading and unloading crude oil, diesel oil, fuel oils and ethyl alcohol 27. Port of LA Petrolane, Unloading LPG Inc. 28. Port of LA UNOCAL Loading and un- loading petroleum products 29. Port of LA LA Terminals Unloading chemicals 30. Port of LA Chevron Chemical Unloading lube oils -60- County Location Terminal Operator Function/Status 31. Port of LA Golden Eagle Unloading Refining Inc. crude oil, loading diesel and fuel oils 32. Port of LA Champlin Petroleum Unloading crude oil and petroleum products, loading diesel and fuel oils 33. Port of LA Shel-I Oil Co. Loading and unloading petroleum products 34. Port of LA GATX Terminals Unloading Corp. crude oil, diesel and fuel oils, loading diesel and fuel oils 35. Port of LA City of LA Unloading fuel Dept..of Water & Oil Power 36. Port of LA Wilmington Liquid Unloading 'Bulk Terminal crude oil, petroleum and petrochemical products, loading diesel and fuel oils 37. Port of LA Refiners Marketing Unloading petro-chemicals 38. Port of LA Mobil Oil Unloading crude loading and unloading petroleum products 39. Port of LA. Pacific Approved but not Texas Pipel.ine yet constructed, Co. (PACTEX) unloading crude for pipeline transportation to Texas 40. Port of Long Exxon Unloading petroleum Beach products and fuel oil, loading bunker fuel County Location Terminal Operator Function/Status 41. Pori of Four Unloading crude oil Long Beach Corners 42. Port.of 'Texaco Unloading crude oil, Long Beach loading/unloading petroleum products, and loading bunker fuel 43. Port of ARCO Loading/Unloading Long Beach petroleum products and loading. bunker fuel loading/unloading crude oil 44. Port of C. Brewer Unloading petroleum Long Beach Terminals products 45. Port of Long Beach Unloading/loading Long Beach Terminal Co. petroleum products Orange 46. Huntington So. Ca. Edison Loading Beach fuel oil 47. Huntington Gulf Oil Loading/Unloading Beach Crude oil San Diego 48. Encina San Diego. Unloading fuel oil Gas & Electric and petroleum products I =loading and unloading refined petroleum products (i.e diesel fuel, l.ub.rica.ting oil, fuel oil, propane) (Source: MMS, Pacific Summary Report 1987, Mr. Phil Kern, formerly with San Francisco Bay Conservation And Development Commission and now with Port San .Francisco, Mr. Gene Serex of the Port of Richmond, Mr. Sid Robinson of Port of Los Angeles, and Ms. Geraldine Knatz of Port of Long Beach.) '-Pow Marine Term'Inals Northern California DN --------- Location Teffnind Qpamt 1. Port of Humboldt Bay UNOCAL HUM 2. Oregon Coast Towing Co. 3. R.A. Knapp (Chevron owned) 4. Crown-Simpson Pulp Co. 5. City of Richmond Chevron Long Wharf 6. Davis Point/Rodeo UNOCAL 1-4 7. Selby Wickland Oil 8. City of Martinez Shell 9. . - Landsea, Tosco Terminals 10. Point Molate/Richmand U.S. Navy it. Point Son Pablo/Richmond U. S. Navy 12. Point Richmond /Richmond Petrol Mark 13. Richmond Harbor Channel UNOCAL 14. ARCO MEN 15. Texaco 16. Costrol 17. Time Oil 18. Point Orient/Richmond Chevron 19. Benicia Port Terminals Benicia Terminal (Exxon Refinery) 20. Huntway Refinery 21. Pier 70/Port of Son Francisco PG&E 22. Port of Redwood City Pilot Oil SON AP SOL MAR 19-20 26 -9 CC 13-17 ALA 21 IV 22 SCL SM Note: See Tabl.e 15 for more information. Statute AID" Source: MMS, Pacific Summary Report, 1987 drcstuamla Coww CaumAwlan Figure 29a Cartograptsy 90.000 Marine Terminals Southern California Location Terminal Opergior 1. Moss Landing. PG&E 2. Estero Bay Chevron 3. U.S. Navy 4. Texaco SC 5. ty orro Bay PG&E 6. Port Son Luis UNOCAL 7. Cojo Bay UNOCAL B. Govioto Texaco (formerly Getty) 9@ 'Ellwood ARCO 10. Carpinteria Chevron 11. El Capitan Exxon MON a 12. Las Flores Exxon 13. Los Flores/OS&T Exxon SLO 14, Ventura River Texaco 1(formerly Getty) 15@ Ventura UNOCAL -4 16. Mandalay Beach Southern Cal Edison 17, Ormond Beach Southern Cal Edison 18. El Segundo Chevron (4 terminals) 19. Port of L. A. U.S. Navy 20. UNOCAL a% SB W VEN LA 21. GATX Terminals Corp. 22. Pennzoil 23. Chevron 7 24. GATX Terminals Corp. 25. BP No. America Trading 26@ Western Fuel 19 39 R 27. Petrolone. Inc. 40-4 28. UNOCAL 29. LA Terminals C.b. SD 30. Chevron Chemical 48 31. Golden Eagle Refining Inc. 32. Champlin Petroleum 33. Shell Oil Co. E* GATX Terminals Corp. 34. 35. L.A. Dept of Water & Power .36. Wilmington Liquid Bulk Terminal 37. Refiners Marketing 38. Mobil Oil 4 39. Pacific Texas Pipeline Co. (PACTEX) 40. Port of Long Beach Exxon (C. Brewer To.-trminal) 41. Four Corners 42. Texaco 43. ARCO 44. C. Brewer Terminals 45. Long Beach Terminal Co. 46. Huntington Beach So. Co. Edison 0 150 47. Gulf Oil Note: See Table 15 for more information. L 48. Encino (So. Carlsbad) Son Diego Gas Electric Statute Was ISource: MMS, Pacific Summary Report, 1987 Approved/No Construction atcantarnis Coastal Commission Fiqure 29b Cartography Section _64- VII. OCS AND STATE PIPELINE SYSTEMS Pipelines are an important means for transporting oil and gas. They are used to transport oil and gas from an offshore platform or onshore production site to an onshore processing and storage facility. After treatment, pipelines are then used to transport oil and gas to a refinery. Iftankers transport the oil after onshore processing, then pipelines are used to carry the oil back offshore. Subsea pipelines from platforms to shore are generally constructed by pipelay or pipe-pull techniques (see Figure 30). In pipelay, pipe sections are welded on a lay barge vessel and installed on the ocean bottom. With pipe-pull, pipes are'welded together onshore or'on a floating barge and pulled into position by a tugboat, winch, or barge. Onshore pipelines are usually buried in trenches (see Figure 31). if technically feasible, pipelines can be constructed by subsurface horizontal drilling of pipeline routes which are known as directionally drilled crossings. A hole is drilled in a horizontal direction of sufficient size to place a conduit casing through which a pipeline "bundle" would be pulled. This method can be used to reduce blasting and trenching impacts. Every pipeline has a maximum throughput and pipeline c apacity which is a function of-diameter, design capacity (pressure), length, oil viscosity and facilities. Ultimately, pipeline capacity is a function of the anci characteristics of the crude. If peak production rates are expected to increase, it may be more economical to build a second parallel line rather than to attempt at the outset a design which would accommodate a later increase in the number of pumps and heaters. However, there would be increased environmental impacts from constructing additional lines in the future. Pipelines can be privately*owned or common carriers. A common'carrier pipeline can-be used by more than one producer. The tariff rates for interstate oil and gas pipelines are regulated by the Federal Energy Regulatory Commission (FERC), or if intrastate, by the State Public Utilities Commission (PUC). However, most of the onshore crude oil pipelines in California are privately owned and operated by integrated companies that maintain control of oil until it is sold as a refined product. These "industry common carrier" lines have equal access, but the facility is hot regulated by the Public Utilities Commission. Since tariffs for privately owned crude oil pipelines are not regulated,.the pipeline company can set its own price for transporting crude (OCS Project Task Force/OPR, Offshore Oil and Gas Development, Vol.1, 1977). Intrastate natural gas pipelines are regulated by t he State Public Utilities Commission. Several natural gas companies serve the southern California coastline from Point Conception to San Diego. There are natural gas transmission and trunk lines operated by the various gas companies within five miles of any landfall for offshore production between Point Conception and the Mexican border (OCS Project Task Force, 1977). There are many existing, proposed, and approved pipelines to serve the OCS area. Some are from platform to platform and some from platform to shore. As of June 1988, there are 164 miles of pipeline installed on the Pacific OCS 4r Offshore Pipeline Construction PIPELINE LAY BARGE JET SLED STORAGE FRAME WELDING WEIGHT & HOIST DK, HOUSE LINE-UP STATIONS COATING. DIRECTION OF BARGES STATION STATION PIPE LAY BARGE PIPE BURY BARGE ARTICULATED STRINGER HOSES TO JET SLED PIPELINE TO SEA BOTTOM JETSLED @`PULL-AIHEAD ANCHOR LINES Source: California Coastal Commission, Coastal Energy Development, 1981 Drawing for illustrative purposes oMyd Figure 30 drColifornio Coostat Commission Cartography Section MMM men Onshore Pipeline Construction Spread _7 or ry '2, ,Or Cleanup And Lowering And Welding Pipe Bending Ditching Restoration Tying-In Clearing And Backfilling Pipe Line-Up Hauling And Grading Coating Stringing ,Source: Adopted trom ERT Drawing for mustrative purposes only. Fiqure 31 dit"liforrito Coastal Commission C.rtor&phy Section -67- (MMS, 4/88). There are approximately 101.5 total miles of pipeline (including offshore and to shore) approved and/or under construction (approved project descriptions) and 6 proposed miles of pipeline (EIR/project descriptions). In state waters, there are existing and proposed pipelines from platforms,. islands, and subsea well completions.- No pipeline mileage figures are readily available for the existing pipelines, but approximately 43.8 new miles of pipeline are now being proposed (Hercules, Haley, and.Heron, Haven, & Holly A & 8). There are existing onshore pipeline systems distributing crude oil to California's three refinery centers. This crude oil transportation system is comprised of six major pipeline corridors: 1. the lower SanJoaquin Valley to Los Angeles Basin;' 2. the San Joaquin Valley to the San Francisco Bay region; 3. the Ventura area to the Los Angeles Basin; 4. a highly integrated and complex network (over 1,000 separate pipelines) in the L.A. Basin moving local production and crude delivered from the San Joaquin Valley, Ventura, Los Angeles and Long Beach Harbors to various refineries in the basin; 5. the central California coast (Estero Bay and Avila Beach) to the San Joaquin Valley, permitting shipment to or from the coast and to the Bay region from Ester o Bay; and, 6. the Four Corners Pipeline, the only-designated common carrier line in California, linking the Los Angeles Basin with the Four Corners area of the Southwest United States. At each producing area there are numerous gathering lines connected to the main trunklines. In addition, there are approved onshore pipelines under construction as well as pipelines proposed in San Luis Obispo and Santa Barbara Counties, and to Texas to carry OCS production. Based on these developments, there would be a total of 3,180 additional pipeline miles including lines to Texas. Tables 16-20 show the location and capacity of existing, approved, and proposed OCS offshore pipelines; major onshore pipeline systems; existing, approved, and proposed onshore pipelines carrying OCS production; and existing, approved, and proposed state offshore pipelines. Refer to Figures 14 through 23 for OCS and State offshore existing, approved, and proposed pipeline corridor locations. Figures 32 through 35 show the locations for existing major onshore pipeline systems and existing, approved, and proposed onshore pipelines in San Luis Obispo, Santa Barbara, and Ventura Counties as well as the proposed pipeline route to Texas. -68- Table 16 Existing, Approved, And Proposed OCS Offshore Pipelines as of December 1988 Pipeline Unit/ Size and Platform operator (field) Landfall type Status Hondo] POPCO Santa Ynez Las 12-in gas Existing (Hondo) Flores Hondo to Exxon (Hondo) Canyon 12-in oil Existing OS&T 2 6-in fuel, 8-in water A UNOCAL (Dos Cuadras) Rincon 12-in oil Existing to shore 12-in gas 6-in water B to A UNOCAL (Dos Cuadras) 2 8-in oil Existing 8-in gas 6-in water C to B UNOCAL (Dos Cuadras) 2 6-in oil Existing 6-in gas 6-in water Henry to sun Dos Cuadras/ 2 8-in oil Existing Hillhouse (Carpinteria 6-in gas (Offshore) 6-in water Hillhouse Sun (Dos Cuadras) 2 8-in oil Ex isting to A 8-in gas 6-in water Houchin to Phillips (Carpinteria La 10-in oil Existing Hogan to shore Offshore) Conchita 12-in gas 10-in gas lift 4-in water Habitat Pacific Pitas Point/ Carpinteria 12-in gas Existing Inter- (Pitas Point) State Off- Shore Co. 1. Oil from Platform Hondo is stored and treated on an offshore storage and treatment vessel, then offloaded onto tankers. Additional platform and pipeline 'emplacements for the Santa Ynez Unit have been approved. 2. Lines indicate pipeline linking to platform. -69- Pipeline Unit/ Size and Platform, operator (field) Landfall type Status Grace to Chevron Santa Clara/ Carpinteria 2-in oil3 Existing Hope (State (Santa Clara) 10-in gas3 waters to 10-in oil to shore) shore Gilda UNOCAL Santa Clara/ Mandalay 12-in oil Existing (Santa Clara) Beach 10-in gas 6-in water Gina UNOCAL (Hueneme) Mandalay 10-in oil Existing Beach and gas 6-in water Ellen to SWEPI Beta/(Beta) 2 14-in oil Existing Elly 4-in gas Elly to SWEPI Beta/(Beta) Long 16-in oil Existing shore Beach Eureka to SWEPI Beta/(Beta) 2 12-in oil Existing Elly 6-in gas 10-in water Edith to Chevron Beta/(Beta)' _2 6-in oil Existing Elly Edith to Chevron Beta/(Beta) Huntington 6-in gas Existing Eva (State Beach waters to shore) Gail to Chevron Santa Clara/ 8-in oil Existing Grace (Sockeye) 8-in gas 8-in oil/gas Hermosa to Chevron (Point Point 24-in oil Existing shore Arguello) Conception 22-in gas Harvest to Texaco (Point 2 12-in oil Existing Hermosa Arguello) 8-in gas Hidalgo to Chevron (Point 2 16-in oil Existing Hermosa Arguello) 10-in gas .2 Lines indicate pipelin e linking to platform. 3Lines from Platform Grace to Platform Hope -70- Pipeline Unit/ Size and Platform operator (field) Landfall type Status Julius to SWEPI San Miguel Guadalupe 20-in oil Approved shore oil field 10-in water (OCS) 8-in fuel requires coastal permit in state waters Irene to UNOCAL (Point Vanden- 20-in oil Existing shore Pedernales) berg Air 8-in gas Force 8-in water Base Iris UNOCAL (Point 2 10-in oil Approved/ to Peder- 6-in gas under Irene nales) construction Heather Exxon Santa Ynez 2 12-in gas to Heritage 16-in oil Heritage to Exxon Santa Ynez Las Flores 12-in gas shore Canyon Heritage to Exxon Santa Ynez 2 20-in oil Approved/ Harmony under construction Harmony to Exxon Santa Ynez 2 14-in gas mid-pt. tie-in Harmony to Exxon Santa Ynez Las Flores 20-in oil shore Canyon Hondo to Exxon Santa Ynez, 2 12-in oil mid pt. tie-in Shore to Exxon Santa Ynez Las Flores 48-in SALM Canyon oil Water outfall Exxon Santa Ynez Las Flores 16-in water Canyon Hacienda Chevron Rocky Point Unit 2 8 or 10-in oil Proposed 6 or B-in gas 2 Lines indicate pipeline linking to platform. (Source: MMS, Pacific Summary Report, July 1987 and EIR project Descriptions.) -71- Table 17 Existing Major Onshore Crude Oil Pipeline Systems in California by Capacity and Throughput as of June 1986 Maximum Average Percent Capacity Throughput Use Pipeline Link (mbd)l (mbd)l 1986 San Joaquin Valley to San Francisco and Estero Bay 514 440 86 San Joaquin Valley to Los.Angeles 158 147 93 Ventura County 163 72 TOTAL 897 750 (Source: California Energy Commission, June, 1988) 1. mbd one thousand barrels per day _72- Ma or Oil Pipeline Corridors Eureka Texaco Four Corners Mendocino Mobil - - - - - - - UNOCAL ...................... ARCO Shell 00000000000 Chevron Note: Pipeline locations approximate. San 0 0, 0 Fran6sco 0 0 0 0 0 0 0 Monter 0 0 ocifinga 0 San r 0 00 00 0 6 o 0\0 gBakersfield Estero Bay 0 0 a ... 6,0. Needles Pt. Concept ion Newhall Ventura Au 7,- Los Angeles IV San Diego 0 150 L L I Statute mass Source: Division of Oil and Gas, 1982 California Energy Commission, 1984 WC&Warnk CaesW Cammiwi= Figure 32 cartagmphy seetim Table 18 Existing onshore Pipelines carrying OCS Production as of December 1988 in Ventura and Santa Barbara Counties Pipeline operator Owner Facility to Facility Size and Type Origin of oil Phillips Ventura Pipeline Phillips-la Oonchita separ- to Mobil-Rincon storage facility 10-in oil Carpinteria offshore Field Company (consortium) Ation treatment facility mobil Ventura Pipeline Mobil-Rincon storage to UNOCAL's and Texaco's marine 22-in oil Dos madras Field; Company (consortium) facility terminals near Ventura Harbor Carpinteria Offshore Field; Santa Clara Unit Connecting line from Mobil to Texaco 8-in and Shell 12-in oil 22-in pipeline 10-in pipelines Connecting line from Mobil Texaco's Willett tank farm 8-In oil 12-in pipeline UNOCAL UNOCAL UNOCAL's marine terminal to UNOCAL's Santa Paula PUMP 8-in oil Santa Clara Unit near Ventura Harbor station Santa Paula pump station to Torrey Canyon pump station 8-in oil Torrey Canyon pump station to Los Angeles Basin 12-in oil Mandalay Beach separation Connecting line to UNOCAL 8-in oil and treatment facility to 12-in pipeline Shell California Shell California Tank terminal in Ventura to Newhall 10-in oil Dos madras Field; Avenue oilfield Carpinteria Offshore Field Texaco Texaco Near Shell's tank terminal to Connecting line to Mobil 8-in oil Santa Clara Unit in Ventura Avenue oilfield 10-in pipeline Texaco Texaco Texaco's Willett Tank Farm to Texaco (formerly Getty) 2-8 in oil Marine Terminal at Ventura lines River loading OCS and other. Crude oil Table 18 (continued) Pipeline operator owner Location Size and Type origin of oil ARCO ARCO Upper Ojai valley to Texaco pump station in 67in oil Santa Clara Unit Fillmore cuyama, to so.cal. Edison's Mandalay 20-in gas* Beach generating station Chevron Chevron Chevron's Carpinteria to mobil-Rincbn plant in 10-in oil Santa Clara Unit separation and treatment in Ventura County plant in Santa Barbara County PAPC0/PANGLl PAPCO/PANGL1 Pt. Conception to Gaviota Oil Gas 24-i n oil, 20-in gas Point Arguello processing Facility 250,000 bbl/day, Hermosa 32 pipeline miles Harvest Hidalgo UNOCAL UNOCAL Santa Ynez River to Lompoc 20-in oil Point Pedernales mouth Dehydration Facility 10-in gas Field (Platform to Orcutt pump Station 10-in water Irene) 8-in gas 48.7 pipeline miles This pipeline is currently transporting gas, but it could be converted to transport crude oil from either Elk Hills to Port Hueneme or from the Ventura-Santa Barbara,county area.to the Bakersfield area. (source; MMS, Pacific = Report, September, 1983) Most curren ion available in Final Plans aand EIR(s) Point Arguello Pipeline Company and Point Arguello Natural Gas Line company S.B. Co. %ZnCo. To Cuyama Onshore Pipelines and I Upper Ojai Valley Field Carpinteria Ventura Coun La Conchita ARCO Fillmore 2 Phillips 10 3 Mobil UNOCAL Rincon Ventura 4 Co Shell Ventura 12 C, Harbor 6 UNOCAL 7 Mandalay Beach Pipelines Oxnard Existing Facilities 0 Mugu Lagoon (3) Chevron Sepcrotlon and Treatment Facility (2) Phillips Separation and Treatment Facility Mobil Storage Facility Texaco Storage Facility V (5) Texaco Marine Terminal (g) UNOCAL Marine Terminal 3 UNOCAL Separation and Treatment Facility (8) Edison Mandalay Generating Station (!@ UNOCAL Santa Paula Pump Station (fo Texaco Pump Station 0 Torrey Canyon Pump Station Shell Pump Station Note: All facilities existing. Statute ufl@ Cartagmphy SecUaz Table 19 Approved/Under Construction and Proposed onshore Pipeline Systems as o. December 1988 in Santa Barbara and San Luis Obispo counties and to Los Angeles and to Texas Platform/Pipeline Operator wcation Size/Type of Line* Status Hondo,* Heritage, Heather, From shore to Las Flores Canyon facilities 20-in oil, 12-in water Approved/Under Harmony/Exxon 140,000 bbl/day, 11.2 pipe- ODnstruction Santa Ynez Unit line miles Julius/sWEPi and From shore to Guadalupe Dunes to Sisquoc 24-in oil Celeron interconnect, Proposed Celeron/All American 20-in oil, 10-in water, 8-in fuel, 125,000 bbl/day 44.4 pipeline miles Celeron/All American IAs Flores Canyon to Gaviota to Emidio in 30-in oil, 1,750 pipeline Coastal Segment from Las Kern County to Freeport, Texas miles, 300,000 bbl/day Flores in permit process Majority of line from Gaviota has been constructed except portion in Texas which is expected by 1989 Pacific-Texas Pipeline Co. San Pedro, California to Midland, Texas 42-in oil, 900,000 bbl/day Approved/No Construction 1,032 pipeline miles Southern California Pipeline Gaviota to Emidio to Los Angeles 30-in oil, Approved in Santa Barbara System/consortium of Four 330,000 bbl/day County; under review in all Corners Pipeline Co., Chevron 260 pipeline miles other areas; No construction Pipeline Co., Texaco USA, and Shell Oil Company luble 19 (continued) Platform/Pipeline Operator Location Size/Type of Line Status Heron, Haven, Holly A B/ Ellwood to Las Flores Canyon 8-in produced water Proposed AROO 8-in vapor, 18-in oil, 13.1 pipeline miles 12-in sweet gas, 12-sour gas, 16-in treated gas, 4 pipe- line miles Hercules/SWEPI (shell) Landfall to Canada De La Huerta 14-in oilf B-in sour gas Proposed 10-in sweet gas, 4-in brine, 4-in water 3-in glycol, 8-in produced water, .6 pipeline miles Hayley/.UW)CAL Landfall to PAPOO/PANGLI line or 6-in oil, 4-in gas Proposed Lompoc Dehydration Facility 36 pipeline miles to Lompoc or 2 pipeline miles to PAPCO/PANGL (Source: MMS, Pacific Summary Re port, July 1987, Hermosa, Irene and Exxon option B Approvals, julius and Exxon Lompoc Pipeline EIRS) Design capaci ty of'pipeline and not actual daily throughput. Chevron Pipeline and Point Arguello Pipeline' Companies and Point Arguello Natural Gas Line Company Onshore Pipelines and IF Santa Barbara and Sun Luis Obilsp Nipomo @j 7 Sat? Son to IN 0 Santa Maria 00 Pt. Sol 4.000 00000 1 Facilities SIsqUoc "00 Chevron-Texaco GoVi ExistIng Oil and Gas Exxon Los Flores Ca _j _j Approved 00 and Go .0 0 5 UNOCAL Lornpoc/Exi z z 2 6 SWEPI (Shell Nipom Proposed OP Proce3 0 ARCO Ellwoo$%lstlr@ G) Oil and Gas r 951 UNOCAL S%IEPI (Shell) Canada Surf Existing and Propose UNOCAL Santa Mario o Lompoc 00 Buellton UNOCAL Battles/Exis 0 0 00 Pt, Arguello 00 0z 0 0 Celeron 0 0 Co<istG) Segment a 0 0 0 6 0*09 2 ARCO Cool 0 0 Wan/papco/pangl 0 cbe\fr 0 00 Golet Gavioto Exx n 01 1 5 Pipeli6es Pt. Conception SWEPI (Shell) Existing S a n t a Barbara Chctnnej ---- Approved 0000000 Proposed 0* Statute kj" ISource: IVIMS, Pacific Summary Report, 1987 mcaHtornia COOBW cam-t-100 Cartoamphy secuan Nam m m Proposed Routes for Crude Oil Pipelines California to Texas California Emidio Barstow Gavioto Arizona L s %@. geleN.. New Mexico Blythe Phoenix 0 Tucson Lordsburg E Paso Midland Texas McCary@ey Pecos Austin 0 0 0 Mexico Freel IV SCIPS (Proposed-No Construction) Celeron-All American (Phase I-Existing) (Phase II-Approved/Under Construction) 0 200 Pacific-Texas (Approved-No Construction) Statute 40" Source: MMS, Paci tacautornLE COINtal commimion Cartepaphy Swum m4r m m m m m Sam m m m Table 20 Existing, Approved/Under oDnstruction, and Proposed State Offshore Pipelines from Platforms/Islands and Subsea Well Cbmpletions as of December 1988 Platforms Platform/operator Location-County/Lease Size/Type Status Hazel/Chevron Santa Barbara PRC 1824.1 one pipeline corridor Existing with Hilda/Chevron Santa Barbara PRC 1824.1 6-in oil, 6-in gas, 8-in gas Helen/Irexacol Santa Barbara PRC.2206.1 6-in oil, 8-in gas Abandoned in place Emy/Phillips Orange PRC 425.1 14-in oil, 8-in gas Existing Herman/Texacol Santa Barbara PRC 2725.1 6-in oil Abandoned in place Eva/UNOCAL Orange PRC 3033.1 8-in gas, 8-in oil Existing OD 0 Hope/Chevron Santa Barbara PRC 3150.1 one pipeline'corridor with Heidi/Chevron Santa Barbara PRC 3150.1 2-10-in oil Existing 1-10 in gas Holly/ARCO Santa Barbara PRC 3242.1 6-in oil, 6-in gas, Existing 4-in gas line Heron, Haven, Holly A&B/AROD (bal Oil Point, Santa Barbara 12-in gas lines, 10-12-in Proposed PRC 309, 3120, 3242 oil lines Hercules/SWEPI (Shell)' Shell Molino, Santa Barbara 14-in oil, 8-in sour gas, Proposed PIC 2920 10-in sweet gas, 4-in brine, 4-in water 3-in glycol, 8-in produced water Hayley/UNOCAL ODjo, Santa Barbara 6-in oil, 4.5-in gas Proposed PRC 2879 Esther/Chevron Orange PRC 3095.1 1-10-in water, 1-4-in water Existing 1-10-in oil, 1-12-in cable line 1. Platforms have been removed. Table 20 @Acontinued) Subsea Well Coupletions Subsea Well CDmpletion Lines Location@-County/Lease Size/Length Status Chevron/ARCO Gaviota, Santa Barbara 11-3-in oil, 2-4-in gas, 1-4 in gas Existing PIC. 2793.1t 2894.1, 2199.1 SWEPI(Shell) Shell Molino, Santa Barbara 7-4-in gas lines (3 lines to be abandoned) Existing PRC 2920.1 Phillips Philiips Tajiguas PRC 2933 16-4-in gas lines Existing 00 Artificial Islands Islands/operators Location-County/Lease Size/Length Status Belmont/Exxon orange PRC 186.1 Existing Rincon/Norris Ventura PRC 1466.1 6-in oil, 6-in gas Existing Grissom/City of Long Beach Existing White/City of Long Beach Los Angeles Granted Tidelands Existing Freeman/City of Long Beach Existing Chaffee/City of Long Beach Existing do (Source: OCS Project Task Force/Office of Planning and-Research, 1977; Cities Service EIR, December 1985; ARCO EIR June 1986; and Hayley And Hercules Development Plans) -82- VIII. OIL AND GAS SEPARATIONITREATMENT AND GAS PROCESSING PLANTS Separation and treatment facilities are designed to remove impurities from a crude oil well stream which-consists of oil, natural gas, and formation water (brine water, dissolved solids, and suspended solids). The oil and gas must be separated and the water removed prior to being processed for final disposition. The separation and treatment process may take place totally or in part offshore or onshore. The equipment used to separate the gas, oil and water components of the well stream is called a separator. Heater treaters and chemicals may be necessary to break down oil/water emulsions into oil and water. Generally, natural gas is removed from the well stream at the platform-and handled separately. If the gas is unassociated (no oil) or if the gas has been separated from oil and most of the water, it is sent to a dehydrator where additional water in the form of vapor is removed. If the gas is sour (high in hydrogen sulfide), it is sent to a gas treatment plant, where the sulfur is removed. The gas then goes to a gas processing plant. If the natural gas is sweet (low in hydrogen sulfide) it goes directly to the gas processing plant. A gas processing plant removes impurities to present standards of the purchasing utility. If economically desirable, the plants may be designed to also recover certain natural gas liquids such as butane, propane, and natural gasoline. Table 21 shows the existing, approved, and proposed separation and treatment and gas processing facilities with offshore throughput in Santa Barbara, San Luis Obispo, and Ventura Counties. Figure 36 indicates the locations of these facilities with numbers that are cross-referenced to the Table 21. OWN Separation and Treatment Facility Table 21 Existing*, hMroved/Under Construction, and Proposed �m!ration and Treatment And/or Gas Processing Facilities in San Luis Obispoe Santa Barbara, and ventura counties as of December 1950 (BPD barrels,per day MMSCFU-= million stanaara WbIC-Feetper day) Unit/Field (platforms or Facility Name Facility state wells) and Location- Operator Permit/Design capacity Process/equipment Status San Miguel Field/ 1. South Nipoma Mesa SWEPI (Shell) Oil: 40,000 BPD oil: Dehyrdation, H2S Proposed (Julius) Separation and Treat- 10-,000 BPD water 7iiioval produced water ment plant at treatment South Niporna Mesa, San Luis Obispo county Santa Maria Oil Fields. 2. Santa Maria Crude UNOCAL oil: 44,000 BPD oil: Delayed coker process, Existing Point Pedernales Field Refinery 'upgrader' @@ith proposed 5is- recovery; H2S absorption 00 (Irene) north of City of retrofit of coker sulfur recovery Guadalupe San Luis plant Obispo County Santa Maria oil fields 3. Battles Gas Processing UNOCAL Gas. 30 MMSCFD Gas: Compression, purification Existing Point Pedernales/(Irene) Plant, Santa Maria, of H2S, and lean oil absorption Santa Barbara County Point Pedernales/(Irene) Lompoc separation UNOCAL oil: 36,000 BPD to oil. Dehydration Gas: Remove Existing and treatment Hy-drocarbon cond4n-sate Facility T2,000 BPD. Produced north of city of Water: 36,000 BPD Larpoc, Santa Barbara county Point Conception Field/ S. Point Conception UNOCAL Oil: 1000 BOD oil and water separation and Existing Coast Guard and State Separation and Treatment Gas: .4 MMSCFD water treatment Lease -Plant near Government Point in Santa Barbara County Table 21 (continued) Unit/Field (platforms or Facility Name Facility state wells) and Location Operator Permit/Design Capacity Process/Equipment Status Point Arguello Field/ 6. Gaviota Separation Chevron Oil: 50,000 BPD Oil: Dehydration H2S removal, Existing (Hermosa, Hidalgo, Harvest) and Treatment/Gas asi. 120 MMSCFD treat produced water. Gas: 'Processing Facility Remove H2S, NGL's, and LPG's Gaviota, Santa Barbara county Alegre Field/State Lease 7. Gaviota Separation ARCO Oil: 350 BPD oil: Separators, 2 storage Existing 2793.1- And Treatment/Gas tanks; Processing Plant at Gas: .45 MMSCFD Gas: glycol dehydrator, gas Gaviota (Texaco Marine Tfft, sales compressor; no LACT terminal property) Santa hand gauged Barbara County I State Lease 2920 (Hercules) 8. Molino Separation SWEPI (Shell) Existing: Gas at Existing Gas: Removal of Existing and 00 and subsea gas well and Treatment/Gas 34/48 MMSCFD heavier hydrocarbons, proposed modi- I completions from 2199 Processing Plant at Proposed: Gas dehydration, compression, pro- fications and Canada de la Huerta, expand to 100 MMSCFD pane and NGL to sales additions Santa Barbara County Oil: 30,000 BPD Proposed oil and Gas Facility: under Santa Dehydration, water cleanup, sour Barbara county gas sweetening, sulfur recovery. Review State Lease 3933 subsea 9. Tajiguas Gas Processing Phillips Gas: 30 MMSCFD Gas.-@ Separation of condensate, Existing gas wells Plant at Tajiguas, compression Santa Barbara county Santa Ynez Unit/Hondo 10. Offshore Separation Exxon Oil: 40,000 BPD oil: Dehydration Existing (Hondo A) and Treatment Facility (CISM, offshore Las Flores Canyon in OCS waters Table 21 (continued) Facility Name Facility Unit/Field (OCS platforms) and Location Operator Permit/Design capacity Process/equipment Status Santa Ynez Unit/Hondo 11. POPOD Separation POPOD Gas: Phase I/ Gas: compression and dehy- Existing (Hondo A) and Treatment/Gas 36-MMCFD Z-ration; tail gas cleanup Processing Facility, Las Phase 11/60 MWFD Flores canyon, Santa Barbara County Santa Ynez Unit/Hondo 12. Las Flores Separation Exxon oil: 140,000 BPD Proposed Oil Facility: Approved/ Sacate,and Pescado fields/ and Treatment/Gas Gas-. 21 MMSCFD Dehydration, reduce H2S, under (Heather, Harmony, Heritage Processing Facility T4jis stripping) water cleanup (brine) sourgas construction Hondo A) Las Flores Canyon, Santa sweetening, compression Barbara county tIn Ellwood Field/Onshore 13. Dos Pueblos Separation ARCO oil: n.a./500-2000 BPD, Oil: Water separation Existing wells State Lease wells and Treatment Facility i5s: n.a./.35-.6 MMSCFD, dis: separation, compression, at Dos Pueblos, sweetening, tank gauge, no LACT Santa Barbara County Coal oil Point/State 14a Existing: Ellwood ARCO Existing: Gas 20 Existing: Oil-heater treaters, Existing oil and Leases PfC 3242, 309, Separation and MSCFD and Oil-20,000 settling and surge tanks Gas: gas processing .308, 208, and 3120/ l4b Treatment Facility BPD liquid gas, separators, gas at Ellwood (Holly, Heron, Haven, at Ellwood, Santa Proposed: Gas plant scrubbers, vapor recovery, Holly A B) Barbara County at Las Flores 60 MMS- glycol regeneration, gas Proposed gas Proposed: Separation CFD, (sour gas) and compression, LACT at Las Flores Treatment/Gas Processing 90 MMSCFD'(Sweetgas) Pra2sed/Gas: Liquid separation, and expanded oil Facility at Las Flores and oil treatment at dehydration, C02 reduction, (80 MBPD? at Canyon or Ellwood, Santa Las Flores or compression, sulphur recovery, Ellwood or Las Barbara County Ellwood 80,000 BPD w/ tailgas treatment, hydrocarbon Flores additional 3 platforms removal, WM and LPG Oil: Additional oil dehydration and treatment equipment-options of commingled or segregated 4r Table 21 (continued) Facility Name Facility Unit/Field (OCS platforms) and Location operator Permit/Design Capacity Process/Equipment Status Santa Clara Unit/Field 15. carpinteria separation Chevron Oil: 30,000 BPD oil. Dehydration, shipping Existing (Grace) Santa Clara Unit/ and Treatment/Gas as-: 23 MMSCFD Ta@abilities, water cleanup Sockeye Field (Gail) darpin- Processing Facility Gas: Compression, dehydration, teria offshore Field (Hope at Carpinteria, Santa U@@r unit Heidi) Summerland Offshore Barbara ODunty Field (Hilda & Hazel) Carpinteria Offshore 16. La Conchita separation Phillips Oil: 27,000 BPD oil: Dehydration, shipping, Existing Field/(Houchin, Hogan) and Treatment Plant iN-s: 22 MKSCFD iia-ter cleanup. [A conchita, ventura Gas: Compression and dehydration county DOr Unit 00 Dos cuadras Field/(A,B,c 17. Rincon Separation Mobil Oil: 36,000 BPD oil: Dehydration, shipping, Existing Hillhouse)/Rincon Offshore and Treatment/Gas 60.MMSCFD i.i-ater cleanup. field (Henry and Rincon Processing Facility Gas: Compression, carbon Island) Rincon, Ventura dTo-xide removal, low temp. County conditioning, LACT Unit. Santa Clara Unit/Field 18. Mand alay Beach UNOCAL Oil: 36,000 BPD oil: Dehydration, shipping, Existing (Gilda) Hueneme offshore Separation and as: 2 MMSCFD Water cleanup. Field (Gina) Treatment/Gas Gas: compression and dehydration, Processing Facility LACr Unit Mandalay Beach, Ventura County (Source of Data: MMS, Pacific Summary Report, 1987, EIR documents, Santa Barbara county Energy Division Staff, OPR Offshore oil and Gas Develomnt, Vol 11, FRT - oc I oftshore 011 1977; ODunty of Santa Barbara, Final EIR for proposed General Plan Amendments Regarding the Consolidation of Onshore aciTlEles to.r Pr ess ng and Gas along the County's SoutYubast, February, 19til. Presently operating Pt. San Luis Separation, 'Treatm And Gas Processing F (ku%s _Rkispo 16arbOro '\00 on C3@_, S Status 03 Pt. Sal Santa Maria 0 Existing 0 Approved 0 0 Proposed Lompoc Pt. Arguello Gaviota 0. 0 7 012 13 Santa Barbar 14b Ellwood Facilities Pt. Conception 14a/b 1. SWEPI (Shell)-Separation and Treatment facility 2. UNOCAL-Crude Refinery *upgrader" I UNOCAL-Gas Processing facility 4. UNOCAL.- Separation and Treatment facility Santa 5. UNOCAL- Separation and Treatment facility Ba?-bara 6. Chevron- Separation and Treatment/Gas Processing facility Channel 7. ARCO-Separation and Treatment/Gas Processing facility 8. SAEPI (Sh ell)- Separation and Treotment/Gas Processing facility* .9. Phillips-Gas processing facility N 10. Exxon-Offshore Separation and Treatment facility 11. POPCO-Separation and Treatment/Gas Processing facility 12. Exxon-Separation and Treatment/Gas Processing facility 13. ARCO-Separation and Treatment facility (formerly Aminoil) -nt facility 14a. ARCO-Separation and Treatme 14b. ARCO-Separation and Treatment/Gas Processing facility 15. Chevron -Separation and Treatment/Gas Processing facility Note: See Table 21 for 16. Phillip-s-Separation and Treatment facility S 0 17. Mobil -Separation and Treatment/Goa Processing facility 0 20 18. UNOCAL- Separa tion and Treatment/Gas Processing facility Statute Miles Source: MMS, Pa *Expanded Facilities Proposed. Santa B da"Lformis Co"U] Commission CarWgraphy SscUon -88- IX. REFINERIES IN CALIFORNIA After partial processing and treatment, crude oil is transported to refineries by pipeline or tanker and processed into marketable products. Unprocessed petroleum contains hydrocarbon compounds with a range of boiling points, and various amounts of oxygen, sulfur, nitrogen, salt, water, and trace metals. The refinery separates the natural components into marketable products such as diesel fuel, lubricating oil, fuel oil,.asphalt,, and propane. Major refining processes include: desalting,-distillation, cracki ng, alkylation, polymer- ization, reforming, and desulfurization (Centaur Associates, Factbook, Oct. 1985). There are 44 operable refineries on the west coast (California, Oregon, Washington) as of January.1, 1987, comprising approximately 18 percent of the nation's refining capacity. California with 36 refineries ranks second in the numbe'r and capacity of refineries nationwide with 16 percent of the nati-onal refining capacity. Of the 44 operable refineries on the west coast only 12 process offshore oil from California (MMIS, Summary Report, July 1987). The annual refining survey conducted by the Oil and Gas Journal in 1985, @oncluded that up to 115,000*barrels'per day of OCS crude could be processed in California with minor modifications to refineries and up to 280,000 barrels per day with the addition of residual conversion and desulfurization (Centaur Associates Inc. 1985). The refineries in the Gulf Coast can process the heavier crude with few or no modifications. Table 22 shows the operating refineries on the West Coast as of 1987. Figures 37(a)(b) shows the locations of the California facilities with numbers that are cross-referenced to Table 22 on page 89. _7 SOURCE: CALIFORNIA COASTAL C034ISSION, COASTAL ENERGY DEVELOMENT. 10 Refining Facilities -89- TABLE 22 Pacific Coast Active Refineries And Their Operable Atmospheric Crude Oil Distillation Capacity on January 1, 1987 Company Location 1987 Crude capacity (bpcd)(1) CALIFORNIA Northern Beacon Oil Co. 1. Hanford 17,300 Chevron USA, Inc. 2. Richmond (2,3) 270,000 Exxon Co. 3. Benicia (2,3) .120,500 Huntway Refining Co. 4. Benicia (2) 7,000 Pacific Refining Co. 5. Hercules (2) 55,000. Shell Oil Co. 6. Martinez (2) 135,200 Tosco Corp. 7. Martinez (2,3) 126,000 UNOCAL Corp. 8. Rodeo (3) 70,000 Southern WRCO 1. Carson (2) 216,000 Champlin Petroleum, Inc. 2. Wilmington (2) 64,000 Chevron.USA, Inc 3. El Segundo (2, 3) 390,000 *15,000 Conoco. Inc 4. Santa Maria 9,500 Edgington Oil 5. Long Beach (2) 41,600 Fletcher Oil & Refining Co. 6. Carson (2) 29,500 Gibson Oil & Refining 7. Bakersfield 9,600 Golden West Refining Co. 8. Sante Fe-Springs (2,3) 40,600 Huntway Refining Co. 9. Wilmington (2) 5,500 Kern Oil & Refining, Inc. 10. Bakersfield 21,400 Lunday Thagard Co. 11. South Gate 8,100 MacMillan Petroleum Co. 12. Signal Hill (2). 14,000 Mobil Oil Corp. 13. Torrance (2,3) 123,000 Newhall Refining 14. Newhall 23,000 Oxnard Refining 15. Oxnard (2) 4,000 Paramount Petroleum Co. 16. Paramount 32,000 *14,500 17. Bakersfield *20,500 Powerine Oil Co. 18. Santa Fe Springs (2) *33,400 Sabre Refining, Inc. 19. Bakersfield *10,000 San Joaquin Refining Co., Inc. 20. Bakersfield 10,000 *14,300 Shell Oil CO. 21. Wilmington (2) 102,000 Sunla'nd Refining Co. 22. .Bakersfield 12,000 Texaco Refining & Marketing, Inc 23. Bakersfield 38,000 24. Wilmington (2,3) 75,000 UNOCAL Corp. 25. Santa Maria (2,3,4,) 41,000 26.-Wilmington (2,3) 108,000 -90- Company. Locat-ion 1987 Crude capacity (bpcd)(1) West Coast Oil CO: 27. Oildale *5,000 Western Oil Refining, Inc. 28. Long Beach *19,200 Total 2,430,700 OREGON Chevron USA, Inc. Portland (3) **0 Total 0 WASHINGTON ARCO Ferndale (2) 163,,000 Chevron USA, Inc. Seattle **0 Mobil Oil Corp. Ferndale (2) 77,000 Shell Oil Co. Anacortes (2) 77,000 Sound Refining., Inc. Tacoma (2) *11,900 Texaco Refining and Marketing, Inc. Anacortes (2) 78,000 U.S. Oil and Refining Co. Tacoma (2) 32,000- Total 438,900 Pacific Total Crude Capacity. 2,869,600 National Total Crude Capacity 15,565,513 Total Number of Operable Pacific Refineries 44 Total Number'o.f Operable National Refineries 219 (1) bptd = barrels per calendar day. (2) Refineries located in the coastal zone (3) Refineries processing California offshore oil. (4) Serves as an upgrader with coke as its only saleable product. Currently idle, but was active during review period. Currently only conducting downstream operations. (Source: Adapted from MMS, Pacific Summary Report July,1987.) Active Refineries Northern CaliforniG Facilities Capacity (b/cd) 1 Beacon Oil Co.-Hanford 2. Chewon U.S.A.-Richmond 0 5,000-50,000 3. Exxon Co.-Benicia 4. Huntway Refining Co.-Benicia 5. Pacific Refining Co.-Hercules 50,001-100,000 6. Shell Oil Co.-Martinez 0 7. Tosco Corp.-Martinez 8. UNOCAL-Rodeo 100,001-500,000 0 Note: See Table 22 for more information. See'', Inset Below Napa CAL Sonoma Cc, @S*Wo ca, 5 In C136 mar, . . . . . . . . . . . ........... Conbv Costa CA@,[ .... ...... ....... ......... ... ......... ..... ............. ........... . ............ .......... .. ....... ... . . .. . .. ... ... ... .. ... .......... ......... ....... so. .............. ...... ate* .. .. ................. ................ .. Alameda Co. 0 150 Statute Maes [Source: MMS, Pacific Summary Report, 1987 conew cAsonderian Figure 37o cartall-phy ftaum 92- Active Refineries Sou'thern. California Faciffitie 1 . ARCO-Carson 2. Champlin Petroleum Co.-Wilmington 3. Chevron USA, Inc.-El Segundo 4. Conoco Inc.-Santa Mario 5. Edgington Oil Co.-Long Beach 6. Fletcher Oil & Refining Co.-Carson 7. Gibson Oil and Refining Co.-Bakersfield 8. Golden West Refinin -Santa Fe Springs Co. 9. Huntway Refining -Wilmington 10. Kern Co. Refining Inc.-Bakersfieid 11. Lundoy Thagard Co.-Southgate (LA) 12. MacMillion Petroleum Co.-Signal Hill 13. Mobil Oil Corp.-Torrance 14. Newhall Refining Co.-Newhall 15. Oxnard Refining Co.-Oxnard 16. Paramount Petroleum Co.-Paramount 17. Paramount Petroleum Co.-Bakersfield 18. Powerine Oil Co.-Santa Fe Springs 19. Sabre Refining, Inc. -Bakersfield 20. Son Joaquin Refining Co.-Bakersfield 21. Shell Oil Co.-Wilmington 22. Suniond Refining Co.-Bakersfield 23. Texaco Refining & Marketing Inc. -Bakersfield 24. Texaco Refining & Marketing Inc.-Wilmington 25. UNOCAL Corp.-Santa Maria 26. UNOCAL Corp.- Wilmington 27. West 'Coast Oil Co.-Oildale 28. Western Oil and Refining Co.-Long Beach C) 1 7 Capacity (b/cd) 19 4 0 5,000-50,000 See Inset Below 50,001-100,000 14 *11Y, 100, 0011 - 500,000 Los Angeles Co. Note: See Table 22 for more ;nformotion. ... .. . . . . . . 13 6 /Oro. Co. 5 24 21 2 0 ISO statuto Miss ISource: MMS, Pacific Summary'Report, 1987 dtc,@ cmiiiital conowmian Figure 37b cart"Mphy awtian -93- X. CREW AND SUPPLY BASES IN CALIFORNIA FOR OFFSHORE OIL Crew and supply bases are necessary support facilities for oil and gas exploration, development, and production. The bases are needed to transport materials, equipment, and personnel from onshore to offshore platforms and exploration rigs either by boat and/or helicopter. The bases generally have a pier or wharf for boat berthage. warehouses, open storage areas, and parking areas. Port Hueneme in Ventura County is presently the major supply base for California OCS activities. The Carpinteria and Ellwood Piers along with Ventura Harbor are used,for transferring light supplies and crew. The Gaviota and Goleta piers are also used for light supplies and crew on a temporary emergency basis requiring prior approval from state and local agencies. Oil development offshore Los Angeles and Orange-Counties use the Port of Los Angeles and Long Beach for crew and supply bases (Centaur Associates, Factbook, October 1985 and Santa Barbara County staff, 1987). There have been*three proposals for crew and supply bases in Santa Barbara and San Luis Obispo counties. K.T. Enterprises considered applying for a supply base project east of Gaviota on land owned by State Department of Parks and Recreation. A second proposal has been considered on the Morehart property at Naples/Dos Pueblos. Coastal Service Corporation proposed a base at Cojo Bay. The Port of San Luis Harbor District has proposed a multi-use harbor with the inclusion of a supply base at a site approximately 3,000 feet north of the Santa Maria River mouth in San Lbis Obispo County. Cojo Bay was the only proposal that was formally submitted to the County. However, the applicant withdrew its permit applicati6n to Santa Barbara County in 1986. The locations of these existing and proposed bases are shown on Figure 38. 0 Supply Boat for Offsh .ore Platforms SOURCE: COASTAL SERVICES CORPORATION Ai SOURCE: CALIFORNIA COASTAL CMIMISSION,. COASTAL ENERGY DEVELOPMENT 1981, Pier for Offshore Crew and Supply Operations Port San Luis Crew and Su Harbor District S. L. 0. Co. Kern Co. S.B. Co. CD - Ven. Co. Cojo Bay Gaviota Moorehart Property ...Ellwood Carpinteria 0 Goleta Ventura sa,'nta Barbara Port Hueneme R;chwdwn Rock 0 Anocapa 1. San Miguel 1. Santa Rosa 1. Santa Cruz ie 7@ Existing crew and major supply base 0 Existing crew and light supply base,k N 0 Proposed crew and supply base Gavioto and Goleta piers used temporarily (requires Prior approval). Begg Rock Santa Son Barbara 1. 0 - ----- Nicholas 1. 20 I Statute Mass Source- Santa Barbara Co., Centaur Associates Inc., and MIAS, Pacific Summary Report, 1987 Imcallftrais, Coesta Commission Cwtolpraphy OsaUm -95- XI. AREAS OFF LIMITS TO OIL AND GAS DEVELOPMENT.I.N CALIFORNIA There are "sanctuary" areas in state and federal waters that are off limits to oil and gas development. A sanctuary area is a specially designated area that is designed to protect marine resources. The Marine Protection, Research, and Sanctuaries Act of 1972 authorizes the federal designation of ocean waters as marine sanctuaries to protect or restore their conservation, recreational, ecological, historical or esthetic values. Marine Sanctuaries are created around distinctive marine resources that require protection through management and planning for optimum beneficial use. There is an established list that identifies areas from which candidates for national marine sanctuaries are selected. There are two existing sanctuaries on the West Coast, the Gulf of the Farallones National Marine Sanctuary and the Channel Islands National Marine Sanctuary. New oil and gas leasing and development are prohibited in these sanctuaries. The California legislature excluded certain state-owned tide and submerged lands from the extraction of oil and gas. These areas include Los Angeles County; portions of Orange County; all of San Diego County; portions of Santa Barbara County; San Clemente and Santa Catalina Islands within three nautical miles; San Luis Obispo County; Monterey County; Santa Cruz County, portions of the Counties.of Humboldt and Mendocino; until January 1, 1995, all lands in San Mateo, San Francisco, Marin, Sonoma, Napa, Alameda, Santa Clara, and D 'el Norte Counties and Solano and Contra Costa Counties except those situated east of the parallel- Carquinez Bridges; and Islands of Anacapa, Santa Cruz, Santa Rosa, and San Miguel within three nautical miles (Public Resources Code, Article 4, Div. 6, Section 6871.2). The abo've areas can be leased for oil development only if the State Lands Commission determines: 1) that oil or gas deposits are believed to be contained in such lands; 2) that the same are being drained by means of wells upon adjacent lands; and 3) that the leasing of.the same for the production of oil and gas will be in the best interests of the state. Areas of Los Angeles County can not be leased even with the above determinations unless such lands are within one nautical mile of the ordinary high water mark and the drilling for oil and gas deposits is to be done by means of slant drilling from an upland site. (Public Resources Code, Article 4, Div. 6, Section 6872). Also, as discussed earlier in Section III, any proposal for oil development in -State waters would have to receive approval from the Coastal Commission as well as other state agencies. In addition to the legislative areas, the State Lands Commission on October 26, 1988 voted to declare 214 miles of State tide and submerged lands off Mendocino and Humboldt Counties as additional sanctuary zones. No oil and gas leasing or development shall be allowed within these designated areas. Figures 39 through 41 show the existing national and state sanctuaries. SOURCE: CALIFOP141A COASTAL COI-VISSION. COASTAL ENERGY DEVELOPMENT, 1981. California Brown Pelican -96- Gulf of the Farallones National Marine Scnctuary Bodego Head 9a Tomales -Pt. Sonoma Co. ....... Morin .... .... .......... 0 Co. ........... Scin Pablo Bay ..... . . .. .... Pt. Rayft C/I ........ Bay .. .... .. .......... Rocky Pt. .... ...... ........... ...... ... ... BcLy . . ........ ....... .......... .. ........ . . .. .... . . ....... .............. ....... . ...*." .. .. . :@@ -t@: .. . .... Son . .. .... ........ ... GO\6e ........... Francisco Co. JsIands . ........ . ...... .. .. .... ... .. . . . ....... ..... .......................... ............. .. .. .. ...... ... . .. .. . ............ ...... ..... 4e. ................ Son Matto ........ .... @4 Co. . .. ... .... . .. ........ arl.. dorl s. Pillar Pt OOLO(z 0 "Muod mom 10 0 Statuto MR" 10 Source: NOAA. 1987 Iftcaworwo 00@ COOZELINAOU Figure 39 cli@ Santa Barbara Co. Ve Pt. Arguello Goviota Santa Barbara Pt. Conception Ca@@interia Santq, Barbar a CA Ventura V7'sS Port Hue . ............... ... . ... Rfch 'dkii.'Rod ...... . ....... . .......... ......... . . ............... . ... ............... I.... .. .............. . . ...... .. ........... ... .... ..... 546.1414WO Wild .,.@nqcqpo. Island Santa Roso Wand . ....... . .... . ............ ........... 1@s .. . .. ...... .......... National Marine Sanctuary Boundary 2 0 National Marine Sanctuar) !@j@ta B or ........... Channel Islands National Marine Sanctuary 0 Nautical 0 Statute MR Source: NOAA, 1987 decamarm" coafftal cammat-ton c.rwsmpby 36.11- -98- Del Norte coastal Oil and Gas Sanctuari.es Humboldt State of California Mendocino Sonoma Morin* Son Francisco* 0. L __j Son Mateo Statute mnes Santa Cruz Monterey San Luis Obispo Santa Barbara Ventura r-.-.-i Sanctuary established by Los Angeles Legislation @W.C.�W 1.4) Li (As, Septarnber Sanctuary established by State Lands Commission Orange (AWrQvW October 26, 1955) Sanctuary to expire Jan. 1, 1915 NOTE: Sanctuaries extend from the San Diego mean high tide line to the three nautical mile limit of State Jurisdiction and include oil of San Francisco and Monterey Says. Source: Sto te Lands Commission, 1988 Figure 41 cartovev" swum -99- XII* MAIOR COASTAI ACT ISSUES IDINT1111D RELATIVE TO 011SHORE OIL AND GAS DEVELOPMENT The Coastal Act policies that govern energy development deal with proliferation of facilities, oil spillage, vessel traffic safety, safety hazards, visual and scenic quality, air quality, commercial fishing, archaeological resources, biological resources, seismic hazards, geologic hazards, water quality, noise, public access, cumulative impacts, and public welfare. In its consistency certification and coastal permit review of c'ertain past lease sales and oil and gas projects, the Coastal Commission has identified the following major Coastal Act concerns and issues: 1) Size and timing of OCS lease sales and resultant development. 2) Need for consolidation of onshore and offshore facilities. 3) Risks to offshore-navigation from an increased number of platforms,, exploratory rigs, and vessel activity. 4) Cumulative impacts relative to air quality, commercial fisheries, oil spills, scenic quality, marine resources, vessel traffic safety, and land resources. 5) Effects from disposal of drill muds and cuttings, formation waters, and other drilling wastes. 6) Transportation of oil by pipeline rather than by tanker to promote consolidation of facilities, reduce risks of oil spills and reduc,e air quality impacts. 7) Protection of wetlands, waterfowl migration, and nesting areas. 8) Protection of commercial fishing and environmentally sensitive areas. 9) Socioeconomic impacts on local communities. 10) Adequacy of oil spill equipment, contingency plans, and training programs. 11) Onshore and offshore effects of air emissions from platforms and exploratory rigs and associated development. 12) *Protection of visual and recreational resources. 13) Protection' of archaeological resources. 14) Protection of marine and estuarine sanctuaries. _100- XIII* MA30R CO"DITIONS, OR IR03-ICT CHANGES RISULTING IRON THE COASTAL COMMISSION'S REVIEW OF ONSHORE AND OFFSHORE OIL AND GAS DEVELOPMENT Under its consistency review authority, the Commission has.often found that the federal stipulations on lease sales and the OCS orders have not been sufficient to find consistency with Coastal Act policies. In addition, under its coastal permit or appeal authority, the Commission has not always found the applicant's proposal or the local government's conditions of approval adequate to find consistency with Coastal Act policies. Therefore, the Commission has required additional conditions on coastal permits or changes to projects on consistency reviews to protect coastal resources and thus find consistency with Coastal Act policies. The major mitigations, conditions or changes that have been.made by the Coastal Commission in consultation with other several federal, state, and local agencies, are as follows: 1) Case by case evaluation of transportation of oil by pipeline rather than by tankers if available and feasible with capacity to market destinations. 2) Specific oil spill containment and clean-up equipment to mitigate oil spill impacts. 3) Oil spill response training for oil company personne.l. 4) Installation of wind, wave, and cur rent data equipment for oil spill trajectory analysis that will help predict the direction of oil spills in. any given oil development area. 5) Provision of the most effective and least toxic oil dispersants to be used to break up oil spills. These chemicals can only be used upon approval of the Environmental Protection Agency. 6) Prohibition of the use and offshore disposal of the most toxic components of drill muds to minimize impacts to marine water quality. 7) Restrictions on the disposal of drill muds and cuttings to protect sensitive marine environments. 8) Well relocations and post-exploration debris surveys to protect commercial fishing areas. 9) Installation of automatic radar plotting aids in appropriate areas and radars with guard zones and audible and visual alarms for offshore vessel traffic safety. 10) Additional lighting for platforms and drill rigs to prevent vessel traffic collisions. 11) Seasonal restrictions on exploration plans to protect migrating, marine species and certain commercial fishing operations. 12) Injection timing retard (40) to reduce NOX emissions. 13) Ventilation of vapors to flare system to reduce fugitive hydrocarbon emissions. 14) Utilization of hydrogen sulfide (H2S) scrubber to remove H2S from gas during well testing. 15) Collection of data on fuel consumption and meteorological conditions and submitting it to ARB and APCD for air quality impact analysis. 16) Pipeline consolidation plans to minimize onshore and offshore area impacts on kelp beds and other marine and land resources. 17) Kelp bed mitigation.programs to mitigate pipeline construction impacts. 18) Ocean floor debris removal. plans to minimize pipeline construction impacts. 19) Relocation of pipelines and other oil and gas structures outside of archaeological and environmentally sensitive areas. 20) Requirements for oil spill contingency, waste disposal, grading, and fire protection plans to minimize impacts from oil spills, pollution, erosion, and fires to the environment. 21) Utilization of supply boat routes and mooring areas adopted by the Santa Barbara Channel Oil Service Vessel Corridor Program Joint Committee' to minimize commercial fishing impacts. 22) Requirements for public access to coastal beach areas. 23) Avoidance of marine construction activities during the whale migration period of December through May. 24) Transportation of NGL's by pipeli ne or rail when it becomes available to the applicant's market destination to avoid road traffic impacts, and public hazard concerns. -102- XIV. MAJOR RESULTS OF COA STAL COMMISSION REVIEW OF OFFSHORE OIL AND GAS DEVELOPMENT The Commission's review authority has resulted in major positive benefits that may not have otherwise occurred with oil and gas development. The following is a listing of some of those major positive benefits in which the Commission: 1) On a'case-by-case basis, estab.lished agreements for oil companies to transport oil by pipeline, when these pipelines are available and' .when their use would clearly reduce environmental impacts. 2) Increased oil spill containment and clean-up capabilities including four major oil spill response vessels dedicated to 24-hour response on line in California. 5) In the forefront of developing and requiring alternatives to traditional exploratory, construction, and production techniques to minimize impacts on commercial fishing operations. 6) Required the submission of improved cumulative impact analysis by oil companies through their project submittals and EIS/R's. As a result, a cumulative impact analysis on commercial fishing has been completed. 5) Recommended and received certain improved federal OCS lease sale stipulations. Lease Sale 73 and 80 require'improved modeling, analysis, and mitigation measures to decrease impacts on onshore air quality, improved communications between the commercial fishing and oil and gas industries, and additional oil spill equipment, training, and drills. 6) Required companies to use chrome-free lignosulfates which reduce toxicity of discharged muds into the marine environment. -103- XV. GLOSSARY OF TERMS Active Leases Areas that have been leased and are stil-1 within the federally required time frame for exploration and/or development. Alkylation - The process of introducing one or more alkyl groups into the structure of hydrocarbons to form high octane fuels. Analog - A continuous physical variable (such as voltage or rotation) which bears a direct relationship (usually linear) to another variable.(such as the motion of the earth because of seismic waves) so that one is proportional to the other. Continuous, as opposed to discrete-or digital. .Associated Gas - Free natural gas in immediate contact, but not in solution, with crude oil in the reservoir (see dissolved gas.). Barrel (BBL) - A barrel. of oil equals 42 gallons. The measure stems from the* 19th century when-oil was carried in wooden 50-gallon barrels that leaked an average of eight gallons during shipment and storage. Block - A geographical area having a square dimension of approximately 3 miles on a side (9 square'miles, 5,760 acres or 2,331 hectares) on the California (Lambert) Plane Coordinate System and 5,693 acres (2,304 hectares) on the Universal Transverse Mercator System (used north of Point Conception and southwest of San Diego). It is used in official MMS protraction diagrams or leasing maps (see Tract). Bonus - Money paid by the lessee for the *execution of an oil and gas lease. BPD ON) - Barrels per day. Call for information and'Mominations The Minerals Management Service formally requests nominations, for those specific areas where oil companies are interested in leasing and where the state and other parties would have problems with development. Catenary Anchor-leg Mooring (CALM) A moored buoy with a fluid swivel top to which a tanker is connected to a mooring line. It is anchored using catenary chain legs. Cargo is transferred through a floating hose connected to the tanker and the buoy fluid swivel. An underbuoy hose connects the floating hose to the subsea pipelines. Christmas Tree - The assembly of pipes, valves and-fittings at the top of the casing which is used to control the f.low of oil and gas from a producing well. Chrome-Free Lignosulfates - An additive to drill muds without chromium. 'E-hromium is a metallic chemical element with a high resistance to corrosion which may be toxic to sensitive life stages of marine organisms. Coastal Act of 1976 A law enacted by the California legislature in 1.976 which regulates development within the coastal zone from the Oregon border to the border of Mexico. The policies of the Act are aimed at protection and preservation of coastal environmental resources as well as the protection and -104- promotion of.public use and enjoyment of coastal resources. The Coastal Commission established under the Act regulates development in the zone through a coastal permit process until local governments in the zone establish their ,local coastal programs (LCP's). The Commission retains permit and appeal authority over certain areas and/or over certain types of development Coastal Zone Boundary The specific mapped area of the State of California established by the Coastal Act of 1976 from the Oregon border to the border of the Republic of Mexico which extends seaward to the State's outer limit of jurisdiction including all offshore islands, and extending inland generally 1000 yards from the mean high tide line of the sea. In significant coastal estuarine, habitat, and recreational areas it extends inland to the first major ridgeline parallelingthe sea or 5 miles from the near high tide line of the sea, whichever is less, and in developed urban areas the zone generally extends inland less than 1,000 yards. Coastal Zone Management Act (CZMA) A federal law enacted in 1972 to Wprotect,.preserve, develop and, where possible, restore, or enhance the. resources of the nation's coastal zone," through encouragement and assistance to states and through state participation in decisions affecting the coastal zone. The states establish coastal management programs subject to federal review and approval which outline principles for development and protection. Federal actions must be consistent with State Coastal Management Plans to the maximum extent practicable. Applicants for federal licenses and permits must submit consistency certifications. A 1976 amendment provides that OCS lessees must submit a consistency certification on exploration and development and production plans for State review and concurrence. An objection can be appealed to the Secretary of Commerce. Condensate - Known sometimes as distillate. Liquid hydrocarb ons produced with natural gas that are separated from the gas by cooling and various other means. Condensate generally has an API gravity of 50 to 120 degrees and is water-white, straw, or bluish in color. Consolidation/Consolidated - Involves requiring offshore and/or onshore operators to minimize the areas used for offshore/onshore operations through multi-use, multi-company facilities. Cracking - A process carried out in a refinery reactor in which the large molecules,in the charge stock are broken up into smaller, lower-boiling, stable hydrocarbon molecules, which leave the vessel as overhead (unfinished cracked gasoline, kerosines, and gas oils). At the same time, certain of the unstable or reactive molecules in the charge stock combine to form tar or coke bottoms. The cracking reaction may be carried out with heat and pressure (thermal cracking) or in the presence of a catalyst (catalytic cracking). Desalting - In the refining process, removing inorganic salts from crude oil to prevent corrosion of process equipment. Oil is separated from water which contains the salts. Disipersants A chemica.1 substance to break up concentrations of toxic fluids @sed sometimes in oil spill cleanups. -105- Desulfurization A process where sulfur compounds such as hydrogen sulfide, mercaptans, sulfides, and disulfides are removed from crude oil Development - Activities that take place following exploration for, discovery of, and delineation of hydrocarbons in commercially recoverable quantities (including but not limited to geophysical activity, drilling, platform construction, placement, and operation of all directly related onshore support facilities) and that are for the purpose of ultimately producing the hydrocarbons discovered. Development and Production Plan OPPJ - A plan describing the specific work to be performed on an offshore lease or leases, including all development and production activities that the operator propose(s)to undertake during the time .period covered by the plan and all actions to be undertaken up to and including the commencement of sustained production. The plan also includes descriptions of facilities and operations to be used; well locations; current geological and geophysical information; environmental safeguards; safety standards and features; time schedules; and other relevant information. Under 30 CFR 250.34-2, all lease operators are required to formulate and obtain approval of such plans by MMS. Before final approval by MMS, the operator must receive a consistency certification by the Cal,ifoenia Coastal Commisison or an override to a Commission objection by the Secretary of Commerce. If the plan is for development in State Tidelands, then the lease operation must receive approval from the State Lands Commission as well as coastal permit approval f'rom the Coastal Commission. Distillation - The process of separating hydrocarbons in crude oil into different Darts with specified boiling point ranges. It results in such* products as raw gasoline, diesel oil, asphalti and fuel oil. Drill Cuttings - Chips and small fragments of rock as the result of drilling that are brought to the surface by the flow of the dril)ing mud as it.is circulated. Drill Muds - A special mixture of clay, water or refined oil, and chemical additives pumped downhole through the drill pipe and drill bit. The mud cools the rapidly rotating bit; lubricates the drill pipe as it turns in the well bore; carries rock cuttings (solid materials removed from drill hole) to the surface; serves as a plaster to prevent the wall'of the bore hole from crumbling or collapsing; provides the weight or hydrostatic head to prevent extraneous fluids from entering the well bore; and controls downhole pressures that'may be encountered. Drillship - A self-propelled, self-contained vessel equipped with a derrick amidships for drilling wells in deep water. Emulsion - Mixture of crude oil and water remaining after free water has dropped out. Environmental Impact Statement (EIS) An analysis of the environmental effects of a project required by the federal National Environmental Policy Act of 1969, -106- Exploration The process of searching for hydrocarbons. Exploration activities include (1) geophysical surOys where magnetic, gravity, seismic,' or other systems are used to detect or infer the geologic conditions conducive to the accumulation of such minerals; and (2) any drilling, except development drilling, whether on or off known geological structures. Exploration also includes the drilling of a well in which'a discovery of oil or natural gas in paying quantities is made and the drilling of any additional well after such a discovery that is heeded to delineate a reservoir and to enable the lessee to determine whether to proceed with development and production. Exploratory Rigs - Vessels used for offshore oil and gas exploration. They can be a drill ship which is a self-propelled, self-contained vessel equipped with a derrick amidships for drilling wells in deep water; a jackup rig that is a bargp.like, floating platform with legs that can be lowered to the sea bottom to raise the decks above water; or a semisubmersible which is a drilling rig mounted on an offshore bargelike vessel whose hull is submerged by flooding its compartments, leaving the derrick and its equipment above the water line. Field - An area within which hyd rocarbons have been concentrated and trapped in economically producible quantities in one or more structural or stratigraphic related reservoirs. Fixed Berth - A pier built out into deep water for tankers at a marine ter@minal. Flare System - A system to burn gas for the purpose of safe disposal. Heater-Treater A vessel in which heat is transferred from a hot fluid to a colder fluid through the walls of pipes which separate the fluids in flow through the vessel. Hydrocarbon - Any organic compound comprised of carbon and hydrogen; for example, parafins, olefins, members of the acetylene series, alicyclic hydrocarbons, and aromatic hydrocarbons, commmonly referred to as petroleum, natural gas, coal, and bitumens. Hydrogen Sulfide (H2S) - A poisonous, corrosive compound consisting of hydrogen and sulfur commonly found in coal, oil, or gas which must be removed .before formal sale of the product. Injection Timing Retard - Air pollution control technology which cools engines lo reduce nitrogen oxide (NOx) emissions. Jack-Up Rig - A mobile drilling platform with extendible legs for support on the ocean floor. LACT - Lease Automatic Custody Transfer is an automatic system for measuring and monitoring produced oil and gas prior to sale. Landfall The location where a pipelin e comes out of the water and onto land. Lay Barge A barge used to lay underwater pipelines. -107- Lease A contract authorizing exploration for and development and production of minerals; the land covered by such a contract. Lease offering - See lease sale. Lease sale - The public opening of sealed bids made after competitive submittal for leases granting companies or individuals the right to explore for and develop certain minerals within a defined period of time. Local Coastal Program (LCP) - Individual.county and city coastal programs mandated by the California Coastal'Act of 1976, each consisting of a land-use plan and zoning implementation ordinances. Marine Sanctuary(jes) - Areas protected under the'federal Marine Protection, Research and Sanctuaries Act of'-1972.' Marine Terminals - A facility that can receive or ship out crude oil or petroleum products. There are pipelines from the terminal mooring to shore, onshore pumping stations and storage tanks. The terminal can be in the form of a fixed pier or berth, an island, a multi-point or a single point mooring. M B P D - Thousand barrels per day (oil). M C F D - One thousand cubic feet per day (natural gas). MMSCF/D Million standard cubic feet per da y . M M B 0 Million barrels per day. Multiple Buoy Mooring - Three to seven moored buoys for mooring tankers depending on ship size and environmental conditions. The buoys are placed in position off the ship's stern. The ship's anchors are used for forward. mooring points. Submerged hoses attached to the subsea pipelines are connected to the tanker once it is moored. NGL - Natural gas liquids which are gaseous at underground reservoir temperatures and pressures but are recoverable by condensation or absorption. @!Ox Emissions - Compounds.of nitrogen and oxygen which may be produced by th@ burning of fossil fuels. They are harmful to health and a contributor to formation of smogs. OCS Lands Act (OCSLA) --A federal law enacted in 1953 which gave primary control to the federal government of submerged lands beyond the three-mile limit of the territorial sea. The Act.was amended in 1978 to require the Secretary of Interior (DOI) to select the size, timing, and location of lease sales in a manner that balances the-potential for oil discovery and adverse impacts on the coastal zone. The Act was amended again in 1986 to require the distribution of a portion of the receipts from the leasing of mineral resources of the OCS to coastal states. OCS Orders - Orders issued by th e Minerals Management Service (MMS) for each OCS area. These orders govern oil and gas lease operations and specify procedures and practices that are required by the MMS during exploration and development and production activities. -108- Offshore Storage and*Treatment Vessel (OS&T) A converted tanker anchored near a platform and used to remove natural gas, water, and.other impurities from crude oil and to store the treated product until it is unloaded by a shuttle vessel. There is one OS&T in federal waters near Platform Hondo off the Gaviota coast, Santa Barbara County. Oil spill Contingency Plan - A plan submitted by the oil/gas operator along with or prior to a suFm-T-s-sion of a plan of exploration or a development/production plan that details provisions for fully defined, specific actions to be taken following discovery and notification of an oil spill. OCS Order No. 7 specifies the requirements of this plan. Outer Continental Shelf (OCS) - All submerged lands lying seaward of the State tidelands. Jurisdiction and control over these lands was asserted in 1945 by President Truman. The so-called Truman Proclamations were incorporated into domestic law by enactment of Congress in 1953 of the Submerged Lands Act (67 Stat. 29) and the Outer Continental Shelf Lands Act (67 Stat. 462). Ozone.- A major component of photochemical smog. Plan of Exploration (POE) - A p lan based on all available relevant information about a leased area that identifies, to the maximum extent possible, all, the potential hydrocarbon accumulations and wells that the operator proposes to drill to evaluate the accumulations within the entire area of the lease(s) covered by the plan. Under 30 CFR 250.34-1, all lease operators are required to formulate and obtain approval of such plans by the Regional Director of MMS before expl.oration activities can commence. Before final approval by MMS, the operator must receive a consistency certification by the California Coastal Commission or an override to a Commission objection by the Secretary 'of Commerce. If the plan is for development in State Tidelands, then the lease operator must receive approval from the State Lands Commission as well as a coastal permit approval from the Coastal Commission and any other applicable state, federal and local permits. Planning Are (s) - Geographical area designated by the Minerals Management Service for potential lease sale offerings. Platform - A fixed steel or concrete structure from which offshore development wells are drilled and produced/oil/gas/water is processed. It consists of a jacket or welded frame which is positioned almost totally underwater and .attached to the ocean floor with piles driven through hollow legs. The deck section where drilling activities occur is welded to the top of the jacket. Polymerization The combining of similar light weight hydrocarbon molecules to fo rm a heavier hydrocarbon molecule as propylene and butylene which are, mixed to produce a gasoline blending stock. Processing A course or method of operations in the production of certain products. Production Activities that take place after the successful establishment of means for the removal of hydrocarbons, including such removal, field operations. transfer of hydrocarbons to shore, operation monitoring, maintenance, and workover drilling. _109- 'efinery - A plant for heating crude oil so that it separates into chemical components which are then distilled off as more. usuable substances as gasoline, kerosene, fuel oil, propane and lubricants. Reforming - A process in which heat and catalysts are used to.rearrange hydrocarbon molecules without changing their composition. Catalytic reforming is used to upgrade low octane naphthas, convert naptha to liquified petroleum gas, and produce aromatic hydrocarbons, a fe edstock for explosives, detergents, plastics, and other petrochemical products. Scrubber - A device-for removing impurities especially from gas. Scrubbers. are used to reduce air pollutants. Sea Island - An offshore pier for tankers consisting of a-platform with loading and/or unloading facilities connected to shore by subsea pipelines. Seismic - Pertaining to, characteristic of, or produced by earthquakes or Earth vibration; having to do with elastic waves in the Earth. Semi-submersible Rigs - Floating drilling platforms which can be used in deepwater exploration. They may be e 'ither self-propelled or require towing. At the drill site, ballast chambers are-flooded to pre-determined water depth with a mooring system to keep the vessel on location. Separation and'Treatment Facilities - Facilities that separate oil and/or gas from produced water, remove natural gasolines from gas, and remove sulfur from crude oil or natural gas. Single Anchor Leg Mooring (SALM) - A semi-rigid anchored mooring used by vessels, primarily tankers, as a system to transfer oil to or from storage tanks or production platforms. The mooring -buoy at the sea surface is attached to a mooring base anchored to the sea floor. Tankers are connected to it by mooring lines. Submarine pipelines are connected to the base from where hoses connect to the tanker. Single Buoy Mooring - A mooring system using one buoy and commonly used for mooring large crude carriers. Two common types are CALM (catenary anchor-leg mooring) and SALM (single anchor leg mooring) (see SALM definition). Sour Crude Crude oil*containing appreciable amounts of hydrogen sulfide and mercaptans. Sour Gas - Hydrocarbon gas containing undesirable sulphur compounds, sulphuretted hydrogen and methyl mercaptan. Stipulations - Conditions of leases under which the federal offshore leases must be developed. Submerged Lands Act A federal law enacted in 1953 which gave primary control over the submerged lands of the coastal waters out to three-miles to the states. _110- Subsea Completion A production well in which the Christmas tree assembly is located at or near the ocean bottom rather than on a platform. The produced liquids or gases are then transferred from the well head either to a nearby fixed platform or to a shore facility for processing. Supply Boats - Vessels that ferry people (crew boat), food, water, fuel, and drilling supplies and equipment to a platform or exploratory rig. Sweet Gat - Hydrocarbon gas free from sulphur compounds. Treatment Facility - A facility that removes impurities, separates hydrocarbons from water, emulsions, and other impurities, and further separates the liquid and gaseous hydrocarbons. Tract - An areal unit usually consisting of a single block from an official protraction diagram. Groups of tracts, having sale-specific numbers, were selected and offered for lease prior to implementation of areawide leasing. Through Lease Sale 80, this was an identification number assigned to a block for a particular lease sale. In the future, MMS will not use tract numbers (see Block). Unitization - A process by which two or more leaseholders allow one company to serve as the operator for exploration, development, and/or production of the affected leases. Glossary Sources 1. Centaur Associates Inc., Prepared for Minerals Management Service, Facilities Related to Outer Continental Shelf Oil and Gas Develo6ment Offshore California: A Factbook, October 1985. 2. Funk and Wagnalls, Standard College Dictionary, 1973. 3. Hunt, V. Daniel, Energy Dictionary, 1979. 4. Langenkamp, R.D., Handbook of Oil Industry Terms and Phrases, Fourth Edition, 1984. OCS Project Task Force, Office of Planning and Research Prepared for California Coastal Commission, Offshore Oil and Gas Development: Southern California, October 1977, Vols. I & II. 6. Trabant, Peter K. Ph.D., Applied High - Resolution Geophysical Methods, 1984, 7. U.S. Department of Interior/Minerals Management Service, Pacific Summary Report, April 1985. B. U.S. Department of Interior/Minerals Management Service', Pacific Summary Report/Index, November 1984-May 1986. XVI. Contacts 1. Anthony, Doug, Planner, Santa Barbara County Energy Division 2. Blaisdell, Dave, Western Oil & Gas Association, Los Angeles, CA 3. Baird, Brian, Supervising Energy Analyst, California Coastal Commission, San Francisco, CA 4. Bates, Devon, Coastal Energy Analyst, formerly with California Coastal Commission, San Francisco, CA 5. Brown, Judy, Staff Services Analyst, State Lands Comission, Sacramento, CA 6. Bubriski, Mark, Energy Specialist, formerly with Santa Barbara County Energy Division, Santa Barbara, CA 7. Callahan, Catherine, Energy Specialist, Santa Barbara County Energy Division, Santa Barbara, CA 8. Charter, Richard, Coordinator for Local Government, The California Local Government Coordination Program 9. Deter, E. Ross, Chief of Assessments Division, California Energy Commission, Sacramento, CA 10. Dinkfeld, Ed, Offshore Regulatory Permitting Specialist, formerly with ARCO, Bakersfield, CA 12. Dougall, David, Environmental Specialist, Phillips Petroleum Company, formerly in Santa Barbara, CA 13. Eoff,'Dennis, Senior Ener gy Specialist, California Energy Commission, Sacramento, CA 14. Flynn, Jim, Division Staff Engineer, Exxon, Thousand Oaks, CA 15. Glaviano, Tom, Energy Analyst, California.Energy Commission, Sacramento, CA 16. Gillen, Dick, Regional Offshore Construction Manager, formerly with UNOCAL, Ventura, CA 17. Goldbeck, Steven, Ass istant Planner, San Francisco Bay Conservation and Development Commission, San Francisco, CA 18. Graham, Mark, Petroleum Engineer, Minerals Management Service, Los Angeles, CA 19. Guerard, Bill, Senior Oil And Gas Engineer, California Division of Oil and Gas, Sacramento, CA 20. Habel, Marilu, Associate Oil & Gas Engineer, California Division of Oil and Gas, Sacramento, CA 21. Howell, Celia, Energy Analyst, California Energy -Commission, Sacramento, CA 22. Jacobs, Fred, Public Relations Officer, Minerals Management Service, Los Angeles, CA. 23. Johnson, James, Coastal Energy Analyst, California Coastal Commission, Santa Barbara, CA 24. kill, Leland, Director of Port Planning, The Port of Long Beach, Long Beach, CA 25. Hubble, Caroline, Executive Director of California Coastal Operators Group, Santa Barbara, CA 26. Kern, Phil, formerly Senior Planner with San Francisco Bay Conservation and Development Commission, San Francisco. Now with Port of San Francisco, San Francisco, CA 27. Kjellberg, Gene, Associate Planner, County of Ventura Planning Division, Ventura, CA 28. Knatz, Geraldine, Assistant Director of Port Planning, The Port of Long Beach, Long Beach, CA 29 Lawrence, Lorraine, Public Affairs Officer, Minerals Management Service, Los Angeles, CA 30. Liebster, Jack, Director of Public Information, California Coastal Commission, San Francisco, CA 31. Livenick, Susan,' Geologist, State Lands Commission, Long Beach, CA 32. Magnuson, Gary, Director, Coastal States Organization, Washington, D.C. 33. Haves, Sharon, Senior Planner, formerly with Santa Barbara County Energy Division, Santa Barbara, CA 34. McCarthy, Richard, Senior Marine Geologist, California Coastal Commission, San Francisco, CA 35. Nicholson, Joe, Supervising Energy Analyst, formerly wi th California Coastal Commission, San Francisco, CA 36. Page, Jim, Energy Specialist, California Energy Commission, Sacramento, CA 37. Poe, Rebecca, FERC Office of External Affairs, Washington, D.C. 38. Robinson, Sid, Director of Planning & Research, Port of Los Angeles, San Pedro, CA 39. Reid, Robert, Regulatory Specialist, California Divsion of Oil and Gas, Sacramento, CA 40. Rogalin, Suzanne, Coastal Energy Analyst, California Coastal Commission, San Francisco, CA 41. Sanders, Dwight, Chief Planner, State Lands Commission, Sacramento, CA 42..Serex, Eugene, Chief Harbor Engineer, Port*of Richmond, Richmond, CA 43. Strachan, Susan, Planner, formerly with the Santa Barbara County Energy Division, Santa Barbara, CA 44. Van Auker, Julia, Geologist, Minerals Management Service, Los Angeles, CA 45. Willard, A.D., Supervising Minerals Resource Engineer, State Lands Commission, Long Beach, CA 46-Wright, Hank, Western Oil &-Gas Association, Los Angeles, CA 10 -n4- XVII. BIBLIOGRAPHY 1. Arthur 0. Little Inc., Union Oil Project/Exxon Project Shamrock and Central Santa Maria Basin Area Study EIS/EIR, Final Report Vols. I & 11, June 24, 1985 2. Arthur 0. Little Inc., Exxon Santa Ynez Unit Project Final Supplemental EIR, August 6, 1986 3. Arthur D. Little, Exxon Lompoc Pipeline Project Supplemental EIR, Vol. I, Public Draft, February-3, 1986 4. California Coastal Commission, Coastal Energy Development: The Cal ifornia Experience, September, 1981 5. California Department of Conservation, Division of Oil and Gas, 73rd Annual Report of the State Oil and Gas Supervisor 1987, 1988 6. California Department of Conservation, Division of Oil and Gas, 1987 California Oil And Gas Production Statistics And New Well Operations Preliminary Report, January 1988 7. California Energy Commission Fossil Fuels Assessments Office, Annual Petroleum Review, June 1984 8. California Energy Commission, quarterly Oil Report, Fourth Quarter 1986, March 1987, Vol. VI, No. 3 9. California Coastal Commission, Staff Reports on Lease Sale 91 and Proposed Five-Year Oil and Gas Lease Program, April 10, 1986 10. Centaur Associates Inc., Prepared for Minerals Management Service, Facilities Related to Outer Continental Shelf Oil and Gas Development Offshore California: A Factbook, October 1985 11. Chambers Group Inc., Draft And Finalizing Addendum ARCO Coal Oil Point Project EIR/EIS, Vol I & II, Inc. September 1986 12. Charter Publications Limited, Los Angeles, Worldport Shipping LA Handbook.- 1986, September-1985- 13. County of Santa Barbara, Resource Management Department, Energy Division, Offshore Oil and Gas, May, 1988 14. Department of Conservation, Division of Oil and Gas, 1987 California Oil and Gas Production Statistics and New Well Operations, Preliminary Report, January 1988 15. ERT, Proposed Getty Gaviota Consolidated Coastal Facility at Gaviota. California Final EIR, February 1985 -115- 16. Letter from Mr. Thomas L. Dunaway of the Minerals Management Service to Mr. Doug Anthony, County of Santa Barbara Energy Division, July 15, 1988 17. Letter from Mr. Thoma .s L. Dunaway of the Minerals Management Service to Ms. Susan Hansch,-California Coastal Commission, April 15, 1988 18. Letter from Mr. Thomas L. Dunaway of the Minerals Management Service to Mr. John Von Reis, San Luis Obispo County, October 29, 1985 19. Letter from Mr. Sid Robinson of the Port of Los Angeles to Ms. Billie C. Blanchard, California Coastal Commission, April 4, 1988 20. Mead, Walter, Asbjorn Moseidjord, and Dennis Muraoka. Alternative Bid Variables as Instruments of OCS Leasing Policy, Contemporary Policy Issues, No. 5, March 1984 21. Memorandum from Mr. A.D. Willard'of State Lands to D.J. Everitts, State Lands Commission, October 2, 1985 22. OCS Project Task Force, Office of Planning and Research Prepared for California Coastal Commission, Offshore Oil and Gas Development: Southern California, October 1977. Vols. I & II 23. Port of Long Beach, Harbor Handbook, 1986 24. Southern California Association of Governments Focus on Oil SCAG's Offshore Oil Bulletin, Vol. 5, March/April 1986 25. Unocal, Draft Development Plan, Point Conception - Cojo Project State Lease 2879.1 Parcel 6, Vo. 1, October, 1984 26. URS Company, San Niguel Project and Northern Santa Maria Basin Area Study Draft EIS/EIR, Volume 1, Part 1 and 2, December 27, 1985 27. U. S. Department of Interior, Minerals Management Serv ice, Mineral Revenues, The 1987 Report on Receipts from Federal and Indian Leases, 1988 @28. U.S. Department of Interior, Minerals Management Service, Oil and Gas Leasing/Production Program: Annual Report/FY 1987, March 31, 1988. 29. U.S. Department of Interior, Minerals Management Service, Status of Leases, August 1988 30. U.S. Department of Interior, Minerals Management Service, Status of Leases Maps, August 1988 31. U.S. Department of Interior/Minerals Management Service, Pacific Summary Report, April 1985 32. U.S. Department of Interior/Minerals Management Service, Pacific Summary Report/Index, June 1986 - July 1987 33. U.S. Department of Interior, Minerals Management Service, Technical Announcement POCSR-7, November 2, 1987 34.-Westec Services Inc. Hercules Development Project, Vol.2, Development Plan, June 1985 -116- Appendix I UNDEVELOPED CALIFORNIA OCS, ACTIVE LEASES AS OF DECEMBER 1988 Active Lease Lease Principal Lease No. (Undeveloped) Sale Holder(s) Unit Name(s) 1. P-0181 P4 Exxon Santa Ynez 2. P-0182 P4 Chevron Santa Ynez Exxon 3. P-0183 P4 Exxon Santa Ynez 4. P-0184 P4 Exxon Santa Ynez 5. P-0185 P4 Shell Santa Ynez 6. P-0187 P4 Exxon Santa Ynez .7. P-0189 P4 Chevron Santa Ynez Exxon 8. P-0191 P4 Exxon Santa Ynez 10 9. P-0192 P4 Chevron Santa Ynez Exxon 10. P-0193 P4 Chevron Santa Ynez Exxon 11. P-0194 P4 Chevron Santa Ynez Exxon 12. P-0195 P4 Chevron Santa Ynez Exxon 13. 0-0196 P4 Chevron Santa Ynez' 14. P-0197 P4 Chevron Santa Ynez Exxon 15. P-0203 P4 Union 16. P-0204 P4 Chevron Santa Clara Exxon 17. P-0208 P4 Chevron Santa Clara Exxon Active Lease Lease Principal Lease NO- (Undevelopedl Sale Holder(s) Unit Name(s) P-0209 P4, Chevron Santa Clara Exxon 19. P-0210 P4 Chevron Santa Clara 20. P-0215 P4 Chevron Santa Clara ARCO 21. P-0231 P4 Exxon Santa Rosa 22. P-0232 P4 Exxon Santa Rosa 23. P-0233 P4 Union Pitas Point Texaco 24. P-0238 P4 Exxon Santa Rosa Chevron 25.' P-0306 035 Beta .26. P-0317 048 Phillips Rocky Point Chevron 27. P-0318 048 Phillips Rocky Point Chevron 28. P-0319 048 Conoco Sword 29. P-0320 048 Conoco Sword 30. P-0321 048 Mobil. Castle Rock 31. P-0322 048 Conoco Sword 32. P-0323 048 Conoco Sword 33. P-0324 048 Phillips Castle Rock Chevron 34. P-0326 048 Chevron Santa Ynez 35. P-0329 048 Exxon Santa Ynez 36. P-0373 053 Maxus 37. P-0374 053 Phillips Active Lease Lease Principal Lease. No. (Undeveloped) Sale Holder(s) Unit Name(s) 38. P-0375 053 Phillips 39. P-0376 053 Phillips 40. P-0377 053 Phillips 41. P-0396 053 Chevron Lion Rock Shell 42. P-0397 053 Chevron Lion Rock Shell 43. P-0402 053 Chevron Lion Rock Shell 44. P-0403 053 Chevron Lion Rock Shell 45. P-0408 053 Chevron Lion Rock Shell 46. P-0414 053 Chevron Lion Rock 47. P-0415 053 Ch evron Point Sal 48. P-0416 053 Shell Point Sal 49. P-0420 053 Shell Santa Maria 50. P-0421 053 Shell Point Sal 51. P-0422 053 Shell Point Sal 52. P-0424 053 Shell Santa Maria 53. P-0425 053 Shell Santa Maria 54. P-0426 053 Chevron Purisima Point 55. P-0427 053 Shell Purisima Point 56. P-0429 053 Samedan Oil Santa Maria 57. P-0430 053 Phillips Santa Maria Elf Aquitaine 58. P-0431 053 Shell Santa Maria 59, P-0432 053 Shell Purisima Point 60. P-0433 053 Samedan Oil Santa Maria -119- Active Lease Lease Principal Lease No. (Undeveloped) Sale Holder(s) Unit Name(s). 40 61. P-0434 .053 Shell Santa Maria 62. P-0435 0-53 Union Shell 63. P-0437 053 ARCO Point'Pedernales 64. P-0438 053 Exxon Point Pedernales 65. P-0443 053 Phillips Bonito Chevron 66. P-0444 053, ARCO Point Pedernales 67. P-0445 053 Phillips Bonito Chevron 68. P-0446 053 Phillips Bonito Chevron 69. P-0447 053 Phillips Rocky Point Chevron 70. P-0448 053 Phillips Rocky Point Chevron 71. P-0449 053 Sun Bonito 72. P-0451 053 Phillips Rocky Point Chevron 73. P-0452 053 Phillips Rocky Point Chevron 74. P-0453 053 Phillips Rocky Point Chevron 75. P-0459 068 Phillips Chevron 76. P-0460 068 ARCO Gato Canyon 77. P-0461 068 Exxon Santa Ynez 78. P-0462 068 Samedan Oil Gato Canyon 79. P-0464 068 ARCO Gato Canyon 80. P-0467 068 BP Alaska Santa Rosa -120- Active Lease Lease Principal Lease No. (Undeveloped) Sale Holder(s) Unit-Name (s) 81. P-0469 068. ARCO: Smuggler's Cove 82. P-0472 068 Amber Resources Anacapa 83. P-0473 068- Chevron Anacapa 84. P-0474 068 Chevron Anacapa 85. P-0475 068 ARCO Smuggler's Cove 86. P-0478 068 Chevron Anacapa 87.- P- 0479 068 Texaco 88. P-0489 068 Amoco 89. P-0490 068 Amoco go. P-0499 RS2 Phillips Bonito Chevron 91. P-0500 RS2 Phillips Bonito Chevron 92. P-0504 073 ARCO 93. P-0505 073 Chevron 94. P-0506 073 Exxon 95. P-0510 073 Chevron Point Pedernales 96. P-0511 080 Texaco 97. P-0512 080 BP Alaska 98. P-0514 080 Texaco 99. P-0515 080 Union Texaco 100. P-0516 080 Texaco 101. P-0517 080 Texaco BP Alaska 102. P-0520 080 Conoco -121- Active Lease Lease Principal Lease No. (Undeveloped)- Sale Holder(s) Unit Name(s) 103. P-0521 080 Conoco 104. P-0522 080 Conoco Smuggler's Cove 105. P-0523 080 B-P Alaska ----- 106. P-0524 080 BP Alaska ----- 107. P-0525 080 Chevron Anacapa 108. P-0527 080 Chevron 109. P-0528 080 Exxon 110. P-0529 080 Exxon ill. P-0530 080 Exxon 112. P-0533 080 Chevron 113.1 P-0534 080 Chevron 114. P-0535 080 Chevron I d I I I I I I I I I I I I I I I of 1 3 6668 14101 0340 1