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Coastal Zone Information Center PB 238 784 APR 2 6 1976 ENVIRONMENTAL IMPACTS, EFFICIENCY, AND COST OF ENERGY SUPPLY AND END USE V0LUME 6l HITTMAN ASSOCIATES, INCORPORATED NOVEMBER 1974 DISTRIBUTED BY: HD 9502 National Technical Information Service U52 U. S. DEPARTMENT OF COMMERCE E58 1974 A KEEP UP TO DATE between the time you ordered this report- searc activities. And you'll get this impor- which is only one of the hundreds of thou- tant information within two weeks of the time sands in the NTIS information collection avail- it's released by originating agencies. able to you and the time you are reading this message, several new reports relevant to WGA newsletters are computer produced your interests probably have entered the col- and electronically photocomposed to slash the time gap between the release of a report lection. and its availability. 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This information product distributed by U.S. DEPARTMENT OF COMMERCE NTIS National Technical Information Service 5285 Port Royal Road Springfield, Virginia 22161 DEPARTMENT OF COMMERCE U.S. D Nation Ia[ Technical Information Service 5285 Port Royal Road Springfield, Virginia 22161 BIBLIOGRAPHIC DATA 1. Report No. SHEET PB 238 784 4. Title and Subtitle 5. Report Date November 1974 Environmental Impacts, Efficiency, and Cost of Energy Supply and End Use Volume 1 6. 7. 8. Performing Organization Reps. No. HIT-593 9. Performing Organization Name and Address 10. Project/Task/Work Unit No. Hittman Associates, Inc. 11. Contract/Grant No. Columbia, Md. EQC 308 12. Sponsoring Organization Name and Address 13. Type of Report & Period Council on Environmental Quality, 722 Jackson Pl. Covered N.W., D.C. 20006; National Science Foundation, 1800 final G St. N.W., D.C. 20550; Environmental Protection 14. Agency 401 M St. S.W., D.C. 20460 15. Supplementary Notes Vol.. II to be released at a later date. 16. AbstractsThe purpose of this study was to determine the environmental im- acts, efficiency, and costs associated with supply and end use of fossil uels. The output is this 2-volume report, which presents tabular, foot- noted, and referenced data quantifying the energy-related environmental im- Pacts on land, water, air, solid waste, and occupational health. All the information is also available in the form of a computerized data base, atrix of Environmental Residuals for Energy Systems. Brookhaven created he data base and has written a number of data management and energy odeling programs, which with MERES are known as the Energy Model and Data ase. Volume II characterizes six technologies with respect to their nvironmental impacts, efficiency, and cost. 17. Key Words and Document Analysis. 17a. Descriptors Energy. Energy systems. Energy model. MERES. Data base. Environmental impacts. Air and water pollution. Solid waste. Land disruption. occupa- tional health. Fossil fuels. Coal. Oil. Natural gas. Fuel supplies. End use. Efficiency. Costs. 17b. Identifiers/Open-Ended Terms PRICES SUBJECT TO CHANGE Reproduced by NATIONAL TECHNICAL INFORMATION SERVICE US Department of Commerce Springfield, VA. 22151 17c. COSATI Field/Group 18. Availability Statement 19.. Security Class (This 121. -No. of Pages NTIS Report) 20. Security Class (This Page UNCLASSIFIED 20. Se (This Page UNCLASSIFIED ENVIRONMENTAL IMPACTS, EFFICIENCY, AND COST OF ENERGY SUPPLY AND END USE VOLUME I FINAL REPORT HIT-593 November 1974 Work Sponsored by The Council on Environmental Quality, RANN Program of The National Science Foundation, and The Environmental Protection Agency Contract EQC 308 HITTMAN ASSOCIATES, INC. COLUMBIA, MARYLAND 1a LEGAL NOTICE "This report was prepared as an account of work sponsored by the United States Government. Neither the United States nor the Council on Environmental Quality, nor any of their employyes, nor any of their contractors, subcontractors, or their employees, makes an warranty, expressed of implied, or assumes any legal liability or responsibility for the accuracy, completeness or usefulness of any information, apparatus, product or process disclosed, or represents that its use would not infringe pri- vately-owned rights." ii FORL. @-IORD The efforts represented by this two volume final report were begun in December 1972. A draft version of Volume I was issued September 1973 and the various sections of Volume II published in*draft form between February and June 1974. Ex- tensive revisions to the draft versions of this work have resulted in a two volume final report. Impetus for the program was recognition of a-need for an organized approach to the environmental impacts caused by energy supply and use. This study, building upon..earlier work completed by the Council on Environmental Quality, provides a systematic technique for identifying environmental tradeoffs and problems associated with current energy scenarios.@ By offering an organized and consistent approach to environmental impacts, this report can lend a quantitative sophistication to policy discussion. This study was directed by 1K. Robert Menchen. Technical contributorsare as follows: David F. Becker Dr. Henry M. Curran Barry K. Hinkle Jay J. Hoenig William C. Koffke Judith H. Marcus W. Robert Menchen .Terry N. Oda James E. Reed Steven A. Rothenberg Robert E. Smalley This work has been sponsored by the Council on Environmental :,Quality, The Environmental Protection Agency, and the RANN Pro- qram, of the National Science Foundation. The Atomic Energy Commission has contributed through support of the energy modeling efforts at Brookhaven National Laboratory (BNL). The data contained in this volume are being placed in a computerized information retrieval system at BNL, and computer programs are being written which will allow rapid analysis of the environ- mental effects of energy systems. Contract monitoring and all technical coordination has been throughthe Council on Environmental Quality. We wish to thank Dr. Steve Rattien, Dr. Stephen Gage, and Mr. Marvin Singer of that office for their continued assistance and support in this effort. Their suggestions over the course of the program have created a more useful product. TABLE OF CONTENTS-VOLUME I Page LEGAL NOTICE ii FOREWORD iii TABLE OF CONTENTS-VOLUME I iv TABLE OF CONTENTS-VOLUE II vi LIST OF FIGURES viii LIST OF TABLES ix I. INTRODUCTION AND SUMMARY I-1 II. DATA BASE DESCRIPTION II-1 A. Nomenclature II-1 B. Format II-3 C. Energy Supply II-8 D. Energy End Use II-17 E. Energy Model and Data Base (EMDB) II-18 III. COAL SUPPLY III-1 A. Introduction III-1 B. Impact Data Tables and Footnotes III-4A IV. OIL SUPPLY IV-1 A. Introduction IV-4 B. Impact Data Tables and Footnotes IV-4 V. NATURA GAS SUPPLY V-1 A. Introduction V-1 B. Impact Data Table and Footnotes V-3 iv VI. POWER PLANT CONVERSION ACTIVITY OF FUEL SUPPLY VI-1 A. Introduction VI-1 B. Impact Data Table and Footnotes VI-2 VII. RESIDENTIAL END USE VII-1 A. Introduction VII-1 B. Impact Data Table and Footnotes VII-2 VIII. COMMERCIAL END USE VIII-1 A. Introduction VIII-1 B. Impact Data Table and Footnotes VIII-2 IX. INDUSTRIAL END USE IX-1 A. Introduction IX-1 B. Impact Data Tables and Footnotes IX-4 X. TRANSPORTATION END USE X-1 A. Introduction X-1 B. Impact Data Table Footnotes X-3 XI. REFERENCES XI-1 APPENDIX A - LIST OF ABBREVIATIONS v TABLE OF CONTENTS-VOLUME II Page LEGAL NOTICE ii FOREWARD iii TABLE OF CONTENTS-VOLUME II iv TABLE OF CONTENTS-VOLUME I vi LIST OF FIGURES viii LIST OF TABLES x I. INTRODUCTION AND SUMMARY I-1 II. DATA BASE DESCRIPTION II-1 A. Nomenclature II-1 B. Format II-3 C. Energy Supply II-8 D. Energy Model and Data Bank (EMDB) II-17 III. LOW BTU GASIFICATION OF COAL III-1 A. Introduction III-1 B. Impact Data Tables and Footnotes III-9 IV. HIGH BTU GASIFICATION OF COAL IV-1 A. Introduction IV-1 B. Impact Data Table and Footnotes IV-11 V. OIL SHALE V-1 A. Introduction V-1 B. Impact Data Table and Footnotes V-6 vi VI. FLUIDIZED BED BOILER COMBUSTION VI-1 A. Introduction VI-1 B. Impact Data Table and Footnotes VI-5 VII. SOLVENT REFINED COAL VII-1 A. Introduction VII-1 B. Impact Data Table and Footnotes VII-3 VIII. COAL LIQUEFACTION VIII-1 A. Introduction VIII-1 B. Impact Data Table and Footnotes VIII-5 IX. REFERENCES IX-1 APPENDIX A - LIST OF ABBREVIATIONS vii vii LIST OF FIGURES Page 1 Description of Phase I Study 1-3 2 Task 3 Regional Studies 1-4 3 Phase II Study Description 1-5 4 Hardness Number Definitions 11-5 5 Numbering.Classification for Footnotes and References 11-6 6 Uncontrolled Incremental Land Impact 11-12. 7 Controlled Incremental Land Impact 11-12 8 Data Access Code for Suppiy 11-'20 9 Data Access Code for Utilization (End Use) 11-21 10 National and Regional C oal Analyses III-lA 11 National Average Refinery IV-2 12 National and Regional Crude Oil Analyses IV-3A 13 Basis For Industrial End-Use Emission Data. IX-3 viii LIST OF TABLES Page 1. Environmental Impacts, Efficiency and 111-5 Cost for Uncontrolled National Coal Supply 2. Environmental.,Impacts, Efficiency and 111-35 cost for Controlled National Coal Supply 3. Environmental Impacts and Efficiency for 111-51 the Uncontrolled Northwest Region of Coal Supply 4. Environmental Impacts and Efficiency for 111-59 the Controlled Northwest Region of Coal Supply 5. Environmental Impacts and Efficiency for 111-63 the Uncontrolled Central Region of Coal Supply 6.1'. 'Environmental Impacts and Efficiency for 111-75 the Controlled Central Region of Coal supply 7. Environmental Impacts and Efficiency for M-81 Uncontrolled Northern Appalachia Region of Coal Supply 8. Environemental Impacts and Efficiency for 1 11-95 the Controlled Northern Appalachia Region of Coal Supply 9. Environmental Impacts and Efficiency for 111-103 the Uncontrolled Central Appalachia Region of Coal Supply 10. Environmental Impacts and Efficiency for the III-i13 Controlled Central Appalachia Region of Coal Supply 11. Environmental Impacts and Efficiency for the 111-119 Uncontrolled Southwest Region of Coal Supply. 12. Environmental Impacts and Efficiency for the 111-125 Controlled Southwest Region of Coal Supply 13. Environmenta '1 Impacts, Efficiency, And Cost IV-5 for Uncontrolled National Oil Supply ix Page 14. En,%,rironmental Impact.s, Efficiency, and IV-31 C03t for Controlled National Oil Supply 15. Environmental Impacts and Efficiency fo:.- the Uncontrolled Domestic On-Shore Region of Oil Supply 16. Environmental Impacts and Efficiency for IV-4 9 the Controlled Domestic On-Shore Region of Oil supply 17. En,-Aronmental Impacts and Efficiency for IV-53 the Uncontrolled Domestic Off-Shore Region of Oil supply 18. Environmental Impacts and Efficiency for the iv-5 7 Controlled Domestic Off-Shore Region of O:il Supply 19. Environmental Impacts and Efficiency for the IV-61 Uncontrolled Imported Canadian Crude Region of' Oil Supply 20. Environmental Impacts and Efficiency for the; IV-65 Controlled Imported Canadian Crude Region of Oil Supply 21. Environmental Impacts and Efficien.c for@ the IV-65 y Uncontrolled Imported Middle East Crude Region of Oil Supply 22. Environmental Impacts and Efficiency for the IV-7 3 qontrolled Imported Middle East Crude Region of' Oil Supply 23. Environmental Impacts and Efficiency,for iv-77 the Uncontrolled South American Residual Region of Oil Supply 24. Environmental Impacts and Efficiency for, IV__8l the Controlled.South American Residual Region of Oil Supply 25. Environmental Impacts, Efficiency and.Cozt V-5 for Uncontrolled and Controlled Natural Gas Supply 26. Environmental Impacts, Efficiency and.Cost V1-3 for the Electric Power.Activity of Uncontrolled and Controlled Coal,. Oil Natural Gas and U-235 Supply x Page 27. Environmental Impacts and Efficiency of VII-3 Residential Energy Use 28. Environmental Impacts and Efficiency of VIII-3 Commercial Energy Use 29. Environmental Impacts and Efficiency of IX 5 Industrial Energy Use 30. Environmental Impacts and Efficiency x-5 of Transportation Energy Use xi I. INTRODUCTIC-4 AND SUMMARY This iskVolume I of a two volume report which describes the results of a study per 'formed by Hittman Associates, Inc.,(HAI), and sponsored by the Councilon Environmental Quality (CEQ), The Environmental Protection Agency, and The RANN Program of the National Science Foundation. The purpose of the-study was to determine the environmental impacts, efficiency, and costs ,associated with the supply and end use of fossil fuels. The study builds.upon preliminary work already completed by CEQ. The output of the study takes two forms. This report pre- sents tabular, footnoted, and referenced data quantifying the broad range of energy-related environmental impacts on land, water, air, solid waste, and occupational health., All of the information contained in this report is also available in the form of a computerized dat 'a base. This data base has been given the name MERES: Matrix of Environmental Residuals for Energy Systems. As part of an ongoing contract with the Atomic Energy Commission,,Brookhaven National Laboratory has created the data base, and also has written a number of data management and energy modeling programs. These programs, together with the MERES data, are known as the Energy Model and Data Base (EMDB). Environmental analyses of energy-related facilities have pre- viously been incomplete. Among other things, these analyses typi- cally considered only individual components, such as.an isolated power plant, refinery, etc., and not entire energy systems., The construction of a coal-fired power plant causes air, water solid waste,.a,nd land impacts not only at the immediate site of the power plant, but also at the site where the coal is mined, washed, processed or prepared, and along the route that the coal is transported. The entire sequence of activities, from the mining of the coal to the production of electricity, and its end use in some home appliance or industrial process,.is what is ..'referred to,as an energy system or "trajectory" and should be analyzed. Similar trajectories or energy supply "chains" exist for oil production and refining. The construction of a refinery causes air and water pollutants, solid waste, and land disruption. However, additional environmental effects are felt at the point of crude oil production, during the crude and product transpor'-. tat ion, and at the point of.marketing and end use. Using-, the data-bank, it is possible to aggregate the environ- mental impacts of a wide variety of fossil fuel,"trajectories" ..traced from the end use of a fuel to its@extraction or vice versa. This makes it possible to estimate environmental impacts for any number of scenarios related to energy consumption patterns en- visioned for the next 1,0 to 20 years. The objectives of the Phase I study reported in this volume are summarized.-in Figure 1. Tasks 1 and 2 are national in nature while Task 3-includes the impacts of regional energy supply sub- systems. In all cases, the data have been developed for coal, oil, and natural gas. A more detailed breakdown.of the reg Iions covered in Ta,sk 3 is provided by Figure 2. Thirty environmental impact tables.are contained in this report. Twelve of these are devoted to'coal supply, twelve to oil supply, one to natural gas supply, four to energy end uses, and one to the electric power plant activity of energy supply. Each entry in these tables is footnoted and referenced. The objective of the Phase II study reported in the com- panion Volume II, was to supplement the Pha.seJ activities with various emerging energy technologies. Six technologies, shown in Figure 3, were characterized with respect to their environ- mental impacts, efficiency, and cost. These technologies repre- sent.additional links in the supply and.end use chain of fossil fuels-and are a necessary component of future energy investiga- tions. It must be noted that the environmental impacts reported. herein only characterize the initial step in the environmental chain--that is, the amount of.effluent discharged from the boundary surrounding a particular process or end use. The inter- action of the outfall, air emission, land use, etc. with the biosphere is not included in this study. 1-2 TASK 1 EXTRACTION, PROCESSING, CONVERSION, AND DELIVERY OF FOSSIL FUEL ENERGY OBJECTIVE 1 DETERMINE PROCESS EFFICIENCIES FOR FOSSIL FUEL PRODUCTION AND DELIVERY OBJECTIVE 2 QUANTIFY ENVIRONMENTAL IMPACTS FOR EACH PRO- CESS, WITH PRESENT CONTROLS OBJECTIVE 3 DETERMINE IMPACTS WITH CONTROL TECHNOLOGY AVAILABLE AND LIKELY TO BE IMPLEMENTED OBJECTIVE 4 DETERMINE SYSTEM COSTS FOR UNCONTROLLED AND CONTROLLED ENERGY SUPPLY TASK 2 END USES OF ENERGY OBJECTIVE 1 DETERMINE ENERGY USE PER APPROPRIATE MEASURE OF USEFUL ACTIVITY OBJECTIVE 2 DETERMINE ENVIRONMENTAL IMPACTS OF END USES TASK 3 SENSITIVITY ANALYSIS OF TASK 1 DATA REGIONAL STUDIES (BOTH UNCONTROLLED AND CONTROLLED) Figure 1. Description of Phase I Study to 1-3 COAL o NORTHWEST (POWDER RIVER BASIN) MONTANA & WYOMING; AREA STRIP o SOUTHWEST (FOUR CORNERS AREA) NEW MEXICO; AREA STRIP o CENTRAL ILLINOIS & INDIANA; AREA STRIP; ROOM & PILLAR DEEP o NORTHERN APPALACHIA NORTHERN W. VA., CENTRAL & W. PA.; CONTOUR STRIP, ROOM & PILLAR DEEP, LONGWALL DEEP o CENTRAL APPALACHIA EASTERN KY., TENN., SOUTHERN W. VA.; STEEP SLOPE CONTOUR STRIP, ROOM & PILLAR DEEP OIL o DOMESTIC ON-SHORE o IMPORTED SOUTH AMERICAN RESIDUAL o IMPORTED MIDDLE EASTERN CRUDE o IMPORTED CANADIAN CRUDE o DOMESTIC OFF-SHORE NATURAL GAS o DOMESTIC ON-SHORE o DOMESTIC OFF-SHORE o IMPORTED CANADIAN Figure 2. Task 3 Regional Studies I-4 TASK 5 LOW BTU GASIFICATION OF COAL TASK 6 HIGH BTU GASIFICATION OF COAL TASK 7 OIL SHALE TASK 8 FLUIDIZED BED BOILER COMBUSTION TASK 9 SOLVENT REFINED. COAL TASK 10 COAL LIQUEFACTION Figure 3. Phase II Study Description 1-5 Ii. DATA Bi-,SE DESCRIPTION' A. Nomenclature In order to describe a scenario dealing with environmental effects of energy, a number of definitions have been adopted:* Term Example/Defin'ition Element S02 emission in transpor- tation of coal by unit train Process Coal transportation by unit train (a set of elements) Activity Coal transportation (com- bination of a set of pro- cesses) Trajectory Coal in the ground to steel production by electric fur- nace (the set of linked activities which connect the supply.of a specific resource with a specific end use) Subsystem Coal in the ground to any linked end use (a logical. collection of trajectories defining an aspect of the total energy system) System. Energy production and use in a given year (collection of all trajectories in the energy economy) These definitions are ide ical to those formulated by Brookhaven National Laboratory These definitions are further explained by the following diagram: TRAJECTORY Sequence of Activities Extraction Transportation Processing or Conversion End Use Storage Distribution -------------------- ----------------- -------- ACTIVITY An activity is one or more processes. One process could be distribution of coal by unit train. Several processes in series might be as shown below. Primary, Rough Sizing washing Coal Breaking Cleaning The Enviromental impacts to be identified and quantified are those which relate to water pollution,air pollution, genera- tion of solid wastes , use of land, occupational, health, and potential for large scale disaster. The water and air pollutants under consideration are the following: Water: Acids Bases Dissolved solids P04, N03 others Suspended solids Organics BOD COD Thermal 11-2 Air: particulates NO 80 Hydrocarbons CO Aldehydes,,, etc. Solid wastes@under consideration are all residuals not en.- tering the air or water that result from the basic fuel resources or from the system processes that make fuels useful for consump- tion, or from the end use of fuels. The land impacts include areas required for extraction, structures, disposal of solid wastes, roads, ports, pipelines, storage, and buffer zones. Both fixed and incremental land effects are considered. Fixed land effects are those associated with facilities such as processing plants, pipelines and storage tanks, whereas incremental land effects are those associated with excavation, suc h as strip mining, and solid waste disposal. Occupational health is considered on the basis of deaths, .injuries, and man-days lost due to injuries, in both the supply and end-use trajectories. All of the environmental impacts mentioned so far are quanti- fied and tabulated with suitable units. Further details are . given in the following. sections on .energy supply and energy end use. The potentia'l-for large scale disaster is identified with respect to the possible nature and magnitude of disasters and to specific processes in the supply and end-use trajectories. No quantifications are associated with these identifications. B. Format The construction of a computerized data bank requires that a large number of inputs be prepared according to a specific for- mat. From the standpoint of,this report, the reader need only be familiar with certain ground rules regarding data identifica- tion. The relationship between the format of data in this report and the-computerized.data bank is explained further-in Section E. 11-3 1. Impact Data and Data Hardnes Each entry of environmental impact data in the supply and end-use tables has three parts. This is illustrated below. 2.40-04 3 7019 footnote number data input hardness number data input to three significant figures 2.40-04 is equivalent to 2.40x10-4 or .000240. Unites of the data are at the top of the column in the table A data hardness number is required for each entry except those with 0998 and 0999 footnote designations. In the computerized data bank, it will be possible to search for hardness numbers in order to categorize the inaccuracy of data blocks. Hardness number definitions are given in Figure 4. As a general rule, it is usefule to consider data hardness in the context of "confidence" and relate this to the 1 to 5 scale. Footnotes and References use abbreviations where possible to facilitate loading of data into the computer data bank. Appenix A is a list of abbreviations and their definitions. When using exponential number such as 1.35x108, the designation within the footnote will be 1.35E+08, 1.35E08, or 1.35+08. 2. Footnotes and References Footnotes and references have been classified according to a numbering system which is shown in Figure 5. Note that specific blocksj of numbers have been allocated to the various pieces of data assembled. The number in Figure 5 indicate whic new foot- notes follow each individual table. These footnotes are related to the new information generated for the table in question. This will become apparent as the tables are used. The term "general reference" has been applied to any reference which is used in more than one area of the impact data (i.e., for both coal supply and oil supply, natural gas supply, and transportation end use, etc.). II-4 Hardness Definition Example 1 Very Good Highest confidence. Nationwide consump- Error probably -510 percent. tion based on Data well accepted and verified. accurate reporting technique. 2 Good - Reputable and accepted. Data from several Error probable 525 percent. major companies used to represent U.S. 3 Fair - Error probably :S50 Data from one com- percent. Validity may be un- pany used to certain due to method of com- represent U.S. bining or applying data. 4 Poor - Low confidence in data. Telecon estimate Error probably 100 percent. used in absence of validity questionable. measurement. 5 Very Poor - Validity of data Assumption based unknown. Error probably within on related refer- or around an order of magnitude. ence. Several Fair or Poor sources combined. Error levels cited refer to cases where the data are non- zero. For zero or "negligible" values, the definitions Good, Fair, etc. should be applied to the various hardness levels. Figure 4. Hardness Number Definitions 11-5 Table Footnote Reference No. Numbers Numbers General. References 0001-0042 Coal National Uncontrolled 1 1000-1099 1001-1080 1801-1827 C oal National Controlled 2 1100-1137 1100-1121 Coal Northwest Uncontrolled 3 1200-1229 1201-1218 1236-1237 Coal Northwest Controlled 4 1230@1235@ 1219-1222 ..Coal.Central Uncontrolled 5 1300-1.348 .-13,01 6 1350-136.4 Coal Central Controlled Coal. Northern,Appalachia. 7 14-00-14 52 Uncontrolled. Coal Northern Appalachia 8 14'55-1472 Controlled Coal Central Appalachia 9 1500-1519 Uncontrolled Coal Ce:.atral Appalachia -Io 1550-1562 Controlled Coal So'Ithwest Uncontrolled 11 1600-1622 Coal Southwest Controlled 12 1625-1629 Oil Nat:Lovl Uncontrolled 13 2001@:22.30999 Oil Mationail Controlled .1 210 0 .2 Oil Dome,stic On@Shore 15 2200-2201 2000-20 2 Uncon-,:rolled oil Domestic Off-Shore 17 2202-2203 Oil Domestic On-Shore Controlled 16 2300-2301 Uncontrolled oil Domestic Off-Shore controlled 18 2302-2130,5 Oil Imported Canadian .19 2204-2205 Uncontrolled@ 1, 1 @ 1 11 i Oil Imported Can-adian Controlled 20 2306-2309 Oil Imported Middle East 21 2206-2207 Uncontrolled Oil Imported Middle East 22 23.10-2313. Controlled- Oil S.A.: Residual,Uncontrolled 23 Oil S.A,,@ Residual Controlled 24 2314-2315 Natural,Gas.(all) 25 3000-3061 3000-3010 Electric: Power,&ctivity of Fuel 26 1900-1919 Supply--Coal Electric: Power Activity of Fuel 26 2901-2908 1900-1926 Supply--Oil Electric Power Activity of Fuel 26 390-1-3905 Supply--Gas Electric, Power Activity of Fuel 26 9600-9,619 960:1 0-9601. Supply.--Nuclear Re@side'ntial End, Use 27 5001-5035 5101-5118 Commercial 28 5501-5510 5501-5513 Industrial--Paper 29 6500-6506 6501-6504 industrial--Transportation 29 6701-6704 6701-6708 Industrial--Stone Clay Glass 29 6300-6333 6300-6319 industrial--Chemicals 29 6100-6134 6100-6118 Industrial--Food 29 6400-6415 6400-6418 Industrial--Primary Metals 29 6600-6611 6600-6606 6630-6638 6630-6632 Transportation 30 7001-7044 7001-7022 Figure 5. Numbering Classification for Footnotes and References 11-6 in addition to the footnot-@s which are printed text, three_ other designations are used in the tables. These are defined as follows: Footnote No. Definition 0907 Zero or negligible impact for this activity - an appropriate hardness value is required 0998 This impact not applicable to this activity 0999 This value not available - an impact for this activity is .assumed to exist To simplify the citation of references within footnotes, the following format has been used: Format for References in Footnotes: (30.04,739) Reference 3004, page 739 (3004,739,742) Reference 3004, pages 739,742 (3004,739/742) Reference 3004, pages.739 through 742, (5123,A-9), Reference 5123, page A-9 (5123,A-9,A-12) Reference 5123, pagesA-9, A-12 (5123PA-9/A-12) Reference 5123, page A-9 through A-12 Note that a reference citatiorx is always enclosed in parentheses. Footnotes which follow the tables appear in the exact form that a computer printout will yield. Each footnote indicates the references and other footnotes it is based upon. In this report some minor inconvenience derives from having to refer to a separate list of references located following all of the tables and footnotes. However, in the computerized data bank, footnotes could be printed out followed immediately by the applicable refer- ences and first order footnote referrals. 11-7 C. Energy Supply 1. Introduction The energy supply tables and footnotes deal with the quanti- fication of the environmental impacts of each process in the fossil fuel energy supply trajectories based on a process input of the fuel equivalent to 10 Btu/yr. The value of 10 Btu/yr was chosen as a convenient unit for an energy rate. The rate form was chosen to facilitate the use of published data on environ- mental impacts in which a time factor is involved, such as, for example, emission rates in lb/day for evaporation losses from gaslonie storage tanks, impacts related to annual production rates, etc. The fuels considered in the supply trajectories are the primary fossil fuels and their derivatives and modifications, as follows: Priamry: Coal, oil, natural gas Derived: Coke, gasoline, jet fuel, kerosene, distillate, residual, liquified petroleum gases (LPG) Modified for transmission: Liquified natural gas (LNG) The environmental impacts are developed initially on a national average basis, with regional effects added in subsequent tables. The categorization of regions is show in Figure 2. Twenty-five tables have been developed in the Energy Supply Sec- tion, representing various degrees of environmental control and region of interest. The order of presentation is coal, oil, and natural gas. Each of the tables is organized as a matrix with the environ- mental impacts as columns and activities and processes as rows. For each activity on the left of the table, the relevant processes are listed immediately below. In general, the entries in the tables are on a process basis, rather than on an activity basis. As noted earlier, an activity may consist of a single process, or it may consist of a number of processes. Each table has a related general footnote which gives basic data pertinent to the fuel considered, such as the amount of the fuel equivalent to 10 12 Btu. It is important to note that all impacts have been derived for a process input of fuel equivalent to 10 12 Btu/yr. In particular, for the extraction activity, this is interpreted to mean 10 12 Btu of resource in the ground. Thus impacts for the extraction activity are express per 10 12 Btu in the ground and not per 10 12 Btu produced or extracted (output of fuel). II-8 A general caution is appl@fzable to all the supply data. Before using any impactexpressed in terms of 1012 Btu, the reader should read the footnote* Potential misuses of the data can readily be cited. increasing the plant capacity'may not in- crease the land impact proportionately, since the land use is not necessarily linearly related to the productive capacity of the plant. Doubling the productive capacity doubles the land requirement only if an additional and identical facility*is con- structed. Caution must be exercised when evaluating the land effects for large multiples of 1012 Btu/yr. Similarly, size considerations are important in cost calculations and the foot- note will relate how the particular entry has been calculated. It is important to note the interrelationships between en- vironmental impacts, efficiency, and cost data. Strictly speaking, a specified level of environmental control has associated with it corresponding levels of cost and energy requirements., This is apparent in a comparison of the uncontrolled and controlled en- vironmental tables. However, this is also true within each supply table, as air pollutant data is related to ancillary fuel use, land use is related to solid waste data, etc. Air pollutants associated with the generation of electricity are ascribed to the power plant activity and not at the site of the process which uses the electricity as an-cillary fuel. 2. Definition of Uncontrolled and Controlled All supply tables are designated either controlled or un- controlled. "Uncontrolled," according to the ground rules adopted in this study, means that impacts are the current national or re- gional average value. In the absence of current.(1972-73) data, impacts typify the use of least stringent environmental controls. "Controlled" implies that impacts are consistent with the use of control technology.which will probably be required and/or available in 5 to 10 years. As an illustration, present laws governing the reclamation of surface mined lands minimally require that effort be made to restore the land. This may include pat- tial backfilling and an attempt at revegetation. However, since the degree and success of reclamation are not mandatory, (for the uncontrolled" condition) reclamation is not assumed for area stripping operations, and only partial backfilling is assumed for contour mines. In the controlled situation, contour backfilling and revegetation are required for either type of stripping operation. The attainment of this high level of reclamation would require such practices as stockpiling and redistribution of the topsoil, segregation of toxic overburden and seed bed.preparation. Generally speaking, the controlled condition incorporates the environmental standards proposed or soon to be implemented by the 11-9 Environmental Protection Agency. A more detailed explanation of controlled and uncontrolled as it is related specifically to each process in the fossil fuel chain is to be found in the writeup preceding each of the supply tables and in the accompany- ing table footnotes. 3. Environmental Parameters In the supply tables, the units for the various environmental impacts are noted abouve the colums. Since the basis for the tables is the fuel equivalent of 1012 Btu/yr, the actual units for the values give in the tables are interpreted as follows: Water Pollutants: Acids, bases, dissolved Tons discharged to water bodies/yr solids, suspended Fuel equivalent to 1012 Btu/yr solids, organics: =tons 1012 Btus BOD, COD: Oxygen demand in tons/yr Fuel equivalent to 1012 Btu/yr =tons 1012 Btu Thermal: Btu discharged to water bodies/yr Fuel equivalent to 1012 Btu/yr =Btu 1012 Btu Air Pollutants: Tons discharged to atmosphere/yr Fuel equivalent to 1012 Btu/yr = tons 1012 Btu Solid Waste: Tons placed on land/yr =tons Fuel equivalent to 1012 Btu/yr 1012 Btu II-10 occupational Health: Deaths: Deaths/yr Deaths 12 12 Fuel equivalent to 10 Btu/yr .10 Btu Injuries:. Serious:'injuries/yr Serious injuries 12 12 Fuel equivalent to 10 Btu/yr 10 Btu Man-days Man-days lost due to serious injuries/yr man-days lost lost:, Fuel equivalent to 10 12 Btu/yr 10 12 Btu Land: Fixed: Acres occupied by fixed facilities Acre-yr Fu'el.-"equivalent to 10 12 Btu/yr 10 12 Btu Incre- Time-averaged incremental acres Acre-yr 12 12 - mental: Fuel equivalent to 10 Btu/yr 10 Btu, The values for land disturbed shown in the tables:are, where applicable, the sum..of fixed and time averaged incremental land impacts. As an example, consider a coal processing plant which handles B Btu/yr Of coal, occupies.A acres, and produces solid waste for disposal occupying an additional a acres/yr. The fixed land impact is defined.as: A of acre-yr A f in units 12 10 Btu The incremental land, impact is defined as: a acre A; in units.0f, 10 12 Btu To sum these..land impacts it is first necessary to intro- duce the units of time, or time average the incremental laiid impact. Conceptually this represents the average acres of land which will be impacted over the lifetime of the plant. Numeri- cally,the time averaging process will depend on whether or not environmental controls, specifically reclawation of-the disturbed- land, will be-emRIO.Yed. Figures 6 and 7 illustrat6..the uncontrolled (i.e.., unreclaimed) and'controlled (reclaimed) environmental con- ditions as they 'pertain' to the time,averaging of, incrementalland n a B n a Uj 4a CC CA_ 3a 2a a c n A 1 2 3 4 V n-'1@ TIME-YEARS NOTES: 1 Pl ant ] i f eti me nyears inc4mental land i mp" a cii."i a d ry r 3 NO."reclamation of di, turt;id,land Figure 6. Uncontrolled Incremental,,,,Land@Impact B ,3a C Uj < 2a a A D n 1 2 3 4 TIME-YEARS NOTES: 1) Plant lifetime n:years 2) Incremental'land impact a acres/yr 3) Reclamation of disturbed land with .3 year time lag for revegetation '1@,.Figure 7. Controlled Incremental Land Impact n- 11-12 use. As shown in Figure 6, for the uncontrolled plant with an n year lifetime and an incremencal land impact of a acres/yr, the total amount of land disrupted after n years would be na acres since the land is not being reclaimed for use. The average land impact over the n year lifetime of the plant is given mathemati- cally by the area of triangle ABC divided by n years, i.e. 1/2 (n) (na) or (n) a. Hence, the time averaged incremental n 2 land impact for the uncontrolled case is defined as: A = n a in units of acre-yr it 2 B 1012 Btu Figure 7 shows the land impact for the same plant employing reclamation practices to recover the land distrupted by the solid waste. In this example three years was chosen as the time period necessary for reestablishing vegetation. Thus, assuming con- currentj reclamation, the land impact curve in Figure 7 levels off after the third year. That is, after the third year, the number of acres impacted remains constant. For each a acres distrupted in an year, an equivalent a acres has been reclaimed (starting three years before). The average land impact over the n year lifetime of the controlled plant would then be given mathematically by area ABCD divided by n years, i.e., (1/2 (3)3a) + (3a) (n-3) or (3-9)a. n 2n Hence the time averaged incremental land impact for the controlled case with a three year time lag for revegetation is defined as: A = (3-9)a in units of acre-yr. it 2n B 1012 Btu Note that the controlled definition given above is only applicable for those cases where three years is required for reestablishing vegetatioin. If this time lag changes, obviously so will the time averaging multiplier. Generally the plant lifetime (n) is taken as 25 years. Based on this value the time averaging multiplier for the uncotrolled case (n) would be 12.5 years, and for the 2 three year time lag controlled case (3-9), the multiplier would would be 2.82 years. 2n This time averaged incremental land impact calculation arbitrarily ignores any land impact which could occur beyond the specified lifetime of the facility. Continuing impact from yet unreclaimed land or the remaining structural facilities beyond the expected useful life (n) of those facilities is not considered. II-13 41.,@:: E'f1f i,clericy Th,,e,- ]BIttman, data.,,tables contain two eff icienby Telated inputs. Thes-e: are -,primary @e:ff iciency (colunm. 2.6@) and ancil 1Ar .y energy. (col umn 27) Eff icienc,y definitions can be related to the following -diagram: Ancillary,Energy 12 U(10 Btu 12 x (10, 'Btu of f ue 1 output 12 12 Input 10'. ztu@, of fuel Process Y (10 Btu consumed- -in -process, 1.2 z 0 Btu physical loss Where: X+y+1z Rrlmary@ Eftiziency = -x [email protected] Overall Zf f iciency = x-u (BNL) Overall Efficiency x :(,Theore,tical') 1+u X_U. for small u, i'.@e. U,<lcl 1+u Tf the' roces se U U everal ,p T2 parates the inp ' t f: el stream into s output fuels., may be taken as the sum of the -energy con- tent@s of -the@ @output fuels and x as an@approximate-value:for'the- ef f i.ciencT, of q-. each output fuel. In some.processes there is apt to be confusion as to whether art energy use is classified as ancillary or part of-the input,flow consumed. In a refinery, refinery gas (which provides ener y-for many processes) is considered@az Iprima .ry fuel consumed .9 . I,! rather' than at An ancillary demand. Any use of a' fuel ''derived V --f the primar flo' from -thb rimary, input stream remainspart.0 y W. 11-14 5. Costs 'Cost data expressed in 1972.dollars are included in the un- controlled and controlled national supply tables in columns 28-30. The total.capital or fixed cost for equipment, structures, etc. is annualized at 10 percent per year and shown in column 28. Yearly operating expenses for fuels, maintenance, labor, etc. are given in column 29, while column 30, which represents the total annual cost,, is thesum of columns 28 and 29. The units for the economic data are shown below: Fixed Cost: ($ of capital expense) x (.10/yr) $ 12 12 Fuel equivalent to 10 Btu/yr input 10 Btu Operating $/yr for operating expenses $ Cost Fuel equivalent to 10 12 Btu/yr input 10 12 Btu The 1.0 percent/yr annualization or "fixed charge rate" (as it is called in the table footnotes) for capital expenses was chosen mainly for convenience and may or may not reflect actual practice within a'particular industry. It is convenient to ex- press the capital cost data in this fashion because: 1) it pro- vides some estimate,.of total annual costs and 2) it allows a quick estimate of totai_@@capital cost from the table data by simply increasing the fixed cost by a factor of ten. That is, for a table fixed cost entry of 1.50+05, the total capital cost*is 1.50+06 or 1-1/2 million dollars/1012.Btu equivalent fuel input. The price ofthe raw energy resource into a process is not included in any of the cost data. The annual cost data repre- sented in.the tables is a major component of thelultimate price level of the fossil fuels delivered. Since the,basis for costs is 1972 dollars, table values would have to be adjusted to re- flect present-day (1974) costs. 11-15 6. Allocation of Table Entries to Process Fuels The following suggest a technique for allocating tabular impacts to the product fuel mix. A refinery of natural gas pro- cessing plant is used as an example. Oil refineries and natural gas processing plants separate input fuel streams into several output fuel streams. If the data are to be used to construct a trajectory for a particular product fuel, starting at the well head where such fuel does not exist as an entity, the table entries for the pro- cessing activity or for activities prior to processing may be used as reasonable approximations for such product fuel. II-16 D. Enercy End Use The end uses of energy have been broken down into the four usually reported categories; residential, commercial, industrial, and transportation. Alternative categorizations exist but these four are,convenient because they most often appear in the litera- ture. From a reporting viewpoint, the end use data format will, at first glance, appear similar to the supply sector. The major difference lies in the units of the data. Rather than air emissions being reported in tons/1012 Btu, a typical end use unit is tons emission/ton steel or tons emission/automobile-passenger- mile. This technique relates environmental impacts to the end use measure that seems most appropriate. The following definitions will help to clarify end use table differences from 'the format used for supply.. Measure: The unit appropriate for the end use at the (Col.27) lowest level of disaggregation. (Example: passenger-mile) Fuel: The fuel consumed at the end use. If a particular (Col.26) end use currently consumes.significant amounts of more than one type of fuel, then more than one line of data is required. (Example: Resi- dential space heating requires entries for distillate fuel oil, natural ga-s, and electricity) Energy: The Btu per unit measure required for each end (Col.28) use. (Example: Btu/ton-mile) .1 multi- The amount of each end use measure for domestic plier: energy consumption. This value is the most (Col.29) recent available, with the, year for each multi- plier given in Column 30. (Example: The multi- plier for piston engine powered general aviation aircraft is 2.4xlO7 hours in 1970) The product of the multiplier and the energy (Column 29 x Column 28) provides an actual yearly energy use.,expressed in Btuls. Projections in energy use can be made by varying the multiplier to correspond with the growth or decrease of a parti- cular end use with time. All end use impact data except the Industrial sector, correspond to a particular fuel. The specific fuel used is the link between the end use and supply portions of the.data bank. 11-17 The product of the multiplier and any one impact value pro- vides the environmental impact measured in tons of emission per year. All en use tables are "uncontrolled" in that the level of control of environmental impacts is representative of very recent or current practice. When using energy data where the fuel is indicated to be electricity, the energy (Column 28) is expressed in fossil fuel equivalent to electricity use. The Btu equivalent is measured at the input to the power palnt using a conversion factor of 10,239 Btu/Kw-hr. It is important to not this so that conver- sion losses are not double counted when complete trajectories are constructed. A quick review of the end use tables will establish that most of the environmental impact entries are for air emissions. Most other entries use a 0998 footnote meaning that the impact is not applicable to the particular end use. For the most part this non-applicability means that any environmental impacts which may occur are not energy related or no rational technique exists to distinguish what portion of the total impact is energy related. As an example fo this, consider the deaths due to the automobile. The primary purpose of the automobile is to transport people not to use energy. The number of deaths cannot be attributed fairly and directly to energy use in the samy way as can the air emissions from the engine. The general guideline used in the end use table preparations is that any impacts recorded must be clearly attributable to energy use. As with the supply tables, the user of Tables 27 through 30 must exercise caution in applying any value derived from a table. The user should first read the footnote to understand the context of the information. E. Energy Model and Data Base (EMDB) The data presented in this report have been entered in a computerized data base (MERES). Brookhaven National Laboratory has combined this data base with a number of data management and energy modeling programs to form a complete package known as the Energy Model and Data Base, Or EMDB. Brookhaven National Laboratory (BNL) will continue to update, maintain, and improve the database and its associated programs. II-18 The EMDB is presently available on the Control Data Corpora- tion computer facility at BNL. It will be directly accessible via a telephone connection and terminal to remote-users. In writing the computer programs for the EMDB, care has been taken to insure that the programs would be easily transferrable to other computer facilities. The basic unit of storage in the EMDB is a particular supply or utilization (end use) process, which corresponds to the com- plete set of numeric values contained in a single row of the tables in'this report. Each basic process storage unit contains all of the numeric values (and their hardness factors) as well as the full documentation for the number set. The specific pro- cess desired is identified by a string.of mnemonics whichhave different.forms for'supply and utilization processes. _2hese string forms are as follows: SUPPLY: /RESOURCE/ACTIVITY/PROCESS/REGION/CONTROL/.. UTILIZATION: /SECTOR/ACTIVITY/PROCESS/FUEL/CONTROL/. The.mnemonics for each supply activity and process can be found in the left-most column of each supply table (Tables 1-26). Likewise, the mnemonics for each utilization activity and process can be found in the left-most column of each utilization (end use) table (Tables 27-30). The accessing codes arefurther d.e- tailed in Figure 8 (supply), and Figure 9 (utilization). One of the programs associated with the EMDB permits the calculation of national energy flows and the impacts of such flows on resource consumption,, pollutant emissions, and dollar costs. This-program, called the Energy System Network.Simulator (ESNS), considers the energy system as a set of process links in a network:represen,tation. These network process links can be associated with particular process blocks (both supply and.utill- zation) in the EMDB. An interfacing program is provided which draws numeric.values from the data base and.makes@them available for flow calculation through the network. Capabilities are also ided for modifyi provi . ng any numeric value for input to the ESNS and for adding new links to the ESNS network. With these capabilities, the effects of various simulation scenarios can be calculated. 11-19 Order of mnemonic string identifier corresponding to-a supply table row: /RE,I;OURCE/ACTIVITY/PROCESS/REGION/CONTROL/. Identifier Mnemonic Resource: Coal COAL Oil OIL -Natural Gas GAS Act.,,vity: (See Supply Table) Proces,s: (See supply Table) Reg.Lon: National NATL Northwest NW Southwest SW Coal Central CNTRL Northern Appalachia NAPPL Central Appalachia CAPPL @Domestic Onshore ONSHR Domestic Offshore OFSHR Imported Middle East Crude MECRD Oil Imported Canadian Crude CANAD .Imported South American SARSD, Residual Onshore ON 'R Offshore OF:HR Gas .Canadian CANAD Control: Controlled 'CONTL Uncontrolled UNCON Figure 8. Data Access Code for Supply 11-20 Order of mnemonic string identifier corresponding to an end use table row: /SECTOR/ACTIVITY/PROCESS/FUEL/CONTROL/. Identifier mnemonic Sector: Residential RSDTL Commercial COMML Industrial INDST Transportation TRNSP Activity: (See End Use Table) Process: (See End Use Table) .,Fuel: Gasoline GASO Distillate DSTL Residual RESID Natural Gas GAS Coal COAL Electricity ELECT Petroleum Coke PCOKE Coke COKF Liquified Petroleum Gas LPG Asphalt ASPH Lubricant LUBE Jet JET Aggregate of all fuels AGGR Control: Controlled CONTL Uncontrolled UNCON Figure 9. Data Access Code for Utilization (End Use) 11-21 III. COAL SUPPLY A. Introduction The environmental impacts resulting from coal mining are quantified and based on an input of Btu/yr for each process in the supply chain. The impacts are determined on a national and regional basis, and for two conditions of environmental con- trol. It is recommended that the footnotes be read before using and interpreting the data presented. Potential misuses are easy to cite. As an example, the data presented in this report for auger mining considers steep slopes with no previous contour stripping. In reality, much of the auger mining follows contour stripping operations and would not produce all of the impacts given in the tables. Other obvious pitfalls are misinter- pretations of the data and drawing erroneous conclusions. Under- ground mining by the longwall method shows a much larger land impact due to subsidence than does mining by conventional or room and pillar methods. However, since subsidence will be more uniform for longwall mining, the land disruption may be less severe. No weighting factor was applied to the data to reflect this qualitative judgement. A comparison of uncontrolled and controlled coal supply tables indicates acid mine drainage and treatment for its elimination. However, only acid mine drainage from active coal mines was con- sidered in this analysis, and it would be incorrect to infer that all acid mine drainage will be eliminated by this treatment. At present, the major source of acid mine drainage is from inactive underground coal mines. The regional analyses cover five geographic areas: (1) Northwest-Powder River Basin, (2) Southwest-New Mexico and in particular the San Juan Basin, (3) Central-Illinois and Indiana, (4) Northern Appalachia-central and western Pennsyl- vania, Ohio and northern West Virginia, and (5) Central Appalachia-southern West Virginia, Virginia and eastern Kentucky. Each of these five regions is unique in terms of coal characteristics, mining techniques, reclamation problems, or a combination of these. Aside from the singular nature of these regions, they are also either the principal producers, or con- tain a significant percentage of the nation's coal reserves. Figure 10 summarizes coal properties used for the national and regional analyses. At the activity level, the supply chain for coal includes extraction, transportation, processing, distribution, storage, and coke conversion. A discussion of each of the activities and their subsequent processes follows. III-1 .,Order of mnemonic string identifier corresponding to an end use table row: /SECTOR/ACTIVITY/PROCESS/FUEL/CONTROL/. Identifier mnemonic sector: Resident'ial RSDTL Commercial COMML Industrial INDST Transportation TRNSP Activity: (See End Use Table) Process: (See End Use Table) Fuel: Gasoline GASO Distillate DSTL Residual RESID Natural Gas GAS Coal COAL Electricity ELECT -Petroleum.Coke PCOKE Coke COKE Liquified Petroleum Gas LPG Asphalt ASPH Lubricant LUBE-- Jet JET Aggregate of all fuels AGGR Control: Controlled CONTL Uncontrolled UNCON Figure 9. Data Access Code for Utilization (End Use) 11-21 III. COAL SUPPLY A., Introduction The environmental impacts resultin3 from coal minin g are quantified and based on an input of 101 Btu/yr for each process in the supply chain. Thle impacts are determined on a national and regional basis, and for two conditions of environmental con- trol. it is recommended that the footnotes be read before using and interpreting the data presented. Potential misuses a:r*e easy to cite. Asan example, the'data presented in thi.s report for auger mining ::onsiders steep slopes with no previous contour stripping. In reality,,, much of the auger mining follows contour stripping operations and would not produce all of the impacts given in the tabl-as. other obvious pitfalls are misinter- pretations of the data and drawing erroneous conclusions. Under- ground mining by the longwall method shows a much larger land. impact due to subsidence than does mining by conventional or room and pillar methods. However, since subsidence will be more uniform for longwall-mini-ig, the land disruption may be less.severe. No weighting factor -was applied to the data to reflect this-qualitative judgement. A comparison- of uncontrolled and controlled coal supply tables indicates acid mine drainage and treatment for its elimination. However, only acid mine drainage from active coal mines was con- sidered in this analys-is-, and it would e r-ncorrect to infer that all acid mine drainage will be eliminated by this treatment. At present, the rajor source of acid mine drainage is from inactive underground coa.1 mines. The regional analyses, cover five geographic areas- (1) Northwest- Powder River Basin, (2) Southwest - New Mexico and in particular the San Juan Basin, (3) Central - Illinois and Indiana, (4) Northern Appalachia - central and western Pennsyl- vania, Ohio and northern, West Virginia, and (5) Central Appalachia - southern West Virginia, Virginia and eastern Kentucky. Each of these five regions is unique in terms of coal characteristics,; mining techniques, reclamation problems, or a combination of these. Aside from the singular nature of these regions, they are also either the principal producers, or con- tain a significant percentage of the nation's coal reserves. Figure 10 summarizes coal properties used for the national and regional analyses. At the activity level, the supply chain for coal includes extraction, transportation, processing, distribution, storage, and coke conversion. A discussion of each of the-activities and their subsequent,processes follows. 0 N 12 Caloric 10 Btu Sulfur Ash Coal Ave. Coal Seam Content Eguivalent Content Content Densit@ Thickness T -B-Fu7 -1 b(Tons) M M (lb/cf) @(ft) Northwest' 8780 57000 0.85 6.77 81 39-Surf. Central 10600 47200 2.92 8.9 81 4.8-Surf. 6.8-Under. Northern Appalachia 42400 3.07 .14.7 85@ 3.9-Surf. 5.1-Under. Central Appalachia 12100 0..93 11.2 85 4.2-Surf 4.7-Under. Southwest 9820 51000 0.6 15.7 81 11.8-Surf. NationalAverage 12180, 41000 2.59 12.53 81 5.2-Surf. 5.1-Under. Figure 10. National and Regional Coal Analyses 1 Extraction At the process level, the extraction phase is categorized by the mining technique@s currently being employed. For under=- ground mining this includes room and pillar, and longwall mining. Surface mining covers both contour and area stripping. Augering.. another form of surface,mining,,is also included.. Due to a lack of environmental data, longwall.,stripping was.not,inve.st,igated. Presently,.a site in northern-West Virginia ,is being selected.for a demonstration project on lohgwall stripping-. All of the m::-ning methods listed above are analyzed on the national level.. For the regional analyses some of the methods are excluded because they either are not employed in the.specific', region, or production by the methods is relatively low. As an .illustration, only area stripping was inc-luded.for,-the.Nbrthwest. Stripping on'steeper slopes has been prohibited by legislation, thus eliminating contour-stripping and augering. Underground mining is not practiced'in the Powder River Bas-in. 2. Transportation The transportation.phase applies to the haulage of the.coal from the-working ::ace to the tipple. Three modes, of transport are studied: (1) trucking - primarily associated with surface. mines, (2) mine rail,s ('or cars),' and (3) conveyors.. As analyzed, the latter two modes of,'Itransportation are applicable to under- ground mines. Although:rails and conveyors are used at surface mines, the primary method for movement, of coal is by trucks. All modes of transportation are inves@igated on the national level, but only those applicable are included.,in the regional analyses. 3. Processing At the process level thisactivity is divided into three fundamental preparation plants: (1) breakingand sizing plant, (2) utility (ste Iam) coal plant, and (3) metallurgical coal plant. Coal that is mined clean (meeting market requirements) is generally just crushed and screened before shipping to the con- sumer. The breaking and sizing.,plant is the simplest of the three plants considered. No washing of the coal is performed. 111-2 The utility (steam) coal plant washes the raw coal to meet the specifications of the steam electric utilities market. The .,raw coal-.is'crushed to a 1.5 in. topsize and the coal greater, .,than,three-eighth in. in size is assumed to be washed in a dense medium bath at a specific gravity of separation of 1.6. The metallurgical coal plant is the most complex of the three plants analyzed, since the requirements for the coking industry-are the most stringent- less than two percent sulfurf eight percent ash and about eight percent moisture. The raw coal is crushed to a 1.5 in. topsize, and the coal.greater than three-eighth in. size is washed in a dense medium bath at a specific gravity of separation of 1.4. The intermediate size coal (three-eighth in. x 28 mesh size fraction) is processed in concentrating tables at a specific gravity of about 1.6. The coal fines (less than 28 mesh in size) are cleaned by froth flotation.. The intermediate and fine size coals are,then thermally dried prior to shipping. The unit processes,that make up the preparation plants are also considered in the national and regional "uncontrolled" analyses. They are disregarded in the "controlled" situation because the.environmental impacts do not change. Aside from the atmospheric discharges, the controls are applied at the Pend-of-pipe." Thus, the controls areapplicable to the plants, rather than the individual processes that comprise the plant. Since the primary focus of the regional analysis is on coals for the utility market, the metallurgical, coal plants were not considered for the regions. In those regions (central Appalachia, northwest and southwest) where the average run-of- mine coal is relatively clean, only the breaking and sizing'plant are included. It should be noted that coal preparationbeyond crushing and sizing is not foreseen. 4. Distribution This activity considers theshipment of-the coal from the mines or preparation plant to the point of consumption. The modes of transportation included are: (1) unit train, (2) mixed train (where the load of anyone train is not composed solely of coal), (3),trucking, (4) pipeline, and (5) conveyor. Again, as for all other activities, only the predominant modes of-transportation utilized in a specific region 'are con- sidered in the regional Analysis. The transport distances,a're adjusted to reflect the mileage from the minesto the major markets for each region. 111-3 5. Conversion This activity includes on coke production. Both slot and beehive ovens are considered. The "controlled" case analysis considers only slot ovens since environment controls on beehive ovens have received much less attention and are, at present, poorly defined. Coke production by beehive ovens is less than one percent of the total coke produced in this country. III-4 III-4 B. Impact Data Tables and Footnotes III-4A ""I A.- I A 4 6 1 No 22 24 21 IN 2. -11 - I - IWATER POLLUTANTS (YOMS/jOlA El COL-AII POLLUTANTS (700111-- STU) occUPTkAAAL MOCAm AT olDS", SA- ADDS ACTNMT1 PROCESS CID. 0. or& Law Poll No. or.. F-ws) SCA!" Tu -TICS No. SON IN ASTI. 2.1 l.-. NN IL ---vT .3 V-1 LL"A,@@ m-1 ------------- 7 7 Al ------ tam - ------ ---- -- --H 7. HN.- ---------- ANN HS 2', Ro ON; U. I AN AN, AN, -A- NN -L4 HM .. ....... 1'-*",- -24- 25. ANN, I-- 1 -11 Al 21, AMN ANN AN, Nll ANA 1-m -:2 NA NNA -4 -1 l..- . - .- 4 ANN Se THA 7 79- NN 1-1 l- ANN I !nt -.-.NN[.-"- A. .4 4S p AS @41 �1 4.1 48 52 NOTE: ALL TABLE ENTRIES ARE BASED ON 1012 BTU OF qEzOClkCE INTO EACH PROCESS OR ACTIVITY. TABLE 1. nVIRO,4N NTAL IMPACT&, OR SEE T007NDIE IDDO FOR NE45UR-- 'Q.Irn"T@ OF 1. NC NT BTU- U 0 ROLLED NATIONAL con OP`- -T -T-- ""'T AA FTN 1000-1003 FOOTNOTES FOR TABLE 1 1000 199 THE AVERAGE CALORIC CONTENT OF COAL DOMESTICALLY PRODUCED IN THE 299 UNITED STATES IN 1971 WAS 12,180 BTU/LB OF COAL (1004,9). 399 THUS, 1 OF 12 BTU OF ENERGY IS EQUIVALENT TO 41,000 T OF COAL 499 THE MEAN DENSITY OF COAL IS APPROXIMATELY 81 LB/CF (1050). THE 599 BASIS OF ALL COMPUTATION IS ON AN ENERGY INPUT OF 1.OE12 699 BTU. 799 1001 199 THE AVERAGE SEAM THICKNESS OF COAL SURFACE MINED IN THE UNITED 299 STATES IN 1965 (THE LATEST SUCH INFORMATION AVAILABLE) WAS 5.2 399 FT. (1017,6). 499 599 IT IS ASSUMED THAT SURFACE MINING ON SLOPES LESS THAN 15 699 DEGREES EMPLOYS THE AREA METHOD. THIS MAY NOT BE COMPLETELY 799 ACCURATE IN THAT CONTOUR MINING IS AT TIMES EMPLOYED ON SLOPES 899 AROUND 12 DEGREES. 999 1099 SINCE NOT ALL STATES, WHERE STRIP MINING IS PRACTICED, HAVE 1199 STRINGENT RECLAMATION LAWS, IT HAS BEEN ASSUMED THAT 1299 RECLAMATION IS NOT PRACTICED. 1399 1499 THUS, FOR A COAL DENSITY OF 81 LB/CF, 4.47 AC OF LAND IS 1599 OVERTURNED PER 1.OE12 BTU IN. THE AVERAGE LIFE OF A LARGE 1699 MINE IS APPROXIMATELY 25 YR WITH A PRODUCTIVE CAPACITY OF 1799 ABOUT 50 MMT (1018). HENCE, THE TIME AVERAGED LAND IMPACT 1899 IS 55.9 AC-YR/1.OEUI BTU IN. 1999 IN A PILE 30 FT HIGH, THE SOLID WASTE WILL OCCUPY .133 2099 AC-YR/1.OE12 BTU IN (FOOTNOTE 1009, SOLID WASTE PRODUC- 2199 TION). 2299 1002 199 OF THE TOTAL TONNAGE OF COAL SUBJECTED TO THERMAL, DRYING 67P IS 299 DRIES IN FLUIDIZED BEDS, 11P BY FLASH DRIERS, AND 22P BY 399 MULTILOUVER TYPE DRIERS (ASSUMING EMISSIONS ARE SIMILAR FOR 499 ALL OTHER EQUIPMENT NOT PREVIOUSLY ACCOUNTED FOR) (1004,46). 599 ASSUMING A CYCLONE WITH A 70P COLLECTION EFFICIENCY IS 699 UTILIZED, THE EMISSIONS ARE AS FOLLOWS (0002,8-10) 799 PARTICULATES, 899 T/1.0E12 BTU 999 FLUIDIZED BED 82.5 1099 MULTILOUVER 33.9 1199 FLASH 10.8 1299 1399 TOTAL 127.2 1499 1599 IT SHOULD BE NOTED THAT 70P, 30P, AND 4P OF THE COAL EXTRACTED 1699 BY UNDERGROUND TECHNIQUES, SURFACE MINING, AND AUERING, 1799 RESPECTIVELY, ARE SUBJECTED TO MECHANICAL CLEANING. AND OF THE 1899 TONNAGE CLEANED ABOUT 20P IS THERMALLY DRIES (1004, 47, 50). 1999 THE CRUSHING, SCREENING, OR SIZING OF COAL ARE MINOR SOURCES 2099 OF DUST EMISSIONS (0002). 2199 1003 199 AVERAGE HAULAGE DISTANCE FROM STRIP MINE TO TIPELE IS 5.3 MT (0001 299 ,344). THE TRUCK CAPACITY IS 100 T. THE FUEL CONSUMP 399 TION RATES IS ASSUMED TO BE 7 GAL/1000 TMI (0002,307). ASSUMING 499 A GROSS TO NET WEIGHT RATIO OF 2.5/1 FOR THE TRUCKS, THE TRIP 599 FROM MINE TO TIPPLE IS 875 TMI AND THE RETURN TRIP 355 TMI. 699 SINCE 410 TRIPS ARE REQUIRED TO HAUL THE 1.0E12 BUT EQUIVA- 799 LENT T, 3530 GAL OF DIESEL FUEL ARE CONSUMED. THE EMISSION 899 Preceding page blank FTN. 1004-1007 BREAKDOWN FOR A DIESEL POWERED TRUCK IS GIVEN IN (0002,3-7). 999 DUSTING FROM HAULAGE ROADS IS ASSUMED TO BE CONTROLLED BY 1099 WATERING DOWN THE ROADS. 1199 1299 NOTE: THE EMISSIONS ARE MAINLY ASSOCIATED WITH SURFACE AND 1399 AUGER MINES. IN THE CASE OF MOST UNDERGROUND MINES THE PREPAR- 1499 ATION PLANT (OR TIPPLE) IS LOCATED AT MINE-MOUTH AND HAULAGE 1599 DISTANCE IS MINIMAL. HAULAGE IS GENERALLY ACCOMPLISHED BY 1699 CONVEYORS OR RAIL CARS. 1799 1004 199 THE DATA FROM STUDIES CONDUCTED IN EASTERN KENTUCKY (1024,1031, 299 1032,1033,1034) INDICATED AN AVERAGE HAULAGE ROAD RIGHT-OF-WAY 399 OF 53 FT (6.4 KC/MI). THE MEAN DISTANCE FROM INE TO TIPPLE IS 499 5.3 MI (0001,334).HENCE, 33.9 AC OF LAND IS UTILIZED BY THE 599 ROADS. ASSUMING AN ANNUAL PRODUCTION FROM THE MINE OF 2 MMT 699 (FOOTNOTE 1022),2.05P FO THE HAULAGE ROAD USAGE IS ATTRIBUTED 799 TO THE TRANSPORT OF 1.0E12 BTU EQUIVALENT T. THE LAND IMPACT 899 IS THEREFORE 03712 AC-YR/1.0E12 BUT IN. 999 1005 199 IN GENERAL A UNIT TRAIN HAULS 10,000 T OF COAL PER TRIP (1005,33) 299 AND UTILIZED THE EQUIVALENT OF 4, 2400 HP DIESEL LOCOMOTIVES 399 (FROM DATA ON MATTHEWS MIN (1006)). 499 ENERGY CONSUMPTION BY FREIGHT TRAINS, ASSUMED TO APPLY AS 599 WELL TO UNIT TRAINS, IS 690 BUT/TMI (FOOTNOTE 7013), OR 699 0.005 GAL DIESEL FUEL/TMI (5.86E6 BUT/BBL, (0005,38). 799 AN ALL STEEL HOPPER CAR WITH A CAPACITY OF 70 T HAS A GROSS TO 899 TARE WEIGHT RATIO OF ABOUT 4/1 (0023,1136). IT IS ASSUMED THAT 999 THIS FIGURE HOLDS FOR 100 T CARS AND THAT THE FUEL CONSUMPTION 1099 PER TRAIN IS AS CITED ABOVE. FROM DATA IN (0021,31) THE ENERGY 1199 CONSUMPTION ASSUMES AN AVERAGE USAGE OF 3 LOCOMOTIVES PER 1299 TRAIN. 1399 THE AVERAGE HAULAGE DISTANCE IS 300 MI (1005,96). HENCE, FUEL 1499 CONSUMPTION IS 25,000 GAL PER ROUND TRIP OR 1.03E5 GAL/1.0E12 1599 BTU. THE EMISSION FACTORS ARE COMPUTED FROM (0002,307). 1699 WINDAGE LOSSES, ASSUMED TO BE AIRBORNE AS PARTICULATES, ARE 1799 ABOUT .04P OF THE TONNAGE HAULED (0002,7-4). SINCE THE LOSSES 1899 OCCUR MAINLY DURING HANDLING AT EITHER ENDPOINT, THEY ARE 1999 ESSENTIALLY INDEPENDENT OF THE HAULAGE DISTANCE. THUS, 16.4 2099 T OF COAL FINES ARE RELEASED AS PARTICULATES FOR EACH 2199 1.0E12 BUT HAULED. 2299 2399 NOTE: HAULAGE BY UNIT TRAIN ACCOUNTS FOR 22P OF THE TOTAL COAL 2499 MOVEMENT (1004,54). 2599 1006 199 THE AVERAGE CAPACITY OF A BARGE IS 25,000 T (1005,34) AND THE 299 AVERAGE HAULAGE DISTANCE IS ASSUMED TO BE 300 MI. THE EMISSION 399 IS CALCULATED FROM DATA ON MOTORSHIPS UNDERWAY IN (0002,3-11) 499 THE WINDAGE LOSSES, OCCURING MAINLY FROM HANDLING AT THE 599 ORIGIN AND TERMINAL POINTS, ARE ASSUMED TO BE .04P OF THE TOTAL 699 SHIPMENT AS IN THE CASE FOR UNIT TRAINS. THUS, 16.4 T OF COAL 799 FINES ARE EMITTED AS PARTICULATES (FOOTNOTE 1005). 899 999 NOTE TRANSPORT BY BARGE ACCOUNTS FOR 13P OF THE TOTAL COAL 1099 MOVEMENT (1004,53). 1199 1007 199 THE AVERAGE HAULAGE DISTANCE IS 300 MI (1005,96) AND FUEL CONSUMP- 299 TION IS AT A RATE OF .005 GAL/TM (FOOTNOTE 1005). ASSUMING 399 1000 T IS CARRIED PER TRIP AND ACCOUNTS FOR 20P OF THE TOTAL 499 TONNAGE OF ANY ONE SHIPMENT. A GROSS TO TARE WEIGHT RATIO OF 599 4/1, AND ONLY ONE WAY DIESEL FUEL CONSUMPTION ATTRIBUTED TO 699 FTN. 1008-1013 COAL, 81,000 GAL OF DIESEL FUEL IS CONSUMED TO TRANSPORT 799 I.OE12 BTU COAL. THE EMISSIONS ARE COMPUTED FROM INFORMA- 899 TION ON DIESELIOCOMOTIVES IN (0002,3-7).. THE WINDAGE LOSSES 999 ARE ASSUMED TO BE APPROXIMATELY .08P OF THE TOTAL SHIPMENT. 1099 HENCE, ABOUT 32.8 T IS RELEASED TO THE ATMOSPHERE AS PARTI- 1199 CULATES. 1299 1399 NOTE ---TRANSPORT BY MIXED TRAIN ACCOUNTS FOR 44 PC OF THE 1499 TOTAL COAL MOVEMENT (1004,53,54). .1599 1008 199 WHEN TRUCKS ARE UTILIZED IT IS USUALLY FOR SHORT HAULAGE DISTANCES 299 THAT AVERAGES ABOUT 10 MI (1013). ASSUMING AN AVERAGE TRUCK 399 CAPACITY OF 20 T, A GROSS TO NET WEIGHT RATIO OF 2.5/1, AND k 499 FUEL-CONSUMPTION RATE OF 7 GAL/1000 TMI, 6600 GAL OF FUEL IS 599 CONSUMED/1.OE12 BTU. THE EMISSIONS FROM A DIESEL ENGINE ARE 699 GIVEN IN (0002,3-7). IT IS ASSUMED THAT .04P OF THE TOTAL 799 SHIPMENT IS LOST DUE TO WINDAGE. THE AMOUNT RELEASED AS PAR- 899 TICULATES IS, THEREFORE, 16.4 TONS (SEE. ALSO FOOTNOTE 1005). 999 1099 NOTE HAULAGE BY TRUCK ACCOUNTS FOR 12P OF THE TOTAL COAL 1199 MOVEMENT (1004,53) 1299 1009 199 THE AVERAGE DEPTH OF OVERBURDEN OF COAL MINED IN 1965 WAS 48 FT 299 (1017). IN AREA SURFACE MINING ALL OF THE OVERBURDEN, EXCEPT 399 THAT WHICH IS REMOVED DURING THE BOX CUT, IS DEPOSITED IN 499 SPOIL BANKS IN THE EXCAVATED AREA. HENCE, THE SOIID WASTE IS 599 PRODUCED ONLY DURING THE INITIAL EXCAVATION. THE DENSITY OF 699 THE OVERBURDEN TS ABOUT 0.05 T/CF. ASSUMING THAT ON THE AVER- 799 AGE 5 AC (PIT SIZE OF ROUGHLY 100 FT BY 2000 FT: (1007)) ARF, 899 EXCAVATED FOR THE BOX CUT AND 50 MMT OF COAL ARE CONSEQUENTLY 999 EXTRACTED, SOLID WASTE P-RODUCTION OCCURS AT A RATE OF 0.0105 1099 T/T OF COAL OUT, OR 347 T/I.OE12 BTU IN. 1199 1010 199 THE PRODUCTION RATE FOR THE AUGERING OPERATION IS ASSUMED TO BE 299 655 T/SHIFT (1061,60,61, AND USING A 65P OPERATING FACTOR, 399 1061,51) AND FUEL CONSUMPTION AT 215 GAL/SHIFT. THUS, FOR THE 499 EXTRACTION OF 1.OE12 BTU EQUIVALENT T THE ENERGY CONSUMPTION 599 IS 1.87E9 BTU OR 8.63E8 BTU/1.OE12 BTU IN. 699 1011 199 THE OCCUPATIGNAL HEALTH STATISTICS FOR THE PREPARATION PLANT 299 COULD NOT BE DISAGGREGITED FOR THE INDIVIDUAL PROCESSES 399 WITHIN THE PLANT NOR COULD A DISTINCTION BE MADE FOR THE 499 DIFFERENT TYPES OF PLANTS. THE DATA REFLECTS AN AVERAGE FOR. 599 THE YEARS 1969 AND 197C (1070,1210). 699 1012 199 CONVEYER SYSTEMS ARE EITHER COVERED OR OPERATED AT SUCH A SPEED 299 THAT DUSTING DOES NOT OCCUR TO ANY GREAT EXTENT (10111. WHERE 399 DUSTING..DOES OCCUR, IT WILL BE CONFINED TO THE INMEDIIXTE AREA 499 AND SHOULD PRESENT NO PROBLEM. THE PROPORTION TRANSPORTED BY 599 THIS METHOD IS.VERY SMALL. THIS MODE OF TRANSPORT IS USUALLY 599 USED IN CONJUNCTION WITH ANOTHER MODE, E.G., TRAIN OR BARGE. 799 1013 199 THE DIESEL FUEL CONSUMPTION FOR A CONTOUR STRIPPING OPERATION IS 199 ESTIMATED TO BE 10600 GAL/1.OE12 BTU IN 399 (FOOTNOTE 1804). THE EMISSION FACTORS ARE 33-AINED FROM REF. 499 (0002,3-7) ASSUMING THE CHARACTERISTICS OF A DIESEL TRUCK 599 ENGINE 699 SINCE @O,ST OF THE COAL PRODUCTION OCCURS IN AREAS WHERE 799 ADEQUATE M 0ISTUPE IS AVAILABLE, FUGITIVE DUST IS NOT EXPECTED '899 TO BE A SERIOUS PROBLEM. -999 111-9 1014 199 EQUIPMENT USED IN UNDERGROUND MINES IS GENERALLY ELECTRICALLY 299 POWERED AND THUS, EMISSIONS ARE NOT ASSOCIATED WITH THESE 399 OPERATIONS. 499 1015 199 THE DIESEL FUEL CONSUMPTION FOR AN AUGERING OPERATION IS ESTIMATED 299 TO BE 6220 GAL/1.0E12 BTU IN (FOOTNOTE 1010). THE EMISSION 399 FACTORS ARE OBTAINED FROM REF. (0002,3-7) ASSUMING THE 499 CHARACTERISTICS OF A DIESEL TRUCK ENGINE. 599 1016 199 THE LAND USAGE BY DIESEL FRIEGHT TRUCKS IS 1.67E-6 AC/TMI (FOOT- 299 NOTE 7026). THUS, THE LAND IMPACT ATTRIBUTED TO THE HAULAGE 399 OF COAL BY TRUCK IS 1.58 AC-YR/1.0E12 BTU (FOOTNOTE 1008). 499 1017 199 THE ONLY PIPELINE IN OPERATION IN THE UNITED STATES IS IN ARIZONA. 299 THE TRANSPORT CAPACITY IS 4.8 MMT/YR AND SPANS A DISTANCE OF 399 273 MI (1015). ASSUMING A RIGHT-OF-WAY OF 62.5 FT, 2070 AC ARE 499 OCCUPIED FOR THE PIPELINE. HENCE, 18.2 AC ARE IMPACTED FOR 599 EACH 1.0E12 BTU. THERE ARE 4 PUMPING STATIONS EACH OCCUPY- 699 ING APPROXIMATELY 50 AC, INCLUSIVE OF STATION HOUSE, ACCESS 799 ROADWAYS AND STORAGE PONDS FOR WATER AND EMERGENCY SLURRY DUMP 899 (1040,153,158). THUS AN ADDITIONAL 1.71 AC-YR/1.OE12 BTU OF 999 LAND IS UTILIZED. 1099 NOTE: THE RIGHT-OF-WAY IS THE AVERAGE VALUE FOR OIL PIPELINES 1199 (2002,14). 1299 1018 199 IT IS ASSUMED THAT THE DRAINAGE FROM UNDERGROUND MINES IS THE 299 SAME REAGRDLESS OF THE METHOD UTILIZED. THIS IS NOT STRICTLY 399 TRUE. SINCE THE RATE OF SUBSIDENCE FOR LONGWALL MINING IS 499 GREATER, THE AMOUNT OF SEEPAGE (THROUGH FAULTS) INTO THE MINE 599 WILL TEND TO BE LARGER THEREBY LEADING TO INCREASED DRAINAGE. 699 BUT IT IS ALSO TRUE THAT THE DRAINAGE BETWEEN MINES, IRRESPEC- 799 TIVE OF THE MINING TECHNIQUE EMPLOYED, WILL VARY TO A DEGREE 899 THAT MAY EVEN BE GREATER. 999 1099 THE DRAINAGE FROM ACTIVE UNDERGROUND MINES OCCURS AT A RATE 1199 OF 1177 T OF ACIDITY PER DAY (1039,5,8) OR 0.0015 T/T OF COAL 1299 EXTRACTED (COAL PRODUCTION FROM (0001)) AND THE SULFATE LOAD- 1399 ING IS ABOUT TWICE AS MUCH AS THE ACID LOADING (1039). 1499 1599 THE CHEMICAL COMPOSITION OF THE DRAINAGE IS ESTIMATED FROM 1699 DATA FRO THE MONOGAHELA RIVER BASIN (1039,133/139 ALSO FOOT- 1799 NOT 1020). THE EFFLUENT DATA WERE ADJUSTED TO REFLECT ONLY 1899 CONTRIBUTIONS FROM ACTIVE UNDERGROUND MINING BY USE OF THE 1999 DATA IN (1039,6). THE EFFLUENT BREAKDOWN IS AS FOLLOWS: 2099 2199 2299 2399 2499 2599 2699 2799 2899 2999 3099 3199 THE DIFFERENCE IN QUANTITIES FOR THE DIFFERENT MINING TECH- 3299 NIQUES IS DUE TO THE DIFFERENCE IN REGIONS OF PRODUCTION AND 3399 III-10 FTN.'1019-1020 THE PRIMARY.-EFfICIENCIES. ACID DRAINAGE FROM DEEP MINES IS 3499 A PROBLEM.MAINLY.IN THE APPALACHIAN REGION. IN THE CENTRAL 3599 REGION (MIDWEST) THIS IS NOT A SERIOUS PROBLEM (1105). MOST 3699 OF THE MINES ARE LOCATED BELOW DRAFNAGE AND IN SOME CASES THE 3799 OVERBURDEN IS ALKALINE. THE OVERBURDEN IN MINES LOCATED IN 3899 THE WEST IS OF HIGH ALKALINE CONTENT, TltUS THE DRAINAGE TENDS 3999 TO BE BASIC. THE EFFLUENT FROM THESE MINES ARE MINIMAL (FOOT- 4099 NOTE 1020, VERY LITTLE UNDERGROUND MINING IS DONE I-N THE 4199 WEST). 4299 HENCE, IT HAS BEEN ASSUMED THAT ACID DRAINAGE OCCURS ONLY IN 4399 THE APPALACHIAN STATES (85P FOR ROOM ANDPILLAR MINES, AND 89P FOR LONGWALL MINES). 4599 THE SEDIMENT YIELD FROM THE REFUSE PILE OCCURS AT A RATE OF 4699 2.54 T/AC-YR-IN OF RUNOFF (COMPUTED FROM INFORMATION IN 4799 (1020)). THUS, ASSUMING AN AVERAGE RUNOFF OF 15 IN, THE SEDI- 4899 MENT LOAD 15 2.04E-2 T/I.OE12 BTU IN (FOOTNOTE 1022 FOR 4999 LAND IMPACTED BY THE SOLID WASTE) FOR ROOM AND PILLAR MINING 5099 AND 3.05E-2 T/1.OE12 BTU IN (FOOTNOTE 1036) FOR LONGWALL 5199 MINING.: 5299 1019 199 PRODUCTION FROM AUGER MINES IS PREDOMINANTLY (99P) FROM THE 299 APPALACHIAN REGION. THUS, DATA ON MINES IN APPALACHIA ARE 399 UTILIZED T(fDETERMINE THE EFFLUENT LOADING. 499 THE DRAINAGE FROM THE MINE IS ASSUMED TO BE THE SAME.AS FOR 599 CONTOUR,MINES (FOOTNOTE 1041). 699 THE SEDIMENT YIELD IS 2.54 T/AC-YR-IN. THUS FOR A RUNOFF OF 799 15 IN, THE SEDIMENT YIELD IS 674 T/1.OE12 BTU IN (FOOTNOTE 899 1026, LAND USE BY SPOIL PILE). 999 1020 199 Of THE TOTAL PRODUCTION OF COAL FROM SURFACE MINES, 92P WAS MINED 299 IN AREAS WHERE THE POTENTIAL FOR ACID DRAINAGE EXISTS. THIS, 399 PROPORTION IS ASSUMED TO HOLD FOR AREA STRIP MINING WHICH IS 499 THE ASSUMED METHOD EMPLOYED ON SLOPES OF LESS THAN 15 DEGREES. 599 699 DRAINAGE FROM ACTIVE MINES IN APPALACHIA IS THE ASSUMED MODEL 799 FOR ACID DRAINAGE. FROM SURFACE MINES ACID WATERS ENTER THE 899 STREAMS AT.A RATE OF 62.0 T/DAY (1039,5,8), OR 2.OE-4 T/T OF 999 COAL EXTRACTED (COAL PRODUCTION FROM (0001)) AND THE SULFATE 1099 LOADING IS ABOUT TWICE THE ACID LOADING (1039). 1199 1299 THE CHEMJCAL COMPOSITION OF THE DRAINAGE FROM THE AICTIVE MINBS1399 IS ESTIMATED FROM DATA ON THE MONONGAHELA RIVER BASIN (1039, 1499 133/139),. THE DATA F ROM 10 GAGING STATIONS WERE USED IN THE 1599 ESTIMATLON AND THE COAL PRODUCTION FIG.URES WERE OBTAINED FROM 1699 REFERENCE (0001). THE EFFLUENT DATA IN TON/TON COAL WERE AD. 1799 JUSTED TO REFLECT ONLY CONTRIBUTIONS FROM ACTIVE SURFACE 1899 MINING BY THE DATA IN (1039,6). IN DETERMINING THE HARDNESS- 1999 A CONCENTRATION OF 100 MG/L WAS ASSUMED TO OCCUR NATURALLY, 2099 WHILE THE METALLIC CONSTITUENTS ARE ASSUMED TO ORIG@IIATI FROM 2191 THE MINES. THE EFFLUENT BREAKDOWN IS AS FOLLOWS 2299 T/103 T COAL STRIPPED T/I OE12 BTU IN 2399 HARDNESS .0.901 27.* 5 2499 FE 0.0158 0.5 2599 MN 0.00668 0.2 2699 AL 0.00198 0.1 2799 S04' 12.2 2899 TOTAL 40.5 2999 3099 ACIDITY (AS CAC03) 6.11 3199 FTN. 1021 IT HAS BEEN ASSUMED THAT THE PROPORTION OF THE DRAINAGE 3299 ASSOCIATED WITH SURFACE MINES IS THE SAME AS THAT FOR THE 3399 ACIDIC DRAINAGE IN THE BASIN. 3499 3599 ALTHOUGH THE MONONGAHELA BASIN IS USED AS A MODEL, IT SHOULD 3699 BE NOTED THAT THE COMPOSITION AND THE QUANTITY OF THE DRAINAGE 3799 VARIES BETWEEN MINES. 3899 3999 THE SEDIMENT YIELD OCCURS AT A RATE 2.54 T.YR-AC-IN OF 4099 RUNOFF (1020). THUS, ASSUMING AN AVERAGE RUNOFF OF 15 INC, 4199 5.07 T OF SILT IS CONTRIBUTED TO THE NATURAL DRAINAGE FOR 4299 EACH 1.0E12 BTU IN ((FOOTNOTE 1001). LAND USE BY SOLID WASTE 4399 PILE). 4499 4599 OF THE COAL MINED IN AREAS WHERE THE DRAINAGE IS NOT ACIDIC, 4699 62P WAS MINED IN THE NORTHERN GREAT PLAINS PROVINCE. HENCE, IT 4799 IS ASSUMED THAT THE WATER LEAVING THE MINES IS SIMILAR TO THAT 4899 OF MINES IN THE POWDER RIVER BASIN. ABOUT 12 GAL OF WATER IS 4999 YIELDED FOR EACH TON OF COAL EXTRACTED (1021,1022) AND THE 5099 GROUNDWATER IN THE AREA CONTAINS (1023) 5199 5299 K AND NA MG CA FE SO4 5399 5499 PPM 210 127 92 25.4 413 5599 5699 THE DRAINAGE FROM THE MINE ALSO CONTAINS ABOUT 1600 PPM 5799 OF COAL FINES AS SUSPENDED SOLIDS (1022). THUS, THE EFFLUENT 5899 BREAKDOWN IS AS FOLLOWS 5999 6099 1.0E-3 T/1.0E12 BTU IN 6199 6299 MG 16.8 6399 CA 12.2 6499 FE 3.4 6599 SO4 54.8 6699 K AND NA 27.6 6799 TOTAL 114.8 6899 6999 SUSPENDED SOLIDS 7099 (COAL FINES) 212.0 7199 7299 1021 199 SOLD WASTE PRODUCTION AT UNDERGROUND MINES IS IN GENERAL RELATED 299 TO THE OPERNING OF THE MINE. ASSUMING AN AVERAGE MINE DEPTHY OF 399 600 FT (WHICH IS THE AVERAGE FOR ILLINOIS (1016) AND A SHAFT 499 OPERNING OF 100 SF, 3000 T OF EARTH IS REMOVED TO SINK THE 599 SHAFT. FURTHER ASSUMING AN AVERAGE PRODUCTION OF 50 MMT PER 699 MINE, THE PRODUCTION OF SOLID WASTE OCCURS AT A RATE OF 60E-6 799 T/T OF COAL MINED. HENCE, 2.46 T OF SOLID WASTE IS PRODUCED 899 PER 1.0E12 BTU EQUIVALENT TONS EXTRACTED. BASED ON A PRIMARY 999 EFFICIENCYOF .85 FOR LONGWALL MINING AND .57 FOR ROOM AND 1099 PILLAR THIS IS EQUIVALENT TO 2.09 AND 1.40 TONS RESPECTIVELY 1199 PER 1.0E12 BTU IN. 1299 III-12 FTN. 1022-1025 1022 199 IN A FILE 30 FT IN HEIGHT, 4.59E-2 AC OF LAND IS OCCUPIED BY THE 299 REFUSE PILE (FOOTNOTE 1021, SOLID WASTE PRODUCTION) . THE 399 AVERAGE ANNUAL PRODUCTION FROM SIZABLE UNDERGROUND MINES IS 499 APPROXIMATELY 2 MMT (1005,90). HENCE, THE LAND (FIXED) UTIL- 599 IZED FOR STORAGE IS 5.36E-4 AC-YR/1.OE12 BTU IN. 699 799 THE AVERAGE THICKNESS OF SEAMS MINED UNDERGROUND 'IN 1965 WAS 899 5.3 FT (1017,5). WHICH WAS ALSO THE AVERAGE THICKNESS FOR 999 THE FEFIOD FROM 1945-1965. ON THIS BASIS, 4.38 AC OF LAND IS 1099 UNDERMINED FOR EVERY 1.OE12 BTU IN. 1199 1299 OF THE ACREAGE UNDERMINED APPROXIMATELY 25P WILL SUBSIDE 1399 (1019). THIS SUBSIDENCE RATE IS ACTUALLY.FOI@ ALL UNDERGB,OUND 1.499 COAL KINES, BUT SINCE THE ROOM,AND PILLAR TECHNIQUE HAS-BEEN 1599 PREDOMINANT IN THE US, IT IS ASSUMED THAT THIS FIGURE CHARAC- 1699 TERIZES THE SUBSIDENCE FOR ROOM & PILLAR MINING. EVENTUALLY 1799 ALL OF THE AREA UNDERMINED MAY SUBSIDE, BUT THE TIM,E SCALE 1899 IS IN EXCESS OF A CENTURY. THE 25P SUBSIDENCE RATE IS DERIVED 1999 FROM HISTORICAL OBSERVATIONS. 2099 2199 SUBSIDENCY AFFECTS A SURFACE AREA GREATER THAN THE AREA 2299 UNDERMINED. THE WIDTH ON THE PERIMETER THAT IS AFFECTED BY 2399 SUBSIDENCE IS DETERMINED FROM 2499 R=H TANX 2599 WHERE, R=WIDTH OF-THE PERIMETER AREA AFFECTED, H=DEPTH OF 2699 MINE, AND X=ANGLE OF DRAW (ANGLE BETWEEN A VERTICAL LINE, AND 2799 1, LIRE =NNECTIN3 THE FACE AND THE LIMIT OF SUBSIDENCE).. THE 2899 ANGLE OF DRAW HAS BEEN' CONSISTENTLY OBSERVED li EUROPEAN COAL 2999 FIELDS TO FALL BETWEEN 35-39 DEGREES (1027,232,233). THUS,FOR 3099 AN ANGLE OF DRAW OF 37 DEGREES AND A MINE DEPTH OF 600 FT,.THE3199 WIDTH OF THE AFFECTED PERIMETER AREA IS 452 FT. 3299 3399 OF THE UNDERMINED AREA 1.10 AC SUBSIDES. ASSUMING, A SQUARE 3499 AREA, THE SIDES ARE 219 FT IN LENGTH. HENCE, 3599 THE ADDITIONAL LAND AFFECTED HAS AN AREA OF 9.09 AC. THERE- 3699 FORE, THE TOTAL AREA AFFECTED BY SUBSIDENCE ENCOKPASSES 10.2 3799 AC. 3899 THE AV,ERAGE LIFE OF A'SIZkBLE UNDERGROUND MINING OPERATION IS 3999 ABOUT 25 YR. THUS, THE TIME AVERAGE LAND IMPACT IS 127 AC-YR 4099 PER 1.OE12 BTU IN. 4199 1 023 199 THE OCCUPA:TIONAL HEALTH STATISTICS FOR ALL METHODS OF MINING 299 REFLECT AVERAGES FOR THE YEARS 1969,'1970 AND 1971 (1070,1071, 399 1210). THE DATA COULD NOT BE DISAGGREGATED FOR-THE DIFFERENT 499 UNDERGROUND AND SURFACE MINING TECHNIQUES. 599 1024 199 DISCHARGE OF THE RESIDUAL WATER FROM THE COAL SLURRY-IS NOT 299 ALLOWED. WASTEWATER AT THE POWER PLANT CONTAINS 25 PPM OF 399 SOLIDS. THE WATER IS USED FOR COOLING TOWER MAKEUP, ASH HAND- 499 LING OR PLANT USE AND THE REMAINDER YS EVAPORATED IN PONDS 599 (1024). 699 1025 199 TH`E EMISSIONS FROM THE THERMAL DRIERS ARE COk_T FINES IN THE FORM 299 OF PAR 'TICULATES. THUS, THE PARTICULTES COLLECTED BY THE 399 CYCLONES ARE USUALLY FED BACK TO THE DRIERS FOR COMBUSTION. 499 THEREFORE, NO SOLID WASTE IS PRODUCED. 599 111-13 FTN. 1026-1029 1026 199 THE AVERAGE THICKNESS OF COAL SEAMS AUGER MINED IN 1965 WAS 4.2 299 FT (1017,7). THUS FOR EVERY 1.0E12 BTU EQUIVALENT TON 5.53 399 AC OF LAND ARE UNDERMINED. UNDER THE ASSUMPTION THAT THE RATIO 499 OF LAND SUBSIDED TOLAND UNDERMINED IS THE SAME AS FOR ROOM 599 AND PILLAR UNDERGROUND MINES (FOOTNOTE 1022), 1.38 AC OF SUR- 699 FACE AREA SUBSIDES. BECAUSE OF THE SHALLOW OVERBURDEN DEPTH, 799 THE PERIMETER EFFECT IS NEGLIGIBLE. FOR AN AUGER LENGTH OF 899 150 FT, ABOUT 1607 FT OF WORKING BENCH ARE CREATED FOR EACH 999 1.0E12 BTU IN. THUS FOR A BENCH WIDTH OF 35 FT (1052), 1.29 1099 AC/1.0E12 BTU INOF LAND ARE DISTURBED. IT IS ASSUMED THAT 1199 THE EXCAVATED OVERBURDEN IS DUMPED ON THE OUTSLOPES. THUS IN 1299 A PILE AVERAGING 15 FT IN HEIGHT THE SPOIL BANK EXTENDS 34.3 1399 FT DOWNSLOPE FROM THE OUTCROP COVERING AN AREA OF 1.27 AC/ 1499 1.0E12 BTU IN (FOOTNOTE 1070 SOLID WASTE PRODUCTION). CALCU- 1599 LATIONS FROM DATA COLLECTED IN EASTERN KENTUCKY (1029,1030, 1699 1031,1032,1033,1034) INDICATE THAT LANDS AFFECTED BY LAND- 1799 SLIDES AMOUNT TO 11.4 PC OF THE OUTSLOPE COVERED BY THE 1899 SPOILS. HENCE, AN ADDITIONAL LAND ACREAGE OF .145 AC/1.0E12 1999 BTU IN IS DAMAGED. THE TOTAL LAND DAMAGED DURING AUGERING 2099 AMOUNTS TO 4.09 AC/1.0E12 BTU IN. THE TIME AVERAGED (OVER 2199 25 YRS) LAND IMPACT IS 51.1 AC-YR/1.0E12 BUT IN. 2299 1027 199 AVERAGE MILES OF ROAD OPERATED IN 1970 WAS 209,401 MI AND OF THE 299 TOTAL TONNAGE HAULED IN THE SAME YEAR, 27P WAS COAL (0011, 399 559). THUS, ASSUMING A RIGHT-OF-WAY OF 50 FT (6 AC/MI), THE 499 LAND IMPACT ASSOCIATED WITH THE TRANSPORT OF COAL IS 339,230 599 AC. OF THE TOTAL TONNAGE OF COAL TRANSPORTED, 1.0E12 BTU 699 EQUIVALENT TONS ACCOUNTS FOR 0.01P. THE LAND IMPACT IS 799 THEREFORE 33.9 AC. 899 1028 199 ASSUMING PARTICULATE REMOVAL EFFICIENCY OF 87P FOR THE QUENCHING 299 PROCESS (1025) AND 95 PC FOR THE COKING CYCLE, THE EMISSIONS 399 ARE AS FOLLOWS (0002,7-4) IN T/1.0E12 BTU (SEE FOOTNOTE 1047 499 FOR COAL HEATING VALUE). 599 699 PARTICULATES SOX CO HC NOX NH3 799 899 BY-PRODUCT 999 COKING: 1099 (HORIZONTAL 1199 CHAMBER) 1299 UNLOADING 7.3 1399 CHARGING 28.9 0.39 11.7 48.9 0.584 .039 1499 COKING CYLCE 0.10 11.7 29.3 0.195 1.17 1599 DISCHARGING 11.7 1.3 3.9 1.95 1699 QUENCHING 2.3 1799 UNDERFIRING 195.0 1899 1999 TOTOLS 50.3 195.4 24.7 82.1 0.779 3.51 2099 2199 2299 BEEHIVE 3900 19.5 156.0 39.0 2399 1029 199 THE EFFICIENCIES FOR PARTICULATE REMOVAL ARE GIVEN IN FOOTNOTE 299 1028. THUS, THE SOLID WASTE PRODUCED IS AS FOLLOWS 399 499 T/1.0E12 BTU 599 699 BY PRODUCT COKING 17.1 799 (HORIZONTAL CHAMBER) 899 III-14 FTN. 1030-1034 10 30 199 AS SUMING A" DENSITY OF 0.03 T/CF FOR THE SOLID WASTE PRODUCED FROM, 299 CCKING AND A REFUSE PILE HEIGHT OF 30 FT, 0.00043 AC WILL BE 399 UTILIZED FCR STORAGE FOR EACH 1.OE12 BTU EQUIVALENT TONS OF 499 COAL PROCESSED FOR THE HORIZO NTAL CHAMBER. THE AV@ERAGE ECONOM- 599 IC LIiE CF PRODUCTION FACILITIES IN THE STEEL INDUSTRY IS .699 ABOUT 26 YR (3022). THUS, ASSUMING THE SAME LIFE SPAN FOR.THE 799 COKE PLANT, THE TIME AVERAGED LAND IMPACTS ARE 0.0.0566 AC-YR/ 899 1.OE12 BTU. 999 1099 AT BETHLEHEM STEEL IN BALTIMORE, APPRoxrMATELY 2.6 MMT OF COAL1199 ARE PROCESSED ANNUALLY AND THE LAND AREA UTILIZED FOR COKE 1299 PRODUCTION AND STORAGE IS ABOUT 90 AC. THUS, 1.35 AC -YR OF 1399 CAND IS ATTRIBUTABLE TO THE PROCESSING OF I.OE12 BTU. 1499 1031 199 STORAGE OF 1.OE12 BTU EQUIVALENT T OF COAL ABOVE GROUND IN A PILE 299 30 FT HIGH, REQUIRES THE USE OF 0.762 AC OF LAND. IT IS 199 AS.SUMED THAT UNDERGROUND STORAGE WILL ALSO REQUIRE THE SAME 499 AMOUNT OF LAND. 599 1032 199 GENERALLY, SILOS HAVE A DIAMETER OF 70 Fl AND ARE ABOUT 150 FT IN 299 HEIGHT. THE STORAGE CAPACITY IS APPRCXIMATELY 11,000 T (1006). 399 THUS, 4 SILOS ARE REQUIRED FOR STORING 1.OE12 BTU EQUIVALENT 499 T. THE LAND UTILIZED BY THE SILOS IS THEREFORE 0.354 AC. 599 1033 199 FOR THE PERICD 1969 TO 1970, SHIPMENT OF COAL ACCOUNTED FOR 27P OF 299 THE TOTAL TONS OF FREIGHT SHIPPED BY FAIL (0011,559). OF THE 399 TOTAL TONNAGE OF COAL TRANSPORTED, 1.OE12 BTUEQUIVALENT T 499 ACCOUNTS FOR 0.01P (TOTAL COAL, 330 MMT). DURING THE SAME .599 FERIOD AN AVERAGE OF 2255 FATALITIES OCCURED AND, 21,666 PER- 699 SONS WERE INJURED IN RAIL ACCIDENTS (0006). THESE FIGURES ARE 799 FOR THOSE OTHER THAN PASSENGER FATALITIES AND INJURIES, AND 899 INCLUDES ALL ACCID ENTS. INJURIES TO EMPLOYEES ON DUTY AVERAGED 999 16,250 PERSONS AND .93 MAN-DAYS WERE LOST PER INJURY (0006) 1099 HENCE, FCR EVERY I.OE12 BTU EQUIVALENT T HAULED THERE ARE 1199 0.061C FATAL INJURIES, 0.585 NONFATAL INJURIES, AND 59.5 MAN- 1299 DAYS LOST. 1399 1034 199 THE EFFLUENTS FE03 A BYPRODUCT COKING OPERATION ARE PRESENTED IN 299 REFERENCE (1037,16) IN TERMS OF TCNS OF DRY COAL P ROCESSED. 399 THE CONVERSION TO TONS OF COAL AS RECEIVED IS DONE FOR A MOIS- 499 TURE CONTENT OF 5P. THIE MOISTUPE CONTENT IS LIMITED TO A MAXI- 599 MUM OF ABOUT 7P TO PREVENT DAMAGE TO THE BRICKWORK j1038). THE 699 EFFLUENT BREAKDOWN IS AS FOLLOWS 799 899 T/1.0112 BTU IN 999 CYANIDE 5.84 1099 AMMONIA 6.49 1199 1299 TOTAL 12.33 1399 1499 BOD5 59 _4 1599 PHENOLS 10.2 1699 1799 1899 THE HEATING VALUE OF COAL RECEIVED AT COKING PLANTS IS ASSUME'D1999 To BE 13000 BTU/LD (FOOTNOTE 1047) . VERY LITTLE THERMAL DIS-' 2099 CHARGES APE ASSOCIATED WITH SLOT OVENS (1044) AND -NO DATA HA .S2199 BEEN FOIJ@ND CN SUSPENDED SOLIDS. BOTH ARE OF COURSE DEPENDENT, 2299 -ON FACILITIES UTILIZED. 2399 111-15 FTN. 1035-1038 1035 IT IS ASSUMED THAT 0.006P OF THE FEED TO THE ROUGH CLEANING UNIT 299 IS REMOVED AS TRAMP IRON. HENCE, 2.46 T OF TRAMP IRON IS 399 COLLECTED FOR EVERY 1.OE12 BTU EQUIVALENT TONS PROCESSED. THE 499 PERCENTAGE OF TRAMP IRON IS ESTIMATED FROM INFORMATION IN REF. 599 (1059,6-31) ASSUMING THAT THE LARGE PLANT PROCESSED 1000 T/HR. 699 1036 199 SINCE IN LONGWALL MINING THE ROOF IS COLLAPSED AS MINING PRO- 299 GRESSES, IT IS ASSUMED THAT SUBSIDENCE OCCURS OVER THE ENTIRE 399 ARE UNDERMINED. THUS 4 38 AC OF LAND SUBSIDES FOR EACH 1.0E 499 12 BTU EQUIVALENT T (SEAM THICKNESS IS 5.3 FT, FOOTNOTE 1022). 599 THE WIDTH OF THE AREA OF INFLUENCE IS 452 FT (FOOTNOTE 1022). 699 THEREFORE, THE ADDITIONAL LAND AFFECTED BY SUBSIDENCE ENCOM- 799 PASSES 18.1 AC. THE TOTAL LAND AFFECTED IS 22.5 AC/1.0E12 BTU, 899 AND THE TIME AVERAGED (OVER THE 25 YR MINE LIFE) LAND IMPACT 999 IS 280 AC-YR/1.0E12 BTU IN. 1099 THE REFUSE PILE OCCUPIES AN AREA OF 8.00E-4 AC-YR/1.0E12 BTU 1199 IN (FOOTNOTE 1022). 1290 1037 199 FOR A COAL SEAM THICKNESS OF 3.8 FT (1001) AND A COAL DENSITY OF 299 81 LB/CF, 6.12 AC OF LAND IS OVERTURNED PER 1.0E12 BTU IN. 399 499 ON SLOPES GREATER 15 DEGREES,TECHNIQUES OF CONTOUR STRIP- 599 PING ARE EMPLOYED. IT IS ASSUMED THAT THE CONVENTIONAL CONTOUR 699 MINING IS USED. EXCEPT FOR THE MATERIAL USED TO BACKFILL THE 799 BENCH, ALL OF THE OVERBURDEN IS DEPOSITED ON THE OUTSLOPE AND 899 ASSUMED TO REST AT THE ANGLE OF REPOSE (ABOUT 37 DEGREES). IT 999 IS ALSO ASSUMED THAT A 15 FT RIM OF BLOSSOM COAL IS LEFT IN 1099 PLACE. THE MEAN SLOPE ANGLE AND THE BENCH WIDTH ARE ASSUMED 1199 TO BE 20 DEGREES (1028,3-6) AND 150 FT RESPECTIVELY. HENCE, 1299 A HIGHWALL OF 60 FT IS CREATED, AND FOR 1.0E12 BTU IN OF COAL 1399 1776 FT OF HIGHWALL (BENCH LENGTH) ARE GENERATED. 1499 THE SPOIL BANK IS ASSUMED TO HAVE A MEAN HEIGHT OF 45 FT. 1599 THUS, THE PILE REACHES 959 FT DOWNSLOPE FROM THE OUTCROP AND 1699 ENCOMPASSES AN AREA OF 3.91 AC/1.0E12 BTU IN (FOOTNOTE 1038, 1799 SOLID WASTE PRODUCTION). 1899 THE DRAINAGE DITCH ABOVE THE HIGHWALL IS ASSUMED TO AFFECT 1999 50 FT UPSLOPE. HENCE, 2.04 AC/1.0E12 BTU IN OF LAND IS 2000 UTILIZED. CALCULATIONS FROM DATA COLLECTED IN EASTER 2100 KENTUCKY (1029,1030,1031,1032,1033,1034) INDICATED THAT LAND 2299 AFFECTED BY LANDSLIDE AMOUNTS TO 11.4P OF THE OUTSLOPE AREA 2399 COVERED BY THE SPOILS. THUS, AN ADDITIONAL LAND ACREAGE OF 2499 0.446 AC/1.0E12 BTU IN IS DAMAGED. IT IS RECOGNIZED THAT THIS 2599 WILL NOT BE THE CASE FOR ALL MINES, IN THAT MORE STABLE SLOPE 2699 ANGLES FOR THE SPOIL BANKS ARE REQUIRED IN SOME STATES. OB- 2799 SERVATIONS (1035) INDICATE THAT THE OCCURRENCE OF LANDSLIDES 2899 IS SIGNIFICANTLY REDUCED WHEN THE OUTSLOPES ARE STABILIZED. 2999 (NO STABILIZATION IS INCLUDED IN THE ABOVE COMPUTATIONS). 3099 THE TOTAL LAND USAGE (EXCLUSIVE OF HAULAGE ROADS) IS 12.5 AC 3199 PER 1.0E12 BTU IN. THE TIME AVERAGED (OVER 25 YRS) LAND IMPACT 3299 IS THEREFORE 156 AC-YR/1.0E12 BTU IN 3399 ALTHOUGH RECLAMATION PRACTICES ARE ESPOUSED, NOT ALL APPALACH- 3499 IAN STATES HAVE MANDATORY VEGETAL SURVIVAL RATE REQUIREMENTS 3599 (1028) NOR ARE THERE STIPULATIONS FOR RECLAMATION OF TOP SOIL. 3699 THUS, EXCEPT FOR COVERING THE EXPOSED SEAM AND THE PIT FLOOR, 3799 NO RECLAMATION HAS BEEN ASSUMED. 3899 1038 199 FOR A SLOPE ANGLE OF 20 DEGREES, A BENCH WIDTH OF 150 FT AND A 299 15 FT RIM OF BLOSSOM COAL (FOOTNOTE 1037). 4.37E05 TON OF 399 EARTH ARE MOVED/1.0E12 BUT IN. 499 III-16 FTN. 1039-1041 AS A REQUIREMENT OF BACKFILLING, IT IS ASSUMED THAT 4 FT OF 5 99 MATERIAL, ABOVE THE HEIGHT OF THE COAL SEAM, MUST IBE REPLACED. 699 THUS, FOR A 3.8 FT SEAM THICKNESS (1001), 5.33EO4 TON/1.OE12 799 BTU IN OF SPOILS ARE REPLACED IN BACKFILLING THE BENCH. 899 THE SOLID WASTE PRODUCTION IS THEREF ORE 3.8,3EO5 T PER I.OE12 999 BTU IN,. 1099 1039 199 THE OCCUPATIONAL HEALTH STATISTICS FOR HAULAGE OF COAI; BETWEEN 299 MINE AND TIPPLE REFLECT AN AVERAGE FOR THE YEARS 1969 AND 399 1970.(-1070,1210). THE DATA INCLUDES THE FIGURES FOR ALL 499 METHCDS OF HAULAGE. 599 1040 199 A TYPICAL BEEHIVE OVEN IS ABOUT 12 FT IN DIAMETER AND OILL HANDLE 299 AN AVERAGE CHARGE OF 7.5 T (0022,35). THE 'COKING TIME PER 399 CHARGE IS APPROXIMATELY 60 HR. THUS, ON THE BASIS OF 5 DAY WK, 499 EACH OVEN IS CAPABLE OF PROCESSING 780 T OF COAL/YR. TO PRO- 599 CESS 1*1112 BTU EQUIVALENT T 01' COAL 10 OVENS ARE REQUIRED* 699 THESE OVENS ARE USUALLY BUILT IN BATTERIES WHICH FOLLOW THE 799 CONTOUR OF THE MOUNTAIN WHERE THEY APE LOCATED. ALLOWING 20 FT 899 OF WORKING AREA,,A TERRACE 32 FT IN WIDTH AND 6C,O FT LONG IS 999 REQUIRED. HENCE, 0.441 AC OF LAND IS UTILIZED. 1099 1199 SINCE THE BEEHIVE OVENS ARE USUALLY ASSOCIATED WITH A SPECIFIC1299 MINE, IT IS ASSUMED THAT ABOUT A MILE OF TRACK IS REQUIRED TO 1399 TRANSPORT THE COAL, THE COAL IS USUALLY CHARGED TO THE OVENS 1499 FROM ABOVE, DIRECTLY FROM THE MINE CARS. ASSUMING A RIGHT-OF- 1599 WAY OF 20 FT, 2.42 AC OF LAND ARE OCCUPIED BY THE TRACK. 1699 1799 IN 1971, 6 PLANTS WERE IN OPERATTON AND PROCESSED 1.29 KHT OF 1899 COAL (1036,5,6). ASSUMING EACH PLANT PROCESSED AN EQUAL 1999 SHARE, 0.215 MMT, THEN 1.OE12 BTU EQUIVALENT T ACCOUNTS FOR .2099 19P OF THE PRODUCTION FOR ANY OF THE PLANTS. THEREFORE, 2199 0.459 AC OF THE LAND OCCUPIED BY THE TRACK IS ATTRIBUTED TO 2299 THE PROCESSING OF 1.OE12 BTU EQUIVALENT T. 2399 2499 THE TOTAL LAND USAGE IS 0.900 AC-YR/1.OE12 BTU. 2599 1041 199 MOST OF THE CONTOUR MINING OCCURS IN THE APPALACHIAN REGION. THUS, 299 DATA FROM APPALACHIA IS USED IN THE DETERMINATION OF THE EF- 399 FLUENTS. 499 599 THE COMPCSITION OF THE DRAINAGE FROM ACTIVE CONTOUR MINES IN 699 APPALACHIA IS AS FOLLOWS (FOOTNOTE 1020) 799 899 T/1.OE12 BTU IN 999 1099 HARDNESS 29.6 1199 FE 0.5 1299 MN 0.2 1399 AL 0.1 1499 S04 13.1 1599 1699 TOTAL 43.5 1799 1899 ACI DI TY 6.56 1999 2099 THE SEDIMENT YI.ELD OCCURS AT A RATE OF 2.54 T/YR-A6-IN OF RUN-2199 OFF (1C@0) AND.--.IS ASSUMED TO ORIGINATE FROM ALL THE SPOILED 2299 AREA. 'THE RUN6FF IS ASSUMED TO BE 15 IN AND THE LAND AREA 2399 IS 54.5 AC-YR/I.OE12 BTU IN (FOOTNOTE 1037). HENCE, 2076 T 2499 OF.SILT IS YIELDED PER I.OE12 BTU IN. 2599 111-17 FTN. 1042-1047 1042 199 THE RAILS ARE MAINLY USED WITH UNDERGROUND MINES AND ARE EITHER 299 ELECTRIC OR DIESEL ELECTRIC POWERED. THUS, THE EMISSIONS ARE 399 EXPECTED TO BE MINIMAL. 499 599 SINCE THE TIPPLE IS USUALLY LOCATED IN THE PROXIMITY OF THE 699 MINE MOUTH AND THE TRACKS ARE RELATIVELY NARROW, VERY LITTLE 799 LAND WILL BE UTILIZED BY THE RAIL. 899 1043 199 IN AN EASTERN KENTUCKY STUDY, THE SEDIMENT YIELD FROM A COAL HAUL 299 ROAD WAS DETERMINED TO BE 90 T/AC-YR (1020,C32). BECAUSE OF 399 THE CONDITIONS, THE YEILD WAS EXCEPTIONALLY HIGH. FOR THE 499 PRESENT COMPUTATION IT IS ASSUMED THAT THE SEDIMENT YIELD 599 AVERAGES TO 35 T/AC-YR. THUS, 24.9 T/1.0E12 BTU OF SEDIMENT 699 IS YIELDED (ACREAGE OF HAULAGE ROAD, FOOTNOTE 1004) 799 1044 199 IN 1971 THE RAILROAD FREIGHT CHARGE WAS $3.70/T (1004,7). ASSUMING 299 THIS FIGURE FOR SHIPMENT BY MIXED TRAIN, THE FREIGHT RATE IS 399 $154,000/1.0E12 BTU. 499 1045 199 FREIGHT CHARGES FOR SHIPMENT BY UNIT TRAIN (IN 1969) AVERAGED 299 ABOUT $0.0061/TMI (1006,10). 399 499 ICC IMPOSED AN 8P AND 6P FREIGHT RATE INCREASE IN 1970 AND 599 1971, RESPECTIVELY. ASSUMING THAT UNIT TRAIN CHARGES INCREASED 699 SIMILARLY THE FREIGHT RATE FOR A 300 MI TRIP (FOOTNOTE 1005) 799 IS ABOUT $2.04/T OR $84,900/1.0E12 BTU. 899 THE FREIGHT CHARGES DO NOT APPEAR TO BE SENSITIVE TO THE 999 OVERNSHIP OF THE CARS (1006,10). 1099 1046 199 THE COAST INVOLVED IN TRANSPORTATION FOR A 2 MMT/YR STRIP MINE HAS 299 BEEN ESTIMATED FROM DATA IN REF. (1047,7/26) AND THE BREAKDOWN 399 IS AS FOLLOWS 499 599 CAPITAL INVESTMENTS 1972 $ 699 ROAD GRACER (2) 132,700 799 TRUCKS (5-100 T) 967,800 899 WATER TRUCK (1) 22,100 999 TOTAL 1,122,600 1099 1199 OPERATING EXPENSE $/1.OE12 BUT 1299 LABOR 158, 590 1399 OPERATING SUPPLIES 158,990 1499 TOTAL 317, 580 6510 1599 1699 FIXED COST (10PC OF CAPITAL INVESTMENT) 112,260 2300 1799 1899 INCLUDED IN LABOR IS THE COST FOR 2 GRADER OPERATORS AND 10 1999 TRUCK DRIVERS EACH AT $40.90/DAY AND 4 MECHANICS EACH AT 2099 $42.50/DAY (WAGE RATES FROM REF. (1042,43044)). ALL OTHER COST 2199 FIGURES HAVE BEEN ADJUSTED FROM 1969 TO 1972 BY A FACTOR OF 2299 10.6P (WHOLESALE INDUSTRIAL PRICE INDEX IN REF. (0011,342)). 2399 1047 199 IN 1971 THE AVERAGE VALUE OF COAL RECEIVED AT OVEN-COKE PLANTS WAS 299 $14/T AND THE AVERAGE VALUE OF RECEIPTS FOR OVEN COKE WAS 399 $37.41/T (1036,13,11). ON THE AVERAGE 1.45 T OF COAL WAS 499 UTILIZED TO PRODUCE A T OF COKE (1036,13). THUS, THE COST OF 599 PRODUCTION AMOUNTS TO $11.80/T OF COAL PROCESSED. 699 799 III-18 FTN. 1048-1050 ASSUMING AN INPUT CALORIC VALUE OF 12,IBO BTU/LB (FOOTNOTE 899 1000) TO THE METALLURGICAL PREPARATION'PLANT, THE HEATING 999 VALUE OF THE PRODUCT, WHICH IS THE CCAL RECEIVED AT COKE 1099 PLANTS,, IS 13000 BTU/LB (WEIGHTED AVERAGE OF THE PRODUCT FROM 1199 EACH OF THE CLEANING PROCESSES FOOTNOTES 1805 AND 1813). 1299 HENCE, THE PRODUCTION COST OF ;VEN COKE is $462,000/1.OE12 1399 13TU IN-. 1499 1048 199 IN 1971 THE AVERAGE VALUE OF COAL RECEIVED AT BEEHIVE@-COKE PLANTS 299 WAS $8.54/T AND THE AVERAGE VALUE OF RECEIPTS FOR BEEHIVE COKE 399 WAS $2.1.45/T (1036,13,11). ON THE AVERAGE 1.67 T OF COAL WAS 499 UTILIZ,ED TO PRODUCE A T OF COKE* THUS, PRODUCTION COST AMOUNTS 599 TO $4.30/T OF COAL PROCESSED OR $168,000/1.OE12 BTU. 699 1049 199 THE AVERAGE LENGTH OF HAULAGE CONVEYORS IS 2121 FT (1004,25). THE 299 ECONOMIC ANALYSIS IS AS FOLLOWS (1043,589/609) 399 499 CAPITAL EXPENDITURE 1972 $ 599 FELT 61,100 699 MACHINERY & STRUCTURES 49,600 799 DRIVES & ELECT EQUIPT 899 200 HP MOTOR 42,500 999 150 HP MOTOR 26,300 1099 TOTAL 179,500 1199 1299 ERECTION & INSTALLATION (25P) 44,900 1399 1499 TOTAL CAPITAL 224,400 1599 1699 OPERATING EXPENSES 1972 $/YR $/I.OE12 BTU 1799 BELT REPLACEMENT (SINKING 6,700 1899 FUND RETURNING FULL 1999 VALUE AT 4P AT END 2099 OF 8 YRS) 2199 REPAIR & MAIVTAINANCE 5,500 2299 POWER ($0.015/KWli) 15,400 2399 LABOR 38,300 @2499 65,900 1351 2599 2699 FIXED COST OOP OF CAPITAL 22,440 460 2799 EXPENSE) 2899 THET MINE PRODUCTION IS 2 MMT/YR OPERATING AT 240 DAY/YR. 2999 WITH 2-8 HR.SHIFTS/DAY. THE OPERATION REQUIRES A BELT 3099 OPERATOR AND A LABORER PER SHIFT AND THE WAGE.-RATES ARE 3199 OBTAINED FROM REF. (1042,43). THE COST OF THE EQUIPMENT 3299 IS ESCALATED FROM 1968 TO 1972 BY 14.8P (0011,@342). 3399 1050 199 THE DISCHAR IGE PER TON OF COKE PROCESSED WAS OBTAINED BY AVERAGING 299 THE DATA (1044) FOR TWO PLANTS, ONE PRODUCING 1000 T OF COKE 399 PER DAY AND THE OTHER 616 T OF COKE/DAY. IN 1971 1.67 T OF 499 COAL WAS REQUIRED TO PRODUCE A T OF COKE (1036,13). ASSUMING 599 AN AVERAGE CALORIC VALUE OF COAL RECEIVED AT COKING PLANTS OF 699 13000 BTU/LB (FOOTNOTE 1047) THE EFFLUENT BREAKDOWN IS AS 799 FCLLOWS, 899 FTN. 1051-1053 T/1.0E12 BTU 999 AMMONIA 1.39 1199 CYANIDE 0.02 1299 1399 1.41 1499 1599 BOD5 0.747 1699 PHENOL 0.117 1799 SUSPENDED SOLIDS 8.45 1899 1999 THERE IS LITTLE OR NO THERMAL DISCHARGE FORM BEEHIVE OVENS 2099 (1044). 2199 1051 199 IN 1971 THE AVERAGE COST OF SHIPPING COAL BY BARGE WAS $0.97/T OF 299 COAL (0031-37). OF THE TOTAL OPERATING EXPENSES APPROXIMATE- 399 LY 12P (INCLUSIVE OF DEPRECIATION, INSURANCE) IS FIXED COST 499 (0021,8,9). WHICH AGREES WITH DATA IN REF. (0032,18). IN TERMS 599 OF ENERGY THE AVERAGE FREIGHT CHARGE IS $40,400/1.0E12. IN TERMS 599 THE FIXED AND OPERATING COST DOES NOT ADD TO TOTAL COST 799 BECAUSE OF INDEPENDENT ROUNDING. 899 1052 199 FOR RAILROAD FREIGHT SERVICE, THE FIXED COSTS IS ABOUT 6P (DEPRECIA- 299 TION ONLY) OF THE TOTAL OPERATING EXPENSES (0033,67/70). IT IS 399 ASSUMED THAT THIS FIGURE APPLIES TO BOTH UNIT AND MIXED 499 TRAINS. SEE FOOTNOTE (1044 AND 1045 FOR FREIGHT CHARGES. THE 599 FIXED AND OPERATING COSTS MAY NOT ADD TO TOTAL COSTS BECAUSE 699 OF INDEPENDENT ROUNDING. 799 1053 199 WHEN A CONVEYOR IS USED FOR DISTRIBUTION OF COAL, IT IS GENERALLY 299 USED IN CONJUNCTION WITH ANOTHER MODE OF TRANSPORTATION, E.G., 399 BARGE OF TRAIN. THE HAULAGE DISTANCE IS RELATIVELY SHORT. 499 ONE OF THE LONGER (12 MI) SYSTEMS IS IN OPERATION IN WESTERN 599 KENTUCKY (1045) UTILIZING A CABLE DRIVEN CONVEYOR. 699 799 HERE, IT IS ASSUMED THAT THE TRANSPORT DISTANCE IS 5 MI AND A 899 CONVENTIONAL CONVEYER SYSTEM IS USED. THE ECONOMIC ANALYSIS IS 999 AS FOLLOWS (1043,598/609) 1099 1199 CAPITAL EXPENDITURE 1972 $ 1299 BELT 1,220,000 1399 MACHINERY 1,109,000 1499 ELEVATED STRUCTURE 1,580,000 1599 DRIVES & ELECT. EQUIPT. 192,000 1699 TOTAL CAPITAL 4,101,000 1799 1899 ERECTION & INSTALLATION (25P) 1,025,000 1999 2099 TOTAL 5,126,000 2199 2299 OPERATING EXPENSES 1972 $/YR $1.0E12 BTU 2399 BELT REPLACEMENT 85,400 2499 REPAIR & MAINTENANCE 118,600 2599 POWER ($0.015/KWH) 25,800 2699 LABOR 18,900 2799 TOTAL OPERATING 249,000 5100 2899 2999 FIXED COST (10P OF CAPITAL COST) 512,600 10500 3099 3199 III-20 FTN. 1054-1058 THE CONVEYER IS DESIGNED TO HANDLE 2 MMT/YR (1000 TPH AT 8 HR 3299 PER DAY, 240 DAY/YR). THE STRUCTURE IS COVERED AND THUS 3399 FUGITIVE DUST IS NOT A PROBLEM. WAGE RATES ARE OBTAINED FROM 3499 REF. (1042,43) FOR ONE LABORER AND ONE EQUIPMENT OPERATOR. 3599 1054 199 THE LENGTH OF THE CONVEYER IS 5 MI (FOOTNOTE 1053). THUS, ASSUMING 299 A RIGHT-OF-WAY OF 30 FT, 18.2 AC OF LAND IS OCCUPIES. THE 399 SYSTEM TRANSPORTS 2 MMT OF COAL ANNUALLY. THEREFORE, IN TERMS 499 OF ENERGY, 0.378 AC-YR/Q.0E12 BTU OF LAND IS UTILIZED. 599 1055 199 THE COST OF TRANSPORTING COAL BY SLURRY PIPELINE IS APPROXIMATELY 299 $0.0061/TMI (1046,FIG.8), WHICH INCLUDES THE COSTS OF SLURRY 399 PREPARATION AND PIPELINE TRANSPORT. OF THE UNIT COST ABOUT 70P 499 IS RELATED TO FIXED CHARGES, 15P IS FOR POWER COSTS AND THE 599 REMAINDER FOR MAINTENANCE (1046). 699 799 THE ONLY PIPELINE IN OPERATION IS 273 MI IN LENGTH (FOOTNOTE 899 1017). THUS, THE COST AMOUNTS TO $1.67/T OR $69,300/1.0E12 999 BTU. 1099 1199 THE NATIONAL AVERAGE HEAT VALUE (12,180 BTU/LB) IS USED IN THE 1299 ABOVE CONVERSION. THE CALORIC VALUE OF COAL FROM BLACK MESA IS 1399 ABOUT 12,300 BTU/LB (AS RECEIVED), BUT BECAUSE OF THE MOISTURE 1499 ACQUIRED FROM THE SLURRY. THE AS BURNED HEATING VALUE IS 1599 SOMEWHAT LOWER. 1699 1056 199 THE INJURY STATISTICS ARE OBTAINED FROM REF. (0001,135) AND THE 299 COKE TO CAOL CONVERSION FROM (0001,428). THE STATISTICS 399 ENTERED IN THE TABLE ARE AVERAGES FOR THE YEAR 1965-1969. THE 499 HEATING VALUE OF THE COAL RECEIVED AT COKING PLANTS IS 599 ASSUMED TO BE 13000 BTU/LB (FOOTNOTE 1047). 699 1057 199 THE COST FOR HAULING COAL BY TRUCK IS ABOUT $0.45/T (1047,5-9) FOR 299 A 10 MI TRIP. THUS, TO HAUL 41,000 T (FOOTNOTE 1001) THE COST 399 AMOUNTS TO $18,500. 499 599 OF THE TOTAL ANNUAL EXPENDITURE, ABOUT 10P IS RELATED TO FIXED 699 COST (0034,10). THE FIXED AND OPERATING COSTS DO NOT ADD TO 799 THE TOTAL BECAUSE OF INDEPENDENT ROUNDING. 899 1058 199 THE FIGURES GIVEN ARE FOR STORAGE WHICH REQUIRES STACKING AND 299 RECLAIMING CONVEYERS AND A BULLDOZER (1047,3). THE SPECIFICA- 399 TIONS FOR THE CONVEYER SYSTEM ARE OBTAINED FROM REF. (1041.16). 499 THE ECONOMIC ANALYSIS IS AS FOLLOWS (1043,589/609) 599 699 CAPITAL EXPENDITURE 1972 $ 799 STORAGE & RECLAIM CONVEYER 899 BELT 55,000 999 INTERMEDIATE MACH. & STRUCTURE 55,000 1099 ELEVATED STRUCTURE 87,000 1199 DRIVES & ELECT. EQUIPMENT 100,000 1299 SUB TOTAL 297,000 1399 ERECTION & INSTALLATION (25P) 74,000 1499 SUBTOTAL 371,000 1599 1699 BULLDOZER (1) 72,000 1799 TOTAL 443,000 1899 1999 III-21 FTN. 1059-1061 OPERATING EXPENSES 1972 $/YR $/1.0E12 BUT 2099 BELT REPLACEMENT-(SINKING FUND 2199 RETURNING FULL VALUE AT 4P 2299 AT END OF 5 YRS) 54,000 2399 REPAIR & MAINTENANCE 2499 5P OF BELT COST 3,000 2699 2P OF EQUIPMENT COST 5,000 2599 POWER AT $0.015/KWH 11,000 2799 LABOR 2899 CONVEYER 19,000 2999 BULLDOZER 20,000 3099 TOTAL 112,000 2300 3199 FIXED COST (10P OF CAPITAL COST) 44,300 908 3299 3399 THE LABOR COSTS INVOLVE AN OPERATOR AND LABORER FOR THE CON- 3499 VEYER SYSTEM & AN OPERATOR AND MECHANIC FOR THE BULLDOZER 3599 (1042,44). ALL COSTS ARE ADJUSTED TO 1972 DOLLARS (FOOTNOTE 3699 1049). 3799 THE SYSTEM HANDLES 2 MMT OF COAL/YR WITH AN AVERAGE HEAT VALUE 3999 OF 12.180 BTU/LB. 4099 1059 199 ALTHOUGH THERE IS MORE SITE PREPARATION INVOLVED IN UNDERGROUND 299 STORAGE, THE ANNUAL EXPENDITURES ARE ASSUMED TO BE SIMILAR TO 399 THAT FOR ABOVE GROUND STORAGE (FOOTNOTE 1058). IN PRACTICE 499 UNDERGROUND STORAGE IS NOT A COMMON METHOD. 599 1060 199 THE CONVEYOR SYSTEM FOR SILO STORAGE IS SIMILAR TO THAT FOR ABOVE 299 GROUND STORAGE (FOOTNOTE 1058). HENCE, THE COST IS ALSO THE 399 SAME, EXCEPT THAT THE COSTS ASSOCIATED WITH THE BULLDOZER DO 499 NOT APPLY HERE. THE COST OF A SILO IS ASSUMED TO BE SIMILAR TO 599 THAT FOR A BULK STORAGE BUILDING (1041,71). THUS, THE COST IS 699 AS FOLLOWS FOR A 2E6 TPY OPERATION. 799 899 CAPITAL EXPENSE $ $/1.0E12 BTU 999 SILO 180,000 1099 1199 OPERATING EXPENSE 1299 CONVEYER SYSTEM 1399 OPERATION, REPAIR & MAINT. 112,000 2300 1499 CONVEYOR FIXED COST (10P 37,100 761 1599 CAPITAL COST) 1699 FIXED COST (10P OF CAPITAL COST) 18,000 370 1899 1061 199 THE ACCIDENT STATISTICS FOR COAL IN 1970 ARE INCLUDED IN THE 'NOT 299 ELSEWHERE CLASSIFIED' CATEGOR IN REF. (0036,14). IN MATCHING 399 DATA WITH REF. (0037,2/9) IT HAS BEEN DEDUCED THAT IN 1970 499 METALLIC ORES, COAL, NON-METALLIC MINERALS AND WASTE AND SCRAP 599 METALS WERE INCLUDED IN THIS CATEGORY. OF THE TOTAL TONNAGE OF 699 THESE COMMODITIES COAL ACCOUNTS FOR 3P A TRANSPORT OF 799 341,000 TONS. OF THE TOTAL TONNAGE OF COAL SHIPPED, 1.0E12 BTU 899 EQUIVALENT T AMOUNTS TO 12P. HENCE, 0.0324 FATALITIES/1.0E12 999 BTU AND 0.692 NON-FATAL INJURIES/1.0E12 BTU ARE ATTRIBUTED 1099 TO THE SHIPMENT OF COAL. FOR THE SAME YEAR THE NUMBER OF 1199 DAYS LOST PER INJURY FOR 'TRUCKING, LOCAL AND LONG DISTANCE' 1299 WAS 65.6 (0038,375). THUS, 45.4 DAYS ARE LOST/1.0E12 BTU. 1399 III-22 FTN. 1 062-1068 1062 199 .IT TAKES ABOUT ONE TON OF COAL TODRY 10O.TONS OR 1.OE10 BTU/YR TO 299 l.CE12 BTU/YR COAL (1048). MEASURED EMISSIONS FROM COAL 399 THERMAL DRYERS ARE 4.5E-2 LB SOX AND 5.35E-1 LB NOX (MID-RANGE 499 VALUES) IER 1.OE6 BTU OF COAL FIRED (1121). 599 1063 199 DURING THE TRANSPORT OF FOSSILFUELS BY RIVER BARGES IN 1971, 3 299 FATALITIES AND 5 NON-FATAL INJURIES CCCURED (1049). IN-THE 399 SAME YEAR 70P OF THE TOTAL TONNAGE OF FOSSIL FUEL SHIPPED WAS 499 COAL (0031,37,40).THUS, 1.93E-3/1.OE12 BTU FATALITIES AND 3.21E-3/1.OE12 BTU INJURIES ARE ATTRIBUTED TO THE TRANSPORT OF 699 COAL. 799 THE AVERAGE DAYS LOST PER INJURY FOR MARINE CARGO HANDLERS FOR 899 THE PERIOD FROM 1963-1967 IS 75.7 (OC38,375). HENCE, 3.243 999 DAYS LOST/1.OE12 BTU HANDLED. 10.99 1064 199 FUEL CONSUMPTION is 3530 GALOF DIESEL/l.CE12 BTU EQUIVALENT T .299 HAULED. FOR A CALORIC CONTENT OF 5.86E6 BTU/BBL, 4.93E8 BTU 399 OF ENERGY ARE CONSUMED (FOOTNOTE 1003). 499 1065 199 THE COIVEYOR SYSTEM CONSUMES 1,03E6 KWH/YR OR ABOUT 21100 K" H/ 299 1.OE12 BTU (FOOTNOTE 1049). THIS IS EQUIVALENT TO 2.2OE8 BTU, 399 WHICH IS 3 TIMES THE BTU EQUIVALENT OF THE POWER CONSUMPTION. 499 1066 .199 THE PRODUCTICN COST FOR AN AUGERING OPERATION OF 222,000 T/YR IS 299 AS FOLLOWS (1052) 399 $/YR $/l.OE12 BTU IN 499 OPERATING COST 346,000 29,400 599 FIXED COST (10% 43,000 3,650 699 OF CAPITAL EXPENSE) 799 THE COST OF HAULING THE COAL TO THE TIPPLE IS EXCLUDED FROM 899 THE ABOVE FIGURES. 999 1067 199 THE PFCDUCTION COST FOR A 2 MMT/YR AREA STRIPPING OPERATION IS 2.99 ESTIMATEV FROM INFORMATION ON A 1 AND 3 MMT/YR MINE IN 399 WESTERN KENTUCKY (1041,27/37,49/60). THE BREAKDOWN IS AS 499 FOLLOWS 5�9 1972 1.OE6 $/YR $/l.OE12 BTU IN 699 OPERATING COST 4.17 69200 799 FIXED COST 2.05 34000 899 999 THE COSTS OF HAULAGE TO TIPPLE AND TRAIN LOADING FACILITIES 1099 ARE EXCLUDED'FROM THE ABOVE FIGURES. THE COSTS ARE ESCALATED, 1199 TO 1972 LOLLARS BY THE INDUSTRIAL WHOLESALE PRICE INDEX 1299 (0011,341). 1399 .1068 199 THE PPODUCTICN COST FOR A 2 MMT/YR CONTOUR MIN *ING OPERKTICN IS 299 ESTIMATED FROM INFORMATION IN REP. (1041,1/26 AND'IS AS 399 FCLLCWS 499 1972 1.OE6 $/YR $/l.OE12 BTU IN 599 OPERATING COST 4.71 77200 699 FIXEC COST 2.11 34600 799 899 111-23 FTN. 1069-1071 THE COSTS HAVE BEEN ADJUSTED TO 1972 DOLLARS BY THE INDUSTRIAL 999 WHOLESALE PRICE INDEX (0011,342). 1099 IT SHOULD BE NOTED THAT ALTHOUGH THE COSTS IN REF. (1041) ARE 1199 DEVELOPED FOR MINES WITH DIFFERENT SPECIFICATIONS, THE COST 1299 PER UNIT ENERGY SHOULD NOT BE IN GREAT ERROR, SINCE FOR 1399 MODERATE SEAM THICKNESS THE COST PER UNIT ENERGY APPEARS TO 1499 BE SENSITIVE ONLY TO THE SIZE OF THE MINE. 1599 HAULAGE TO TIPPLE AND TRAIN LOADING FACILITIES IS EXCLUDED 1699 FROM THE ABOVE COSTS. 1799 1069 199 THE FUGITIVE DUST GENERATED FROM THE HANDLING OF RAW COAL AT THE 299 PREPARATION PLANT IS IN GENERAL CONFINED TO THE PLANT PROPER. 399 IT APPEARS TO PRESENT AN OCCUPATIONAL HEALTH TYPE OF 'PROBLEM, 499 RATHER THAN ONE OF AIR POLLUTION, PER SE. (1058). 599 AS A CONSEQUENCE OF THE FEDERAL COAL MINE HEALTH AND SAFETY 699 ACT OF 1969, THE R.O.M. COAL FROM UNDERGROUND MINES HAS BEEN 799 HIGHER IN SURAFCE MOISTURE (DUE TO THE USE OF INCREASED 899 QUANTITIES OF WATER FOR DUST SUPRESSION). THUS, THE DUST 999 GENERATED FROM HANDLING THESE COALS HAS BEEN REDUCED IN 1099 RECENT YEARS. 1199 1070 199 FOR A SLOPE OF 40 DEGREES (IN CASES WHERE THE SLOPES ARE LESS 299 STEEP IT IS MORE LIKELY THAT THE COAL WILL BE EXTRACTED BY 399 STRIP MINING. AUGERING MAY THEN FOLLOW, (REF. 1051,30)). A 499 BENCH WIDTH OF 35 FT AND A BENCH LENGTH OF 1607 FT. 41300 T/ 599 1.0E12 BTU IN OF SOLID WASTE IS PRODUCED (FOOTNOTE 1026). 699 1071 199 THE PLANT FOR UTILITY COAL PREPARATION IS ASSUMED TO PROCESS 500 299 T/HR (1010). THE R.O.M. COAL IS CRUSHED TO A 1.5 IN. TOPSIZE. 399 THE 1.5 X 3/8 IN. SIZES ARE PROCESSED IN A DENSE MEDIUM BATH 499 AT A SEPARATION SPECIFIC GRAVITY OF 1.6, WHILE THE COALS LESS 599 THAN 3/8 IN. IN SIZE ARE NOT SUBJECTED TO ANY CLEANING. 699 799 THE ASH AND SULFUR COMPOSITION OF THE COAL FROM THE UPPER 899 FREEPORT BED IN CLEARFIELD COUNTY, PA. IS VERY SIMILAR TO THE 999 CHARACTERISTICS OF THE AVERAGE (OVER MOST OF THE COUNTRY) 1099 UTILITY COAL (14.4P ASH, 3.23P S, REF. 1053,16). THEREFORE, 1199 THE WASHABILITY DATA OF THE UPPER FREEPORT COAL (1053,130) 1299 ARE UTILIZED. AT A SEPARATION SPECIFIC GRAVITY OF 1.6 THE 1399 DATA INDICATE A THEORETICAL CLEAN COAL RECOVERY OF 90.3P. 1499 A STUDY OF 6 DENSE MEDIUM WASHERS REVEALED AN AVERAGE 1599 EFFICIENCY OF .96.9P (1054,28). THUS, IT IS ASSUMED THAT THE 1699 ACTUAL RECOVERY OF CLEAN COAL IS 87.5P 1799 SINCE NO SCREEN ANALYSIS IS AVAILABLE ON THE UPPER FREEPORT 1899 COAL THE DATA ON THE LOWER KITANNING BED OF ARMSTRONG COUNTY, 1999 PA. (WHICH HAVE SOMEWHAT SIMILAR CHARACTERISTICS) ARE USED. 2099 OF THE CRUSHED COAL, THE 1.5X 3/8 IN.SIZE FRACTIOIN CONSTITUTES 2199 72P (1055). HENCE, THE DENSE MEDIUM BATH IS FED AT A RATE OF 2299 360 T/HR PRODUCING CLEAN COAL AT A RATE OF 314T/HR AND SOLID 2399 WASTE AT A RATE OF 45.5 T/HR OR 3740 T/1.0E12 BTU IN. 2499 AN ADDED SOURCE OF REFUSE IS THE MAGNETITE LOSSES DURING 2599 PROCESSING. THE AVERAGE LOSS OF MAGNETITE AMOUNTS TO 0.9 LB/ 2699 TON OF CLEAN COAL. THUS, AN ADDITIONAL AMOUNT OF 11.6 T/1.0E12 2799 III-24 FTN. 1072-1074 BTU OF SOLID IS PRODUCED (REF. 1054) 2899 THE COLLECTING OF TRAMP IRON AMOUNTS TO 2.46 T/1.0E12 BTU 2999 (FOOTNOTE 1035). THE SUM TOTAL SOLID WASTE GENERATED IS THUS 3099 3.75E03 TON/1.0E12 BTU. 3199 1072 199 SEEPAGE FROM THE REFUSE PILE IS ESTIMATED TO BE 1670 GAL/AC-DAY 299 AND CONTAINS .091 LB ACIDITY/GAL, .144 LB SULFATES/GAL, 399 .0258 LB IRON/GAL AND 3.78E-4 LB MN/GAL. (1009). THUS, THE 499 DRAINAGE WILL CONTAIN 599 T/1.0E12 BTU 699 799 SULFATES 31.5 899 MANGANESE 0.08 999 IRON 5.6 1099 TOTAL 37.2 1199 ACIDITY 19.9 1299 1399 OF THE RAW CRUSHED COAL 1P IS LESS THAN 100 MESH IN SIZE 1499 (1055). A PROPORTION OF THIS SIZE FRACTION ENDS UP IN THE FEED 1599 TO THE DENSE MEDIUM CIRCUIT. ASSUMING 10P OF THE COAL LESS 1699 THAN 100 MESH IN SIZE IS YIELDED AS BLACKWATER DISCHARGE, 1799 SUSPENDED SOLIDS ARE GENERATED AT A RATE OF 0.5 T.HR. IT IS 1899 UNREALISTIC TO ASSUME THAT ALL OF THE BLACKWATER IS DICHARGED 1999 TO NATURAL DRAINAGE OF THAT THE PLANT OPERATES ON A CLOSED 2099 CYCLE. OF THE 685 PLANTS APPLYING FOR PERMITS THROUGH EPA 37.5 2199 P HAVE TREATMENT FACILITIES (1112). RATHER THAN APPLYING ANY 2299 TREATMENT, THE BLACKWATER IS ASSUMED TO BE DISCHARGED TO A 2399 SETTLING POND AND 62.5P OF THE BLACKWATER GENERATED ENTERS THE 2499 NATURAL DRAINAGE THROUGH LEAKS, OVERFLOWS AND IMPROPER SET- 2599 TLING. THUS 25.6 T/10E12 BTU OF SUSPENDED SOLIDS ARE DIS- 2699 CHARGED. SOME MINERALS WILL ALSO BE DISCHARGED AS DISSOLVED 2799 SEDIMENT YIELD FROM THE REFUSE PILE OCCURS AT A RATE OF 2999 2.54 T/AC-YR-IN. OF RUNOFF. THUS, FOR AN AVERAGE RUNOFF OF 3099 15 IN. AND A REFUSE PILE AREA OF 0.718 AC-YR/1.0E12 BTU IN 3199 (FOOTNOTE 1073). THE SEDIMENT YIELD IS 27.4 T/1.0E12 BTU IN. 3299 THE TOTAL SUSPENDED SOLIDS DISCHARGED TO NATURAL DRAINAGE IS 3399 53.0 T/1.0E12 BTU IN. 3499 1073 199 THE REFUSE BANK IN A PILE AVERAGING 30 FT IN HEIGHT OCCUPIES AN 299 AREA OF .0574 AC/1.0E12 BTU. (SOLID WASTE PRODUCTION, FOOTNOTE 399 1071). THE TIME AVERAGED (OVER 25 YRS) LAND IMPACT IS THERE- 499 FORE 0.718 AC-YR/1.0E12 BTU. 599 LAND REQUIRED FOR THE PREPARATION PLANT IS ABOUT 5 AC (1008). 699 THE LOADING AREA FOR A 10000 T UNIT TRAIN IS ESTIMATED TO BE 799 ABOUT 40 AC (DATA ON THE MATTHEWS MINE, (1006,85) AND THE 899 SETTLING POND OCCUPIES ABOUT 50 AC (1009). THE PLANT PROCESSES 999 2 MMT/YR, THUS THE LAND IMPACT IS 1.95 AC-YR1.0E12 BTU. 1099 IT IS ASSUMED THAT BOTH THE STEAM AND METALLURGICAL PLANTS 1199 HAVE SIMILAR LAND REQUIREMENTS, SINCE THE EQUIPMENT 1299 DOES NOT OCCUPY LARGE AREAS. 1399 FOR THE METALLURGICAL PLANT THE SOLID WASTE PILE OCCUPIES 1499 0.124 AC/1.0E12 BTU (SOLID WASTE PRODUCTION, FOOTNOTE 1813). 1599 THE TIME AVERAGED LAND IMPACT IS 1.55 AC-YR/1.0E12 BTU. 1699 1074 199 A MAJORITY OF ACTIVE AND INACTIVE COAL WASTE BANKS SURVEYED (1067, 299 1068) WERE FOUND BURNING OR SMOLDERING, ADDING TO THE PROBLEM 399 OF AIR POLLUTION. IT IS ASSUMED THAT THE REFUSE BANK IN THIS 499 CASE IS BURNING. THE EMISSION FACTORS ARE DETERMINED FROM 599 INFORMATION IN REF. 0017 AND FROM THE KNOWLEDGE OF THE SOLID 699 WASTE PRODUCED (FOOTNOTE 1071), AND ARE AS FOLLOWS 799 II-25 899 FTN. 1075-1077 PART. SOX CO HC NOX 999 1.10E12 BTU 1.58 2.37 4.75 0.792 0.792 1099 1199 SINCE THE INTERMEDIATE AND FINE SIZE COALS ARE NOT SUJECTED 1299 TO ANY CLEANING (FOOTNOTE 1071) THE ASSOCIATED PROBLEMS ARE 1399 NON-EXISTENT. 1499 THE PROBLEM OF FURGUITVE DUST AT THE PREPARATION PLANT IS NOT 1599 SIGNIFICANT EXCEPT FOR THE HANDLING OF THERMALLY DRIED FINES 1699 (1048). THE FEDERAL COAL MINE HEALTH AND SAFETY ACT OF 1969 1799 HAS LED TO AN INCREASED USE OF WATER FOR DUST SUPPRESSION IN 1899 UNDERGROUN MINES. CONSEQUENTLY THE SURFACE MOISTURE OF THE 1999 R.O.M. COAL HAS INCREASED AND THERREBY REDUCED THE FUGITIVE 2099 DUST PROBLEMS AT TRANSFER POINTS AND THE CRUSHERS. SEE 2199 FOOTNOTE 1077. 2299 THE DUST PROBLEM FROM WIND EROSION OF THE STORAGE PILES IS 2399 MINIMAL DUE TO THE RELATIVELY RAPID MOVEMENT OF THE PILES. 2499 1075 199 THE COSTS FOR OPERATING A PREPARATION PLANT CLEANING THE 1.5 IN. X 299 3/8 IN. A DENSE MEDIUM BATH ARE AS FOLLOWS (1056,34/36) 399 FOR A 2 X 10 TPY PLANT 499 1.0E6 $ 599 CAPITAL EXPENSE 1.18 699 1.0E6 $/YR $/1.0E12 BTU 799 OPERATING EXPENSE 0.265 5520 899 FIXED COST (10P OF 999 CAPITAL EXPENSE) 0.118 2480 1099 1199 THE REFUSE DISPOSAL COSTS ARE OBTAINED BY ADJUSTING THE DATA 1299 IN REF. 1057. ONE 13 T TRUCK IS USED FOR HAULING THE REFUSE. 1399 FROM THE INFORMATION ON ALTERNATE DISPOSAL METHOD FOR THE 1499 KENTUCKY MINE (1057,11/12) THE DISPOSAL COSTS ARE ESTIMATED 1599 TO BE AS FOLLOWS 1699 1799 1.0E5 $ 1899 CAPITAL EXPENSE 1.79 1999 1.0E 5 $/YR $/1.0E12 BTU 2099 OPERATING EXPENSE 1.71 3560 2199 FIXED COST (10P OF 2299 CAPITAL EXPENSE 0.18 380 2399 1076 199 THE COSTS INVOLVED IN OPERATING A PLANT FOR SIMPLE CRUSHING AND 299 SIZING OF R.O.M. COAL ARE AS FOLLOWS (1056,IV-34/36)FOR A 399 2E6 TPY PLANT. 499 1.0E4 $ (1972) 599 CAPITAL EXPENSE 14.4 699 4/1.0E12 BTU IN 799 OPERATING EXPENSE 9.36 1950 899 FIXED COST (10P OF 1.44 300 999 CAPITAL EXPENSE) 1099 IN ESTIMATING THE COSTS IT HAS BEEN ASSUMED THAT 60P OF THE 1299 CRUSHED COAL CAN BE CLASSIFIED AS COARSE (1.5 IN. X 3.8 IN.). 1399 1077 199 THE FUGITIVE DUST PROBLEM ASSOCIATED WITH PREPARATION PLANTS IS 299 IN GENERAL CONFINED TO THE IMMEDIATE SITE (1058). IT APPEARS 399 TO BE MORE OF AN OCCUPATIONAL HEALTH PROBLEM. 499 IN THE HANDLING OF R.O.M. COAL FROM UNDERGROUN MINES THIS 599 PROBLEM HAS DECREASED IN RECENT YEARS. FOLLOWING THE ENACTMENT 699 OF THE FEDERAL COAL MINE HEALTH AND SAFETY ACT IN 1969, A 799 GREATER AMOUNT OF WATER IS BEING USED FOR THE SUPPRESION OF 899 DUST, THEREBY INCREASING THE SURFACE MOISTURE AND CONSEQUENTLY 999 III-26 FTN. 1078-1090 REDUCING THE QUANTITY OF DUST GENERATED DURING HANDLING OF 1099 THE RAW COAL. 1199 1078 199 THE QUANTITY OF WATER USED-AT TRA13FER PCINTS IN A PREPARATION 299 PLANT TO SUPPRESS DUST IS VERY SMALL (1058). THUS, ONLY SMALL 399 QUANTITIESOF WATER, IF ANY, MAY BE DISCHARGED. IT DOES NOT 499 SEEM LIKELY THAT -STREAM QUALITY WILL BE AFFECTED EXCEPT 599 POSSIBLY AT THE OUTFALL. 699 IT SHOULD BE NOTED THAT NOT ALL PLANTS UTILIZE WATER FOR DUST 799 SUPRESSION. MANY PLANTS DO NOT APPLY ANY CONTROL MEASURES. 899 1079 199 DISASTERS (A SINGLE ACCIDENT RESULTING IN 5 OR MORE DEATHS) OCCUR 299 FREQUENTLY IN UNDERGROUND MINES. IN THE PAST 40 YRS ONLY 6 399 CALENDAR@YEARS WENT WITHOUT A DISASTER OCCURING. 499 SINCEIN LCNGWALL MINING THE ROOF IS COLLAPSED AS MINING 599 PROGRESSES, UNEXPECTED ROOF FAILURE IS AVOIDED, THUS, IT WILL 699 BE LESS HAZARDOUS. 799 1080 199 THE POTENTIAL FOR DISASTERS TO OCCUR DURING AUGER MINING IS 299 MINIMAL. ONLY THE FAILURE OF THE HIGHWALL PRESENTS ANY REAL 399 HAZARD TO THE WOREERS. 499 1081 199 LARGE SCALE LISASTERS AT STRIP-MINES ARE RARITIES. AS IN AUGER 299 MINING ONLY THE FAILURE OF THE HIGHWALL PRESENTS ANY POTENTIAL 399 FOR A DISASTER. 499 1082 log THE POTENTIAL FOR LARGE SCALE DISASTERS IS NON-EXISTENT. .299 1083 199 FUEL CONSUMPTION BY THE UNIT TR&IN IS 1.03E5 GAL/1.OE12 BTU 299 LQUIVALENi T TFANSFORTED.(FOOTNOTE 1005). FOR A CALORIC VALUE 399 OF 5.825E16 BTU/BBL, 1.43E10 BTU OFENERGY IS CONSUMED. 499 1084 199 FUEL CONSUMPTION BY MIXED TRAIN IS 81000 GAL/1.OE12 BTU EQUIVALENT. 299 T TRANSPOPTED (FOOTNOTE 1007). THIS AMOUNTS TO AN ENERGY @399 SONSUMPTION 0 F 1.12E10@BTU (5.825E6 ETU/BBL). . . 499 1085 1919 A BARGE CONSUMES 378 BTU/TMI (FOO@NOTE 7001). THUS, FOR AN AVERAGE 299 HAULAGE BISTA.NCE OF 300 MI (FOOTNOTE 1006) AND AN ASSUMED 399 GROSS TO TARE WEIGHT RATIO OF 4 TO 1, 7.76E9 BTU OF ENERGY IS 499 CONSUMED FOR THE TRANSPORT OF,1.OE12 BTU EQUIVALENT T. 599 1086 199 ENERGY CONSUMPTION FOR THE TRANSPORT OF COAL BY PIPELINE AMOUNTS 299 TO 6.93E5 KWH (FOOTNOTE 1055 ASSUMING $.015/KWH). THE REAL 399 'CONSUMPTION OF ENERGY IS THE PRODUCT OF THE BTU EQUIVALENT (OF 499 6.93E5 KWH) AND 3. 599 1087 igg FUEL CONSUMPTION FOR, THE.TRANSPORT,I.OE12 BTU EQUIVALENT T BY 299 TRUCK AMOUNTS TO 66ob-GAL OR 9.17E8 BTU (5.83E6 BTU/BBL) J99 ,(FOOTNOTE 1008). 499 1088 199 ENERGY CCNSUMFTION FOR THE MOVEMENT OF COAL BY CONVEYORS IS 299 3. 53E4 KWH/1 . CE 12 BTU (FOOT NOT E 1053) . TH E REAL E NERGY CON- 399 SUMPTION IS 3 TIMES THE BTU EQUIVALENT OF 3.53E4 KWH., 499 1089 199 ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEYORS FOR 299 STORA',;E AMOUNTS TO 1.52t4 KWH./1.0E12 BTU (FOOTNOTES 1058,1059e 399 1060)- THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVA 499 LENT OF THE ELECTRICAL POWER. 1090 599 199 IT HAS bEEN ESTIMATED THAT DURING LONGWALL MINING PHYSICAL LOSSES 299 AMCUNT TC AFF11OXIMAT"ELY 15P (1060). 399 FTN. 1091-1804 1091 199 ESTIMATES FOR ROOM AND PILLAR UNDERGROUND MINES INDICATE THAT 299 LOSSES AMOUNT TO ABOUT 43P (1060 AND 1061). 399 1092 199 THE RECOVERY EFFICICENCY FOR AUGER MINING IS ESTIMATED TO BE 46P 299 (1062). 399 1093 199 PHYSICAL LOSSES DURING CONTOUR MINING AMOUNT TO ABOUT 20P (1063). 299 1094 199 PHYSICAL LOSSES DURING AREA STRIPPING AMOUNT TO APPROXIMATELY 19P 299 (1063). THE RECOVERY PERCENTAGE FOR AREA STRIPPING HAS A 399 GREATER VARIABILITY THAN CONTOUR MINING. THE UPPER LIMIT IS IN 499 THE VICINITY OF 982. 599 1095 199 ENERGY CONSUMPTION AT A CRUSHING AND SIZING PLANT IS ABOUT 1.6E9 299 BTU/1.0E12 BTU EQUIVALENT T PROCESSED. OF THE TOTAL CONSUMP- 399 TION 1.4E5 KWH IS ELECTRICITY (1064, 12A-16,39) AND 2.48E8 BTU 499 IS OIL (1064, 12A-16,39), ASSUMING ALL FUEL PURCHASED TO BE OIL 599 AT A COST OF $0.20/GAL). THE TOTAL IS OBTAINED BY ADDING 3 699 TIMES THE BTU EQUIVALENT OF TH ELECTRICAL CONSUMPTION TO THE 799 OIL USAGE. 899 1096 199 ANCILLARY FUEL CONSUMPTION DURING COKE PRODUCTION IN BOTH BEEHIVE 299 AND SLOT OVENS IS NIL. 399 1097 199 LOSSES (DUE TO OXIDATION) IN HEAT CONTENT OF THE COAL IN AN 299 ACTIVE STORAGE PILE ARE NEGLIGIBLE, WHILE IN DEAD STORAGE THE 399 LOSSES AMOUNT TO ABOUT 1P/YR FOR OPEN (ABOVE AND UNDERGROUND) 499 PILES AND 0.72/YR FOR SILOS (1047 AND 1065). THESE FIGURES 599 ASSUME PROPER STORAGE TECHNIQUES ARE EMPLOYED. OTHERWIDE THE 699 LOSSES DURING THE FIRST YR MAY AMOUNT TO 3-5P. IN GENERAL, THE 799 LOWER THE BANK OF COAL, THE GREATER WILL BE THE LOSSES. 899 1098 199 COAL LOSES CUFING HAULAGE FROM MINE TO TIPPLE ARE ASSUMED TO BE 299 NEGLIGIBLE. 399 1099 199 THE AMOUNT OF FEED REMOVED AS TRAMP IRON IS MINISCULE (0.006P). 299 THE EFFICIENCY IS THEREFORE APPROXIMATELY 100P. 399 1801 199 WINDAGE LOSSES FOR UNIT TRAIN, BARGE AND TRUCKING AMOUNTS TO 299 .04 P (FOOTNOTES 1005,1006,1008), WHILE FOR MIXED TRAIN 399 LOSSES AMOUNT TO .08P (FOOTNOTE 1007). 499 1802 199 AN ESTIMATED THERMAL EFFICIENCY REDUCTION OF ABOUT 2P RESULTS 299 FROM THE SLURRY WATER REMAINING IN THE BOILER FEED (1006,6-24). 399 THIS LOSS IS CONSIDERED TO BE EFFECTIVELY A REDUCTION IN THE 499 HEATING VALUE OF THE COAL AND ATTRIBUTABLE TO TH MODE OF 599 TRANSPORT. 699 1803 199 IT IS ASSUMED THAT ABOUT .04P OF THE COAL TRANSPORTED IS LOST 299 THROUGH SPILLAGE AT TRANSFER POINTS. SINCE THE CONVEYOR IS 399 COVERED, NO WINDAGE LOSSES ARE ASSUMED. 499 1804 199 BY LINEARLY INTERPCLATING THE DATA IN REF. (1041,12,22) AND ASSUM- 299 ING THE OILS TO BE DIESEL FUELS COSTING $.20/GAL AND THE COST 399 OF POWER TO BE $.015/KWH THE TOTAL ENERGY CONSUMPTION FOR A 499 2 MMT CONTOUR STRIPPING OPERATION IS ABOUT 1.34E10 BTU FOR 599 EVERY 1.0E12 BTU EQUIVALENT T EXTRACTED. THE TOTAL IS COMPOSED 699 OF 1.84E9 BTU OF FUEL AND 1.13E6 KWH OF ELECTRICAL POWER. THE 799 TOTAL IS OBTAINED BY ADDING 3 TIMES THE BTU EQUIVALENT OF THE 899 ELECTRICAL POWER USAGE TO THE FUEL CONSUMPTION. ON A 1.0E12 999 BTU IN BASIS THE TOTAL IS 1.07E10 BTU. 1099 FTN. 1805-1806 1805 199 THE ASSUMPTICN IS MADE HERE THAT THE CHARACTERISTICS OF THE WASTE 299 FRODUCTS AND EFFLUENT FROM COAL CLEANING PLANTS WILL DEPEND 399 PRIMARILY ON THE PROPERTIES OF THE INPUT COAL, I.E., THE 499 WASHABILITY CHARACTERISTIC OF THE COAL RATHER THAN ON SPECIFIC 599 EQUIPMENT IN THE PLANT. 699 799 IN GENERAL, ALL COAL IS MECHANICALLY CRUSHED AND SIZED, BERORE 899 USING IT AS A FUEL OR RAW MATERIAL. APPROXIMATELY 50P OF ALL 999 THE COAL PRODUCED IN THE U.S. IS CLEANED. A SMALL PORTION IS 1099 'CLEANED FOR PRODUCTION OF COKE FOR METALLURGICAL APPLICATIONS 1199 AND THE REST IS CLEANED FOR STEAM RAISING APPLICATIONS. 1299 A METALLURGICAL COAL-IS DEFINED AS ANY COAL-WHICH CAN BE 1399 CLEANED TO AN ASH CONTENT BELOW 8P.AND A SULFUR CONTENT BELOW 1499 1.25 P USING A LOW WASH SPECIFIC GRAVITY IN THE VICINITY OF 1599 1.4 . 1699 A COAL PREPARED.FOR FUEL USE OR STEAP RAISING APPLICATIONS IS 1799 GENERALLY CLEANED AT A SPECIFIC GRAVITY NOT LESS THAN 1.6. 1899 FRCM DATA ON WASHABILITY CHARACTERISTICS OF COAL, ONE CAN 1999 DERIVE A RELATION BETWEEN THE MAXIMUM THEORETICAL THERMAL 2099 PECOVERY EFFICIENCY, THE INPUT ASH CONTENT OF THE COAL AND. 2199 THE SPECIFIC GRAVITY OF THE WASH. FROM THE AVERAGED DATA IN 2299 REFERENCE (1010) TWO RELATIONS WERE DEVELOPED. FOR A SPECIFIC 2399 GRAVITY OF WASHING OF 1.6 2499 P BTU EFFICIENCY = -0.342 (P ASH) + 100. 2599 SPECIFIC GRAVITY OF WASHING OF 1.4 GIVES 2699 P BTU EFFICIENCY = -1.316 (P ASH) + 100. 2799 THE NATIONAL AVERAGE ASH CONTENT IS 14.4 P FOR UTILITY COAL 2899 (1053,229). THUS, WASHING Al A SPECIFIC GRAVITY OF 1.6 YIELDS2999 A 95.1 P THERMAL RECOVERY. THE OVERALL STEAM COAL PLANT THER- 3099 MAL EFFICIENCY IS THE WEIGHTED AVERAGE OF THE EFFICIENCY FOR 3199 THE WASHED AND UNWASHED PORTIONS - 95.1 P AND 100.0 P RESPEC- 3299 TIVELY, OR 96.5 P (SEE FOOTNOTE 1071). THE ASH CONTENT OF 3399 COAL PROCESSED FOR METALLURGICAL PURPOSES IS 16.0 PC (FOOT- 3499 NOTE 1813). HENCE, THE OVERALL EFFICIENCY FOR THE METALLURGI- 3599 CAL PLANT IS 81*1 PC, IN DETERMINING THE OVERALL EFFICIENCY 3699 OF THE METALLURGICAL PLANT IT IS ASSUMED THAT THE CALORIC 3799 VALUE OF THE FEED INTO EACH PROCESS (DENSE MEDIUM BATH, 3899 TABLES'AND FLOTATION) IS THE SAME (12,180 BTU/LB). THE DENSE 4099 MEDIUM BATH WASHES AT A 1.4 SPECIFIC GRAVITY AND THE CONCEN- 4199 TRATING TABLE AT A 1.6 SPECIFIC GRAVITY. THE THERMAL EFFI- 4299 CIENCY OF THE FLOTATION UNIT IS ASSUMED TO BE 85 PC. THE 4399 OVERALL THERMAL EFFICIENCY IS THE WEIGHTED AVERAGE OF THE 4499 EFFICIENCIES FOR THE INDIVIDUAL PROCESSES-79 PC, 95 PC, AND 4599 85 PC FOR THE BATH, TABLE AND FROTH.FLOTATION., RESPECTIVELY- 4699 LESS THAT USED BY THE THERMAL DRYER (FOOTNOTE 1814). 4799 1806 195 BY LINEARLY INTERPOLATING THE DATA BETWEEN A 1 AND A 3 MMT/YR 299 AFFA STRIFFING OFERATION IN WESTERN KENTUCKY (1041,32,54) THE 399 POWER CONSUMPTION FOR A 2 MMT/YR OPERATION IS DETERMINED. IT 499 IS ASSUMED THAT THE OILS ARE DIESEL FUEL COSTING $0.20/GAL AND 599 THE COST OF ELECTRICAL POWER TO BE $0.015/KWH. THE TOTAL 699 ENERGY CONSUMPTION FOR THE EXTRACTION OF 1.OE12 BTU EQUIVALENT 799 T IS COMPUTED TO BE 6.97E9 BTU, WHICH IS COMPOSED OF 1.15E9 899 111-29 FTN. 1807-1813 BTU OF DIESEL FUEL AND 5.68E5 KWH OF ELECTRICAL POWER. IN 999 OBTAINING THE TOAL 3 TIMES THE ELECTRICAL POWER USAGE IS 1099 ADDED TO THE FUEL CONSUMPTION. ON A 1.0E12 BTU IN BASIS THE 1199 TOTAL ENERGY CONSUMPTION IS 5.65E09 BTU. 1299 1807 199 NO LOSSES ARE ATTRIBUTED TO THESE PROCESSES EXCEPT FOR ROUGH 299 CLEANING, DURING ROUGH CLEANING TRAMP IRON IS REMOVED AND 399 AMOUNTS TO APPROXIMATELY 0.006 P. 499 1808 100 THE DIESEL FUEL CONSUMPTION FOR AN AREA STRIPPING OPERATION IS 299 ESTIMATED TO 6710 GAL/1.0E12 BTU IN (FOOTNOTE 1806). 399 THE EMISSION FACTORS ARE OBTAINED FROM REFERENCE (0002, 499 3-7) ASSUMING THE CHARACTERISTICS OF A DIESEL TRUCK 599 ENGINE. 699 SINCE MOST OF THE COAL PRODUCTION OCCURS IN AREAS WHERE 799 ADEQUATE MOISTURE IS AVAILABLE, FUGITIVE DUST IS NOT ELECTED 899 TO BE A SERIOUS PROBLEM. 999 1809 199 APPROXIMATELY 1 T OF COAL IS REQUIRED TO DRY 100 T OF COAL (FOOT- 299 NOTE 1062). IN GENERAL A PORTION OF THE COAL EEC TO THE 399 DRIER IS UTILIZED., THUS, THE EFFICIENCY IS 99PC. 499 1810 199 THE OPERATING COST FOR A MCNALLY FLOWDRYER IS $0.083373/T OF DRIED 299 PRODUCT (1074). CAPITAL COSTS ARE ESTIMATED AT 5.5E5 $ FOR 399 A 1.74E6 TPY DRYER OR 1.30E3 $/1.0E12 BTU (1080). 499 1811 199 THE ELECTRICL POWER CONSUMPTION AMOUNTS TO 1.82 KWH/T OF DRIED 299 COAL PRODUCT OR 7.56E8 BTU/1.0E12 BTU IN (1074). 399 1812 199 APPROXIMATELY 35 AC OF LAND IS UTILIZED FOR THE CRUSHING AND 299 SIZING PLANT, AND A 10000 T UNIT TRAIN LOADING FACILITY 399 (1021). THUS, THE LAND IMPACT IS 0.729 AC-YR/1.0E12 BTU 499 IT IS ASSUMED THAT THE MODES OF TRANSPORT OTHER THAN UNIT 599 TRAINS HAVE SIMILAR LAND REQUIREMENTS. 699 1813 199 THE METALLURGIAL PREPARATION PLANT PROCESSES 500 T/HR OF R.O.M. 299 COAL (ABOUT 2MMT/YR, FOOTNOTE 1071). AT THE PLANT THE COAL IS 399 CRUSHED TO 1.5 IN. TOPSIZE. THE 1.5 X 3/8 IN. SIZE FRACTION IS 499 WASHED IN A DENSE MEDIUM VESSEL, THE 3/8 X 28 MESH SIZED ARE 599 CLEANED ON CONCENTRATING TABLES, AND THE COAL LESS THAN 28 699 MESH IS CLEANED BY FROTH FLOTATION. 799 THE COAL FROM THE UPPER FREEPORT BED OF THE IRISH RIDGE MINE 899 IN PRESTON COUNTY, W. VA. IS UTILIZED IN THIS ANALYSIS, SINCE 999 IT APPEARS TO REPRESENT A TYPICAL COAL REQUIRING BENEFICIATION 1099 TO MEET METALLURGICAL COKING STANDARDS. THE COAL CONTAINS 1199 16.0PC ASH AND 2.49PC SULFUR (1075,30). 1299 AT A SPECIFIC GRAVITY OF SEPARATION OF 1.4, THE WASHABILITY 1399 DATA INDICATE A THEORETICAL CLEAN COAL RECOVERY OF 78.4PC 1499 (1075,25). FOR A RECOVERY EFFICIENCY OF 96.9 (1054,28). THE 1599 ACTUAL RECOVERY IS 76PC. 1699 FROM THE DISTRIBUTION DATA ON CONCENTRATING TABLES FOR PLANT E 1799 (1076,10-52) AND THE WASHABILITY DATA, THE THEORETICAL 1899 RECOVERY EFFICIENCY IS ESTIMATED TO BE 88 PC. THE RECOVERY 1999 EFFICIENCY IS ABOUT 98PC (1077). THUS THE ACTUAL CLEAN COAL 2099 RECOVERY IS 86PC. 2199 THE FIXED CARBON CONTENT (DRY AND MINERAL FREE) FOR THIS COAL 2299 IS ABOUT 65PC(1075,30) WHICH IS SIMILAR TOTHE UPPER FREEPORT 2399 BED COAL ANALYZED FOR WASHABILITY BY FLOTATION. THUS, USING 2499 THIS DATA, THE THEORETICAL CLEAN COAL RECOVERY BY FROTH FLOT- 2599 III-30 FTN. 1814-1815 ATION IS ESTIMATED TO BE 86.6PC.THE RECOVERY EFFICINCY IS 2699 APOUT 92PC(1077), THUS THE ACTUAL FECOVERY IS 80.OPC. 279,9 THE SCREEN ANALYSIS OF THIS COAL INCLUDES SIZES GREATER THAN 2899 1.5 IN. (lC75,30). IT IS ASSUMED THAT THE SIZE DISTRIBUTION 2999 OF THE COAL LESS THAN 1.5 IN. IS SIMILAR WHEN THE COAL IS 3099' CEUS HED TO A TOPSIZE OF 1.5 IN. ON THIS BASIS THE DENSE 3199 MEDIU14 SATH WASHES 266 T/HR, THE CCNCENTRATING TABLES 200 T/HR3299 AND THE FLOTATION UNITS 34 T/HR. HENCE, SOLID WASTE IS PRO- 3399 DUCED AT A RATE OF 98.8 T/HR, OR 8100 T/1.OE12 BTU. 3499 THE AVERAGE MAGNETITE LOSSES FROM THE DENSE MEDIUM BATH 3599 AMOUNTS TO 0.9 LB/T OF CLEAN COAL PRODUCED FROM THE BATH 3699 (1054). THUS., AN ADDITIONAL AMOUNT OF REFUSE,.7.47 T/I.OE12 3799 BTU, IS FRODUCED. 3899 AN ADDITIONAL 2.46 T/1.OE12 BTU OF TFAMP IRON IS COLLECTED 3999 DURING RCUGH CLEANING (FOOTNOTE 1035). THE SUM TOTAL SOLID 4099 WASTE GENERATED IS THUS 8.11E03 T/1.OE12 BTU. 4199. 1814 199 THE EMISSIONS ASSOCIATED WITH BURNING COAL REFUSE BANKS.ARE AS 299 FOLLOWS (SOLID WASTE PRODUCTION, FGOTNOTE 1813, SEE ALSO 399 FCCTNOTE 1074) 499 PART. sox co HC NOX 599 T/1.OE12 BTU 3.41 5.11 10.2 1.71 1.71 699 79 9' THE THERMAL DRIER PROCESSES ALL OF THE COAL LESS THAN 3/8 IN. 899 IN SIZE (197 T/HR, FOOTNOTE 1813), THUS REQUIRING THE COMBUS- 999 TION OF 2.00 T OF COAL/HR OR 164 T/1.OE12 BTU. ASSUMINGA 1099 FLUIDIZED BED DRIER, THE EMISSIONS ARE AS FOLLOWS (FOOTNOTE 1199 1062 AND REP. (0002,8-10) AND FOOTNOTE 1123). 1299 PA 87. SOX NOX 1399 T/1.OE12 BTU 48.6 C967 1.15 1499. 1599 THE PARTICULATES ARE REMOVED WITH A 70 P EFFICI.ENCY BY A 1699 CYCLONE (FCOTNOTE 1002). 1799 1815 199 THE SEEPAGE FFOM THE'REFUSE PILE IS CONSTITU@ED AS FOLLOWS (SEE 299 FOOTNOTE 1072) 399 T/1.OE12 BTU 499 FE 12.2 59�" S04 68.0 699 MN .2 799 TOTAL 80.4 899 999 1199 ACIDITY 42.9 1099 OF THE RAW CRUSHED COAL,1.OP IS LESS THAN 100 MtSH IN SIZE 1299 (1075,30). IT IS ASSUMED THAT 50P OF THIS SIZE FRACTION ENDS 1399 UP AS; BLACKWATER DISCHARGE (FOOTNOTES 1820,1821 AND 1822) . 1499 THUS, 205 T/1.OE12 BTU OF SUSPENDED SOLIDS ARE DISCHARGED TO 1599 THE SETTIING POND. OF THIS TOTAL,62.5PC IS ASSUMED TO BE 1699 DISCHARGED TO THE NATURAL DRAINAGE THROUGH LEAKS, OVERFLOWS 1799 AND IMPROPER SETTLING (FOOTNOTE 1072). THIS AMOUNTS TO A 1899 DISCHARGE OF 128 T/l.CE12 BTU OF SUSPENDED SOLIDS. OTHER 1999 MINERALS ARE ALSO DISCHARGED, BUT NO DATA HAS BEEN FOUND. 209.9 SEDI11ENT YIELD FROM THE REFUSE PILE OCCURS AT A RATE OF 2 54 2199 T/AC-YR-IN. OF RUNOFF. THUS, FOR-AN AVERA6E RUNOFF OF l5ili. 2299 THE SEDIMi@NT YIELD IS 59.1 T/1.OE12 BTU (LAND USAGE BY REFUSE 2399 PILE,..FOCTNOTE 1073). 2499 111-31 FTN. 1816-1820 1816 199 THE COSTS INVOLVED IN OPERATING A PREPARATION PLANT PRODUCING 299 METALLURGIAL QUALITY COAL ARE AS FOLLOWS (1056, IV-34/36) 399 FOR A 2E6 TPY PLANT. 499 1.0E6 599 CAPITAL EXPENSE 2.64 699 1.0E6 $/YR $/1.0E12 BTU 799 OPERATING EXPENSE 0.0394 8200 899 FIXED COST (10PC OF 999 CAPITAL EXPENSE 0.264 5500 1099 1199 THE REFUSE DISPOSAL COSTS ARE OBTAINED BY ADJUSTING THE DATA 1299 IN REF. (1057). ONE 60 T TRUCK US USED FOR HAULING THE REFUSE. 1399 FROM THE INFORMATION ON ALTERNATE DISPOSAL METHODS FOR THE 1499 KENTUCKY MINE (1057,11/12) THE DISPOSAL COSTS ARE ESTIMATED 1599 TO BE AS FOLLOWS 1699 1799 1.0E5 $ 1899 CAPITAL EXPENSE 2.76 1999 1.0E5 $/YR $/10E12 BTU 2099 OPERATING EXPENSE 1.82 3790 2199 FIXED COST (10PC OF 2299 CAPITAL EXPENSE) 0.28 570 2399 1817 199 THE DENSE MEDIUM BATH IS ASSUMED TO BE CLEANING 1.5 X 3/8 IN. SIZE 299 FRACTIONS AT A 1.4 SPECIFIC GRAVITY OF SEPARATION. THE COAL 399 BEING PROCESSED IS FROM THE UPPER FREEPORT BED OF THE IRISH 499 RIDGE MINE IN PRESTON COUNTY, W. VA. THE CLEAN COAL RECOVERY 599 EFFICIENCY IS 76PC(FOOTNOTE 1813). THUS, FOR THE PROCESSING 699 OF 1.0E12 BTU EQUIVALENT T OF COAL, 9850 T OF SOLID WASTE IS 799 PRODUCED. 899 1818 199 THE CONCENTRATING TABLE IS ASSUMED TO BE CLEANING 3/8 IN. X 28 299 MESH SIZE FRACTIONS. FROM THE DISTRIBUTION CURVE DATA ON 5 399 TABLES (1076,10-52) AND THE WASHABILITY DATA OF THE COAL 499 (1075,25). THE THEORETICAL CLEAN COAL RECOVERY IS ESTIMATED 599 TO BE 98 PC. THE RECOVERY EFFICIENCY IS ABOUT 98PC (1077), THUS 699 THE ACTUAL CLEAN COAL RECOVERY IS 86 PC.THUS, FOR THE PROCESS-799 ING OF 1.0E12 BTU EQUIVALENT T, 5740 T OF SOLID WASTE IS 899 GENERATED. 999 1819 199 THE COAL LESS THAN 28 MESH IN SIZE IS PROCESSED BY FROTH FLOTA- 299 TION. THE COAL FROM THE UPPER FREEPORT BED OF THE IRISH RIDGE 399 MINE IN PRESTON COUNTY, W. VA., CONTAINS ABOUT 65 PC FIXED 499 CARBON (DRY AND MINERAL FREE). THIS IS SIMILAR TO THE FIXED 599 CARBON CONTENT OF UPPER FREEPORT BED OF HARMAVILLE, PA., FOR 699 WHICH FLOTATION WASHABILITY STUDIES WERE CONDUCTED. THE DATA 799 INDICATE A THEORETICAL RECOVERY OF 86.6PC (1078,29). THE 899 RECOVERY EFFICIENCY IS ABOUT 92PC(1077), THUS THE ACTUAL CLEAN 999 COAL RECOVERY IS 80 PC. SOLID WASTE IS THEREFORE GENERATED AT 1099 A RATE OF 8200 T/1.0E12 BTU. 1199 1820 199 OF THE RAW (RUSHED COAL 1P IS LESS THAN 100 MESH IN SIZE (1075,30 299 AND FOOTNOTE 1813) AND A PORTION OF THIS SIZE FRACTION ENDS 399 UP IN THE FEED TO THE DENSE MEDIUM CIRCUIT. IT IS ASSUMED 499 THAT 10P OF THE COAL LESS THAN 100 MESH IN SIZE IS YIELDED AS 599 BLACKWATER DISCHARGE FROM THIS CIRCUIT. HENCE, SUSPENDED 699 SOLIDS ARE GENERATED AT A RATE OF 41 T/1.0E12 BTU FROM THE 799 DENSE MEDIUM CIRCUIT. 899 OTHER ELEMENTS WILL ALSO BE CONTAINED IN THE DISCHARGE, BUT 999 DATA HAS NOT BEEN FOUND. 1099 III-32. FTN. 1821-1826 1821 199 A PORTION OF THE COAL LESS THAN 100 MESH IN SIZE END S UP IN THE 299 FEED TO SHE CONCENTRATING TABLE CIRCUIT (1P OF THE RAW CRUSHED 399 COAL IS LESS THAN 100 MES11 IN SIZE, FOOTNOTE 1820). IT IS 499 ASSUMED THAT 10P OF THE COAL LESS THAN 100 MESH IN SIZE IS 599 DISCHARGED FROM THIS CIRCUIT AS BLACKWATER. HENCE, SUSPENDED . 699 SOLIDS ARE GENERATED AT A BATE OF 41 T/1.OE12 BTU. - 799 OTHER ELEMENTS WILL ALSO BE CONTAINED IN THE DISCHARGE, BUT 899 DATA HAS NOT BEEN FOUND. 999 1822 199 THE COAL LESS THAN 28 MESH IN SIZE IS FEE TO THE FROTH FLOTATION 299 CIRCUIT. IT IS ASSUMED THAT 30P OF THE COAL LESS THAN 100 MESH 399 IN SIZE IS DISCHARGED FROM THIS CIRCUIT AS BLACKWATER. THUS, 499 SUSPENDEE.SOLIBS ARE GENERATED AT A RATE OF 123'T/1.OE12 BTU. 599 OTHER ELEMENTS WILL ALSO BE CONTAINEE IN THE DISCHARGE, BUT 699 DATA HAS NOT BEEN FOUND. 799 1823 199 TH E CALORIC CONTENT OF THE COAL FEED IS 13000 BTU/LB (FOOTNOTE 299 1047) AND COKE HAS A HEAT VALUE OF 24.BE6 BTU/T (1042,117). 399 ON THE AVERAGE 1.45 AND 1.67 T OF COAL ARE UTILIZED TO PRODUCE 499 A T OF COKE IN SLOT AND BEEHIVE OVENS, RESPECTIVELY (FOOTNOTE 599 1047 AND 1048). HENCE, THE EFFICIENCY (TOTAL HEAT VALUE OF 699 COAL FEED DIVIDED BY THE TOTAL HEAT VALUE OF THE COKE PRODUC- 799 ED) IS 66.8P FOR SLOT OVENS AND 58.1P FOR BEEHIVE-OVENS. 899 1824 199 A CRUSHER OPERATING AT 275 T/HR AND CRUSHING TO A TOPSIZE OF 1.5 299 IN. REQUIRES A 140 HP MOTOR (1014,7-14). THUS, 1.56E4 KWH 399 OF ENERGY ARE UTILIZED TO CRUSH 1.OE12 BTU EQUIVALENT T OF 499 COAL. THE ENERgY CONSUMED ITS EQUAL TO 3 TIMES THE BTU EQUIVA- 519 LENT- OF THE ELECTRICAL POWER UTILIZATICN OR 1.60E8 BTU. 6*9 9 1825 199 ENERGY CCNSUMPTION AT THE PREPARATION PLANT IS 2.13E9 BTU/1.OE12 299 BTU EQUIVALENT T PROCESSED. OF THE TOTAL CONSUMPTION 1.62E5 399 KWH ARE ELECTRICAL POWER AND 4.74E8 BTU ARE. OIL (ASSUMING ALL 499 FUEL PURCHASED TO BE OIL). THE TOTAL IS OBTAINED BY ADDING 3 599 TIMES THE BTU EQUIVALENT OF THE ELECTRICAL POWER CONSUMPTION 699 TO THE FUEL UTILIZATION (1064,12A-16,39). 799 SINCE THE, DISTINCTION BETWEEN THE TYPES OF PREPARATION PLANTS 899 COULD NOT BE MADE IN THE DATA, THE POWER CONSUMPTION DETER- 999 MINED ABCVE IS ASSUMED FOR BOTH STEAM AND METALLURGICAL COAL 1099 PREPARATION PLANTS. ligg 1826 199 THE COSTS FOR A 2 MMT/YR ROOM AND PILLAR DEEP MINING OPERATION 299 UTILIZING A CONTINUOUS MINERrRAIL CARS FOR HAULAGE To TIPPLE 399 AND WORKING A 6 FT SEAM AT 70 PC EFFICIENCY,ARE ESTIMATED AS 499 FOLLOWS (1079) 599 699 'CAPITAL EXPENSE $17,700,000 799 899 $/T $/l.OE12 BTU'IN 999 OPERATING EXPENSE 5.89 137,600 1099 FIXED COST (10 PC OF 1199 CAPITAL EXPENSE) 0.89 20,800 1299 TOTAL 6.78 158,400 1399 1499 111-33 FTN. 1827- THESE ARE THE ONLY FIGURES THAT COULD BE LOCATED. A PUB- 1599 LICATION ON COST ANALSIS FOR UNDERGROUND MINING WILL BE 1699 RELEASED BY THE BUR. OF MINES AROUND OCTOBER 1973. IT SHOULD 1799 BE NOTED THAT THE ABOVE COSTS INCLUDE HAULAGE FROM FACE TO 1899 TIPPLE. ALSO, THE EFFICIENCY AND SEAM THICKNESS ARE NOT THE 1999 SAME AS WERE USED TO DETERMINE THE ENVIRONMENTAL IMPACTS. 2099 NOT, HOWEVER, THAT THE $1.0E12 BTU IN CALCULATION USES A 2199 57 PERCENT PRIMARY EFFICIENCY SO AS TO BE CONSISTENT WITH THE 2299 OTHER DATA. 2399 1827 199 THE EXPENSE INCURRED FOR ELECTRICAL POWER IN ROOM AND PILLAR 299 MINING IS ESTIMATED TO BE $0.17/T AT $0.01/KWH (1079). THUS, 399 THE ENERGY REQUIREMENT FOR AN UNDERGROUND MINING OPERATION IS 499 6.97E5 KWH/1.0E12 BTU EQUIVALENT T EXTRACTED, AND THE REAL 599 ENERGY CONSUMPTION IS 7.14E9 BTU/1.0E12 BTU OUT (3 TIMES THE 699 BTU EQUIVALENT OF THE ENERGY REQUIREMENT). ON A 1.0E12 BTU 799 IN BASIS THIS IS 4.07E09 BTU. THE ENERGY CONSUMPTION FOR A 899 LONGWALL MINING OPERATION IS ABOUT 10 PC LESS THAN THE ENERGY 999 USED IN A ROOM AND PILLAR MINE (1079). THUS, FOR EVERY 1.0E12 1099 BTU EQUIVALENT T OF COAL EXTRACTED, 6.27E5 KWH OR 6.42E9 BTU 1199 OF ENERGY ARE CONSUMED. ON A 1.0E12 BTU IN BASIS THIS BECOMES 1299 5.46E09 BTU. 1399 III-34 4 1 A MA P-L-T$ (TININ8110 B,L) occN3NAL HEALTH -Y, -mos oM SCIR.B.11 ONNIA.C. T BOB -BA.- AL. .,01CI LARGE TOTAL T- to. BA,,tNxNs' COP TC, - rurr, ]-Na '"s 2AK3 P% o. HER YO,- tiB` -Toft- xNo., SCALE, OPL. .-TI. -3 - ------- - ------- On!- L,;-. 4 A . . . ... ...... 7o __j 75- IS -H RO! 76 T7 B_ IN 33 _L7 ------- BOB, A- IUN 4. j NOTE: ALL TABLE ENTRIES ARE BASIC 03 1012 BTU OF RESOURCE INTO EACH PROCESS OR ACTIVITY. SEE FOOTNOTE 1000 FOR MEASURE EQUIVALENTS OF ;012 BYU- 2. ENVEELONMMiTAL WACTS. RMCIENCT AXD COST FOR cONTiEtor T NA=N,&L coLL suwLy 111-35 FTN. 1100-1101 FOOTNOTES FOR TABLE 2 1100 199 A HYDRATED LIME PROCESS IS UTILIZED FOR TREATMENT OF ACID MTNE 299 DRAINAGE. ASSUMING AN ACID LOAD OF 3000 PPM, THE PLANT WILL 399 HAVE TO FROCESS .94 MMG/D OF DRAINAGE FROM ROOM AND PILLAR 499 MINES, AND .87 MMG/D FROM LONGWALL MINES (MINE DRAINAGE 599 POLLUTANT LOADS FOOTNOTE 1018). THE TOTAL IRON CONCENTRATION 699 IS ABOUT 500 PP@ FOR BOTH TYPES OF MINE. FOR THE PURPOSE OF 799 COST ESTIMATION THE PLANT IS ASSUMED TO HAVE A CAPACITY OF 899 TREATING 1 MMG/D. THE ESTIMATED COSTS ARE AS FOLLOWS (1102, 999 234,236). 1099 MILLIONS OF 1199 DOLLARS 1299 CAPITAL EXPENSE 1399 (WITH SLUDGE DISPOSAL) 1.40 1499 $/I.OE12 BTU IN 1599, 1699 OPERATING EXPENSE 0.830 9700 1799 FIXED COST-(10 PC OF 1899 .CAPITAL EXPENSE) 0.140 1640 .1999 at 2099 THE TREATMENT FACILITY IS RELATED TO A MINE PRODUCING 2 MMT/YR2199 OF CCAL WITH A CALORIC CONTENT OF 12,180 BTU/LB. 2299 IT SHOULD BE NOTED THAT A LIMESTGNE-LIME TREATMENT FACILITY 2399 MAY BE 5CRE ECONOMICAL AND EFFICIENT, BUT COST ESTIMATES FOR 24�9 SUCH A PLANT HAVE NOT BEEN DEVELOPED (1105). ALSO, DRAINAGE 2599 VARIES SUBSTANTIALLY FROM MINE TO MINE AMD THEREFORE THE 2699 MOST EFFECT1VE METHOD FOR TREATING MINE DRA1NAGE WILL NOT 2799 BE THE SAME FOR EACH MINE. 2899 QUICKSETIING DOUBLE BULKHEAD HYDRAULIC SEALS ARE EMPLOYED TO 2999 SEAL THE ADIT AT THE CLOSING OF THE MINE (1102 80/82). DUE TO 3099 FRACTURES THATUSUALLY DEVELOP IN THE STRATA SURROU.NDING THE 3199 MINE ENTRANCE, THE BULKHEAD ITSELF WILL NOT SUFFICIENTLY 3299 PREVENT ACID DRAINAGE. HENCE, CURTAIN GROUTING IS ALSO EMPLOY-3399 ED. THE COSTS INCURRED FOR MINE SEALING ARE ADDED TO OTHER 3499 ANNUAL EXPENSES AS FIXED COSTF AND ARE AS FOLLOWS 3599 3699 $ 3799 CAPITAL EXPENSE 3899 MINE SEAL (1102,94) 9600 3999 CURTAIN GROUTING (1102,95) 11100 4099 4199 ANNUAL EXPENSE S/I.OE12 BTU IN 4299 FIXED COST (10 PC OF 4399 CAPITAL EXPENSE) 2070 24.2 4499 4599 THE COSTS GIVEN HERE ARE IN ADDITION TO THE COSTS SHOWN IN 4699 FOOTNOTE 1826 FOR ROOM AND PILLAR MINING. 4799 1101 199 THE AVERAGE ANNUAL POWER EXPENSE FOR THE HYDRATED LIME SYSTEMS 299 UTILIZED IN OPERATION YELLOWBOY WAS ABOUT $16400/MMG/D (1102, 399 231). THUS AT A COST OF $0.015/KWH THE ENERGY REQUIREMENT TO 499 OPERATE A 1 MMG/D HYDRATED LIME PROCESS (ASSOCIATED WITH A 599 2EO6 TON/YR MINE) IS 1-115E10 BTU/YR. THU3 2.28EO8 BTU/YR OF 699 ENERGY IS REQUIRED TO TREAT THE OUTPUT ASSOCIATED WITH A 799 1..OE112 BTU/YR MINE. ON A I.OE12 BTU IN BASIS THIS AMOUNTS TO 899 Preceding page blank 111-37 FTN. 1102-1104 1.31E08 BTU FOR ROOM AND PILLAR MINES AND 1.95E8 BTU FOR 999 LONGWALL MINES. THIS ENERGY CONSUMPTION IS IN ADDITION TO 1099 THE POWER UTILIZED DURING NORMAL MINING OPERATIONS (FOOTNOTE 1199 1827). 1299 1102 199 SOLID WASTE PRODUCTION FOR A 1MMG/D HYDRATED LIME PLANT TREATING 299 A DRAINAGE COMPOSED OF 3000 PPM ACIDITY IS ABOUT 33 AC-FT/YR 399 (1102,233). ASSUMING A PRECIPITATE DENISTY OF 71 LBS/CF 499 (1114,288) SOLID WASTE IS GENERATED AT A RATE OF 51000 T/YR 599 FOR A 2MM TPY MINE. ON A 1.0E12 BTU IN BASIS THIS BECOMES 889 699 TON FOR LONGWAL MINING AND 596 TON FOR ROOM AND PILLAR. THIS 799 IS IN ADDITION TO THE SOLID WASTE PRODUCTION OF FOOTNOTE 1021. 899 IT SHOULD BE NOTED THAT, IN SOME CASES, THE SLUDGE PRODUCED 999 FROM THE TREATMENT FACILITY COULD BE DISPOSED INTO ABANDONED 1099 DEEP MINES (1103). THIS WOULD ELIMINATE LAND USE FOR DISPOSAL 1199 AND MAY POSSIBLY REDUCE SUBSIDENCE. CONDITIONS PERMITING, THIS 1299 APPEARS TO BE AN EFFECTIVE MEANS FOR DISPOSAL OF THE SLUDGE. 1399 1103 199 FOR CONTOUR MINING (SLOPES GREATER THAN 15 DEGREES) IT IS ASSUMED 299 THAT THE MODIFIED BLOCK CUT METHOD IS EMPLOYED. 399 THE THICKNESS OF THE SEAM IS 3.8FT. THUS 6.12 AC OF LAND ARE 499 OVERTURNED PER 1.0E12 BTU IN. AT THE SAME TIME 1776 FT OF 599 BENCH ARE CREATED (FOOTNOTE 1037). ASSUMING STRIPS OF LAND 699 50 FT WIDE ARE AFFECTED FOR THE DIVERSION DITCH AND FOR THE 799 STORAGE OF TOP SOIL ON THE OUTSLOPE. AN ADDITIONAL 4.08 AC 899 ARE DISTURBED FOR EACH 1.0E12 BTU IN. 999 THE SOLID WASTE GENERATED DURING THE BOX CUT (FOOTNOTE 1104) 1099 IS DISPOSED OF BY THE PARALLEL SLOPE METHOD. THE ANGLE AT THE 1199 TOE OF FILL IS 35 DEGREES. IN A PILE 40 FT HIGH. THE TOE 1299 REACHES 400 FT DOWNSLOPE FROM THE OUTCROP. HENCE, 1.69 AC 1399 (FIXED LAND USE) ARE DISTURBED. 1499 IN TIME AVERAGING THE LAND IMPACTS, CONSIDERATION MUST BE GIVEN 1599 TO THE EFFECTS OF RECLAMATION, WHICH IN THIS CASE IMPLIES 1699 CONTOUR BACKFILLING, SEED BED PREPARATION, TERRACING AND 1799 REVEGETATION. THE CRITERION FOR REVEGATATION IS THE ESTABLISH- 1899 MENT OF AN HERBACEOUS COVER SUFFICIENT TO STABILIZE THE SUR- 1999 FACE AGAINST EROSION. OTHER RECLAMATION PRACTICES, E.G., 2099 REFORESTATION, CAN BE OCCURING SIMULTANEOUSLY. 2199 IN APPALACHIA, WHERE MOST CONTOUR MINING IS PRACTICED, 3 2299 GROWING SEASONS ARE REQUIRED TO ESTABLISH A 95 PC COVER OF 2399 GRASS AND LEGUMES (1101). EMPLOYING THIS TIME SCALE AS A 2499 STANDARD. THE TIME AVERAGED (OVER 25 YRS) LAND IMPACT OF THE 2599 VARIABLE LAND USE (10.2 AC/1.0E12 BTU) IS 28.8 AC-YR/1.0E12 2699 BTU IN. THE LAND IMPACT OF THE RECLAIMED WASTE IS NEGLIGIBLE 2799 RELATIVE TO THE OVERALL LAND IMPACTED. 2899 AN ADDITIONAL 3.08 AC OF LAND IS UTILIZED FOR A SETTLING POND 2999 10 FT IN DEPTH WITH A CAPACITY OF 10 MMGAL. THE TREATMENT 3099 FACILITY (SODA ASH) TO NEUTRALIZE THE ACID RUNOFF OCCUPIES 3199 VERY LITTLE LAND (FOOTNOTE 1105). THUS, FOR A PRODUCTION 3299 CAPACITY OF 2 MMT/YR, THE LAND IMPACT IS 0.050 AC-YR/1.0E12 3399 BTU IN. 3499 THE TOTAL LAND IMPACT IS THEREFORE, 28.9 AC-YR/1.0E12 BTU IN. 3599 1104 199 FOR THE MODIFIED BLOCK CUT MINING TECHNIQUE, SOLID WASTE IS PRO- 299 DUCED ONLY DURING THE BOX CUT. HENCE, FOR A SLOPE ANGLE OF 399 20 DEGREES, A BENCH WIDTH OF 150 FT, A 15 FT RIM OF BLOSSOM 499 COAL, AND A BOX CUT OF 600 FT IN LENGHT, 0.148 MMT OR 96.8 599 T/1.0E12 BTU IN OF SOLID WASTE IS PRODUCED (SUBSEQUENT TO THE 699 BOX CUT 50 MMT OF COAL IS REMOVED OVER A 25 YR PERIOD). THE 799 III-38 FTN. 1105-1106 LENGTH OF THE BOX CUT IS BASED ON 250 FT LONG SECOND AND 899 JHIRD CUTS (1104) AND ALLOWS FOR EXPANSION. 999 THE SLUDGE PRODUCED FROM THE SODA ASH TREATMENT PROCESS IS 1099 ABOUT 4P BY VOLUME (EXTRAPOLATED FROM INFORMATION ON CONSOL. 1199 COAL CO. PROCESS, REF. 1106). THUS FOR THE TREATMENT OF 0.5 1299 MMG/D (FOOTNOT@ 1106), THE SOLID WASTE IS GENERATED AT A RATE 1399 OF 321 T/1.OE12 BTU IN. 1499 1105 199 ACID DRAINAGE FROM CONTOUR MINES IS NEUTRALIZED.BY A SODA ASH 299 TFEAIMENT PROCESS. THIS PROCESS IS IN MOST COMMON USAGE FOR 399 MINES WITH SMALL DRAINAGE (1105). THE FACILITY DESCRIBED HERE 499 IS ONE THAT IS UTILIZED BY CONSOLIDATED COAL COMPANY (1106). 599 THE FACIIITY TREATS A DRAINAGE WITH ABOUT 300 PPM ACIDITY AND 699 ALL FIGURES HAVE BEEN SCALED UP LINEARLY FOR TREATING A 0.5 799 MMG/D WITH AN ACIDITY CONCENTRATION OF 600 PPM (MINE DRAINAGE 899 POLLUTANT LOAD, FOOTNOTE 1041). THE COSTS (ASSOCIATED WITH 999 A 2EO6 TCN/YR MINE) ARE AS FOLLOWS 1099 l.'OE3 $ 1199 CAPITAL EXPENSE 62.0 1299 1399 ANNUAL EXPENSE 1.OE3 $/YR $/1.0E12 BTU IN 1499 REPAIR, MAINTENANCE, 1599 ETC. ($.11/1000 GAL) 13.2 1699 FOWER 1/1000 GAL) 12.0 179T SOrA ASH (6.7 LBS/1000 1899 GAL, $125/T) 52.8 1999 SUBTOTAL 78.0 1280 2099 2199 FIXED COST (10 PC OF 2299 CA PITAL EXPENSE) 6.2 102 2399 2499 THE COSTS OF MINING BY THE MODIFIED BLOCK CUT TECHNIQUE, 2599 INCLUDING RECLAMATION COSTS, ARE AS FOLLOWS (1028,,29) 2699, 2799 $/T $/l.OE12 BTU IN 2899 OPERATING EXPENSE 3.92 lZ8,600 2999 FIXED COST .54 17,700 3099 3199 THE ABOVE EST IMATES ARE BASED ON A MINING OPERATION WITH A 3299 PRODUCTION RATE OF 0.25 MMT/YR, A SEAM THICKNESS,OF 3 FT AND 3399 A HIGHWAIL 55 FT HIGH. THESE ARE NOT THE SAME SPECIFICATIONS 3499 FOR WHICH THE ENVIRONMENTAL IMPACTS WERE DETERMINED BUT ARE 3599 THE ONLY COST DATA AVAILABLE. IT SHOULD BE.NOTED THAT THE 3699 CCST OF FRODUCTION BY STRIP MINING IN TERMS OF U WIT ENERGY 3799 DISPLAYS SENSITIVITY MAINLY TO THE ECONOMIES OF SCALE (,1041,3)3899 NOTE THAT THE MINING METHOD USED IN THE CONTROLLED CASE 3999 DIFFERS FROM THAT USED IN THE UNCONTROLLED CASE. 4099 1106 199 SODIUM BASED ALKALIS EFFECTIVELY REMOVE ACIDITY, IRON, ALUMINUM 299 AND OTHER OXIDES, BUT WILL NOT-REMOVE THE SULFATES AS SODIUM 399 SULFATE IS A H'IGHLY SOLUBLE SALT (1102,130). THIS HAS BEEN 499 VERIFIED IN THE MEASUREMENTS OF THE EFFLUENTS FROM A SODA ASH 599 FACILITY, WHERE THE PH WAS RAISED TO ABOUT 7. THE ACIDITY 699 REDUCED TO 0, THE ALKALINITY TO 88 PPM AND THE IRON DOWN TO 799 0.9 PPM (1106). THE DISCHARGE TO NATURAL DRAINAGE IS ASSUMED 899 TO BE AS FOLLOWS (MINE DRAINAGE POLLUTANT LOAD,FOOTNOTE 1041. 999 .ALSO SEE FOOTNOTE 1105),FACILITY OPERATES 245.D/YR: 1099 111-39 FTN. 1107-1109 PPM T/1.0E12 BTU IN 1199 ACIDITY 0 0 1299 ALKALINITY 88.0 0.734 1399 1499 IRON 0.9 0.00753 1599 MANGANESE 1.5 0.0126 1699 ALUMINUM 0.5 0.00418 1799 SULFATE 13.1 1899 SODIUM 2.92 1999 SUBTOTAL 16.0 2099 2199 SUSPENDED SOLIDS 30.0 0.251 2299 2399 THE SUSPENDED SOLIDS ARE ASSUMED TO BE IN COMPLIANCE WITH THE 2499 GUIDELINES ESTABLISHED BY EPA (1112). 2599 1107 199 FOR AREA STRIPPING (SLOPE LESS THAN 15 DEGREES) 4.47 AC OF LAND 299 ARE OVERTURNED PER 1.0E12 BTU IN AND 0.133 ACY-YR IS OCCUPIED 399 BY THE SOLID WASTE PILE (FOOTNOTE 1001). WITH RECLAMATION, THE 499 LAND IS RESTORED TO THE ORIGINAL CONTOUR, GRADED TO MINIMIZE 599 EROSION AND REVEGETATED. FOR THE PURPOSES OF QUANTIFICATION 699 OF THE IMPACTS, STABILIZATION BY A HERBACEOUS COVER IS THE 799 CRITERION FOR DETERMINING RECLAMATION. 899 IN THE WEST, UPWARDS OF 5 YRS ARE REQUIRED TO ESTABLISH A 999 VEGETAL COVER (IT MAY NOT AT ALL BE POSSIBLE TO REESTABLISH A 1099 STABLE COVER IN THE ARID AND SEMI-ARID REGIONS) AND UPWARDS OF 1199 2 YEARS ARE REQUIRED IN APPALACHIA AND THE CENTRAL REGION (1100) 1299 SINCE MOST OF THE PRODUCTION (90P) OCCURS IN REGIONS OTHER 1399 THAN THE WEST, IT IS ASSUMED THAT 3 YRS ARE REQUIRED TO REES- 1499 TABLISH AN HERBACEOUS COVER TO STABILIZE THE SURFACE AGAINST 1599 EROSION (FOOTNOTE 1103). HENCE, THE TIME AVERAGED (OVER 25 1699 YEARS LAND IMPACT IS 12.6 AC-YR/1.0E12 BTU IN. 1799 ANOTHER 0.051 AC-YR/1.0E12 BTU IN IS UTILIZED FOR THE SODA ASH 1899 TREATMENT FACILITY (FOOTNOTE 1103). 1999 1108 199 IN THE MINING OPERATION SOLID WASTE IS GENERATED ONLY FROM THE BOX 299 CUT. THE WASTE AMOUNTS TO 347 T/1.0E12 BTU IN (FOOTNOTE 1009). 399 THE SLUDE PRODUCED FROM THE SODA ASH TREATMENT FACILITY IS 499 ABOUT 4P BY VOLUME (EXTRAPOLATED FROM INFORMATION OF CONSOL. 599 COAL CO. PROCESS, REF. 1106). THUS FOR THE TREATMENT OF 0.5 699 MMG/DAY THE SOLID WASTE IS GENERATED AT A RATE OF 325 T/1.0E12 799 BTU IN (FOOTNOTE 1104). 899 1109 199 A SODA ASH TREATMENT PROCESS IS UTILIZED FOR TREATING THE ACID 299 DRAINAGE (FOOTNOTE 1105). THE FACILITY TREATS 0.5 MMG/DAY 399 (ASSOCIATED WITH A 2.0E06 TON/YR MINE) WITH AN ACID 499 CONCENTRATION OF 700 PPM. THE COST FIGURES ARE AS FOLLOWS 699 CAPITAL EXPENSES $62,000 799 899 999 ANNUAL EXPENSES $/YR $/1.0E12 BTU IN 1099 REPAIR,MAINT.,ETC. ($.11/1000 GAL) $13,200 1199 POWER ($.1/1000 GAL) 12,000 1299 SODA ASH ($125/T,5.9LBS/1000 GAL) 46,200 1399 TOTAL 71,400 1190 1499 1599 FIXED COST (10P OF CAPITAL EXPENSE) 6,200 103 1699 GRAND TOTAL 79,600 1290 1799 THE CAPITAL COST FIGURES INCLUDE THE COSTS OF A 10 MMG LAGOON. 1899 THE TREATMENT FACILITY,PIPES,ETC. THE LAND IS ASSUMED TO BE 1999 AVAILABLE. 2099 III-40 FTN. 1110-1112 IN CASES WHERE AREA MINES ARE BEING WORKED BELOW THE WATER 2199 TABLE,A LARGER TREATMENT FACILITY MAY BE REQUIRED. DUE TO THE 2299 HIGH COST CF SODA ASH,A LIME OR LIMESTONE PROCESS WOULD THEN 2399 BE UTILIZED. 2499 GRADING THE SPOIL BANKS TO THE ORIGINAL CONTOUR AND REDUCING 2599 THE SLOPES OF THE HIGHWALL INCURS AN ADDITIONAL EXPENSE OF 2699 ABOUT $500/AC ($400 TO REDUCE THE BANKS TO A 5/1 SLOPE (1108, 2799 32). COMFLETE LEVELING COSTS AN ADDITIONAL $100,(.1109)). THE 2899 COST FOR RECLAIMING THE TOPSOIL IS APPROXIMATELY $400/AC IF 2999 THE,WORK IS DONE WITH SCRAPERS AND STOCKPILED ONCE (1100). THE3099 COST FOR REVEGETATION IS ABOUT $300/AC (1110,6). HENCE, 3199 THE TOTAL COST OF RECLAMATION AMOUNTS TO $1200/AC or $5370/ 3299 .l.OE12 BTU IN, WHICH INCLUDES THE COST FOR RECLAIMING THE 3399 SOLID WASTE PILE (S.EE FOOTNOTE 1001). 3499 THE TOTAL-COST IN ADDITION TO THE USUAL MINING OPERATION IS 3599 $6660/1.OE12 BTU IN (FOOTNOTE 1067). 3699 1110 199 THE DISCHARGE FROM THE TREATMENT FACILITY TO THE NATURAL DRAINAGE 299 IS ASSUMED TO HAVE THE FOLLOWING COMPOSITION((FOOTNOTE 1020 399 FOR RAW WASTE LOAD, ALSO FOOTNOTE 1106 AND 1109). 499 PPM T/I.OE12 BTU IN 599 ACIDI;Y 0 0 699 ALKALINITY 88 0.744 799 899 'IRON 0.8 0.00677 999, MANGANESE 1.5 0.0127 1099 ALUMINUM 0.5 0.00424 1199 .SULFATES 12.2 1299 SODIUM 2.61 1399 TOTAL 14.8 1499 SUSPENDED SOLIDS 30.0 0.254 1599 1699 1799 THE SUSPENDED SOLIDS ARE ASSUMED TO BE IN COMPLIANCE WITH THE 1899 GUIDELINES ESTABLISHED BY EPA (1112).. THE TREATMENT FACILITY 1999 IS ASSUMED TO OPERATE 245 D/YR. 2099 lill. 199 AT $0.015/KWH THE ENERGY CONSUMED BY THE SODA ASH TREATMENT FACI- 299 LITY IS 8.16E9 BTU (FOOTNOTE 1109) FOR A 2E6 TPY MINE OR 399 1.36E8 BTU/1.OE12 BTU IN. THE TOPSOIL IS HANDLED BY A SCRAPER 499 AND THE SOIL BANKS ARE LEVELED WITH A BULLDOZER. ASSUMING 599 THE ENERGY CONSUMPTION BY THE DOZER IS CHARACTERISTICALLY 699 SIMILAR TO THAT FOR A SCRAPER, THE ENERGY CONSUMPTION IS AS 799 FOLLOWS (1111,476). 899 I.OE9 BTU 999 1099 TOPSOIL (4750 CY/1.OE12 BTU IN, PERFOR- 0.101 1199 MANCE OF 75 CY/HR AND 11.34 GAL/HR) 1299 RECLAMATION (.35600 CY/I.OE12 BTU IN, PER- 0.222 1399 FORMANCE OF 250 CY/HR AND 11.34 GAL/HR) 1499 1599 THUS, FOR I.OE12 BTU IN THE TOTAL ENERGY REQUIREMENT FOR 1699 CONTROLS IS 4.59EO8 BTU AND IS IN ADDITION TO THAT FROM THE 1799 USUAL MINING OPERATION (FOOTNOTE 1806). 1899 1112 199 THE DRAINAGE FROM AUGER MINES HAS BEEN ASSUMED TO THE.SAME AS 299 THAT FROM CONTOUR MINES (FOOTNOTE 1019). THUS, A SIMILAR 399 WATER TREATMENT FACILITY IS UTILIZED AND THE EFFLUENT LOADING 499 IS THEREFORE THE SAME (FOOTNOTE 1106). THE TABLE ENTRIES 599 DIFFER BECAUSE OF THE PRIMARY EFFICIENCY DIFFERENCE. 699 111-41 FTN. 1113-1116 1113 199 IN AUGER MINING THE BEACH AND SPOIL PILE COVER AN AREA OF 2.71 299 AC FOR EVERY 1.0E121 BTU IN AND AN ADDITIONAL 1.38 AC/1.0E12 399 BTU IN ARE AFFECTED BY SUBSIDENCE (FOOTNOTE 1026). 499 RECLAMATION INCLUDES CONTOUR BACKFILLING AND REVEGETATION AS 599 WELL AS PLUGGING THE FIRST 6 FT OF THE AUGER HOLE TO MINIMIZE 699 DRAINAGE PROBLEMSJ (1051,31). 799 IT IS ASSUMED THAT 3 YRS ARE REQUIRED TO REESTABLISH AN 899 HERBACEOUS COVER TO STABILIZE THE SURFACE (FOOTNOTE 1103). 999 HENCE, THE TIME AVERAGED (OVER 25 YRS) LAND IMPACT IS 7.64 1099 AC-YR/1.0E12 BTU IN FOR THE BENCH AND SPOIL PILE AND 17.3 1199 AC-YR/1.0E12 BTU IN FOR THE SUBSIDED AREA. 1299 AN ADDITIONAL 0.029 AC-YR/1.0E12 BTU IS AFFECTED BY THE SODA 1399 ASH TREATMENT FACILITY (FOOTNOTE 1103). 1499 1114 199 THE SOLID WASTE PRODUCED FROM AUGER MINES IS 41300 T/1.0E12 BTU IN 299 (FOOTNOTE 1070). THE ADDITIONAL SOLID WASTE PRODUCED FROM THE 399 DRAINAGE TREATMENT FACILITY AMOUNTS TO 184 T/1.0E12 BTU IN 499 (FOOTNOTE 1101. THE TREATMENT FACILITY USED AT CONTOUR MINES 599 IS UTILIZED FOR AUGER MINES). 1115 199 THE COSTS INVOLVED IN OPERATING THE SODA ASH TREATMENT FACILITY 299 ARE AS FOLLOWS (FOOTNOTE 1105), oPERATING EXPENSE, $1280/1.0E 399 12 BTU IN. FIXED COST, $102/1.0E12 BTU IN. 499 RECLAMATION COSTS ARE AS FOLLOWS (SEET FOOTNOTE 1026). 599 699 $/AC $/1.0E12 BTU IN REFERENCE 799 CONTOUR BACKFILLING 351 453 (1102,29) 899 999 REVEGETATION 400 516 (1102,48) 1099 1199 THE ESTIMATED COST FOR BACKFILLING MAY BE INFLATED SINCE THE 1299 DATA ARE FOR RECLAMATION OF ABANDONED MINES. THE DATA WERE 1399 UTILIZED BECAUSE THEY APPLY SPECIFICALLY TO PARTS OF THE 1499 APPALACHIAN REGION. 1599 RECLAIMING THE TOPSOIL WILL COST ABOUT $400/AC. THIS ASSUMES 1699 THAT THE SOIL IS HANDLED ONLY MINIMALLY. STOCKPILING THE SOIL 1799 ABOVE THE HIGHWALL WILL MEET THIS REQUIREMENT. THE ADDITIONAL 1899 EXPENSE AMOUNTS TO $516/1.0E12 BTU IN. 1999 THE TOTAL INCREMENTAL COST TO THE USUAL AUGERING OPERATION IS 2099 $2870/1.0E12 BTU IN. 2199 THE NORMAL COST FOR AUGER MINING (FOR A 222,000 T/YR OPERA- 2299 TION) LESS HAULAGE TO TIPPLE AND RECLAMATION IS $3650/1.0E12 2399 BTU IN FOR FIXED COST AND $29400/1.0E12 BTU IN FOR OPERATING 2499 COST (REF. 1052 AND FOOTNOTE 1066). 2599 1116 199 THE ENERGY CONSUMED BY THE SODA ASH TREATMENT FACILITY IS 7.69E7 299 BTU/1.0E12 BTU IN (FOOTNOTE 1105, AT $0.015/KWH). THE ENERGY 399 UTILIZATION FOR RECLAMATION IS ASSUMED TO BE SIMILAR TO THAT 499 FOR AREA MINES EXCEPT FOR THE LESSER AMOUNT OF MATERIAL 599 HANDLED IN THIS CASE (43P OF THE MATERIAL HANDLED BY AREA 699 MINES). THUS, THE ENERGY CONSUMED IS 0.14E9 BTU/1.E12 BTU IN 799 (SEE FOOTNOTE 1111). THUS FOR 1.0E12 BTU IN THE ENERGY RE- 899 QUIREMENT FOR CONTROLS IS 2.17E8 BTU AND IS IN ADDITION TO 999 THAT FROM THE USUAL MINING OPERATION (FOOTNOTE 1010). 1099 III-42 FTN. 1117-1120 1117 199 IT IS ASSUMED THAT THE EFFLUENTS WILL MEET THE STANDARDS ESTAB- .299 LISHED BY EPA (1112). IN LIME TREATMENT THE SULFATE LOAD WILL 399 BE REDUCED SINCE THE SOLUBILITY OF CALCIUM SULFATE IS 20dO PPM 499 (1113,24). THE HARDNESS WILL ALSO BE INCREASED. THE EFFLUENT 599 BREAK-DOWN IS AS FOLLOWS 699 T/1.OE12 BTU IN 799@ PPM ROOM AND PILLAR LONGWALL 899 SUSPENDED SOLIDS 30 0.285 0.394 999 ACIDITY 0 0 0 1099 ALKALINITY 60 0.570 0.788'@ 1199 1299 IRON 4 0.0386 0.0526 1399 MANGANESE 4 0.0386 0.052.6 1499 ALUMINUM 1 0.00946 0.0132 1599 CALCIUM SULFATE 2000 19.0 26,* 3 1699 TOTAL 2009 19.1 26.4 1799 1899 THE ALKALINITY FIGURE WAS OBTAINED FROM DATA IN REF. (1103). 1999 THE VOLUME OF DISCHARGE IS ABOUT 85P OF THE INFLOW VOLUME 2099 (i103)-OR .80 MMG/D FOR ROOM AND PILLAR MINES AND.74 MMG/D 219� FOR LONGWALL MINES (FOOTNOTE 1100) AND THE PLA14T IS 22.99 ASSUMED TO OPERATE 245 D/YR. 2399 1118 199 IT IS ASSUMED THAT THE TPFATMENT FACILITY WILL REQUIRE A 2MMG RAW 299 WATER STCRAGE POND AND A 100MMG SETTLING POND, AND THAT THE 399 LAND IS AVAILABLE (THE COST FOR SL'UDGE DISPOSAL IS INCLUDED 499 IN THE COSI ESTIMATESi bUT THE SIZE OF THE PONDS ARE NOT 599 STIPULATED). AT A DEPTH OF 10 FT FOR THE RAW WATER POND AND A 699 DEPTH OF 20 FT FOR THE SETTLING PCND, 15.5 AC OF LAND ARE 799 REQUIRED. THE TREATMENT,PLANT WILL REQUIRE ABOUT 3 AC (1114). 899 THUS, THE TOTAL LAND REQUIRED BY THE TREATMENT FACILITY IS 999 0.385 AC-YR/1.OE12. ON A 1,OE12 BTU IN BASIS THIS AMOUNTS TO 1099 0.329 AC-YR FOR LONGWALL AND 0.221 Ac-YR FOR ROOM AND PILLAR 1199 MINING. THIS LAND IMPACT IS ADDITIONAL TO THE LAND USAGE OF 1299 FOOTNOTES 1022 AND 1036 FOR ROOM AND PILLAR AND LONGWALL 1399 MINING, RESPECTIVELY@ 1499 1119 199 PARTICULATE EMISSIONS FROM BY-PRODUCT COKING OPERATIONS CAN BE 299 REDUCED AS FOLLOWS. CHARGING PARTICULATE EMISSIONS CAN BE 399 VIRTUALLY ELIMINATED BY THf USE OF A PIPELINE CLOSED CHARGING 499 SYSTEM (1117,190). PUSHING PARTICULATE EMISSIONS CAN BE 599 LCWERED BY 99.8P BY THE USE OFA COLLECTING HOOD CONNECTED TO 699 A VENTURI SCRUBBING AND CYCLONE SEPARATOR SYSTEM (1118,14). 799 THE RESULTING PARTICULATE EMISSIONS AMOUNT TO .5232 LB/TON OF 899 COAL COKED (FROM (0002,7-4)AND FOOTNOTE 1028) OR 10.2 TON/1.0 .999 E12 BTU. 1099 1120 199 (1119) LISTS THE EFFLUENT LIMITATIONS FOR COKE MANUFACTURING BASED 299 ON THE USE OF BEST PRACTICAL CONTROL TECHNOLOGY CURRENTLY 399 AVAILABLE. THE CONTROL TECHNCLOGY USED TO ACHIEVE THESE 499 (TREATMENT LEVEL A) VALUES INCLUDES AMMONIA STILLS, A CYANIDE 599 STRIPPING STILL, RECYCLE OF COOLING EFFLUENTS, A DISSOLVED AIR 699 k' FLOTATION.UNIT, AND A PHENOL BIO-OXIDATION SYSTEM. THE 799 CCNTRO,LLED DISCHARGE LEVEL IS 899 FOLLUTANT LBS/TON DRY COAL TON/1.OE12 BTU IN 999 AMMCNIA(N) .20 3.71 1099 CYANIDE@ .005 .0927 1199 PHENOL .0002 .00371 1299 BOD5 .70 13.0 1399 111-43 FTN. 1121-1124 THE ABOVE NO. ARE BASED ON AN INPUT METALLURGICAL COAL WITH 5 1499 P MOISTURE AND A HEATING VALUE OF 13000 BTU/LB (SEE FOOTNOTE 1599 1C34). THE CONTROLLED BOD5 EMISSION GIVEN ABOVE IS BASED ON AN 1699 80P REDUCTION OF BOD5 IN THE PHENOL BIO-OXIDIZER (SEE FOOTNOTE 1799 1034). 1899 1121 199 BASED ON 100B REMOVAL OF PARTICULATES FROM COKE CHARGING AN 99.8P 299 REMOVAL FROM THE PUSHING OPERATION (SEE FOOTNOTES 1119 AND 399 1028). AN ADDITIONAL 2.099 LB SOLID WASTE/TON COAL COKED IS 499 GENERATED, OR 41.0 TON/1.0E12 BTU. THIS IS ADDED TO THE 599 UNCONTROLLED SOLID WASTE NO. (SEE FOOTNOTE 1029) TO GIVE A 699 TOTAL SOLID WASTE GENERATION OF 58.2 TON/1.0E12 BTU. BASED ON 799 FOOTNOTE 1030 THIS SOLID WASTE OCCUPIES .02 ACRE-YR/1.0E12 899 BTU. THE LAND REQUIRED FOR THE CHARGING AND PUSHING CONTROL 999 SYSTEMS CAN BE A SIGNIFICANT FRACTION OF THE LAND REQUIRED FOR 1099 THE COKE BATTERY (1120). IT HAS BEEN ASSUMED THAT THE LAND 1199 REQUIRED FOR CONTROLS AMOUNTS TO 25P OF THE LAND OCCUPIED BY 1299 THE COKE BATTERY. THUS 1.69 ACRE-YR/1.0E12 BTU IS REQUIRED FOR 1399 THE BATTERY AND SUPPORTING CONTROLS (SEE FOOTNOTE 1030). THE 1499 TOTAL LAND REQUIREMENT FOR THE COKE BATTERY AND CONTROL SYSTEM 1599 THEREFORE IS 1.71 ACRE-YR/1.0E12 BTU. 1699 1122 199 THE TOTAL ANNUAL COST FOR THE CONTROL OF AIR AND WATER EMISSIONS 299 HAS BEEN ESTIMATED TO BE 3P OF THE SELLING PRICE OF COKE FROM 399 (1118,18). NO ADDITIONAL INFORMATION HAS BEEN FOUND. THUS 499 BASED ON $37.41/TON OF COKE, 1.45 TON OF COAL TO PRODUCE 1 TON 599 OF COKE, AND 38500 TON COAL/1.0E12 BTU (FOOTNOTE 1047), 29800 699 $/1.0E12 BTU WOULD BE THE INCREMENTAL TOTAL COST FOR AIR AND 799 WATER CONTROLS. 899 1123 199 PARTICULATE EMISSIONS IN COMPLIANCE WITH THE NEW SOURCE 299 PERFORMANCE STANDARDS FOR COAL THERMAL DRYERS ARE LIMITED TO 399 .03 GRAIN/DSCF (1121). BASED ON 24000 DSCF/TON DRY COAL INPUT 499 TO DRYER (1121) AND 197.2 T/HR INPUT TO DRYER/5CO T/HR COAL 599 FEED TO PREP PLANT (FOOTNOTES 1813,1821,1822), THE PARTICULATE 699 EMISSION IS .833 TON/1.OE12 BTU AND CAN BE ATTAINED BY THE USE 799 OF A VENTURI-TYPE WET SCRUBBER AND MIST ELIMINATOR. THE SO2 899 AND NOX EMISSIONS ASSOCIATED WITH THE COMBUSTION OF COAL IN 999 THE THERMAL DRYER ARE GIVEN AS 4.5E-02 LB SO2 AND 5.35E-01 LB 1099 NOX PER 1.0E06 BTU COAL FIRED (1121). BASED ON 1 TON OF COAL 1199 COMBUSTED TO DRY 100 TONS IN A FLUIDIZED BED DRYER (1048), AND 1299 ON 26.2E06 BTU/TON OF COAL FED TO THE DRYER (FOOTNOTES 1813 1399 AND 1905), 9.67E-02 TON SO2 AND 1.15 TON NOX ARE EMITTED FOR 1499 EACH 1.0E12 BTU COAL INPUT TO THE METALLURGICAL PREP PLANT. 1599 EMISSIONS ASSOCIATED WITH THE BURNING COAL REFUSE PILE (SEE 1699 FOOTNOTE 1814) ARE COMPLETELY ELIMINATED BY RECLAMATION OF THE 1799 REFUSE PILE. BAHOUSES FOR CONTROL OF FUGITIVE DUST EMISSIONS 1899 ARE USED IN THE CONTROLLED MET PREP PLANT AT THE ROTARY 1999 BREAKER AND AT TRANSFER POINTS NEAR THE RAW COAL BINS, CLEANED 2099 COAL BINS, AND LOAD-OUT BINS, IN ORDER TO COMPLY WITH THE 10P 2199 OPACITY LIMIT FOR VISIBLE EMISSIONS FROM NEW PREP PLANTS (1121) 299 1124 199 SEEPAGE FROM THE REFUSE PILE IS ASSUMED TO BE COMPLETELY 299 ELIMINATED BY THE SOIL COVER ESTABLISHED IN RECLAIMING THE 399 REFUSE PILE. RUNOFF FROM THE REFUSE PILE. HOWEVER, CONTINUES 499 BECAUSE OF THE 3 YEAR TIME LAG ASSOCIATED WITH ESTABLISHMENT 599 OF AN HERBACEOUS COVER (SEE FOOTNOTE 1103). BASED ON 2.54 TON 699 SUSPENDED SOLIDS/ACRE-YR-IN RUNOFF AND ON 15 IN RUNOFF SEE 799 III-44 FTN. 1125-1126 FOOTNOTE lC72) AND 2.91E-01 ACRE-YR/J.OE12 BTU (FOOTNOTE 1128) 899 11.1 TON SUSPENDED SOLIDS/1.OE12 BTU ARE GENERATED IN RUNOFF 9.99 FROM THE RECLAIMED REFUSE PILE. SUSPENDED SOLIDS GENERATED IN 1099 THE PREP PLANT ARE ELIMINATED BYTHE USE OF A SETTLING POND. 119q 1125 199 IT HAS NOT BEEN POSSIBLE TO QUANTIFY FUGITIVE DUST EMISSIONS FROM 299 COAL PREP PLANTS. THUS IT IS NOT POSSIBLE TO QUANTIFY THE 399 INCREMENTAL SOLID WASTE GENEPATED BY THE USE OF BAGHOUSES TO 499 CONTROL THESE EMISSIONS. THEREFORE,THE SOLID WASTE GENERATED 599 IN THE CCNTPOLLED METALLURGICAL COAL PREP PLANT IS THE SAME AS 699 GIVEN IN FOOTNOTE 1613, NAMELY 8110 TON/1.OE12 BTU.. 799 1126 199 THE COST FOR CONTROLS ON A METALLURGICAL COAL PREP PLANT ARE GIVEN 299 IN THIS SECTION. 399 COSTS FOR CONTROLLING AIR EMISSIONS 499 THE CAPITAL COST FOR A VENTURI SCRUBBER AND MIST ELIMINATOR 599 FOR A 250 T/HR THERMAL DRYER IN A 500 T/HR COAL PREP PLANT IS 699 $200000 (1080,64). SCALING THIS BY A .6 EXPONENT GIVES A 799 CAPITAL COST FOR A SCRUBBER ON A 200 T/HR DRYER OF $175000(SEE 899 FOOTNOTE 1814). THE SCRUBBER ON THE DRYER IN (1080,64) IS FOR 999 A PLANT EaRCCESSING 1.74EC6 TON COAL/YR (500 T/HR AND 3480 HR/ 1099 YP OPERATION). THUS FOR A PLANT PROCESSING 41000 TON COAL/YR 1199 (EQUIVALENT TO 1.OE12 BTU/YR) THE ASSOCIATED CAPITAL COST FOR 1299 A VENTURI SCRUBBER-MIST ELIMINATOR SYSTEM IS 412 S/1.DE12 BTU 1399 (AT 10P FCR). THE OPERATING COSTS FOR A SCRUBBER ON A 250 T/ 1499 HP THERMAL DRYER AMOUNT TO 50350 $/YR (1080,81). SCALING THIS 1599 DIRECTLY FOR A 200 T/HR DRYER.AND SIZING THE RESULTING COST 1699. FOP A 1.rF12 BTtl/YP COAL PREP PLANT GIVES AN OPERATING COST OF1799 94� $/l.CE12 BTU'. 1899 THE CAPITAL COST FOR 7 BAGHOUSES TO CONTROL FUGITIVE DUST FROM1999 A 500 T/HP PREP PLANT IS $260000 (1080,64). THIS PLANT 2099 PROCESSES 1.74EO6 TON COAL/YR (BASED ON 3480 HR/YR OPERATION).2199 THUS FOR A PREP PLANT PROCESSING 41000 TON COAL/YR (1.OE12 BTU2299 /YR) THE ASSOCIATED CAPITAL COST IS 613 $/l.OE12 BTU (AT 10P 2399 FCF) . THE OPERATING COST FOR THE 7 BAGHOUSES, EACH RATED AT 2499 10000 CFM, IN THE 500 T/HR PREP PLANT IS 12500 $1YR (1080,73).2599 THUS THE OPERATING COST FOR BAGHOUSES IN A 1.OE12 BTU/YR COAL 2699 PREP PLANT IS 294 $/l.OE12 BTU. 2799 COSTS FOR RECLAMATION OF SOLID WASTES 2899 THE CAPITAL COST ASSOCIATED WITH RECLAMATION OF THE COAL PREP 2999 PLANT REFUSE PILE IS TAKEN AS THE AVERAGE CAPITAL COST FOR THE3099 IDAMAY MINE NO.44 (UNDERGROUND) IN BARRACKVILLE.W.VA., MINE 3199 19 (STRIP) IN HALLOWELI,KANSAS, AND-THE COLONIAL MINE (STRIP) 3299 IN MADISCNVILLE,KENTUCKY (1115,3) AND IS $314,300. THIS 3399 EQUIPMENT WAS USED TO RECLAIM AN AVERAGE OF 9.67EO6 TONS OF 3499 REFUSE (1115,5,10,19). BASED ON A TOTAL PLANT-LIFE REFUSE 3599 GENERATION OF 2.025ED5 TON FOR A 1.OE12 BTU/YR.MET PREP PLANT 3699 (8110 TON/YR FOR 25 YR (FOOTNOTE 1813)), THE CAPITAL COST IS 3799 660 $/YR (AT 10P FCR). THE 3-MINE AVERAGE OPERATING COST FG.R 3899 REFUSE DISPOSAL IS .16 $/TON-MILE. ASSUMING AN AVERAGE HAULAGE3999 DISTANCE OF 1 MILE AND 8110 TON REeUSE/YR (FOOTNOTE 1813) 4099 GIVES A REFUSE DISPOSAL COST OF 1297 $/I.OE12 BTU. THE AVERAGE4199 REFUSE SFFEADING AND COMPACTION COST (FOR THE IDAMAY AND 4299 COLONIAL MINES) IS GIVEN AS .08 $/TON uR 648 $/l.OE12 BTU. 4399 THE 3-MINE AVERAGE OPERATING COST FOR SOIL COVERING AND 449@9 PLANTING IS 832 $/ACRE. BASED ON 2.025EO5 TON REFUSE I GENERATED4599 OVER.THE 25 YR LIFETIME OF THE PREP PLANT AND AN ASSUMED 4699 111-45 FTN. 1127 REFUSE DENSITY AFTER COMPACTION OF .06 TON/CP, A TOTAL OF 4799 3.38E06 OF REFUSE MUST BE RECLAIMED. THIS REFUSE IS ASSUMED 4899 TO BE STACKED 30 FT HIGH AND SLOPED AT A 37 DEGREE ANGLE OF 4999 REPOSE. THE TOTAL LAND REQUIRED FOR RECLAMATION (ON THE SLOPES 5099 AND TOP) IS 3.42 ACRES. THE TOTAL SOIL COVERING AND PLANTING 5199 COST IS THUS $2840 BUT IS INCURRED OVER 25 YR OF PREP PLANT 5299 OPERATION . THE YEARLY COST IS $114. THE TOTAL OPERATING COST 5399 FOR RECLAMATION IS THE SUM OF COSTS FOR REFUESE DISPOSAL. 5499 REFUSE SPREADING AND COMPACTION, AND SOIL COVERING AND 5599 PLANTING OR 2059 $/1.0E12 BTU. 5699 COSTS FOR CONTROLLING WATER POLLUTANTS 5799 SUSPENDED SOLIDS CAN BE COMPLETELY ELIMINATED BY CLOSING THE 5899 WATER CIRCUIT THROUGH A SETTLING POND. FOR A 500 TON/HR PREP 5999 PLANT THE CAPITAL COST IS $136000 (1116). THE PLANT IN (1116) 6099 OPERATES 14 HR/D, 2500/YR AND PROCESSES 1.75E06 TON COAL/YR. 6199 THE CAPITAL COSTS FOR A 1.0E12 BTU/YR PREP PLANT IS THUS 319 6299 $/1.0E12 BTU (AT 10P FCR). (1116) GIVES THE OPERATING COSTS 6399 FOR THE SETTLING POND SYSTEM AS .0595 $/TON SUSPENDED SOLID 6499 THE TOTAL SUSPENDED SOLIDS GENERATED IN THE PREP PLANT IS THE 6599 SUM OF 205 TON FROM THE UNCONTROLLED METALLURGICAL PREP PLANT 6699 (FOOTNOTE 1815) AND 47.8 TON PRODUCED BY THE VENTURI WET 6799 SCRUBBER (THE DIFFERENCE IN PARTICULATE EMISSIONS FOR THE 6899 UNCONTROLLED THERMAL DRYER (FOOTNOTE 1814) AND CONTROLLED 6999 DRYER (FOOTNOTE 1123)), OR 252.8 TON SUSPENDED SOLIDS. THUS 7099 THE OPERATING COST FOR A SETTLING POND IS 15.1 $/1.0E12 BTU. 7199 BOTH CAPITAL AND OPERATING COSTS HAVE BEEN ESCALATED FROM 7299 THEIR 1965 BASIS TO 1972 $. 7399 CONTROL COST SUMMARY 7499 CAPITAL COST-$/1.0E12 BTU OPERATING COST-$/1.0E12 BTU 7599 412 THERMAL DRYER 949 THERMAL DRYER 7699 613 7 BAGHOUSES 294 7 BAGHOUSES 7799 660 REFUSE RECLAMATION 2059 REFUSE RECLAMATION 7899 386 WATER CLARIFICATION 18 WATER CLARIFICATION 7999 2071 TOTAL INCREMENTAL 3320 TOTAL INCREMENTAL 8099 CAPITAL COST FOR CONTROLS OPERATING COST FOR CONTROLS 8199 1127 199 THE ENERGY REQUIREMENTS ASSOCIATED WITH CONTROLS ON A 1.0E12 BTU/ 299 YR METALLURGICAL COAL PREP PLANT ARE GIVEN HERE. A VENTURI 399 SCRUBBER ON A 250 TON/HR THERMAL DRYER REQUIRES 2.69E06 KWH/ 499 YR (1080,81). SCALING THIS DIRECTLY FOR A 200 TON/HR DRYER, 599 SIZING THE RESULTING ENERGY REQUIREMENT FOR A 1.0E12 BTU/YR 699 COAL PREP PLANT (SEET FOOTNOTE 1126), AND CONVERTING THE KWH 799 INTO BTU BY 10200 BTU/KWH GIVES AN ENERGY REQUIREMENT FOR 899 OPERATION OF THE VENTURI SCRUBBER OF 5.19E08 BTU/1.0E12 BTU. 999 THE TOTAL POWER REQUIREMENT FOR THE 7 BAGHOUSES IN A 500 TON/ 1099 HR PREP PLANT IS 175 HP (1080,73) OR 4.55E-05 KWH/YR (BASED ON 1199 3480 HR/YR OPERATION). CONVERTING THIS BY 10200 BTU/KWH AND 1299 SIZING THE RESULT FOR A 1.0E12 BTU/YR PREP PLANT GIVE AN 1399 ENERGY REQUIREMENT OF 1.09E08 BTU/1.0E12 BTU. NO INFORMATION 1499 WAS AVAILABLE ON ENERGY REQUIREMENTS FOR REFUSE RECLAMATION. 1599 THE ENERGY REQUIRED FOR THE CLOSED CIRCUIT SETTLING POIND IS 1699 BASED ON .0378 $/TON SUSPENDED SOLIDS (1116) OR .0457 $/TON 1799 (ESCALATED TO 1972 COSTS), 252.8 TON SUSPENDED SOLIDS (FOOTNOTE 1899 1126) AND $.01/KWH TO GIVE 1.16E03 KWH/1.0E12 BTU OR 1.18E07 1999 BTU/1.0E12 BTU (CONVERTING AT 10200 BTU/KWH). THE SUM TOTAL 2099 INCREMENTAL ENERGY DEMAND ASSOCIATED WITH CONTROLS ON A 1.0E 2199 12 BTU/YR METALLURGICAL COAL PREP PLANT IS THUS 6.40E08 BTU/ 2299 1.0E12 BTU. 2399 III-46 FTN. 1128-1132 lu8 199 BASED' ON A SOLID WASTE PRODUCTION OF 8110 TON/I.OE12 BTU (FOOTNOTE 299 1813), A,COMPACTED REFUSE DENSITY OF .06 TON/CF, AND A 30 FT 399 HIGH REFUSE PILE, .103 ACRES OF LAND/1.OE12 BTU IS IMPACTED. 495 BASED ON A 3 YEAR TIME LAG TO ESTABLISH AN HERBACEOUS COVER 599' AND A 25 YR PLANT OPERATING LIFETIME, 2.82 TIMES THE YEARLY 699 LAND IMPACT REPRESENTS THE TIME AVERAGED LAND IMPACT (FOOTgOTE 799 1103). THUS .291 ACRE-YR/1.OE12 BTU IS THE TIME AVERAGED LAND 899 IMPACT. IHE LAND REQUIREMENT FOR THE MET COAL PEEP PLANT IS 999 1.95 ACRE-YR/l.-OE12 BTU (FOOTNOTE 1073) SO THAT THE TOTAL LAND1099 REQUIREMENT IS 2.24 ACRE-YR/1.OE12 BTU. 1199 1129 199 EMISSIONS ASSOCIATED WITH THE BURNING COAL REFUSE PILE (FOOTNOTE. -299 1074) ARE CCMPLETELY ELIMINATED BY RECLAMATIONOF THE REFUSt 399 PILE. BAGHOUSES FOR CONTFOL OF FUGITIVE DUST EMISSIONS ARE 499 USED IN THE CONTROLLED UTILITY PREP PLANT IN ORDER TO COMPLY 599 WITH THE 10P OPACITY LIMIT FOR-VISIBLE EMISSIONS FROM NEW PREP 699 PLANTS (1121). 799 1130 199 SEEPAGE FROM THE REFUSE PILE IS ASSUMED TO BE COMPLETELY. 299 ELIKINATED BY THE SOILCOVER ESTABLISHED IN RECLAIMING THE .399 REFUSE PILE. RUNOFF FROM THE REFUSE FILE, HOWEVER, CONTINUES 499 .BECAUSE CF THE 3 YEAR TIME-LAG ASSOCIATED WITH ESTABLISHMENT 599 OF AN HERBACEOUS COVER (FOOTNOTE 1103). BASED ON 2.54 TON 699 SUSPENDED SOLIDS/ACRE-YR-IN RUNOFF AND ON 15 IN RUNOFF (SEE 799 FOOTNOTE 1072) AND .135 ACRE-YR/I.OE12 BTU (FOOTNOTE 1134), 899 5.14 TON SUSPENDED SOLIDS/1.OE12 BTU ARE GENERATED IN RUNOFF @999 FROM THE RECLAIMED IFFUSE FILI, SUSPENDED SOLIDS GENERAT ED IN 1199 THE PREP PLANT ARE ELIMINATED BY THE USE OF A SETTLING POND. 1199 1131 199 IT HAS NOT BEEN FOSSIBLE TO QUANTIFY FUGITIVE DUST EMISSIONS FROM 299 COAL PREP PLANTS. THUS IT IS NOT POSSIBLE TO QUANTIFY THE 399 INCREMENTAL SOLID WASTE GENERATED BY THE USE OF BAGHOUSES TO 499 CONTROL THESE EMISSIONS. THEREFORE, THE SOLID WASTE GENERATED 599 IN THE CCNTROLLED UTILITY COAL PREP PLANT IS THE SAME AS GIVEN 699 IN FCOTNOTE 1071, NAMELY 3750 TON/1.OE12 BTU. 799 ..1132 199 THE COST FOR CONTROLS ON,A UTILITY COAL PREP PLANT ARE GIVEN HERE. 299 COSTS FOR CONTROLLING AIR EMISSIONS 399, THE CAPITAL COST FOR 7 BAGHOUSES TO CONTROL FUGITIVE DUST FROM 499 A 500 T/HR PREP PLANT IS $260000 (1080,64). THIS PLANT 599 PROC.ESSES 1.74EO6 TON COAL/YR (BASED ON 3480 HR/YR OPERATION). 699 THUS FOR A PREP PLANT PROCESSING 41000 TON COAL/YR (1.OE12 BTU 799 /YR) THE ASSOCIATED CAPITAL COST IS 613 $/l.OE12 BTU (AT 10P 899 FCR). THE OPERATING COST.FOR THE 7 BAGHOUSES, EACH RATED AT 999 1COOO CFM, IN THE 500 T/HR PREP PLANT IS 12500 $/YR (1080,73).1099. THUS THE OPERATING COST FOR BAGHOUSES IN A 1.OE12 BTU/YR COAL 1199 PREP PLANT IS 294 $/l.DE12 BTU. 1299 COSTS FOR RECLAMATION OF SOLID WASTES 1399 BASED ON .03255 $/TON REFUSE RECLAIMED (SEE FOOTNOTE 1126) AND1499 A TOTAL UTILITY PREP-PLANT-LIFE REFUSE GENERATION OF 9.38EO4 1599 TON (3754 TON/YR FOR 25 YR (FOOTNOTE 1071)), THE CAPITAL COST 1699 ASSOCIATED WITH RECLAMATION IS 305 $/YR .(AT 10P FCR). THE 1799 OPERATING COSTS FOR REFUSE DISPOSAL, SPREADING, AND COMPACTION1899 AMOUNT To $.24/TON REFUSE (FOOTNOTE 1126) SO THAT FOR 3754 TON1999 /YR A COST OF 900 $/l.OE12 BTU IS INCURRED. BASED ON 9.38EO4 2099 TON REFUSE GENERATED OVER THE 25 YR LIFETIME OF.THE UTILITY 2199 111-47 FTN. 1133-1134 PREP PLANT AND ON CRITERIA SET FORTH IN FOOTNOTE 1126, THE 2299 TOTAL LAND REQUIRED FOR RECLAMATION (ON THE SLOPES AND TOP) 2399 IS 1.78 ACRES. BASED ON A SOIL COVERING AND PLANTING COST OF 2499 832 $/ACRE THIS AMOUNTS TO $1480 INCURRED OVER 25 YR OF PLANT 2599 OPERATION, OR 59.2 $/YR. THE TOTAL OPERATING COST FOR 2699 RECLAMATION IS THUS 959.2 $1.0E12 BTU. 2799 COSTS FOR CONTROLLING WATER POLLUTANTS 2899 SUSPENDED SOLIDS CAN BE COMPLETELY ELMINATED BY CLOSING THE 2999 WATER CIRCUIT THROUGH A SETTLING POND. FOR A 500 TON/HR PREP 3099 PLANT, PROCESSING 1.75E06 TON COAL/YR, THE CAPITAL COST IS 3199 $136000 (1116). THUS FOR A 1.0E12 BTU/YR PREP PLANT THE 3299 CAPITAL COST IS #3190 (1965 $) OR 386 $/1.0E12 BTU (1972 $ AND 3399 10P FCR). (1116) GIVES THE OPERATING COSTS FOR THE SETTLING 3499 POND SYSTEM AS .0595 $/TON SUSPENDED SOLIDS. THE TOTAL 3599 SUSPENDED SOLIDS GENERATED IN THE UTILITY PREP PLANT IS 41 3699 TONS/1.0E12 BTU (FOOTNOT 1072). THUS THE OPERATING COST FOR 3799 A SETTLING POND IS 2.95 $/1.0E12 BTU (1972 $). 3899 CONTROL COST SUMMARY 3999 CAPTIAL COST-$/1.0E12 BTU OPERATING COST-$/1.0E12 BTU 4099 613 7 BAGHOUSES 294 7 BAGHOUSES 4199 305 REFUSE RECLAMATION 959 REFUSE RECLAMATION 4299 386 WATER CLARIFICATION 3 WATER CLARIFICATION 4399 1304 TOTAL INCREMENTAL 1256 TOTAL INCREMENTAL 4499 1133 199 THE TOTAL POWER REQUIREMENT FOR THE 7 BAGHOUSES IN A 500 TON/HR 299 PREP PLANT IS 175 HP (1080,73) OR 4.55E05 KWH/YR (BASED ON 399 3480 HR/YR OPERATION). CONVERTING THIS BY 10200 BTU/KWH AND 499 SIZING THE RESULT FOR A 1.0E12 BTU/YR PREP PLANT GIVES AN 599 ENERGY REQUIREMENT OF 1.095E08 BTU/1.0E12 BTU. NO INFORMATION 699 WAS AVAILABLE ON ENERGY REQUIREMENTS FOR REFUSE RECLAMATION. 799 THE ENERGY REQUIRED FOR THE CLOSED CIRCUIT SETTLING POND IS 899 BASED ON .0457 $/TON SUSPENDED SOLIDS (FOOTNOTE 1126), 41 TONS 999 OF SOLIDS (FOOTNOTE 1072), AND $.01/KWH TO GIVE 1.87E02 KWH/ 1099 1.0E12 BTU OR 1.91E06 BTU/1.0E12 BTU (CONVERTING AT 10200 BTU 1199 /KWH). THE SUME TOTAL INCREMENTAL ENERGY DEMAND ASSOCIATED WITH 1299 CONTROLS ON A 1.0E12 BTU/YR UTILITY COAL PREP PLANT IS THUS 1399 1.114E08 BTU/1.0E12 BTU. 1499 1134 199 BASED ON A SOLID WASTE PRODUCTION OF 3750 TON/1.0E12 BTU (FOOTNOTE 299 1071), A COMPACTED REFUSE DENSITY OF .06 TON/CF, AND A 30 FT 399 HIGH REFUSE PILE, .048 ACRES OF LAND/1.0E12 BTU IS IMPACTED. 499 BASED ON A 3 YEAR TIME LAG TO ESTABLISH A HERBACEOUS COVER 599 AND A 25 YR PLANT OPERATING LIFETIME, 2.82 TIMES THE YEARLY 699 LAND IMPACT REPRESENTS THE TIME AVERAGED LAND IMPACT (FOOTNOTE 799 1103). THUS .135 ACRE-YR/1.0E12 BTU IS THE TIME AVERAGED LAND 899 IMPACT. THE LAND REQUIREMENT FOR THE UTILITY COAL PREP PLANT 999 IS 1.95 ACRE-YR/1.0E12 BTU (FOOTNOTE 1073) SO THAT THE TOTAL 1099 LAND REQUIREMENT IS 2.09 ACRE-YR/1.0E12 BTU. 1199 III-48 FTN. 1135-1137 1135 199 SEDIMENT RUNOFF FROM COAL HAULAGE ROADS CAN BE CONTROLLED BY 299 DITCHING ALONGSIDE THE ROADS AND DIVERTING THE RUNOFF TO 399 SMALL SETTLING PONDS. THE COST FOR DITCHING IS SMALL AND IS 499 FORMALLY A PART OF THE ROAD CONSTRUCTION AND MAINTENANCE COST. 599 THE CAPITAL COST FOR THE SETTLING POND IS TAKEN AS $20000 699 (1100) AND 5 PONDS ARE ASSUMED FOR A ROAD SERVICING A 2EO6 TON 799 /YR MINING OPERATION. THUS 205. $/I.OE12 BTU IS THE FIXED 899 COST. INFORMATION ON OPERATING COSTS WAS NOT AVAILABLE. 999 1136 199 THE ENERGY CONSUMED BY THE SO DA ASH TREATMENT FACILITY IS 8.16EO9 299 BTU/YR (FOOTNOTE 1105, AT $0.015/KWH) AND IS ASSOCIATED WITH 399 A 2E06 TON/YR MINE. FOR 1.OE12 BTU IN THIS ENERGY REQUIREMENT 499 IS 1.34EO8 BTU. THIS ENERGY CONSUMPTION IS PROBABLY MINOR IN 599 COMPARISON TO THAT FOR THE MINING METHOD ITSELF. HOWEVER, 699 ENERGY CONSUMPTION DATA FOR A MODIFIED BLOCK CUT TECHNIQUE 799 WAS NOT AVAILABLE AND WAS THUS ASSUMED SIMILAR TO THAT FOR 899 CONVENTIONAL CONTOUR'STRIPPING, I.E. 1.07EIO BTU/1.OE12 BTU IN.999 1137 199 IT IS ASSUMEE THAT A SETTLING POND IS REQUIRED FOR EACH MILE OF .299 ROAD AND THAT EACH PONE USES AN ACRE. THUS, 5 AC ARE UTILIZED 399 FOR THE SETTLING PONDS (THE HAUL ROAD IS 5.3 MI IN LENGTH, 499 FOOTNOTE 1004). THE LAND IMPACT IS 0.103 AC-YR/1.OE12 BTU. 599 THIS IS IN ADDITION TO THE LAND IMPACTED BY THE ROAD 0.712 699 AC-YR/1.OE12 BTU (FOOTNOTE 1004) 799 111-49 EOM--- -t, S 4 5 6 1 A F-F-- T- 11 12 IS L.- I1 1. 21 21 E WATER POLLUTANTS @TONS/ ID" ?-U. E- tCL JOE POLLUTANTS (r-o" ml OCCUPATIONAL H @@LTH PITEE-Al SOLIDS __CA LA- -aA A. NSNE ACIOOTI PROCESS DIS, @D SOLIDS .1DRo- ALCE. VION o. OTHER TOTAE DE) SOL' D, -S BOD CO. PER so@ CAJN@ CO TOTAL TONS I IJI@Z.@E-D-., F-i A T. AUEN-a. iErM E TC' 7 an ECET .8 11A cAEr- ACIDS ASE,S I %'S 6.7, ULATE!S - o- LosTidto O'SASEEER PrT --c ) oc u 1 1. loom 7Ron 7 2 2 LJ, 4 -.L 4 6 O't 1.-10 0', OUNOO Ell - - - --- ---- Ol Oil N, Aim. 2 IS ON' 12 IS ZS 9 21 2" BA _�4 B9 55 44 AD 41 46 47 .4 48 ME: ALL TABLE EXTRIES ARE BASED D' A ID12.BTU OF EESOj2CE 111TO EA ED ACI I 1".111111TI. A:11A,:@S ... ...... E "oo FOR 111, SULFUR D DO [email protected]@ OF NoRT"W"I'll COAL ARD BE, LSc2 B T U14CONTROLLED:NORTHWEST REMON op, COAL SUPPLY 51 Receding a e b a BA t4 53 ] '4 4' ED FTN. 1260-1203 FOOTNOTES FOR TABLE 3 1200 199 THE NORTHWEST@REGION FOR THIS STUDY IS COMPRISED SOLELY OF THE 299 POWDER RIVER BASIN. THE AVERAGE CALORIC CONTENT OF THE COAL 399 DELIVERED TO ELECTRIC UTILITIES IN MONTANA AND W YORING DURING 499 THE 3RD AND 4TH QUARTERS OF 1972 WAS ABOUT 8780 BTU/LB AND THE 599 SULFUR CONTENT WAS APPROXIMATELY 0.85PC(1212,AND 1213). THE 699 AVERAGE ASH CONTENT OF COAL FROM THE BIG SKY AND COLSTRI P .799 MINES IN MONTANA AND THE BIG HORN MINE IN WYOMING IS 6.177P 899 AS RECEIVED (1026 AND 12C2). THE DENSITY OF THE COAL FROM THIS 999 REGIONIS 81 LB/CF (1201). 1099 FOR THE:COAL IN THIS REGION 1.OE12 BTU IS THE EQUIVALENT OF 1199 57000 T. ALL.THE COMPUTATIONS ARE BASED ON 1.OE12 BTU. 1299 NONE OF THE SURFACE MINED COAL OF THIS REGION IS SUBJECTED TO 1399 ANY FREPARATION EXCEPT CRUSHING AND SIZING (1004,47). ALTHOUGH149 '9 WASHABILITY STUDIES INDICATE THAT THESE COALS CAN BE WASHED 1599 (1216 AND 1217), MORE ELABORATE PREPARATION IS NOT FORESEEN 1699 (1008 A'ND 1021). 1799 1201 199 THE OCCUPATIONAL HEALTH IMPACTS WITH RESEECT TO DEATH (FATALITIES),299 INJURIES (NON-FATALITIES) AND WORK DAYS LOST ARE BASED ON THE 399 STATISTICS PRESENTED IN (1200)'THROUGH (1210). - 499 THE WORK-DAYS LOST PER INJURY QUANTITIES DURING STRIP MINING 599 RESULT FROM AVERAGE SEVERITY STATISTICS TABULATED IN THE 699 PFEVIOUSLY CITED REFERENCES. AVERAGE SEVERITY IS DEFINED BY 799 THE BUREAU OF MINES AS BEING THE NUMBER OF DAYS CHARGED 899 (OR LOST) DIVIDED BY THE NUMBER OF INJURIES. AVERAGE SEVERITY 999 QUANTITIES WERE USED BASED ONTHE NUMBER OF TERPORARY TOTAL 1099 DISABILITIES, THE OVERWHELMINGLY, LARGEST CATEGORY OF, NON-FATAL 1199 INJURIES. TEMPORARY TOTAL DISABILITY IS DEFINED AS ANY NON- 1299 FATAL INJURY THAT DOES NOT RESULT IN PERMANENT IMPAIRMENT,BUT 1399 THAT RENDERS THE INJURED PERSON UNABLE TO PERFORM A REGULARLY 1499 ESTABLISHED JOB. THEREFORE,AS A RESULT OF STRIP MINING, AN 1599 AVERAGE OF 24*8 WORK-DAYS LOST PER INJURY ITEMPORARY TOTAL 1699 DISABILITY) IS DERIVED FOR MONTANA AND WYOMING 1799 FOR THE YEARS 1964-1966,1968 AND 1969. 1899 . 1202. 199 THE 'HAULAGE' STATISTICS PUBLISHFD IN (1206) THRU (1210) WERE 299 EMPLOYED HERE. HAULAGE ENCOMPASS,ES A BROAD 399. CATEGORY.WHICH INCLUDES THE FOLLOWING TRANSPORTATION MODES FOR 499 THE COAL-(1)FROM AN UNDERGROUND MINE TO THE SURFACE BY RAIL 599 AND 2)FRCM THE SURFACE TO THE COAL PREPARATION PLANTS BY TRUCK. AFTER STRIP MINING IN THE STATES OF MONTANA AND 799 WYOMINGf NO FATALITIES FOR COAL HAULAGE WERE REPORTED OVER 899 THE YEARS 1964-1966,1968 AND 1969. AN AVERAGE OF 0.473 NON- 999 FATALITIES /1.OE6 TONS PRODUCTION WAS COMPUTED FOR COAL 1099 HAULAGE, OCCURRING PRIMARILY IN WYOMING. 1199 ANAPPROXIMATE AVERAGE OF 25 WORK-.DAYS LOST PER INJURY IS 1299 ASSUMED FOR TRANSPORT FOLLOWING STRIP MINING. THIS QUANTITY 1399 RESULTS FFCM AVERAGING THE WORK-DAYS LOST/INJURY 1499 FOR MONTANA AND WYOMING. THE BASIC STATISTICS ON AVERAGE 1599 SEVERITIES WERE COMPRISED OF CONTRIBUTIONS DUE TO'STRIP 1699 MINING AND HAULAGE. THE RELATIVE CONTRIBUTION 'OF EACH CANNOT 1799 BE ISOLATED. 1899 1203 199 THE STATISTICS UNDER 'MECHANICAL CLEAN,ING PLANTS9 OR 'COAL PRE..FAPATICN PLANTS' WERE EMPLOYED AS TABULATED IN REFERENCES 399 1208-1210.IN THE YEARS 19b4-1966,1968 AND 1969, NO FATALITIES 499 WERE PEFOFTED UNDER THESE CATEGORIES FOR THE STATES OF MONTANA 599 111-53 Preceding page blank FTN. 1204-1209 AND WYOMING. AN AVERAGE OF 0.0505 NON-FATALITIES /1.0E6 TONS 699 PRODUCTION OCCURRED AT MECHANICAL CLEANING PLANTS, LOCATED 799 PRIMARILY IN WYOMING. 899 AVERAGE SEVERITY STATISTICS (DEFINED IN FOOTNOTE 1201) HAVE 999 ONLY BEEN PRESENTED IN THE MORE RECENT REPORTS ENTITLED, 1099 'INJURY EXPERIENCE IN COAL MINING'. 1199 THEREFORE MAN-DAYS LOST PER INJURY COULD ONLY BE OBTAINED 1299 FROM AVERAGING THE AVAILABEL STATISTICS FOR THE YEARS 1966, 1399 1968 AND 1969. UNDER COAL PREPARATION, AN AVERAGE OF 51.5 1499 WORK-DAYS LOST PER INJURY (TEMPORARY TOTAL DISABILITY) WAS 1599 COMPUTED FOR THE STATES OF MONTANA AND WYOMING. 1699 1204 199 IN 1969 THE AVERAGE HAULAGE DISTANCE FROM STRIP MINE TO TIPPLE WAS 299 1.5 MILES (0001,344). DATA FROM STUDIES CONDUCTED IN EASTERN 399 KENTUCKY (1024)&(1031) THRU (1034) INDICATE AN AVERAGE 499 HAULAGE ROAD RIGHT-OF-WAY OF 6.4 AC / MI. ASSUMING AN ANNUAL 599 PRODUCTION OF 2MMT. 2.85PC OF ROAD USAGE IS ATTRIBUTABLE TO THE 699 TRANSPORT OF 1.0E12 BTU EQUIVALENT T. HENCE, THE LAND IMAPCT 799 IS 0.274 AC-YR / 1.0E12 BTU. 899 1205 199 THE AVERAGE DENISTY OF COAL IN MONTANA IS APPROXIMATELY 81 LB/CF 299 (FOOTNOTE 1201). THE AVERAGE THICKNESS OF COAL SEAMS MINED IN 399 THE POWDER RIVER BASIN IS ABOUT 39 FEET, WHICH WAS COMPUTED 499 FROM DATA IN REFERENCES (1203,32) $ (1204,6). THUS, THE 599 INCREMENTAL LAND DAMAGED IS 0.828 AC / 1.0E12 BTU, AND THE 699 TIME AVERAGED (0VER 25 YEARS) LAND IMPACT IS 10.4 AC-YR / 799 1.0E12 BTU IN. 899 SINCE IN STRIP MINING SOLID WASTE IS PRODUCED ONLY FROM THE 999 SPOILS OF THE FIRST CUT AND ARE PERMANENTLY SITUATED, THE LAND 1099 THE SOLID WASTE OCCUPIES IS CLASSIFIED AS FIXED LAND IMPACT. 1199 FOR SOLID WASTE STORAGE IN A PILE 30 FEET HIGH, THE 1299 UTILIZED IS 0.279 AC-YR/1.0E12 BTU IN (SOLID WASTE PRODUC- 1399 TION, FOOTNOTE 1206). 1499 1206 199 THE DENSITY OF THE MINE REFUSE PILES WAS COMPUTED TO BE 0.05 TONS 299 / CF FROM INFORMATION IN REFERENCE (1205). THE AVERAGE 399 OVERBURDEN DEPTH IS 60 FEET (WHICH WAS THE AVERAGE DEPTH 499 MINED IN WYOMING IN 1969 (1204) AND IN MONTANA IN 1965 (1017)). 599 IN AREA MINING, THE SOLID WASTE IS PRODUCED ONLY DURING THE BOX 699 CUT. ASSUMING THE BOX CUT COVERS AN AREA OF 5 AC (1007) AND 50 799 MMT OF COAL IS SUBSEQUENTLY EXTRACTED, SOLID WASTE IS PRODUCED 899 AT A RATE OF 730 T / 1.0E12 BTU IN. 999 1207 199 THE EMISSIONS FROM EXCAVATING EQUIPMENT FUEL USE ARE NEGL. ALL BUT 299 ONE PIECE OF EQUIPMT IN MONT. IS ELECTRICALLY POWERED WHILE 399 FOR WYOMING THE FIGURE IS 66PC(1004,38). 499 NEVERTHELESS OTHER EQUIPMENT IS DIESEL POWERED. THE DIESEL 599 FUEL CONSUMED FOR EACH 1.0E12 BTU IN IS ABOUT 5580 GAL. 699 (FOOTNOTE 1227). THE EMISSION FACTORS ARE OBTAINED FROM 799 REF. (0002,3-7). 899 BEING A SEMI-ARID AREA, WIND EROSIOIN IS LIKELY TO OCCUR, THE 999 EXTENT IS DEPENDENT ON SOIL CONDITIONS, VEGETAL COVER AND 1099 PRECIPITATION. NO DUST PASSAGE HAS BEEN REPORTED AT GLASGOW, 1199 MONTANA AND RAPID CITY, S.D. (1211,9). BUT, DUE TO THE SURFACE 1299 DAMAGE CAUSED BY STRIP MINING, EROSION IS ASSUMED TO OCCUR AT A 1399 RATE OF 428 LB/AC-YR, WHICH IS THE RATE FOR THE MORE ERROSIVE 1499 SOUTHERN GREAT PLAINS (1211,18). HENCE, 2.23 T OF PARTICULATES 1599 ARE EMITTED FOR EVERY 1.0E12 BTU IN (SEE FOOTNOTE 1205). 1699 1208 199 THE EFFICIENCY OF EXTRACTION IS ABOUT 98PC (1021). 299 1209 199 III-54 FTN. 1210-1211 SINCE NO EMPIRICAL RESULTS WERE AVAILABLE FOR THE SPECIFIC AREA, - 299 .,rHE SEDIMENT YIELD FROM THE WASTE PILE IS COMPUTED FROM THE 399 FOILOWING EQUATION (1210). 499 E = F C (S EXP1.35)(L EXPO.35)(P EXP1.75 599 WHERE, E = PROBABLE SOIL LOSS (T/AC-YR) 699 L = 120 FT = LENGTH OF SLOPE 799 P = 0.4 = SOIL FACTOR (RELATIVE ERODAbILITY) 899 S = 8.4 = SLOPE IN PC/10 999 P = 1.5 = RAINFALL 2 YR FREQUENCY, 30 MINUTE 1099 MAXIMUM INTENSITY (INCHES) 1199 C = 1.0 = CROP FACTOR 1299 THE VALUES FOR F,P,kND C WERE OBTAINED FROM THE REFERENCE 1399 PAPER,WHILE S AND L WERE ESTIMATED *THE SEDIMENT YIELD IS 1499 77.1 TONS/AC-YR. 1 1599 IT IS ASSUMED THAT THE SOLID WASTE PILE ALONE WILL CONTRIBUTE 1699 SEDIMENT TO THE NATURAL DRAINAGE, SINCE THE SPOIL BANKS ARE 1799 LOCATED IN THE PIT AND THE RUNOFF IS CONTAINED THEREIN 'THE 1899 RUNOFF FROM AND SEEPAGE IN THE SPOIL BANKS COULD CONTAMINATE 1999 THE GROUND WATER SUPPLY). THE REFUSE PILE REMAINS THE SAME 2099 THROUGHOUT THE LIFE OF THE MINE (ONE OOX CUT), AND OCCUPIES 2199 AN AREA OF 0.279 ACRE-YR/1.OE12 BTU IN. HENCE, THE SEDIMENT 2299 YIELD FROM THE REFUSE PILE IS 21.5 TONS/I.OE12 BTU IN. 2399 INFORMATICN ON THE DECKER MINE INDICATE THAT 150 GALLONS PER 2499 MINUTE ARE BEING PUMPED INTERMITTENTlY FROM THE MINE (1021 2599 AND 1022) SINCE THE DECKER MINE IS NEW AND THE ONLY ONE IN 2699 THE AREA, THE GROUNDWATER SEEPAGE INTO THE MINE IS 2799 EXCEFTIONALLY HIGH.THU S FOR THIS ANAlYSIS A FIGURE OF 50 GPM 2899 PUMPING 50 PERCENT OF THE TIME IS ASSUMED. AT AN AVERAGE 2999 PRODUCTION OF 8300 TONS COAL PERDAY, ABOUT 4.3 GALLONS OF 309.9 WATER ARE YIELDED FOR EACH TON OF COAL EXTRACTED. 3199 THE EFFLUENT BREAKDOWN IS AS FOLLOWS 3299 3399 REP. PPM T/1.OE12 BTU IN 3499 3599 SUSPENDED SOLIDS (COAL PINES) (1022) 1600 1.7 3699 SEDIMENT 21.5 3799 SUBTCTAL 23.2 3899 3999 K AND NA (1215) 210 0.216 4099 FE (1215) 25 0.026 4199 SULFATE (1215) 413 0.426 4299 4399 4499 CA (1215) 92 0.095@ 4599 MG (1215) 127 0.131 4699 SUBTOTAL 0.894 4799 1210 199 THE SEDIMENT YIELD FROM THE HAULAGE ROADS IS ASSUMED TO OCCUR AT 299 THE SAME RATE AS FROM THE SPOIL PILES (77.1 T/AC-YR, FOOTNOTE 399 1209). HENCE, 21.1 T/1.OE12 BTU OF SILT IS CONTRIBUTED TO THE 499 RUNOFF (FOOTNOTE 1204, LAND USE BY HAUL ROAD). 599 1211 199 THE AVERAGE HAULAGE DISTANCE FROM STRIP MINE TO TIPPLE IS 1.5 MI 299 AND THE AVERAGE TRUCK CAPACITY IS 62 T (0001,344). ASSUMING A 399 GROSS TO TARE WEIGHT RATIO OF 2.5 TO 1, A 710UND TRIP TRANS- 499 PORTS 217 TMI. FUEL CONSUMPTION IS AT A RATE OF 7 GAL/1000 Tmi 599 (0002,3-7). HFNCE, SINCE 920 TRIPS APE REQUIRED TO HAUL 1.OE12 699 BTU EQUIVALENT TONS, 1400 GAL OF DIESEL FUEL ARE CONSUMED. THE 799 EMISSION FACTORS ARE OBTAINED FROM REP. (0002,3-7). 899 THE FUGITIVE DUST FROM THE HAULAGE ROADS IS ASSUSED, TO BE 999 CCKTROLLED. GENERAL PRACTICE IS TO WATER DOWN THE ROADS. 1099 111-55 FTN. 1212-1219 1212 199 DIESEL FUEL IS CONSUMED AT A RATE OF 1400 GAL FOR EVERY 1.0E12 BTU 299 EQUIVALENT TONS TRANSPORTTED (FOOTNOTE 1211). THUS, FOR ENERGY 399 CONTENT OF 5.83E6 BTU/BBL OF DIESEL FUEL. 1.94E8 BTU OF 499 ENERGY IS CONSUMED. 599 1213 199 NO COAL IS ASSUMED LOST BETWEEN MINE AND TIPPLE. 299 1214 199] IT IS ASSUMED THAT .006PC OF THE FEED TO THE PREPARATION PLANT IS 299 REMOVED AS TRAMP IRON. HENCE, 3.42 T OF TRAMP IRON IS 399 COLLECTED FOR EVERY 1.0E12 BTU EQUIVALENT T PROCESSED. THE 499 PERCENTAGE OF TRAMP IRON IS ESTIMATED FROM INFORMATION IN REF. 599 (1059,6-31), ASSUMING THAT THE LARGE PLANT PROCESSES 1000 T/HR. 699 1215 199 THE AMOUNT OF FEED REMOVED AS TRAMP IRON IS MINISCULE (.006 PC). 299 THE EFFICIENCY IS THEREFORE APPROXIMATELY 100PC. 399 1216 199 APPROXIMATELY 35AC OF LAND ARE UTILIZED FOR THE PREPARATION PLANT 299 AND A 10000 T UNIT TRAIN LOADING FACILITY (1021). THUS, THE 399 LAND IMPACT IS ABOUT 0.997 AC-YR/1.0E12 BTU. 499 IT IS ASSUMED THAT THE MODES OF TRANSPORT OTHER THAN UNIT 599 TRAINS HAVE SIMILAR LAND REQUIREMENTS. 699 1217 199 IN GENERAL, A UNIT TRAIN HAULS 10,000 T CF COAL PER TRIP (1005,33) 299 AND UTILIZES THE EQUIVALENT OF 4, 2400 HP DIESEL LOCOMOTIVES 399 (FROM DATA ON MATTHEWS MINE IN (1006)). 499 599 ENERGY CONSUMPTION BY FREIGHT TRAINS IS 690 BTU/TM (FOOTNOTE 699 7013), OR 0.005 GAL DIESEL FUEL/TM (5.83E6 BTU/BBL,0005,38). 799 AN ALL STEEL HOPPER CAR WITH A CAPACITY OF 70 T HAS A GROSS TO 899 TARE WEIGHT RATIO OF ABOUT 4/1 (0023,1136). IT IS ASSUMED THAT 999 THIS FIGURE HOLDS FRO 100 T CARS AND THAT THE FUEL CONSUMPTION 1099 PER TRAIN IS AS CITED ABOVE. FROM DATA IN (0021,31) THE ENERGY 1199 CONSUMPTION ASSUMES AN AVERAGE USAGE OF 3 LOCOMOTIVES PER 1299 THE AVERAGE HAULAGE DISTANCE, ASSUMED TO BE 150 MI WHICH IS 1399 THE APPROXIMATE DISTANCE BETWEEN DECKER AND BILLINGS, MONTANA 1499 (LOCATED IN BILLINGS IS THE LARGEST COAL BURNING POWER PLANT 1599 IN MONTANA (1218,39)). HENCE, FUEL CONSUMPTION IS 12500 GAL 1699 PER ROUND TRIP OR 7.13E4 GAL/1.0E12 BTU. THE EMISSION FACTORS 1799 ARE COMPUTED FROM (0002,3-7). 1899 WINDAGE LOSSES, ASSUMED TO BE AIRBORNE AS PARTICULATES, ARE 1999 ABOUT .04P OF THE TONNAGE HAULED (0002, 7-4). SINCE THE LOSSES 2099 OCCUR MAINLY DURING HANDLING AT EITHER END POINT, THE ARE 2199 ESSENTIALLY INDEPENDENT OF HAULAGE DISTANCE. THUS, 22.8 T OF 2299 COAL FINES ARE RELEASED AS PARTICULATES FOR EACH 1.0E12 BTU 2399 EQUIVALENT T SHIPPED. 2499 1218 199 THE AVERAGE HAULAGE DISTANCE IS 150 MI (1005,96) AND FUEL CON- 299 SUMPTION IS AT A RATE OF .005 GAL/TM (FOOTNOTE 1005). ASSUM- 399 ING 1000 T IS CARRIED PER TRIP AND ACCOUNTS FOR 20P OF THE 499 TOTAL TONNAGE OF ANY ONE SHIPMENT. A GROSS TO TARE WEIGHT RATIO 599 OF 4/1, AND ONLY ONE WAY DIESEL FUEL CONSUMPTION ATTRIBUTED 699 THE COAL, 56400 GAL OF DIESEL FUEL CONSUMED ARE ATTRIBUTED TO 799 THE RRANSPORT OF 1.0E12 BTU. THE EMISSIONS ARE COMPUTED FROM 899 INFORMATION ON DIESEL LOCOMOTIVES IN (0002,3-7) THE WINDAGE 999 LOSSES ARE ASSUMED TO BE APPROXIMATELY .08P OF THE TOTAL 1099 SHIPMENT. HENCE, ABOUT 45.6 T IS RELEASED TO THE ATMOSPHERE 1199 AS PARTICULATES/1.0E12 BTU. 1299 1219 199 DUE TO THE LARGE COAL DEPOSITS IN THE AREA AND THE PROXIMITY OF 299 OF THE POPULATION CENTERS IN THE REGION, A SIZABLE PERCENTAGE 399 OF THE POWER PLANTS ARE LOCATED AT MINE-MOUTH. 499 IT IS ASSUMED THAT TRUCK HAULAGE DISTANCE AVERAGES 10 MI. THIS 599 FTN. 1220-1226 IS THE APPROXIMATE DISTANCE BETWEEN GLENROCK, WYOMING, WHERE 699 THE LARGEST.COAL FIRING POWER PLANT IN THE REGION IS LOCATED, 799 (1218,41), AND THE COAL DEPOSITS (1204,21). 899 ASSUMING AN AVERAGE TRUCK CAPACITY OF 20 T, A GROSS TO TARE 999 WEIGHT RATIO OF 2.5. TO 1 AND A FUEL CONSUMPTION RATE OF 7 1099 GAL/1000 TMI (FOOTNOTE 1211), 9160 GAL-OF DIESEL FUEL ARE 1199 CONSUMED. THE EMISSIONS FROM A DIESEL ENGINE ARE GIVEN IN REF.1299 (0002,3-7). 1399 .IT IS ASSUME.D THAT .04P OF THE TOTAL SHIPMENT IS LOST DUE TO 1499 WINDAGE. THE,COAL FINES RELEASED AS PARTICULATES THEREFORE 1599 AMOUNT TO 22.8 T/1.OE12 BTU EQUIVALEVT T SHIPPED. 1699 1220 199 WINDAGE LOSSES ACCOUNT FOR .04P OF THE TONNAGE SHIPPED BY UNIT 299 TRAIN AND TRUCK (FOOTNOTE 1217 AND 1219). WHILEFOR MIXED 399 TRAINS THE LOSSES ARE .08PC(FOOTNOTE 1218). 499 1221 199 @THE AVERAGE HILES OF RAI LFOAD OPERATED WEST OF THE MISSISSIPPI IN 299 1971 WERE 119,000 MI (0033,59) AND OF THE TOTAL TONNAGE HAULED 399 IN THE SAME YEAR COAL ACCOUNTED FOR 9PC(0039,27). 499 ASSUMING A RIGHT-OF-WAY OF 6 AC/MI, THE LAND UTILIZATION 599 ASSOCIATED WITH THE TRANSPCRT OF COAL IS 64200 AC. 699 RAIL SHIPMENT OF COAL FROM MONTANA AND WYOMING IN 1971 AMOUNT- 799 EL TC 11.1*E6 T (1004,52,53) OR ABOUT 24 PC OF THE TOTAL COAL 899 MOVEMENT BY RAIL WEST OF THE MISSSIPPI RIVER. THUS, THE LAND 991 IMPACT IS 11*1 AC-YR/1*OE12 BTU* 1099 1222 199 COAL SHIPMENT IN THE REGION WEST OF THE MISSISSIPPI ACCOUNTS FOR 299 9P OF THE TOTAL FREIGHT MOVEMENT IN THIS REGION (0039,27) AND 399 24 PC OF THE COAL MOVEMENT ORIGINATED IN MONTANA AND WYOMING. 499 (1004,52/53). IN THIS REGION,ACCIDENTS CLAIMED 714 LIVES AND 599 INJURED 5700 PERSONS (0006,17,54),.AND AN AVERAGE OF 93 MAN- 699 DAYS WERE LOST PER INJURY (.0006,4).:.HENCE, .0750 FATALITIES, 799* 0.599 NON-F ATAL INJURIES AND 55.6 MAN-DAYS LOST ARE ATTRIBUT- 899 ABLE TO THE SHIPMENT OF I.OE12 BTU EQUIVALENT T FROM MONTANA 999 AND WYOMING (SEE FOOTNOTE 1221 FOR-COAL TONNAGE) 1099 i223 199 THE ACCIDENT STATISTICS FOR COAL IN 1970 ARE INCLUDED IN THE 'NOT 299 ELSEW.HERE CLASSIFIED' CATEGORY IN REF.(0036,14). IN MATCHING 399 DATA WITH REF. (0037,2/9) IT HAS BEEN DEDUCED THAT IN 1970 499 METALLIC ORES, COAL, NON-METALLIC MINERALS AND WASTE AND SCRAP 599 METALS ARE INCLUDED IN THIS CATEGORY. OF THE TOTAL TONNAGE OF 699 THESE COMMODITIES,COAL ACCOUNTS FOR 3PC-- A TRANSPORT OF 799 341,000 TONS. OF THE TOTAL TONNAGE OF COAL SHIPPED, 1.OE12 BTU 899 EQUIVALENT T AMOUNTS TO 12PC. HENCE,. 0.0324 FATALITIES/1.OF12 999 BTU AND 0*692 NOI-FATAL INJURIE,5/1,*lE12*BTU IS ATTRIBUTED 1099 TO THE SHIPMENT OF COAL. FOR THE SAME YEAR THE NUMBER OF 1199 DAYS LOST PER INJURY. FOR 'TRUCKING, LOCAL AND LONG DISTANCE' 1294 WAS 65.6 (0038,375). THUS, 45.4 DAYS ARE LOST/I.OE12 BTU. 1399 NC REGIONAL DATA HAVE BEEN LOCATED. 1499 1224 199 THE UNIT TRAIN CONSUMES 7.13E4 GAL'OF DIESEL FUEL/1.OE12 BTU 299, EQUIVALENT T OF COAL TRANSPORTED (FOOTNOTE 1217). FOR A HEAT 399 CONTENT OF 5.825E6 BTU/BBL, 9.9OE9 BTU OF ENERGY IS CONSUMED. 499 1225 199 THE MIXED TRAIN CONSUMES 5.64E4 GAL OF DIESE@_ FUEL/1.OE12 BTU 299- EQUIVALENT T OF COAL TRANSPORTED (FOOTNOTE 1218). FOR A HEAT 399-. CONTENT OF 5.825E6 BTU/BBL, 7.82E9 BTU OF ENERGY IS CONSUMED. 499 1226 199 FOR HAULAGE CF COAL BY TRUCK, 9160 GAL OF DIESEL FUEL IS CONSUMED 299 FOR THE SHIPMENT OF 1.OE12 BTU EQUIVALENT T (FOOTNOTE 1219). 399 FOR A HEAT CONTENT OF 5.825E6 BTU/BBL, THE ENERGY CONSUMPTION 499 111-57 FTN. 1227-1237 IS 1.27E9 BTU 599 1227 199 THE ENERGY UTILIZATION BY AN AREA STRIPPING OPERATION IN THIS 299 REGION IS ESTIMATED FROM INFORMATION IN REF. (1041,91). 399 IT IS ASSUMED THAT FUEL AND POWER REQUIREMENTS PER T OF COAL 499 EXTRACTED ARE INVARIANT WITH RESPECT TO ANNUAL PRODUCTION (THE 599 DATA ON LIGNITE MINING IN THS REGION ARE INDICATIVE, (1041, 699 100/116)). FOR FUEL COST AT $0.20/GAL AND POWER AT $0.015/KWH, 799 THE TOTAL ENERGY CONSUMPTION FOR THE EXTRACTION OF 1.0E12 BTU 899 EQUIVALENT T IS 1.96E9 BTU. WHICH IS COMPOSED OF 7.91E8 999 BTU OF DIESEL FUEL AND 1.14E5 KWH OF ELECTRICAL POWER. THE 1099 TOTAL IS OBTAINED BY ADDING 3 TIMES THE BTU EQUIVALENT OF THE 1199 ELECTRICAL POWER USAGE TO THE FUEL CONSUMPTION. ON A 1.0E12 1299 BTU IN BASIS THE TOTAL ENERGY CONSUMPTION IS 1.92E9 BTU. 1399 1228 199 ENERGY CONSUMPTION AT A CRUSHING AND SIZING PLANT IS ABOUT 2.19E9 299 BTU/1.0E12 BTU EQUIVALENT T PROCESSED. OF THE TOTAL CONSUMP- 399 TION 1.82E5 KWH ARE ELECTRICITY AND 3.818E8 BTU ARE OIL ((1064, 499 12A-16,39) ASSUMING ALL FUEL PURCHASED TO BE OIL AT A COST OF 599 $0.20/GAL). THE TOTAL IS OBTAINED BY ADDING 3 TIMES THE BTU 699 EQUIVALENT OF TH ELECTRICAL ENERGY CONSUMPTION TO THE OIL 799 USAGE. 899 1229 199 ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEYORS FOR 299 STORAGE AMOUNTS TO 2.08E4 KWH/1.0E12 BTU (FOOTNOTES 1058,1059, 399 1060). THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVA- 499 LENT OF THE ELECTRICAL ENERGY. 599 1236 199 STORAGE OF 1.0E12 BTU EQUIVALENT TON OF COAL ABOVE GROUND IN A 299 PILE 30 FT HIGH REQUIRES THE USE OF 1.08 AC OR LAND. IT IS 399 ASSUMED THAT UNDERGROUN STORAGE WILL ALSO REQUIRE THE SAME 499 AMOUNT OF LAND. 599 1237 199 GENERALLY SILOS HAVE A DIAMETER OF 70 FT AND ARE ABOUT 150 FT IN 299 HEIGHT. THE STORAGE CAPACITY IS APPROXIMATELY 11,000 TON 399 (1006). THUS 5 SILOS ARE REQUIRED FOR STORING 1.0E12 BTU 499 EQUIVALENT TON. THE LAND UTILIZED BY THE SILOS IS THEREFORE 599 .442 ACRE. 699 III 58 1 2 1 4 IT A 7 11 a .4 15 1. 7 IN El 22 @4 No 2. 1 IATER POLLUTANTS (TONS, IO'l BTU, EX. COL 12) AIR POLLUTANTS I (Tomand. m) OCCUPATIONAL HEALY. POTENT@AL OX ACTIVITY PROCESS DISSCAYED ENTLIDS SUSPENDED TOTAL @@ N,.c- -.o- A@ SOLIDS LAND SOD A% co OE. TOTAL T El. (I. "S ..-DAT5 IT INNUARICS COLN ALI ACIDS BASES -A 10TALION). SWDS tJL.TE. cAA`BCNNs ET. LONTADSYL DISASTER XT BTU) DEATN5 3 A --1 -0, 1., IT ittE BEXAMM3 AND 71- . . .... . .... _L- 2 _22 ---------- NII 16 IF tan 71. 11 ma M=4 IN, IN OM ------ m! --m 77m; BIT 21 .2 ka 27 NO j NO 31 ag 37 _L7 INS 41 12 .3 P, 7 MDTE, ALt, TABLE ENTRIES ARE BASED ON IG12 BTU OF RE50UCE jXTO EAU PRKESS Ot'AtTIVITY. 'TABLE 4. ENVIRONMENTAL DeAM AM EFFWMKZ R= THE SEE F OTNOIE 12DO FOR NEASURE EQU IVALENTS OF 1012 AT". SSLM AND 43N CONTENTS CONTROLLM NORTHWEST REMN CEF OF I ONE NAESTERN COAL AND REGIONAL 011CRIPTIM COAL SUP@LV@ 111-59 FTN. 1230-1233 FOOTNOTES FOR TABLE 4 1230 199 IN THE POWDER RIVER BASIN, 0.828 AC OF LAND IS OVERTURNED PER 299 I.OE12 BTU IN.BY AREA STRIPPING AND 10.AC ARE OCCUPIED-BY 399 THE REFUSE PILE .(FOOTNOTE 1205). 499 IN TIME AVERAGING THE LAND IMPACTS, CONSIDERATION MUST BE 599 GIVEN TO THE EFFECTS OF RECLAMATION, WHICH IN THIS CASE 699 IMELIES CCNTOUR BACKFILLING, REDISTRIBUTION OF TOPSOIL, SEED 799 BED PREPARATION, TERRACING (GOUGING) AND REVEGETATION. THE 899 CRITERION FOR REVEG?TATION IS THE ESTABLISHMENT OF AN HERBA_ 999 CEOUS COVER SUFFICIENT TO STABILIZE THE SURFACE AGAINST 1099 EROSION. OT HER RECLAMATION PRACTICES CAN BE OCCURING SIMULTA- 1199 NEOUSLY. 1299 IN THE ARID AND SEMI-ARID WEST,RECLAMATION STUDIES ARE BEING 1399 CONDUCTED. FINDINGS TO DATE ARE INCONCLUSIVE. UNDER CONTROLLED1499 CCNDITIONS (IRRIGATION, FERTILIZATION, ETC.) VEGETAL GRCWTH 1599 HAVE BEEN INDUCED, BUT WHETHER THEY ARE SELF SUSTAINING AND 1699 CAPABLE CF SUPPORTING USE HAS YET TO BE PROVEN (1219 AND 1220). IT HAS BEEN CLAIMED THAT ANYWHERE FROM 5 TO 25 YRS ARE 1899 REQUIRED TO ESTABLISH A VEGETAL COVER CAPABLE OF SUPPORTING 1999 GRAZING (1021), WHILE OTHERS FEEL THAT THE ESTABLISHMENT OF 2099 A SELF SUSTAINING COVER MAY REQUIRE MORE THAN A CENTURY.(1219 2199 AND 1220). 2299 FOR THE FURPOSES OF QUANTIFYING THE IMPACTS IT IS ASSUMED 2399 THAT 5@@YRS ARE SUFFICIENT TO MEET THE ABOVE CFITERION 2499 FOR RECLAMATION. THUS, THF TTMF AVERAGED LAND IMPA' IS 3 7- 2599 AC-YR/1.OE12 BTU IN (THE LAND USE FOR STORAGE OF TNE SOLI6'5' 2699 WASTE IS ASSUMED TO BE ZERO, I.E., INSTANTANEOUS RECLAMATION).2799 IT IS ASSUMED THAT 5 AC ARE REQUIRED FOR THE SETTLING BASIN,- 2899. WHICH FOR A DEPTH OF 10 FT, HAS A CAPACITY OF ABOUT 16 2999 MMG.AL. THIS IS FOR A 2xJ06 TPY MINE HENCE THE LAND IMPArT IS, 3099 0.140 AC-YR/I.OE12 BTU IN. 3199 1231 199 THE GROUNDWATER SEEPAGE INTO THE PIT AND THE RUNOFF FROM' THE WASTE 299 PILE ARE COLLECTED IN A SETTLING BASIN. WATER BEING A VALUABLE@ 399 COMMODITY INTHIS REGION, IT IS ASSUMED THAT THE WATER 499 IS UTILIZED FOR DUST SUPPRESSION AND IRRIGATION OF THE 599 RECLAIMED AREAS, AS IN THE CASE FOR THE SOUTHWEST (1040). 699 THE DISCHARGE TO THE LOCAL DRAINAGE IS NIL, THUS, THERE IS NO 799 CONTAMINATION OF THE SURFACE WATER SUPPLY. 899 1232 199 TO CONTROL SEDIMENTATION,THE RUNOFF FROM THE HAUL ROADS IS 29.9 DIVERTED TO SETTLING PONDS PLACED AT INTERVALS ALONG, THE 399 ROADWAY (1100). SINCE THE ROAD IS RELATIVELY SHOET.(1.5 MI, 499 FOOTNOTE 1204) ONLY ONE SETTLING BASIN IS ASSUMLD To BE 599 NEEDED. BECAUSE OF THE LOW RAINFALL, THE SETTLING POND IS 699 ASSUMED ADEQUATE TO CONTAIN ALL THE RUNOFF (FOOTNOTE 1233). @99 THE CONTAINED WATER CAN BE UTILIZED FOR DUST SUPPRESSION OF 899, THE HAUL ROADS OR ALLOWED To EVAPORATE, 999 1233 199 THE HAUL ROAD LAND IMPACT IS 0.274 AC-YR/1.OE12 BTU (FOOTNOTE 299 1204). THE SETTLING POND IS ASSUMED TO HAV7 A SURFACE AREA. 399 OF 1 AC, WHICH FOR A DEPTH Of 5 FT HAS A STORAGE CAPACITY OF 499 1.6 MMGAL. THUS, THE LAND IMPACT FOR THE SETTLING POND IS @99 0.0265 AC-YR/1.OE12 BTU (2MMT/YR HAULED ON ROADS). 699 THE TOTAL LAND IMPACT Is. 0.303 Ac-yfl/l.OE12 BTU., 799 Preceding page blank 111-61 FTN. 1234-1235 1234 199 BASED ON AN EROSION RATE OF 428 LB/AC-YR (FOOTNOTE 1207) AND A 199 TIME AVERAGED LAND IMPACT OF 3.73 AC-YR/1.OE12 BTU IN 399 (FOOTNOTE 1230), .798 TON PART/1.OE12 BTU IN ARE GENERATED. 499 THIS IS IN ADDITION TO THE PARTICULATES FROM THE DIESEL FUEL 599 CONSUMED (FOOTNOTE 1207). 699 1235 log ASSUMING A SPOIL PILE HEIGHT OF 80 FT AND GEOMETRICALLY UNIFORM 299 PARALLEL SPOIL BANKS RESTING AT AN ANGLE OF REPOSE OF 38 399 DEGREES, THE PEAK TO PEAK DISTANCE IS ABOUT A 10C FT. THUS, 499 THE ENERGY CONSUMED TO LEVEL THE SPOIL BANKS AMOUNTS TO 599 A BOUT 39 20 H P-HF/AC ( ( 122 2 , 67) AN D AS SUMING A 6 PC PERFOMANCE 699 EFFICIE ICY) . THUS, 8. 26E6 BTU/1 OE1 2 BTU IN ARE EXPENDED 799 (FOOTNOTE 1205, LAND TO BE RECLAIMED). 899 THIS ENERGY USE IS IN ADDITION TO THE ENERGY REQUIRED FOR THE 999 MINING OPERATION 1.92E9 BTU (FOOTNOTE, 1227) . 1099 111-62 Rl 1 10 11 m 14 Is I. UE ED 21 2R 0 24 RE R. WATER POLLUTANTS IT-Sl UGU BTU. EX. COE 12) AIR POLLUTANTS (TOWS/ldc BTU) OCCUPATIONAL HEALTH POTENTIAL -DISSOLVED SOLIDS GUNPE-D TOTAL "YDNO- ALDEN,'DER .-S LAND LARGE WNSAIRA, INWHE- ACTIVITY PROCESS ..D COD THIEFINAIL NO@ so. Co T 11 DE-3 J!"JR)RIES -DAYS ICA E ULATC- I - IC'M LMld`BYU 0. SASTE WEALL ORGANICS COL. .".a E5 BOWS ETC, TOTAL ON C... .0. BTU IT ACIDS BASES NOT OEM., TOTAL 1.11 SOLID. IT ETY'Il.-Y I 2 M22 - --------- 10 I ....... I 1. '0 YNY ..I IN. N- I U` IS .4 UPPE4 14 NET I 1 -1 1- 15 -1-- -01 3 Twis ------------ 1U. I-- 0 L 0 21 -1 1 1HIT Y. -I- -7 24 -1 WIN I -I I I'll URY IAP 241 2' WIN -1 YUI WIN WU n 2. RE 2. 30 3-1 1361 AA As 3 3a AST N1 .2 AS GG 45 WE: ILL, MEE ENTRIE5 ART BASED ON IDIZ BTU Of RESQURCE [.TO EACH PROCESS OR ACTITITf. TABLE 5. ENVIRONMENTAL IMPACTS AM EFTWONCY FOR, THE 'E 'OlTl Tt 1111 101 "111111 11111AIIIIII ff TO" 11U. ILLI.I.A.L) 19-H C..TC.Tl UNCONTROLLED CENTRAL BEGMS OF, 'T CEII, "I GAL A'C @E'@o.'AL @E'CGPT@N COAL SUPPLY 111-63 Cl FTN. 1300-1303 FOOTNOTES FOR TABLE 5 1300 199 THE CENTRAL. REGI'ON FOR THIS STUDY IS COMPRISED OF THE STATES.OF 299 ILLINOIS AND INDIANA. THE AVERAGE CALORIC CONTENT OF COAL 399 DELIVERED TO ELECTRIC UTILITIES IN THIS REGION DURINC THE 499 3BD AND 4TH QUARTERS OF 1972 WAS ABOUT 10600 BTU/LB AND THE 599 AVERAGE SULFUR CONTENT WAS APPROXIMATELY 2.92 PC(1212 AND 699 1213). THE AVERAGE ASH CONTENT OF CCAL MINED IN INDIANA AND 799 ILLINOIS IS ABOUT 8.9 PC(1026). THE DENSITY OF THE COAL IS 899 81 LB/CF. 999 FOR THE GIVEN HEAT VALUE 1.OE12 BTU IS EQUIVALENT TO 47200 T. 1099 ALTHOUGH ILLINOIS PRODUCED 7.3P OF THE METALLURGICAL COAL 1199 CONSUMPTION IN 1971 (1036), IT IS N07 CONSIDERED IN THIS 1299 ANALYSIS. ONLY STEAM RAISING COAL IS STUDIED. 1399 1301 199 THE OCCUPATIONAL HEALTH IMPACTS DUE.TO THE MINING OF CENTRAL COAL 299 WERE BASED ON STATISTICS IN REFERENCE (1206-1210). 399 THE NUMBER OF FATALITIES AND NON-FATALITIES AND COAL 499 PRODUCTICN QUANTITIES WERE TABULATED FOR UNDERGROUND AND STRIP 599 MINES@ANC AVERAGES OBTAINED OVER THE FIVE YEARS OF &ECORD. THEREFORE, FOR DEEP MINING, THERE RESULTS 0.22.2 FATALITIES 799 1.OE6 TONS PRODUCTION AND 23.1 NON-FATALITIES (INJURIES) 899 1.0E6 TONS PRODUCTION.FOR SURFACE (STRIP) MINING , 0.072 999 FATALITIES / 1.OE6 TONS PRODUCTION AND 4.19 NON-FATALITIES 1099 1.OE6-TONS PRODUCTION RESULT. 1199 FROM AVERAG 1299 THE MAN-EAYS LOST PER INJURY QUANTITIES RESULT E SEVFRTTY STATISTICS FOR BOTH UNDERGROUND AND STRIP MINING. 1399 FOR EACH MINING MODE, AVERAGING WAS PERFORMED BETWEEN 'IRE TWO 1499 STATES AND OVER THE FIVE YEARS OF RECORD. AVERAGE SEVERITY 1599 QUANTITIES WERE USED BASED ONTHE NUMBER OF TEMPCRARY TOTAL 1699 DISABILITIES. AS A RESULT OF DEEP MINING, 36.4 RORK-DAYS-LOST 1799 / INJURY WAS DERIVED. FOR STRIP OR SURFACE MINING, 24.9 WORK 1899 -DAYS WERE LOST PER INJURY. 1999 1302 199 THE INJURY STATISTICS DUE TO, HAULAGE FOR THE TWO TYPES OF MINING, 29,9 UNDERGROUND AND STRIP, WERE COMBINED. AVERAGING WAS PERFORMED 399 BETWEEN THE TWO STATES, ILLINOIS AND INDIANA, AND OVER THE 499 FIVE YEARS OF RECORD. AVERAGES OF 0.0236 FATALITIES / 1.OE6 599 TONS PROCUCTION AND 1*64 NON-FATALITIES / 1.OE6 PRODUCTION 699 WERE COMPUTED FOR COAL HAULAGE. 799 AN APPROXIMATE AVERAGE OF 30 WORK-DAYS LOST PER INJURY IS 899 DETERMINED FOR TRANSPORT FOLLOWING EITHER DEEP OR SURFACE 999 MINING. THIS QUANTITY RESULTS FROM AVERAGING THE TWO VALUES @1099 REPORTED IN.FOOTNOTE 1301. THE REPORTED STATISTICS ON AVERAGE 1199 SEVERITIES WER .E COMPRISED OF CONTRIBUTIONS DUE TO EXTRACTIO.N 1299 AND HAULAGE. THE RELATIVE CONTRIBUTICN.OF EACHICANNOT'BE 1399 ISOLATED. 1499 1303 199 THE INJURY STATISTICS UNDER MECHANICAL CLEANING OR COAL 299 PREPAkATION PLANTS FOR ILLINOIS AND INDIANA WEREEMPLOYED.: IN 399 THE YEARS A.964-1966 AND 1968,NO FATALITIES WERE REPORTED. IN 499 1969, ONE@ FATALITY WAS REPORTED IN ILLINOIS. THUS AN AVERAGE 599 OF O.OClE4 FATALITIES / 1.OE6 TONS PRODTI.-_TION RESULTED. FOR 699 THESE TWC.STATES AN AVERAGE OF 0.363 NON-FATALITIES / 1.OE6 799 TONS PRODUCTION WAS COMPUTED TO OCCUR AT MECHANICAL CLEANING 899 PLANTS. 999 AVERAGE SEVERITY STATISTICS FOR MECHANICAL CLEANING PLANTS 1099 HAVE ONLY BEEN REPORTED IN THE MORE RECENT REPORTS . MAN-DAYS 1199 LOST PER INJURY COULD ONLY BE OBTAINED FROM AVERAGING THE 1299 111-65 Preceding page blank FTN. 1304-1305 STATISTICS FOR THE YEARS 1966, 1968, AND 1969. FOR THE 1399 STATES OF ILLINOIS AND INDIANA AN AVERAGE OF 26.3 WORK-DAYS 1499 LOST PER INJURY (TEMPORARY TOTAL DISABILITY) WAS COMPUTED. 1599 1304 199 THE AVERAGE THICKNESS OF COAL SEAMS MINED UNDERGROUND IN THIS 299 REGION IN 1965 WAS 6.8 FT (1017). THUS, FOR 1.OEI2 BTU 399 EQUIVALENT T.3.93 AC IS UNDERMINED. 499 OF THE ACREAGE UNDERMINED APPROXIMATELY 25P WILL SUBSIDE. 599 (1019) . THIS SUBSIDENCE RATE IS ACTUALLY FOR ALL UNDERGROUND 699 COAL MINES, BUT SINCE THE ROOM & PILLAR TECHNIQUE HAS BEEN 799 PREDCMINANT IN THE U.S., IT IS ASSUMED THAT THIS FIGURE CHAR- 899 ACTERIZES THE SUBSIDENCE FOR ROOM & PILLAR MINING. EVENTUALLY 999 ALL OF THE AREA UNDERMINED MAY SUBSIDE, BUT THE TIME SCALE, 1099 IS III EXCESS OF A CENTURY. THE 25P SUBSIDENCE RATE IS DERIVED. 1199 FROM HISTORICAL OBSERVATIONS. 1299 1399 SUBSIDENCE AFFECTS A SURFACE AREA GREATER THAN THE AREA 1499 UNDERMINED. THE WIDTH ON THE PERIMETER THAT IS AFFECTED BY 1599 SUBSIDENCE IS DETERMINED FROM 1699 R=H TANX 1795 1899 1999 WHERE, R=WIDTH OF THE PERIMETER AREA AFFECTED, H=DEPTH OF 2OOC MINE,.ANP X=ANGLE OF DRAW (ANGLE BETWEEN A VERTICAL LINE, AND 2299 A LINE CCNNECTING THE FACE AND THE LIMIT OF SUBSIDENCE) . T HE 2199 ANGLE OF DRAW HAS BEEN CONSISTENTLY OBSERVED IN EUROPEAN COAL 2399 FIELDS TO FALL BETWEEN 35-39 DEGREES ( 10 27, 232, 233) . THUS, F0R 28q*99 AN ANGLE OF DRAW OF 37 DEGREES AND A MINE DEPTH OF 600FT, TH 2599 WIDTH OF THE AFFECTED PERIMETER AREA IS 452 FT. 2699 OF THE AREA UNDERMINED .984 AC SUBSIDES. ASSUMING A SQUARE AREA2799 THE SIDES ARE 207 FT IN LENGTH. THUS, AN ADDITIONAL 8.59 2899 ARE AFFECTED BY SUBSIDENCE. TIME AVERAGING (OVER 25 YR OF THE 2999 MINI: LIFE EXPECTENCY) THE ACREAGE AFFECTEDBY SUBSIDENCE, THE 3000 LAND IMPACT IS 120 AC-YR/1.OE12 BTU IN. 3299 INLPILE 30 FT HIGH, 4.59E-2 AC OF LAND IS OCCUPIED BY THE 3399 REFUSE PILE (FOOTNOTE 1306, SOLID WASTE PRODUCTION) . THE 3499 AVERAGE ANNUAL PRODUCTION FROM SIZABLE UNDERGROUND MINES 3599 ABOUT 2 MMT (1005,90). HENCE, THE LAND (FIXED) UTILIZED FOR 3699 STORAGE IS 6.16E-4 AC-YR/1.OE12 BTU IN. 3799 199 ACID MINE DRAINAGE IS NOT A SERIOUS PROBLEM IN THIS REGION, SINCE 299 MOST OF THE MINES ARE LOCATED BELOW DRAINAGE AND IN SOME CASES:399 THE OVERBURDEN IS ALKALINE IN CONTENT (1008,1009 AND 1105). 499 THE DRAINAGE PROBLEM IS PRIMARILY ONE OF DISPOSING THE SEEPAGE 599 WATER FROM ACTIVE WORKINGS, WHICH COULD BE ACIDIC IN NATURE.' 699 SINCE NO WATER QUALITY DATA ARE AVAILABLE -FOR THIS REGION, 799 ACID YIEID IS ASSUMED TO BE 5 PC OF THE YIELD IN APPALACHIAN 8199 (THE MILES OF STREAMS AFFECTED BY ACID POLLUTION IN ILLINOIS 999 AND INDIANA AMOUNT TO 5 PC OF THE MILES OF POLLUTED STREAMS 1099 IN APPALACHIA (1301,122) ) , I. E., 7.50E-5 T OF ACIDITY/T 0F 1199 COAl EXTRACTED FROM UNDERGROUND MINES (FOOTNOTE 1018) . THE" 1299 SULFATE LOADING IS TWICE AS MUCH AS THE ACID LOADING AND THE 1399 MINERAL COMPOSITION IS ASSUMED TO BE THE SAME AS FOR APPAL- 1499 CHIA. THUS, THE EFFLUENT BREAKDOWN IS AS FOLLOWS 1599 1699 T/1.4OEI2 BTU IN 1799 HARDNESS 328.0 1899 FE Reproduced from 5.76 1999 MN best available copy. 2.44 2099 111-66 FTN. 1306-1310 AL .724 2199 S04 4.04 2299 TOTAL .341.0 2399 2499 ACIDITY 2.02 2599 2699 IT SHOULD BE NOTED THAT SIGNIFICANT QUANTITIES OF CHLORIDE- 2799 ARE FOUND IN THE MINE DRAINAGE OF THIS REGION. ' 2899 THE SEDIMENT YIELD FROM THE WASTE PILE OCCURS AT A RATE OF 2999 2.54 T/AC-YP-IN. OF RUNOFF (COMPUTED FROM INFORMATION IN 3099 (1020)). THUS, FOR A RUNOFF OF 10 IN., THE SEDIMENT YIELD IS 3199 .0156 T/1.OE12 BTU IN (FOOTNOTE 1304, LAND USE BY WASTE PILE).3299 THE APPALACHIAN DATA ARE USED ABOVE BECAUSE OF THE LACK OF 3399 ADEQUATE DATA FROM THE CENTRAL REGION. 3499 1306 199 SOLID WASTE FRODUCTION AT UNDERGROUND MINES IS IN GENERAL RELATED 299 TO THE OPENING OF THE MINE. ASSUMING AN AVERAGE MINE DEPTH OF 399 600 FT (WHICH IS THF AVERAGE FOR ILLINOIS (1016)) AND A SHAFT 499 OPENING OF 103 SF, 300C T OF EARTH IS REMOVED TO SINK@THE 599 SHAFT. FURTHER ASSUMING AN AVERAGE PRODUCTION OF 50 MMT PER 699 MINE,, THE PRODUCTION OF SOLID WASTE OCCURS AT A RATE OF 60E-6 799 T/I OF COAL MINED. HENCE, 1.61 T OF SOLID WASTE IS PRODUCED 899 PER 1.3E12 BTU IN. 999 1307 199 THE AVERAGE THICKNESS OF COAL SEAMS STRIP MINED IN 1965 WAS 4.8 299 FT (1017,6). THUS, 5.57 AC OF LAND ARE OVERTURNED FOR EACH 399 I.OE12 BTU IN. THE TIME AVERAGED (OVER 25 YR OF MINE LIFE 499 EXPECTENCY) LAND IMPACT IS THEREFORE 69.7 AC-YR/1.OE12 BTU IN. 599 THE LAND OCCUPIED BY THE SOLID WASTE PILE 30 FT HIGH IS 8.66 699 AC OR, FOR A PRODUCTION RATE OF 2 MMT/YR, 0.166 AC-YR/1.OE12 799 BTU IN (FOOTNOTE 1308, SOLIB WASTE PRODUCTION). 899 1308 199 THE MEAN OVERBURDEN DEPTH IS 52 FT (1017). IN SURFACE MINING ALL 299 OF THE OVERBURDEN, EXCEPT THAT WHICH IS REMOVZD DURING THE BOX 399 CUT, IS DEFOSITED IN SPOIL 3ANKS IN THE EXCAVATEL AREA. HENCE, 499 THE SOLID WASTE IS PRODUCED ONLY DURING THE OPENING OF THE 599 MINE. ASSUMING THAT ON THE AVERAGE FIVE ACRES (PIT SIZE OF 699 ROUGHLY 100 FEET BY 2COG FEET (10C7)) ARE EXCAVATED FOR THE 799 BOX CUT AND 50 MILLION TONS OF COAL ARE CONSEQUENTLY 899 EXTRACTEE, THE SOLID WASTE (566,OCO TONS OF EARTH) PRODUCTION 999. is 433TONS /1.OE12 BTU IN. 1099 1309 199 A MAJ0FITY (59 PC) OF THE EXCAVATING EQUIPMENT IN THIS REGION ARE 299 ELECTRICALLY POWERED (1004,18), BUT THE SUPPORTING EQUIPMENT 199 IS DIESEL FIRED. 499 AN AREA STRIPPING OPEPATION CONSUMES ABOUT 7650 GAL OF DIESEL 599 FUEL PER 1.OE12 BTU IN (FOOTNOTE 1343). THE EMISSION 699 FACTORS ARE OBTAINED FROM REF. (0002.3-7) ASSUMING THE CHAR- 799 ACTERISTICS OF A DIESEL TRUCK ENGINE. SINCE ADEQUATE MOISTURE 899 IS AVAILABLE IN THIS REGION THE FUGITIVE DUST PROBLEM SHOULD 999 NOT BE SERIOUS. 1099 1310 199 DUE TO THE LACK OF ADEQUATE DATA IN THE CENTRAL REGION,THE 29,j DRAINAGE FROM STRIP MINES IS ASSUMED TO BE THE SAME AS 399 FOP CENTPAL APPALACHIA (FOOTNOTE 1514). THE ACIDITY OCCURS 499 AT A RATE OF 1-3.7 T/DAY, OR 1.OE-4 T/T OF COAL EXTRACTED. THE 599 SULFATE LOADING IS TWICE THE ACID LOAD. THE EFFLUENT BREAKDOWN 699 IS AS FOLLOWS 799 T/1.OE12 BTU IN 899 HARDNESS 34.4 999 111-67 FTN. 1311-1315 FE .604 1099 MN .255 1199 AL .0757 1299 SO4 7.64 1299 TOTAL 43.0 1499 1599 ACIDITY 3.82 1699 1799 IT SHOULD BE NOTED THAT SIGNIFICANT QUANTITIES OR CHLORIDE 1899 AREFOUND IN THE MINE DRAINAGE OF THIS REGION. 1999 THE SEDIMENT YIELD FROM THE SPOINT PILES OCCURS AT A RATE OF3099 2.5- T/AC-YR-IN. OF RUNOFF (FOOTNOTE 1305). THUS, FOR A 2199 RUNOFF OF 10 IN., THE SEDIMENT YIELD IS 4.22 T/1.OE12 BTU IN2299 (FOOTNOTE 1307) 2399 1311 199 THE DATA FROM STUDIES CONDUCTED IN EASTERN KENTUCKY(1024,1031, 299 1032,1033,1034) INDICATE AN AVERAGE HAULAGE ROAD RIGHT-OF-WAY 399 OF 53 FT (6.4 AC/MI). THE MEAN DISTANCE FROM MINE TO TIPPLE IS 499 3.8 MI (0001,334). HENCE, 24.3 AC OF LAND IS UTILIZED BY THE 599 ROADS. ASSUMING AN ANNUAL PRODUCTION FROM THE MINE OR 2 --T 699 (FOOTNOTE 1022), 2.4P OF THE HAULAGE ROAD USAGE IS ATTRIBUTED 799 TO THE TRANSPORT OF 1.0E12 BTU EQUIVALENT TO THE LAND IMPACT 899 IS THEREFORE 0.5484 AC-YR/1.OE12 BTU. 999 1312 199 IN 1969 THE AVERAGE TRUCK CAPACITY FOR THIS REGION WAS 59 T AND 299 THE AVERAGE HAULAGE DISTANCE FROM MINE TO TIPPPLE WAS 3.8 MI 399 (0001,334). THE FUEL CONSUMPTION RATE IS ASSUMED TO BE 7 GAL/ 499 1000 TMI (0002,3-7). ASSUMING A GROSS TO TARE WEIGHT RATIO OF 599 2.5 TO 1 FOR THE TRUCKS, A ROUND TRIP IS 520 TMI. SINCE 800 699 ROUND TRIPS ARE REQUIRED TO HAUL 1.OE12 BTU EQUIVALENT T, 2920 799 GAL OF DIESEL FUEL ARE CONSUMED, THE EMISSIONS BREAKDOWN FOR A 899 DIESEL POWERED TRUCK IS GIVEN IN REF. (0002,3-7). 999 DUSTING FROM HAULAGE ROADS ARE CONTROLLED BUY WATERING DOWN, 1099 OILING OR SOME OTHER METHOD. 1199 1313 199 IN AN EASTER KENTUCKY STUDY THE SEDIMENT YIELD FROM A COAL HAUL 299 ROAD WAS DETERMINED TO BE 90 T/AC-YR (1020,C32). THIS STUDY 399 WAS CONDUCTED FOR AN ABANDONED MINE AND FOR A RELATIVELY 499 STEEP SLOPING AREA. THUS, SILTATION WAS EXCEPTIONALLY HIGH. 599 FOR THE PRESENT COMPUTATION IT IS ASSUMED THAT THE SEDIMENT 699 YIELD AVERAGES TO 35 T/AC-YR. HENCE, 20.2 T/1.0E12 BTU OF 799 SEDIMENT IS YIELDED (FOOTNOTE 1311). 899 1314 199 IT IS ASSUMED THAT .006PC OF THE FEED TO THE PREPARATION PLANT IS 299 REMOVED AS TRAMP IRON. HENCE, 2.83 T OF TRAMP IRON IS 399 COLLECTED FOR EVERY 1.0E12 BTU EQUIVALENT T PROCESSED. THE 499 PERCENTAGE OF TRAMP IRON IS ESTIMATED FROM INFORMATION IN REF. 599 (1059,6-31), ASSUMING THAT THE LARGE PLANT PROCESSES 1000 COAL 699 T/HP. 799 1315 199 MANY REFUSE BANKS ARE FOUND BURNING OR SMOLDERING IN ILLINOIS AND 299 INIDANA (1067). THUS, THE WASTE PILE IS ASSUMED TO BE BURNING. 399 THE EMISSION FACTORS ARE OBTAINED FROM REF. (0017). (FOOTNOTE 499 1318 SOLID WASTE PRODUCTION). 599 1316 199 THE BTU EFFICIENCY OF WASHING, I.E., THE RATIO OF THE CALORIC 299 CONTENT OF THE INPUT COAL AND THE OUTPUT COAL MULTIPLIED BY 399 THE YIELD, DEPENDS ON THE ASH CONTENT O;F THE PEED COAL AS WELL 499 AS THE SPECIFIC GRAVITY OF THE WASH AND THE SIZE DISTRIBUTION 599 WASHED. THUS, TO CALCULATE A FIRM NUMBER REQUIRES THE KNOW- 699 LEDGE OF THE ASH CONTENT OF THE R.O.M. COAL AND THE SPECIFIC 799 GRAVITY OF THE BATH. FROM THE AVERAGE AND DATA IN REF. (1010) 899 III-68 FTN. 1317-1319 THE EQUATION FOLLOWING HAS BEEN DEVELOPED FOR A SPECIFIC 999 GRAVITY CF WASHING OF 1.6 1099 1199 PC BTU EFFICIENCY ='-0.342 (PC ASH) + 100 1299 1399 THUS, FOR AN ASH CONTENT OF 14.lPC(1053,13) THE EFFICIENCY IS 1499 95.2 PC. 1599 1.317 199 THE DENSE MEDIUM BATH IS ASSUMED TO BE WASHING AT*A SPECIFIC 299 GRAVITY OF 1.6, AS FOR THE STEAM COAL PREPARATION PLANT (FOOT- 399 NOTE 1318).,THE FEED TO THE BATH IS 1.5 X 3/8 IN SIZE COAL AND 499 IS ASSUMED TO HAVE THE CHARACTERISTICS OF THE AVERAGE UTILITY 599 COAL FOR THIS REGION, I.E., 14.1P ASH AND 3.92P TOTAL SULFUR 699 (THIS AVERAGE INCLUDES COAL FROM WEST KENTUCKY, ( 1053, 13) ) . 799 THE WASHABILITY DATA FOR THE NO. 9 CCALSED IN HOPKINS COUNTY, 899 KENTUCKY IS USED FOR THIS ANALYSIS (1053,71). 999 THE AVERAGE RECOVERY EFFICIENCY FOR,DENSE MEDIUM VESSELS IS 1099 ABOUT 97P (1054). THUS, THE YIELD AT A WASH SPECIFIC GRAVITY 1199 OF 1.6 IS ESTIMATED TO BE 84.5P WHICH IMPLIES A SOLID WASTE 1299 PRODUCTION OF 7316 T/1.OE12 BTU EQUIVALENT T OF COAL PROCESS- 1399 ED. 1499 THE SCREEN ANALYSIS FOR THIS COAL INDICATE THAT 3.3P OF THE 1599 1.5 X 0 IN. CRUSHED COAL IS CONTAINED IN THE SIZE FRACTION 1.699 LESS THAN 100 MESH (1055) IS IS ASSUMED THAT 10P OF 1799 THIS SIZE FRACTION ENDS UP AS BLACKWATER DISCHARGE. THUS, 156 1899. T OF COAL FINES ARE DISCHARGED AS SUSPENDED SOLIDS FOR EVERY 1999 1.OE12 BTU EQUIVALENT T OF COAL PROCESSED. 2099 MAGNETITE LOSSES AMOUNT TO 0.9 LB/T CF CLEAN COAL PRODUCED. 219.9 THUS, AN ADDITIONAL 18 T OF SOLID UASTE IS PRODUCED. 2299 1318 igg THE PREPARATION PLANT P90CESSES 500 T/HR OF R.O.M. COAL. THE COAL 299 IS CRUSHED TO 1.5 IN. TOPSIZE. THE 1.5 X 3/8 IN. SIZE FRACTION 399 IS WASHED IN A DENSE MEDIUM VESSEL AT A SPECIFIC GRAVITY OF 499 1.6, WHILE THE COAL LESS THAN 3/8 IN. IN SIZE IS NOT SUBJECT- 599 ED TC ANY CLEANING. 699 THE WASHABILITY DATA FOR THE NO. 9 COALBED IN HOPKINS COUNTY, 799 KENTUCKY (1053,71) ARE USED FOR THIS ANALYSIS SINCE THE 899 CHARACTEFISTICS OF THIS COAL ARE SIMILAR TO THE AVERAGE 999 UTILITY COAL FOR THIS REGION, I.E., 14.1P ASH AND 3.92P.TOTAL 1099 SULFUR (1053,13). 1199 THE SCREEN ANALYSIS OF THIS COAL INDICATE THAT 44 P OF THE 1299 CRUSHED COAL IS LESS THAN 3/8 IN. IN SIZE. 1399 THUS, 280 T/HR OF 1.5 X 3/8 IN. SIZE FRACTION IS FED TO THE 1499 DENSE MEDIUM BATH. 1599 THE WASHABILITY DATA INDICATE A THEORETICAL RECOVERY OF 87.1P. 1699 FOR A RECOVERY EFFICIENCY OF 97P (1054), THE ACTUAL WASHED 1799 COAL RECOVERY IS 84.5P. THIS IMPLIES THAT FOR EVERY 1.OE12 1899 BTU EQUIVALENT T OF COAL FED TO THE PREPARATION PLANT, 4115 T 1999 OF REFUSE ARE GENERATED. 2399 MAGNETITE LOSSES AMOUNT TO 0.9 LB/T OF CLEAN COAL OUTPUT FROM 2199 THE BATH (1054) . THUS AN ADDITIONAL 10.1 T/1.0E 12 BTU OF 2299 SOLID WASTE ARE PRODUCED. THE COLLECTING OF TRAMP IRON AMOUNTS 23,99 TO 2.83 TON/1.OE12 BTU (FOOTNOTE 1314). 2499 1319 199 THE LAND REQUIRED FOR THE PREPARATION PLANT IS ABOUT 5 AC (1008). 299 THE LOADING AREA FOR A 10000 T UNIT TRAIN IS ESTIMATED TO BE 399 ABOUT 40 AC (DATA ON THE MATTHEWS MINE, (1006,85)) AND THE 499 SETTLING PCND OCCUPIES ABOUT 50 AC (1009). THE PLANT PROCESSES 599 2 MMT/YR, THUS THE LAND IMPACT IS 2.24 AC-YR/1.OE12 BTU. 699 IN A PILE 30 FT HIGH THE REFUSE (FOOTNOTE 1318) OCCUPIES. 799 0.0632 AC/1.OE12 BTU. THE TIME AVERAGED (OVER THE 25 YR LIFE 899 EXPECTENCY OF THE PLANT) LAND IMPACT IS 0.791 AC-YR/1.OE12 999 111-69 FTN. 1320-1322 BTU. 1099 1320 199 APPROX. 35 ACRES OF LAND ARE UTILIZED FOR THE PREPARATION PLANT 299 AND A 10000 T UNIT TRAIN LOADING FACILITY (1021). THUS, THE 399 LAND IMPACT IS ABOUT 0.826 AC-YR/1.0E12 BTU. 499 IT IS ASSUMED THAT THE MODES OF TRANSPORT OTHER THAN UNIT 599 TRAINS HAVE SIMILAR LAND REQUIREMENTS. 699 AT A CRUSHING AND SIZING PLANT, NO SIGNIFICANT SOLID WASTE IS 799 GENERATED. THUS ADDITIONAL LAND REQUIRED FOR STORAGE IS 899 NEGLIBIBLE. 999 1321 199 THE SEEPAGE FROM THE REFUSE PILE ASSUMED TO OCCUR AT A RATE OF 299 1670 GAL/AC-DAY CONTAINS. 0.091 LB OF ACIDITY/GAL, 0.144 LB 399 SULFATE/GAL, 0.0258 LB IRON/GAL AND 3.78E-4 LB MANGANESE/GAL 499 (100-). THE DISCHAGE IS THEREFORE CONSTITUED AS FOLLOWS 599 T/1.0E12 BTU IN 699 FE 6.2 799 SO- 34.8 REPRODUCED FROM 899 MN 0.1 BEST AVAILABLE COPY. 999 TOTAL 21.9 1099 1199 ACIDITY 21.9 1299 THE SEDIMENT YIELD FROM THE REFUSE PILE IS 20.1 T/1.0E12 BTU 1399 (FOOTNOTE 1310). (SEE FOOTNOTE 1319 FOR LAND USE BY THE REFUSE 1499 PILE. 1599 OF THE RAW CRUSHED COAL 3.3PC IS LESS THAN 100 MESH IN SIZE 1699 (1055). A PROPORTION OF THIS SIZE FRACTION ENDS UP IN THE FEED 1799 TO THE DENSE MEDIUM CIRCUIT. ASSUMING 10 PC OF THE COAL LESS 1899 THAN 100 MESH IN SIZE IS YIELDED AS BLACKWATER DISCHARGE, 1999 SUSPENDED SOLIDS ARE GENERATED AT A RATE OF 1.65 T/HR. IT IS 2099 UNREALISTIC TO ASSUME THAT ALL OF THE BLACKWATER IS 2199 DISCHARGED TO THE NATURAL DRAINAGE SINCE SOME PLANTS DO HAVE 2299 CONTROLS. IN INDIANA AND ILLINOIS ABOUT 50P OF THE PLANTS HAVE 2399 SOME TREATMENT FACILITY (1073). THUS IT IS ASSUMED THAT 50P OF 2499 THE BLACKWATER GENERATED, 0.825 T/HR, IS DISCHARGED TO THE 2599 NATURAL DRAINAGE TRHOUGH LEAKS, OVERFLOWS AND IMPROPER 2699 SETTLING. SUSPENDED SOLIDS ARE THEREFORE DISCHARGED AT A 2799 RATE OF 78.0 T/1.0E12 BTU. 2899 1322 199 ENERGY CONSUMPTION BY FREIGHT TRAINS, ASUMMED TO APPLY AS WELL TO 299 UNIT TRAINS, IS 690 BTU/TMI (FOOTNOTE 7013), OR 0.005 GAL OF 399 DIESEL FUEL/TMI (5.83-6 BTU/BBL, (0005,38)). AN ALL STEEL HOP- 499 PER CAR WITH A CAPACITY OF 70 T HAS A GROSS TO TARE WEIGHT RA- 599 TIO OF ABOUT 4 TO 1 (0023, 1136). IT IS ASSUMED THAT THIS FIG- 699 URE HOLDS FOR 100 T CARS AND THAT THE FUEL CONSUMPTION PER 799 TRAIN IS AS CITED ABOVE. FROM DATA IN (0021, 31) THE ENERGY 899 CONSUMPTION ASSUMES AN AVERAGE USAGE OF 3 LOCOMOTIVES PER 999 TRAIN. IN GENERAL A UNIT TRAIN HAULS 10,000 TON COAL PER 1099 TRIP (1005,33). 1199 THE AVERAGE HAULAGE DISTANCE FOR 3 UNIT TRAINS STUDIED BY THE 1299 BUR OF MINES IS ABOUT 290 MI (1006,10). THIS IS ALSO THE 1399 APPROXIMATE DISTANCE BETWEEN CHICAGO AND THE SOUTHERN AREA OF 1499 ILLINOIS WHERE MOST OF THE COAL IN THIS REGION IS MINED. 1599 ASSUMING 290 MI AVERAGE HAULAGE DISTANCE FOR THIS REGION, FUEL 1699 CONSUMPTION IS 24200 GAL PER ROUND TRIP OR 1.14E5 GAL/1.0E12 1799 BTU. THE EMISSION FACTORS ARE COMPUTED FROM (0002,3-7). 1899 WINDAGE LOSSES, ASSUMED TO BE AIRBORNED AS PARTICULAES, ARE 1999 ABOUT .04 PC OF THE TONNAGE HAULED. SINCE THE LOSSES OCCUR 2099 MAINLY DURING HANDLING AT EITHER END POINT, THEY ARE ESSEN- 2199 TIALLY INDEPENDENT OF THE HAULAGE DISTANCE. THUS, 18.9 T OF 2299 COAL FINES ARE RELEASED AS PARTICULATES FOR EACH 1.OE12 BTU 2399 EUIVALENT T HAULED. 2499 III-79 1323 FTN. 1323-1330 CONSUMPTION OF DIESEL FUEL AMOUNTS TO 1.14E5 GAL/1.OE12 BTU (FOOT- 299 NOTE 1322). THUS, THE ENERGY CONSUMPTION IS 1.58E 10 BTU. 399 1324 199 THE AVERAGE MILES OF RAILROAD OPERATED IN THE EASTERN.DISTRICT 299 (DIVISIONS MADE BY ICC,(0033,II)) I-S 54000 MI (0033,59).. THUS, 399 FOR A RIGHT-OF-WAY OF 6 AC/MI (FOOTNOTE 1027) THE TOTAL LAND 499 USAGE IS 324,000 AC. 599 OF THE TOTAL TONNAGE OF FREIGHT HAULED IN 1971 214EO6 TON 699 WERE COAL, OR 43 PC. OF THIS 4.96EO6 TON OR 2.32 PC ORIGI- 799 NATED FROM ILLINOIS AND INDIANA (0039,27 AND 1004,52,53). 899 HENCE, 30.4 AC-YR/1.OE12 BTU IS ATTRIBUTED TO THE HAULAGE 999 OF COAL FROM ILLINOIS AND INDIANA. 1099 1325 199 IN THE EASTERN DISTRICT RAILWAY ACCIDENTS CLAIMED 705 LIVES, 299 INJURED 9304 PERSONS (OOC6,17,54) AND AN AVERAGE OF 93 MAN- 399 DAYS WERE LOST PER INJURY (0006,4). 499 OF THE TOTAL KILLED AND INJURED 0.0663 FATALATILS AND 0.876 599 NON-FATAL INJURIES ARE ATTRIBUTED T.0 THE TRANSPORT OF 1.OE12 699 BTUEQUIVALENT T FROM ILLINOIS AND INDIANA. FOR THE SAME 799 HAULAGE 81@3 MAN-DAYS ARE LOST. (FOOTNOTE 1324, COAL 899 TRANSP .0-RIED IN 197 1) 999 1326 199 THE INJURY STATISTICS ARE NATIONAL AVERAGES (FOOTNOTE 1063). NO 299 REGIONAL DATA HAVE BEEN LOCATED. 399 1327 199 THE INJURY STATISTICS ARE NATIONAL AVERAGES (FOOTNOTE 1061). NO 299 REGIONAL DATA HAVE BEEN LOCATED. 399 1328 199 THE AVERAGE HAULAGE DISTANCE IS ASSUMED TO BE 290 MI AND FUEL 299 CCNSUMPTION IS 0.005 GAL/TMI (FOOTNOTE 1322). ASSUMING 1000 399 TONS ARE CARRIED PER TRIP & COAL ACCOUNTS FOR 20PC OF THE 499 TONNAGE OF ANY ONE SHIPMENT,A GROSS TO TARE WEIGHT RATIO 599 OF 4 TO 1 AND ONLY ONE WAY DIESEL FUEL CONSUMPTION ATTRIBUTED 699 TO COAL, 1930 GAL OF DIESEL FUEL CONSUMED PER TRIP ARE 799 ATTRIBUTED TO THE SHIPMENT OF THE COAL OR 9.12E4 GAL/1.OE12 899 BTU. THE EMISSIONS ARE COMPUTED FROM INFORMATION ON DIESEL 999 LOCOMOTIVES IN (0002,3-7). 1099 THE WINDAGE LOSSES ARE ASSUMED TO BE APPROXIMATELY .08 PC OF' 1199 THE TOTAL SHIPMENT. HENCE, ABOUT 37.8 T ARE RELEASED TO THE 1299 ATMOSPHERE AS PARTICULATES. (MOST OF THESE LOSSES OCCUR 1399 DURING HANDLING AT EITHER END POINT.) 1499 1329 199 THE AVERAGE CAPACITY OF A BARGE IS 25000 T (1005,34), AND THE 299 AVERAGE HAULAGE DISTANCE IS ASSUMED TO BE 300 MI (THE APPRO- 399 XIMATE DISTANCE FRCM THE SOUTHERN COAL FIELDS OF ILLINOIS TO 499 CHICAGO VIA THE ILLINOIS RIVER). THE EMISSION IS CALCULATED 599 FROM DATA CN MOTORSHIPS UNDERWAY IN (0002,3-11) . 699 THE WINDAG-E LOSSES, OCCURING MAINLY FROM HANDLING AT THE 799 ORIGIN AND TERMINAL POINTS, ARE ASSUMED TO BE .04 PC OF THE 899 TOTAL SHIPMENT AS IN THE CASE FOR UNIT TRAINS. THUS, 18.9 T OF 999 COAL FINES ARE EMITTED AS PARTICTTLATES. 1099 1330 199 WHEN TRUCKS ARE UTILIZED IT IS USUALLY FOR SHORT HAULAGE DISTANCES 299 THAT AVERAGES ABOUT 10 MI (1013). Af-UMING AN AVERAGE TRUCK 399 CAPACITY OF 20 T, A GROSS TO NET WEIGHT RATIO OF 2.5 TO 1, AND 499 A FUEL CCNSUMPTION RATE OF 7 GAL/1000 TMI, 7700 GAL OF,DIESEL 599 FUEL IS CONSUMED/I.OE12 BTU. THE EMISSIONS FROM A DIESEL 699 ENGINE ARE GIVEN IN (0002,3-7). IT IS ASSUMED THAT .04 PC 799 OF THE TOTAL SHIPMENT IS LOST DUE TO WINDAGE (FOOTNOTE 1322). 899 THE AMOUNT RELEASED AS PARTICULATES IS, THEREFORE, 18.9 T. 999 111-71 FTN. 1331-1341 1331 199 FUEL CONSUMPTION FOR TRANSPORT BY TRUCK IS ETIMATED TO BE 7700 299 GAL/--OE12 BTU EQUIVALENT T HAULED (FOOTNOTE 1330). THUS 399 THE ENERGY CONSUMPTION IS 1.07E9 BTU (5.825E6 BUT/BBL). 499 1332 199 THE LAND USE BY DIESEL FREIGHT TRUCKS IS 1.67E-6 AC/TMI (FOOTNOTE 299 7026. THUS, THE LAND IMPACT ATTRIBUTED TO THE HAULAGE OF 399 THE COAL BY TRUCK IS 1.84 AC-YR/1.0E12 BTU (FOOTNOTE 1330). 499 1333 199 DIESEL FUEL CONSUMPTION BY MIXED TRAIN AMOUNT TO 9.12E4 GAL/ 299 1.OE12 BTU EQUIVALENT T HAULED. THUS, THE ENERGY CONSUMPTION 399 IS 1.26E10 BTU (5.8256E6 BTU/BBL) (SEE FOOTNOTE 1328). 499 1334 199 A BARGE CPMSI,ER 378 BTU/TMI (FOOTNOTE 7001). THUS, FOR AN AVERAGE299 HAULAGE DITANCE OF 300 MI (FOOTNOTE 1329), A BARGE CAPACITY 399 OF 25000 T AND ASSUMING A GROSS TO TARE WEIGHT RATIO OR 4 TO 499 1, THE ENERGY CONSUMPTION IS 8.94E9 BTU/1.OE12 BTU. 599 1335 199 WHEN A CONVEYOR IS USED FOR DISTRIBUTION OF COAL, IT IS GENERALLY 299 USED IN CONJUNCTION WITH ANOTHER MODE OF TRANSPORTATION, E.G., 399 BARGE OR TRAIN. THE HAULAGE DISTANCE IS RELATIVELY SHORT. ONE 499 OF THE LONGER (12 MI) SYSTEMS IS IN OPERATION IN WESTERN 599 KENTUCKY (1045) AND UTILIZES A CABLE DRIVER CONVEYOR. 699 FOR THE PURPOSES OF THIS ANALYSIS IT IS ASSUMED THAT THE 799 AVERAGE CONVEYOR LENGTH IS 5 MI. HENCE, FOR A RIGHT-OF-WAY OF 899 30 FT. 18.2 AC OF LAND IS OCCUPIED. THE SYSTEM TRANSPORTS 999 2 MMT/YR, THEREFORE IN TERMS OF ENERGY, O.420 AC-YR/1.OE12 1099 BTU OF LAND IS IMPACTED 1199 1336 199 ELECTRICAL ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEY- 299 ERS IS A 4.04E4 KWH/1.OE12 BTU (FOOTNOTE 1053). THE REAL ENERGY 399 CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT OF ELCTRICAL ENERGY 499 CONSUMPTION. 599 1337 199 STORAGE OF THE COAL IN A PILE AVERAGING 30 PT IN HEIGHT REQUIRES 299 THE USE OF 0.879 AC-YR/1.OE12 BTU 399 IT IS ASSUMED THAT UNDERGROUND STORAGE ALSO REQUIRES THE SAME 499 AMOUNT OF LAND. 599 1338 199 GENERALLY, SILOS HAVE A DIAMTER OF 70 FT AND ARE ABOUT 150 FT IN 299 HEIGHT. THE STORAGE CAPACITY IS APPROXIMATELY 11000 T (1OO6). 399 THUS, 5 SILOS ARE REQUIRED FOR STORING 1.OE12 BTU EQUIVALENT 499 T/ THE LAND IMPACTED BY THE SILOS IS THEREFORE 0.441 AC-YR/ 599 1/OE12 BTU. 699 1339 199 ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEYERS FOR 299 STORAGE AMOUNTS TO 1.72ER KWH/1.OE12 BTU (FOOTNOTS 1058, 1059, 399 1060). THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVA 499 LENT OF THE ELECTRICAL ENERGY CONSUMED. 599 1340 199 THE BTU EFFICIENCY FOR THE DENSE MEDIUM BATH WHICH WASHES 56 PC OF299 FEED IS 95.2 PC, WHILE THE UNWASHED PORTION (44 PC) HAS A 100 399 PC EFFICIENCY (SEE FOOTNOTE 1316). THUS, THE WEIGHTED AVERAGE 499 EFFICIENCY FOR THE PLANT IS 97.3 PC. 599 1341 199 ENERGY CONSUMPTION AT THE PREPARATION PLANT IS 2.42E9 BTU/1.OE12 299 BTU EQUIVALENT T PROCESSED. OF THE TOTAL CONSUMPTION, 1.8385 399 KWH ARE ELECTRICAL ENERGY AND 5.36E8 BTU ARE OIL (ASSUMING ALL 499 FUEL PURCHASED TO BE OIL). THE TOTAL IS OBTAINED BY ADDING 3 599 TIMES THE BTU EQUIVALENT OF THE ELECTRICAL POWER CONSUMPTION 699 TO THE FUEL USE. (SEE REF. (1064,12A-16,39)). 799 III-72 FTN. 1342-1348 1342 199 ENERGY CONSUMPTION AT A CRUSHING AND SIZING PLANT IS ABOUT 1.81E9 299 BTU/1 OE12 BTU EQUIVALENT T PROCESSED OF THE TOTAL CONSUMP- 399 TION, ELECTRICITY AMOUNT TO 1.59E5 KWH AND 2.72E8 BTU IS OIT 499 ASSUMING FUEL PURCHASED TO BE OIT AT A COST OF $.20/GAL (1064, 599 12A-16.39)/ THE TOTAL IS OBTAINED BY ADDING 3 TIMES THE BTU 699 EQUIVALENT OF THE ELECTRICAL ENERGY CONSUMPTION TO THE OIL 799 USAGE. 899 1343 199 BY LINEARLY INTERPCLATING THE DATA BETWEEN A 1 AND A 3 MMT/YR 299 AREA STRIPPTING OPERATION IN WESTERN KENTUCKY (1041,32, 54) THE 399 ENERGY REQUIREMENT FOR A 2 MMT/YR OPERATION IS ESTIMATED. IT 499 IS ASSUMED THAT OILS ARE DIESEL FUEL COSTING $0.20/GAL AND THE 599 COST OF ELECRICAL POWER TO BE $0.014/KWH. THE TOTAL ENERGY 699 CONSUMPTION FOR THE EXTRACTION OF 1.0E12 BTU EQUIVALENT T IS 799 COMPUTED TO BE 8.OOE9 BTU, WHICH IS COMPOSED OF 1.31E9 BTU OF 899 DIESEL FUEL AND 6.54E5 KWH OF ELECTRICAL ENERGY. THE TOTAL IS 999 3 TIMES THE BTU EQUIVALENT OF THE ELECTRICAL ENERGY CONSUMP- 1099 TION ADDED TO THE FUEL USAGE. ON A 1.OE12 BTU IN BASIS THE 1199 ENERGY CONSUMPTION IS 6.48E9 BTU. 1344 199 FUEL CONSUMPTION BY HAULAGE TRUCKS AMOUNTS TO 2920 GAL/1.OE12 299 BTU. THUS THE ENERGY CONSUMPTION IS 4.05E8 BTU (5.825E6 399 BTU/BBL).(SEE FOOTNOTE 1312). 499 1345 199 THE CONVEYOR SYSTEM CONSUMES 1.0-E6 KWH/YR OR ABOUT 24300 KWH/ 299 1.OE12 BTU (FOOTNOTE 1049). THE REAL ENERGY CONSUMPTION IS 3 399 TIMES THE BTU EQUIVALENT. 499 1346 199 A CRUSHER OPERATING AT 275 T/HR AND CRUSHING TO A TOPSIZE OF 1.5 299 IN. REQUIRES A 140 HP MOTOR (1014,7-14). THUS, 1.79E4 KWH OF 399 ENERGY ARE UTILIZED TO CRUSH 1.OE12 BUT EQUIVALENT T OF COAL. 499 THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT. 599 1347 199 THE EXPENSE INCURRED FOR ELECTRICAL POWER IS ESTIMATED TO BE 299 $0.17/T AT $0.01/KWH (1079). THUS, THE ENERGY REQUIREMENT FOR 399 AN UNDERGROUND MINING OPERATION IS 8,15E5 KWH/1.OE12 BUT 499 EQUIVALENT T EXTRACTED (AT 10600 BTU/LB,FOOTNOTE 1300). THE 599 PEAL ENERGY CONSUMPTION IS 8.23E9 BTU/1.OE12 BTU (3 TIMES THE 699 BTU EUIVALENT OF THE ENERGY REQUIREMENT). ON A 1.OE12 BTU 799 IN BASIS THE ENERGY CONSUMPTION IS 4.74E9 BTU. 899 1348 199 WINDAGE LOSSES FOR UNIT TRAIN, BARGE, AND TRUCKING AMOUNT TO 299 .04P (FOOTNOTES 1322, 1329, 1330), WHILE FOR MIXED TRAIN 399 LOSSES AMOUNT TO .08P (FOOTNOTE 1328). 499 III-73 r R o I I 1 2 A 5 1 1 Is 1. 15 1. 20 A, It 23 4 Is 1. v FUEL RIGION WATER POLLUTANTS (TONS' lo" STU. E.. COL 'I) AIR POLLUTA,MTS j-110" M) OCCUPATIONAL mEAETH PO"'Al"Al ALDE"Y swo, LAW. LARMI --l ACTMTY PROCESS -IDl wEPENoEo 'T.T L RIIIAL PARTI So. N,mo- Co TONU,, AcW,-) D LT E. EFFC-@ SCN-ID8 OL-S coo THE , ACIDI BASES P., No@ OTNER TOTAL(M md*BT ULAIII CARE- ETC (,..g I 3 LL -22201. -- 4 -4 WIN U.. ------ - - ------ 73 IN' PIN - ------- .11 - --------- 14 -------- -- -in i IT us L-2. I U@, ..N." I UU,j -I Im -- -.4 , . co ------- m, 7.- INN --mm m- I I'- 1.11-0I I ..-I I w vn- NWI U .,I. - ----- - I I I.,. I MIT 0- .1 W. WIN I WW -1 1 A -IN -1 WIN I- Is IF BE 2i IF `3 3 WE NOTE: ALL TABLE EXTRIES ARE MEO 04 iDI2 BTU D IF BE5OU*CF IRT06EK 3: P0 ESS OR ACTIVIT T. SEE IMTKeTE 13DO FOR NEASURE SOL TABIX 6. ENVMONMMAL BOACTS AM kwvwuaC2 ME IM @F C tl0 VAL EN [TALENTS GF ID12 IST15, mR Amo As, co.,Evi XAL AL Ahl) DES RIPTION. COMMOT1 R Cqj@ HB=5 f-v COAL SU"LY IL 111-75 Preceding p;ge bbg ACT T PRO C E !SS EITU I&- BTU ILMAO" AA_ T FOOTNOTES FOR TABLE 6 FTN. 1350-1354 1350 199 A HYDRATED LIME SYSTEM IS USED TO NEUTRALIZE THE DISCHARGE 299 FROM THE U.NDERGROUND MINE. ASSUMING AN ACID LOAD OF 250 PPM 399 THE PLANI WILL HAVETO PROCESS ABOUT 0.6 MMGAL/DAY (FOOTNOTE 499 1305., MINE DRAINAGE POLLUTANT LOADS). THUS, THE SOLID WASTE 599 PRODUCTICN IS ABOUT 3.0 AC-FT/YR (ESTIMATED FROM DATA IN 699 (1102, 233) . ASSUMING A PRECIPITATE rENSITY OF, 7 1 LB/CF (1114, 799 288) SOLID WASTE PRODUCED AT A RATE OF 4640 T/YR FOR A 2 MM 899 TPY MINE OR62.4 TON/1.OE12 BTU IN. 999 THIS IS IN ADDITION TO THE SOLID WASTE PRODUCED DURING THE 1099 MINING OPERATION - 1.61 T/1.OE12 BTU (FOOTNOTE 1306). 1199 1351 199 THE AVER AG E ANNUAL POWER REQUIREMENT IS 1.10E6 KWH/MMGAL/D (FOOT- 299 NOTE 1101). THUS, TO OPERATE THE 0.6 MMGAL/D HYDRATED LIME 399 F ACILITY 0 .66E6 KWH/YR , OR 8. 82 E3 KW H/1 . OE 12 BTU I N ARE 499 EXPENDED. THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU 599 EQUIVALENT OF THE ELECTRICITY CONSUMED. 699 THIS ENERGY IS IN ADDITION TO THE ENERGY REQUIRED FOR THE 799 MINING OPERATION, I. E., 4.75E9 BTU (FOOTNOTE 1347) . 899 1352 199 IT IS A,SSUMEE THAT THE FINAL rISCHARGE WILL BE IN COMPLIANCE WITH 299 THE GUIDELINES ESTABLISHED BY EPA (1112). IN LIME TREATMENTI 399 BECAUSE OF THE SOLUBILITY OF CALCIUM SULFATE, THE HARDNESS OF 499 THE WATER WILL INCREASE (1113,24). MOST OF THE METALLIC 599 SALTS WILL PRECIPITATE AS THE PH OF THE SOLUTION IS RAISED. 699 THE EFFLUENT BREAKDOWN IS AS FOLLOWS 799 899 PPM T/ 1.'0E 12 BTU I N 999 SUSPENDED SOLIDS 30 .210 1099 ACIDITY .0 0.00 1199 ALKALINITY 60 .420 1299 1399 IRON 4 .0280 1499 M N 4 ..0280 1599 AL 1 .00701 1699 CAS04 2000 14.0 1799 SUBTOTAL 14.1 169 9 1999' THE ALKALINITY CONCENTRATION IS OBTAINED FROM DATA IN REF. 2099 (1103), THE MN AND AL FRCM SOLUBILITY CURVES, WHILE THE 2199 REMAINDER ARE IN COMPLIANCE WITH THE EPA GUIDELINES. THE VOL- 2299 UME OF THE DISCHARGE IS ABOUT 85 PC OF THE INFLOW VOLUME 2399 (1103), I.E., 0.51 MMGAL/DAY. THE . FACILITY OPERATES 245 D/YR. 2499 13@3 199 IT.I5 ASSUMEE THAT THE TREATMENT FACILITY REQUIRES A 1 5 MMGAL RAW 299 WATER STORAGE POND AND A 30 NMGAL SETTLING POND. T@E LAND IS 399 ASSUMED AVAILABLE. FOR A DEPTH OF 20 FT FOR BOTH PONDS, 4.8 499 AC OF SUFFACE AREA ARE 'REQUIRED. THE TREATMENT PLANT OCCUPIES 599 ABOUT 3 AC (1114). THUS, THE TOTAL LAND !MPACTIIS .184 AC-YR/ 69 9. 1.OE12 BTU OUT OR .105 AC-YR/1.OE12 BTU IN. 799 THIS IS IN ADDITION TO THE 120 AC-YR/1.OE12 BTU IN OF LAND 899 IMPACTED DURING MINING (FOOTNOTE 1304). 999 1354 199 A HYDRATED LIME PROCESS IS UTILIZED TO NEUTRALIZE THE ACID rRAIN- 299 AGF,FROM THE AREA STRIPPING OPERATION. ASSUMING AN ACID LOAD 399 OF 500 PPM THE PLANT,WILL HAVE TO PROCESS 0.4'MMGAL/DAY 499 (FOOTNOTE 1310, MINE DRAINAGE POLLUTANT LOADS). THE TOTAL IRON 599 CCNCENTRATION IS ABOUT 75 PPM. THE SOLID WASTE PRODUCTION FOR 699 111-17 Preceding page blank FTN. 1355-1358 THE PLANT AMOUNTS TO ABOUT 4.4 AC-PT/YR (1101,233). ASSUMING 799 A PRECIPITATE DENSITY OF 71 LB/CF (1114,288), SOLID WASTE IS 899 GENERATED AT A RATE OF 6800 T/YR, OR 130 T/1.OE12 BTU IN. 999 THIS IS IN ADDITION TO THE 433 T/1.OE12 BTU IN OF SOLID WASTE 1099 PRODUCED DURING STRIPPING (FOOTNOTE 1308). 1199 1355 199 THE ENERGY REQUIREMENT TO OPERATE A 0.4 MMGAL/DAY HYDRATED LINE 299 PLANT IS 0.44E6 KWH/YR, OR 8.33E3 KWH/1.OE12 BTU IN (FOOTNOTE 399 1351). THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVA- 499 LENT OF THE ELECTRICAL ENERGY CONSUMED. 599 THE SPOILS ARE STACKED IN PILES ABOUT 80 FT HIGH. ASSUMING 699 GEOMETRICALLY UNIFORM PARALLEL SPOIL PILES RESTING AT AN AGNGLE 799 OF REPOSE OF 38 DEGREES, THE PEAK TO PEAK DISTANCE IS ABOUT 899 100 FT. THUS THE ENERGY CONSUMED DURING THE LEVELING OF THE 999 SPOIL BANKS AMOUNTS TO 3920 HP-HR/AC ((1222,67) AND ASSUMING 1099 A 6 PC PERFORMANCE EFFICIENCY), OR 5,56E7 BTU/1.OE12 BUT IN 1199 (FOOTNOTE 1307, LAND TO BE RECLAIMED). 1299 THE ENERGY UTILIZED FOR WASTE WATER TREATMENT AND RELCAMATION 1399 ARE IN ADDITION TO THE ENERGY USED DURING THE MINING OPERATION 1499 - 6.48E9 BTU (FOOTNOTE 1343). 1599 1356 199 IT IS ASSUMED THAT THE FINAL DISCHARGE WILL BE IN COMPLIANCE WITH 299 THE GUIDLINES ESTABLISHED BY EPA (1112). THE VOLUME OF DIS- 399 CHARGE IS ABOUT 85 PC OF THE IN FLOW VOLUME (1103), I.E., 499 0.340 MMGAL/DAY. THE EFFLUENT BREAKDOWN IS AS FOLLOWS (FOOT- 599 NOTE 1352). THE FACILITY OPERATES 245 D/YR. 699 PPM T/1.OE12 BTU IN 799 SUSPENDED SOLIDS 30 .198 899 ACIDITY 0 0.000 999 ALKALINITY 60 .398 1099 1199 IRON 4 .0266 1299 MN 4 .0266 1399 AL 1 .00663 1499 CASO4 2000 13.3 1599 SUBTOTAL 13.4 1699 1357 199 FOR AREA STRIPPING (SLOPE LESS THAN 15 DEGREES) 5.57 AC OF LAND 299 ARE OVERTURNED PER 1.OE12 BUT IN (FOOTNOTE 1307). 399 499 IN TIME AVERAGING THE LAND IMPACT THE EFFECTS OF RECLAMATION 599 MUST BE CONSIDERED. RECLAMATION IN THIS CASE REQUIRES THE 699 RESTORATION OF THE LAND TO THE ORGINIAL CONTOUR (OR AS CLOSE 799 TO THE ORIGINAL CONTOUR AS POSSIBLE), AND STABILIZING TH 899 SURFACE AGAINST EROSION. MINIMIZING EROSION INVOLVES BENEFI- 999 CIAL GRADING (TERRACING;, GOUGING, ETC.) AND ESTABLISHING AN 1099 HERBACEOUS COVER. IN APPALACHIA ABOUT 3 GROWING SEASONS ARE 1199 REQUIRED TO ESTABLISH A 95 PC COVER OF GRASS AND LEGUMES. 1299 (1101). IT IS ASSUMED THIS ALSO APPLIES IN THIS REGION, SINCE 1399 ADEQUATE MOITURE AND TOPSOIL ARE GENERALLY AVAILABLE. 1499 USING THE 3 YR CRITERION THE TIME AVERAGED LAND IMPACT IS 1599 15.7 AC-YR/1.OE12 BUT IN. TH LAND IMPACT DUE TO THE WASTE 1699 PILE IS ASSUMED TO BE NIL, WHICH IMPLIES INSTANTEOUS 1799 RECLAMATION. 1899 IT IS ASSUMED THAT THE TREATMENT PLANT REQUIRES A 1 MMGAL RAW 1999 WATER STORAGE POND AND A 45 MMGAL SETTLING POND. THE LAND IS 2099 ASSUMED AVAILABLE, FOR AN AVERAGE DEPTH OF 20 FT FOR BOTH 2199 PONDS, ABOUT 7.0 AC OF SURFACE AREA ARE REQUIRED. THE TREAT- 2299 MENT PLANT OCCUPIES APPROXIMATTELY 3 AC (1114). THUS, THE LAND 2399 IMPACT IS 0.191 AC-YR/1.OE12 BTU IN. 2499 1358 199 III-78V FTN. 1359-1364 TO CONTROL SILTATION, THE RUNOFF FROM THE HAUL ROADS ARE DIVERTED 299 TO SETTLING PONDS PLACED ALONG THE ROADWAY (1100). IT IS 399 ASSUMED THAT ALL THE SEDIMENT IS REMOVED. 499 1359 199 IT IS ASSUMED THAT A SETTLING POND IS REQUIRED FOR EACH MILE OF 299 ROAD AND THAT EACH POND USES AN ACRE OF LAND. THUS, 4 AC ARE. 399 UTILIZZD FOR THE SETTLING POND (THE HAUL ROAD IS 3.8 MI LONG, 499 FOOTNOTE,1312). THE LAND IMPACT IS 0.0945 AC-YR/1.OE12 BTU. 599 THIS IS IN ADDITION TO THE LAND IMPACTED BY THE ROAD - 0.584 699 AC-YF/1.OE12 BTU (FOOTNOTE 1311). 799 1360 199 SEEPAGE FROM THE REFUSE PILE IS ASSUMED TO BE COMPLETELY 299 ELIMINATED BY THE SOIL COVER ESTABLISHED IN RECLAIMING THE 399 REFUSE PILE. RUNOFF FROM THE REFUSE PILE, HOWEVER, CONTINUES 499 BECAUSE OF THE 3 YEAR TIME LAG ASSOCIATED WITH ESTABLISHMENT 599 OF AN HERBACEOUS COVER (FOOTNOTE 1103). BASED ON 2.54 TON 699 SUSPENDED SOLIDS/ACRE-YR-TN RUNOFF AND ON 10 IN RUNOFF AND 799 .149 AC-YR/1.OE12 BTU (FOOTNOTE 1363), 3.78 TON SUSPENDED 8199 SOLIDS/1.OE12 BTU ARE GENERATED IN RUNOFF FROM THE RECLAIMED 999 REFUSE PILE. SUSPENDED SOLIDS.GENERATED IN THE PREP PLANT ARE 1099 ELIMINATED BY THE USE OF A SETTLING EOND. 1199 1361 199 EMISSIONS ASSOCIATED WITH TH E BURNING COAL REFUSE PILE (FOOTNOTE 299 13,15) ARE COMPLETELY ELIMINATED BY RECLAMATION OF THE REFUSE 399 PILE. BAGHOUSES FOR CONTROL OF FUGITIVE DUST EMISSIONS ARE 499 USED IN THE CONTROLLED UTILITY PREP PLANT IN ORDER TO COMPLY 599 WITH THE 10P OPACITY LIMIT FOR VISIBLE EMISSIONS FROM NEW 699 PREP PLANTS (1121). 799 1362 199 IT HAS NOT BEEN POSSIBLE TO QUANTIFY FUGITIVE DUST EMISSIONS FROM 299 COAL PREP PLANTS. THUS IT IS NOT ' POSSIBLE TO QUANTIFY THE 399 INCREMENIAL SOLID WASTE GENERATED BY THE USE OF BAGHOUSES TO 499 CONTROL THESE EMISSIONS. THEREFORE,.THE SOLID WASTE GENERATED 599 IN THE CCNTROLLED UTILITY COAL PREP PLANT IS THE SAME AS GIVEN 1699 IN FOOTNOTE 13180 NAMELY 4130 TON/1.OE12 BTU IN. 799 1363 199 BASED ON A SOLID WASTE PRODUCTION OF 4130 TON/I.OE12 BTU (FOOTNOTE 299 1362), A COMPACTED REFUSE DENSITY OF .06 TON/CF, AND A 30 FT 399 HIGH REFUSE PILE. .053 ACRES OF LAND/1.OE12 BTU is IMPACTED. 499 BASEL CN A 3 YEAR TIME LAG TO ESTABLISH AN HERBACEOUS COVER 599 AND A 25 YR PLANT OPERATING LIFETIME, 2.82 TIMES THE YEARLY 699 LAND IMPACT REPRESENTS THE TIME AVERAGED LAND IMPACT (FOOTNOTE 799 1103). THUS .149 ACRE-YR/1.OE12 BTU IS THE TIME AVERAGED LAND 899 IMPACT. THE LAND REQUIREMENT FOR THE UTILITY COAL PREP PLANT 999 IS 2.24 ACRE-YR/1.OE12 BTU (FOOTNOTE 1319) SO THAT THE TOTAL 1099. LAND REQUIPEM.ENT is 2.39 ACRE-YR/1.OE12 BTU. 1199 1364 199 THE TGTAL POWER 2EUIREMENT FOR THE 7 BAGHOUSES IN A 500 TON/HR 299 PREP PLANT IS 175 HP (108.0,73) OR 4.55EO5 KWH/YR (BASED-ON 399 348.0 HR/YR OPERATION). CONVERTING THIS-BY 10200 BTU/KWH AND 499 SIZING THE RESULT i FOR A 1.OE12 BTU/YR PREP PLANT GIVES AN 599 ENERGY REQUIREMENT OF 1.26E08 BTU/1.OE12 BTU. NO INFORMATION 699 WAS AVAILABLE ON ENERGY REQUIREMENTS FOR REFUSE RECLAMATION. 799 THE ENERGY REQUIRED FOR THE CLOSED CIRCUIT SETTLING POND IS 899 BASED ON .0457 $/TON SUSPENDED SOLIDS (FOOTNOTE 1126), 156 T 999 OF SOLIDS (FOOTNOTE 1321), AND $.01/KWH TO GIVE 7.13EO2 KWH/ 10'9 9 1.OE12 ETU OR 7.26EO6 BTU/1.0E12 BTU (CONVERTING AT 10200 BTU 1199 /KWH). THE SUM TOTAL INCREMENTAL ENERGY. DEMAND ASSOCIATED WITH1299 CONTROLS ON A 1.OE12 BTU/YR UTILITY COA L PREP PLANT IS THUS 1.399 1.33EO8 BTU/1.OE12 BTU. 14,99 111-79 z 31 5 6 1 A I I. I I IN .3 14 11 1. NI .9 20 22 2A WATER POLLUTANTS (TO.S1 IOU TO, COL 12) AIR POLLUTAW- M) OCCUY*TICAUL 1EALT1 POTE-AL HY - swos LAR.f P BOO Co. So, TOTAL -15/ NON. ACTiviry PROCESS NsTmvfo SOLIDS AM wz@-7 PAFIT- ALINE -T A UNBRUNCA 1OT L T- OTHER rOTAL(DS) yU ULATES SCALE 10"'c'e... IN ACIDS BASES Po. No, SOLID .-s ETC.. .1R) De"'I 'o. m 'o' RTU ---------- .0 ------ 72 -2 R, I--- @3 75 -10 14 IS mmm 2!j -Bill 9 72 24 47 --ni ---.mL 27 w 7* 42 44 43 43 4P NDTE:6 ALL TABLE ENTRIES ARE BASED OR IDIZ BTU GF FESOURCE LXT6 EAC14 PROCESS OR ACTIVITY. SEE lo'T"O" "A'OLA FDA KEA@URE EQ.11AL EATI ZF 1312 BTU. SULFUR AND A-R CONTENTS TABLE7. ENVIRONMMTAL MIPACTS AND EMCMMCY XM THE 1RE.1 All @."H COAL AND REQIo%A, VE!C1,11n@ UNCONTROLLED NORTM3RN AppALAC3UA REGION OF CQALL SUPPLY 111-81 preceding.. page blank FTN. 1400-1402 POO',:NOTES FOR TABLE 7 1400 199 THE REGION OF NORTHERN APPALACHIA INCLUDES CENTRAL A NE WESTERN 299 PENNSYLVANIAi NORTHERN W..VIRGINIA AND OHIO. THE AVERAGE 399 CALORIC CONTENT OF COAL DELIVERED TO ELECTRIC UTILITIES IN 499 THIS REGION DURING THE 3RD AND 4TH QUARTERS OF 1972 WAS 11800 599 BTU/LB (1212 AND 1213). THE AVERAGE ASH AND SULFUR CONTENT OF 699 THE COAL IN THIS REGION, INCLUDING MARYLAND, IS 14.7 AND 3.07 799 PC, RESPECTIVELY (1053,9). (THE AVERAGE SULFUR CONTENT OF COAL 899 DELIVERED TO ELECTRIC UTILITIES DURING THE 3RD QUARTER OF 1972 999 WAS 2.31 PC (1212)..) 109q FOR THE COAL IN THIS REGIGN,1.GE12 BTU IS EQUIVALENT TO 1199 42400 T GF COAL. ALL, COMPUTATIONS ARE BASED 09 1.OE12 BTU IN. 1299 THE DENSITY OF THE COAL IS ABOUT 85 LB/CF (1050). 1399 1401 199 SOLID WASTE PRODUCTION FROM UNDERGROUND MINES IS IN GENERAL.RELAT- 299 ED TO THE CFENING OF THE MINE (SHAFT SINKING FOR SHAFT AND 399 SLOPE MINES). ASSUMING AN AVERAGE MINE DEPTH OF 600 FT AND 499 AN ADIT OF-100 SF, 3000 T OF EARTH ARE REMOVED TO SINK THE 599 SHAFT. 699 SIZABLE UNDERGROUND MINES HAVE AN AVERAGE'PRODUCTIVE LIFE OF 799 ABOUT 25 YRS PRODUCING 2 MMT/YR (1018). HENCE, SOLID WASTE, 899 IS'@PRODUCED AT A RATE OF 60 T/MMT OF COAL MINED, OR 999 1.45 T/1.OE12 BTU INFOR ROOM AND PILLAR MINING AND 2.16 T/ 1099 1.OE12 BTU IN FOR LONGWALL MINING. 1199 1402 199 THE AVERAGE SEAM THICKNESS OF COAL MINED UNDERGROUND IN' THIS 299 19cc WAS 5." FT 11017). ASSUMING THIS VALUE STILL 399 v .0 A s . k APPLIES 4.49 AC OF LAND ARE UNDERMINED PER 1.OE12 BTU 499 EQUIVAHNT TON IN. 599 OF THE ACREAGE UNDERMINED APPROXIMATELY 25P WILL SUBSIDE 699 (1019) . THIS SUBSIDENCE RATE IS ACTUALLY FOR ALL UNDERGROUND 799 COAL MINES, BUT SINCE THE ROOM .6 PILLAR TECHNIQUE HAS BEEN 899 PREDOMINANT 'IN THE U.S., IT IS ASSUMED THAT THIS FIGURE CHAR- 999 ACTERIZES THE SUBSIDENCE FOR ROOM & PILLAR MINING. EVENTUALLY 1099 ALL OF TEE AREA UNDERMINED MAY SUBSIrE, BUT THE TIME SCALE 1199 IS IN EXCESS OF A CENTURY. THE 25P SUBSIDENCE RATE IS DERIVED 1299 FROM HISTORICAL OBSEPVATIONS. 1399 SUBSIDENCE AFFECTS A SURFACE AREA GREATER THAN THE AREA 1499 UNDERMIN.ED.*THE WIDTH ON THE PERIMETER THAT IS AFFECTED BY 1599 SUBSIDENCE IS DETERMINED FROM 1699 1799 R=H TANX 1899 WHERE, R=WIDTH OF THE PERIMETER AREA AFFECTED, H=DEPTH OF @1999 2099 MINE, ANE X=ANGLE OF DRAW (ANGLE BETWEEN A VERTICAL LINE, AND 2199 A LINE CCNNECTING THE FACE AND THE LIMIT OF SUBSIDENCE),. THE 2299 ANGLE OF DRAW HAS BEEN CONSISTENTLY CBSERVED IN EUROPEAN COAL 2399 FIELDS TO FALL BETWEEN 35-39 DEGREES (1027,232,233). THUS,FOR 2499 AN ANGLE OF DRAW OF 37 DEGREES AND A. MINE DEPTH OF 600 :FT, ..THE 2599 WIDTH.OF THE AFFECTED PERIMETER AREA IS 452 FT. 2699 OF THE UNDERMINED AREA 1.12 AC SUBSIDES. ASSUMING A SQUARE 2799 AREA, THE SIDES ARE 221 FT IN LENGTH. HENCE, AN ADDITIONAL 2899 9.117 AC ARE AFFECTED. THE TOTAL AREA AFFECTED BYSUBSIDENCE 2999 ENCOMPASSES.10.3 AC. 3099 TIME AVERAGING THIS VARIABLE LAND USAGE OVER-25 YRS,(FOOTNOTE 3199 1401) THE LAND IMPACT IS 129 AC-YR/1.OE12 BTU IN. 3299 IN A PILE 30 FT IN HEIGHT, 4.59 E-2 AC OF LAND IS OCCUPIED By 3399 THE REFUSE PILE (FOOTNOTE 1401, SOLIE WASTE PRODUCTION)@. FOR 3499 111-83 Preceding page blank FTN. 1403-1404 AN ANNUAL PRODUCTION OF 2 MMT (FOOTNOTE 1041), THE LAND 3599 IMPACT IS 5.53E-4 AC-YR/1.OE12 BTU IN. 3699 1403 199 THE AVERAGE SEAM THICKNESS IS 5.1 FT (FOOTNOTE 1402). THUS, 299 4.49 AC ARE UNDERMINED FOR EACH 1.OE12 BTU IN. SINCE IN 399 LONGWALL MINING THE ROOF IS COLLASED AS MINING PROGRESSES, 499 IT IS ASSUMED THAT ALL OF THE SURFACE AREA UNDERMINED WILL 599 SUBSIDE. THE WIDTH OF THE AREA OF INFLUENCE IS 452 FT 699 (FOOTNOTE 1402) AND, ASSUMING A SQUARE AREA, THE LENGTH OF THE 799 SIDES OF THE UNDERMINED ACREAGE IS 442 FT. HENCE, AN ADDI- 899 TIONAL 18.3 AC ARE AFFECTED BY SUBSINENCE. 999 THE TIME AVERAGED (OVER 25 YRS, FOOTNOTE 1401) VALUE OF THE 1099 LAND IMPACTED BY SUBSIDENCE IS 285 AC-YR/1.OE12 BTU IN. 1199 THE LAND UTILIZED FOR STORAGE OF THE REFUSE IS 8.25E-4 1299 AC-YR/1.OE12 BTU IN (FOOTNOTE 1402). 1399 1404 199 IT IS ASSUMED THAT THE DRAINAGE FROM UNDERGROUND MINES IS THE SAME299 REGARDLESS OF THE METHOD UTILIZED. THIS IS NOT STRICTLY TRUE. 399 SINCE THE RATE OF SUBSIDENCE FOR LONGWALL MINING IS GREATER, 499 THE AMOUNT OF SEEPAGE (THROUGH FAULTS) INTO THE MINE WILL TEND 599 TO BE LARGER THEREBY LEADING TO INCREASED DRAINAGE. BUT IT IS 699 ALSO TRUE THAT THE DRAINAGE BETWEEN MINES, IRRESPECTIVE OF THE 799 MINING TECHNIQUE EMPLOYED, WILL VARY TO A DEGREE THAT MY EVEN 899 BE GREATER. 999 THE ACID DRAINAGE FROM ACTIVE DEEP MINES IN NORTHERN APPALA- 1099 CHIA OCCURS AT A RATE OF 905 T OF ACIDITY/DAY, OR 0.0028 T/- 1199 OF COAL MINED. (THE ACIDITY IS COMPUTED FROM DATA ON SUB-AREAS 1299 3-13 AND 16 IN REF. (1039,5,8,9) ASSUMING THE CONTRIBUTION 1399 FROM THE DIFFERENT SOURCES ARE IN THE SAME PROPORTION AS FOR 1499 ALL OF APPALACHIA, THE PRODUCTION FIGURES ARE OBTAINED FROM 1599 REF. (0001).) THE SULFATE LOADING IS ABOUT TWICE AS MUCH AS 1699 THE ACID LOADING. (1039). 1799 THE CHEMICAL COMPOSITION OF THE DRAINAGE FROM THE ACTIVE MINES 1899 IS ESTIMATED FROM DATA ON THE MONOGAHELA RIVER BASIN (1039, 1999 133/139). THE DATA FROM 10 GAGING STATIONS WERE USED IN THE 2099 ESTIMATION AND THE COAL PRODUCTION FIGURES WERE OBTAINED FROM 2199 RED. (0001). IN DETERMINING THE HARDNESS, A CONCENTRATION OF 2299 100 MG/L WAS ASSUMED TO OCCUR NATURALLY, WHILE THE METALLICE 2399 CONSTITUENTS ARE ASSUMED TO ORIGINATE FROM THE MINES. THE 2499 RELATIVE CONTRIBUTION FROM THE DIFFERENT SOURCES WAS ASSUMED 2599 TO BE THE SAME AS FOR AL OF APPALACHIA. THE EFFLUENT 2699 BREAKDOWN IS AS FOLLOWS 2799 ROOM & PILLAR LONGWALL 2899 T/1.OE12 BTU IN T/1.OE12 BTU IN 2999 HARDNESS 295.0 440.0 3099 FE 5.2 7.7 3199 MN 2.2 3.3 3299 AL 0.65 0.97 3399 SO4 135.0 202.0 3499 TOTAL 438.1 654.0 3599 3699 ACIDITY 67.7 101.0 3799 3899 THE SEDIMENT YIELD FROM THE SOLID WASTE PILE OCCURS AT A RATE 3999 OF 2.54 T/AC-YR-IN OF RUNOFF (COMPUTED FROM DATE IN REF. 4099 (1020). THE RUNOFF IN THIS REGION AVERAGES ABOUT 20 IN/YR. 4199 THUS, THE SEDIMENT YIELD AMOUNTS TO 2.81E-2 T/1.OE12 BTU IN 4299 FOR ROOM AND PILLAR MINES (FOOTNOTE 1402, LAND USE BY REFUSE 4399 PILE) AND 4.19E-2T/1.OE12 BTU IN FOR LONGWALL MINES (FOOTNOTE 4499 1403, LAND USE BY REFUSE PILE). III-84 FTN. 1405-1408 1405 199 THE AVERAGE DEPTH OF OVERBURDEN OF COAL MINED IN 1965 WAS 47 FT 299 (1017). IN AREA SURFACE MINING ALL OF THE OVERBURDEN, EXCEPT 399 THAT WHICH IS REMOVED DURING THE BOX CUT, IS DEPOSITED IN 499 SPOIL BANKS IN THE EXCAVATED AREA. HENCE, THE SOLID WASTE IS 599 PRODUCED ONLY DURING THE INITIAL EXCAVATION. THE DENSITY OF 699 THE OVERBURDEN IS ABOUT 0.05 T/CF. ASSUMING THAT ON THE AVER- 799 AGE 5 AC (PIT SIZE OF ROUGHLY 100 FT BY 2000 FT, (lC07)) ARE a99 EXCAVATED FOR THE BOX CUT AND 50 MMT OF COAL ARE CONSEQUENTLY 999 EXTRACTED, SOLID WASTE PRODUCTION OCCURS AT'A RATE OF 0.0103 1099 T/T OF COAL, OR 352 T/1.OE12 BTU IN. 1199 THE PRODUCTIVE LIFE OF SIZABLE AREA STRIP MINES IS ABOUT 25 1299 YRS WITH AN AVERAGE OF 2 MMT/YR (1018). 1399 14-06 199 THE AVERAGE SEAM THICKNESS FOR SURFACE MIN,ES IN THIS REGION IS 299 319 FT (1017). 399 IT IS ASSUMED THAT SURFACE MINING ON SLOPES LESS THAN 15 499 LEGREES IS DONE BY AREA STRIPPING, WHILE ON STLEPER SLOPES 599 CONTOUR STRIPPING IS IMPLOYED. 699 FOR A COAL DENSITY OF 85 L'B/CF, 5.87 AC OF LAND IS OVERTURNED 799 PER 1.OE12 BTU EQUIVALENTTOIN IN. THUS, THE TIME AVERAGED (OVER 899 25 YRS, FOOTNOTE 1405) LAND IMPACT IS 73.4 AC-YR/1.OE12 BTU 999 IN. 1099 IN A PILE 30 FT IN HEIGHT, THE SOLID WASTES PILE OCCUPIES 1199 0.135 AC-YR/1.OE12 BTU IN (FOOTNOTE 1405). 1299 1407 199 THE ACID DRAINAGE FROM ACTIVE SURFACE MINES IN.NORTHERN APPALACHIA 299 OCCURS AT A RATE OF 47 T OF ACIDITY/DAY OR 0.0002 T/T OF COAL 3919 MINED (lb39,5,8,9)(SEE ALSO FOOTNOTE 14C4). THE SULFATE 499 LOADING IS ABOUT TWICE THE ACID LOADING (1039). THE CHEMICAL 599 COMPOSITION OF THE DRAINAGE WAS DETERMINED FROM DATA ON THE 699 MCNONGAHELA RIVER BASIN (FOOTNOTE 1404). THE EFFLUENT 799 BREAKDOWN IS AS FOLLOWS 899 STRIP CONTOUR 999 T/1.OEI2 BTU IN T/1.OE12 BTU IN 1099 HARDNESS 30.9 30.6 1199 F E 0.5 .0.5 1299 MN 0.2 0.2 1399 AL 0.07 0.07 1499 S04 13.8 13.6 1599 TOTAL 45.5 45.0 1699 ACIDITY 6.9 6.8 1899 1999 THE SEDIMENT IS YIELDED AT A RATE OF .2.54 T/AC-YR-IN. OF 2099 RUNOFF. THE AVERAGE RUNOFF FOR THIS REGION IS ABOUT 20 IN. 2199 FOR AREA STRIPPING, THE SEDIMENT YIELD IS 6.86 T/1.OE12 BTU 2299 IN (FOOTNOTE 1406, LAND USE BY SOLID WASTE PILE) AND FOR 2399 CONTOUR STRIPPING THE SEDIMENT YIELD IS 2650 T/I.OE12 BTU IN 2499 (FOOTNOTE 1413, LAND USE SPOIL BANK). 21599 1408 199 BY LINEARLY INTERPOLATING THE DATA BETWEEN A 1 AND A 2 MMr/YR 299 AREA STRIPPING OPERATION IN WESTERN KENTUCKY:(1041,32,54),TfiE 399 POWER CONSUMPTION FOR A 2 MMT/YR OPERATION IS DETERMINED. IT 499 IS ASSUMED THAT THE OILS ARE DIESEL FUELS COSTING $0.20/GAL 599 AND THE COST OF ELECTRICAL POWER TO 9,E $0.015/KWH. THE TOTAL 699 ENERGY CONSUMPTION FOR THE EXTRACTION OF 1.OE12 BTU EQUIVALENT 799 T IS COMFUTED TO BE 7.18E9 BTU, WHICH IS COMPOSEE OF 1.18E9 899 BTU OF DIESEL FUEL AND 5.87E5 KWH OF ELECTRICAL POWER. IN 999 OBTAINING THE TOTAL, 3 TIMES THE ELECTRICAL POWER USAGE IS 1099 ADDED TO THE FUEL CONSUMPTION. ON A 1.OE12 BTU IN BASIS THE 1199 ENERGY CONSUMPTION IS 5.82E9 BTU. 111-85 1299 FTN. 1409-1413 1409 199 THE DIESEL FUEL CONSUMPTION FOR AN AREA STRIPPING OPERATION IS 299 ESTIMATED TO BE 6890 GAL/1.OE12 BTU IN (FOOTNOTE 1408). THE 399 EMISSION FACTORS ARE OBTAINED FROM REF. (0002,3-7) ASSUMING 499 THE CHARACTERISTICS OF A DIESEL TRUCK ENGINE. (HEAT CONTENT) 599 OF DIESEL FULE IS 5.825E6 BTU/BBL) SINCE ADEQUATE MOISTURE 699 IS AVAILABLE IN THIS AREA, FUGITIVE DUST IS NOT EXPECT TO 799 BE A SERIOUS PROBLEM. 899 1410 199 BY LINEARLY INTERPOLATING THE DATA IN REF. (1041, 12, 23), AND 299 ASSUMING THE OILS TO BE DIESEL FUELS COSTING $O.20/GAL AND THE 399 COST OF POWER TO BE $0.014/KWH THE TOTAL ENERGY CONSUMPTION 499 FOR A 2 MMT/YR CONTOUR STRIPPING OPERATION IS ABOUT 1.36E10 599 BTU FOR EVERY 1.0E12 BTU EQUIVALENT T EXTRACTED. THE TOTAL IS 699 COMPOSED OF 1.87E0 BTU OF FUEL AND 1.17E6KWH OF ELECTRICAL 799 POWER. THE TOTAL IS OBTAINED BY ADDING 3 TIMES THE BTU 899 EQUIVALENT OF THE ELECTRICAL POWER USAGE TO THE FUEL CONSUMP- 999 TION. ON A 1.OE12 BTU IN BASIS THE ENERGY CONSUMPTION IS 1099 1.09E10 BTU. 1199 1411 199 THE EXPENSE INCURRED FOR ELECTRICAL POWER IS ESTIMATED TO BE 299 $0.17/T AT $0.01/KWH (1079). THUS, THE ENERGY REQUIREMENT FOR 399 AN UNDERGROUND MINING OPERATION IS 7.21E5 KWH/1.0E12 BTU 499 EQUIVALENT T EXTRACTED (AT 11800 BTU/LB, FOOTNOTE 1400). THE 599 REAL ENERGY CONSUMPTION IS 7.38E9 BTU/1.E12 BTU (3 TIMES THE 699 BTU EQUIVALENT OF THE KWH REQUIREMENT). 799 THE ENERGY CONSUMPTION FOR A LONGWALL MINING OPERATION IS 899 ABOUT 10 PC LESS THAN THE ENERGY USED IN A ROOM AND PILLAR 999 MINE (1079). THUS, FOR EVERY 1.OE12 BTU EQUIVALENT T OF COAL 1099 EXTRACTED, 6.49EFKWH OR 6.64E9 BTU OF ENERGY ARE CONSUMED. 1199 THE CONDITINS UNDER WHICH THE ENERGY CONSUMPTION FIGURE WAS 1299 DEVELOPED DO NOT EXACTELY COINCIDE WITH THE CONDITIONS UNDER 1399 WHICH THE ENVIRONMENTAL IMPACTS WERE DETERMINED (FOOTNOTE 1499 1826). ON A 1.OE12 BTU IN BASIS, THE ENERGY CONSUMPTION FOR 1599 ROOM AND PILLAR MINES IS 4.21E9 BTU AND FOR LONGWALL MINING 1699 IS IS 5.64E9 BTU. 1799 1412 199 THE DIESEL FUEL CONSUMPTION FOR A CONTOUR STRIPPING OPEATION IS 299 ESTIMATED TO BE 10800 GAL/1.OE12 BTU IN (FOOTNOTE 1410 AND 399 5.825E6 BTU/BBL OF DIESEL FUEL.) THE EMISSION FACTORS ARE 499 OBTAINED FROM REF. (0002,3-7) ASSUMING THE CHARACTERISTICS 599 OF A DIESEL TRUCK ENGINE. 699 SINCE ADEQUATE MOISTURE IS AVAILABLE IN THIS REGION, FUGITIVE 799 DUST ISN OT EXPECTED TO BE A SERIOUS PROBLEM. 899 1413 199 FOR A COAL SEAM THICKNESS OF 3.9 FT (1017) AND A COAL DENSITY OF 299 85 LB/CF, 5. 87 AC OF LAND IS OVERTURNED PER 1.OE12 BTU 399 EQUIVALENT TONS IN. 499 ON SLOPES GREATER THAN 15 DEGREES, TECHNIQUES OF CONTOUR STRIP- 599 PING ARE EMPLOYED. IT IS ASSUMED THAT THE CONVENTIONAL CON- 699 TOUR MINING IS USED. EXCEPT FOR THE MATERIAL USED TO BACKFILL 799 THE BENCH, ALL OF THE OVERBURDEN IS DEPOSITED ON THE OUTSLOPE 899 AND ASSUMED TO REST AT THE ANGLE OF REPOSE (ABOUT 37 DEGREES). 999 IT IS ALSO ASSUMED THAT A 15 FT RIM OF BLOSSOM COAL IS LEFT 1099 IN PLACE. THE MEAN SLOPE ANGLE AND THE BENCH WIDTH ARE 1199 ASSUMED TO BE 20 DEGREES (1028, 51) AND 150 FT RESPECTIVELY. 1299 (THE 20 DEGREE SLOPE ANGLE IS THE AVERAGE FOR SLOPES GREATER 1399 THAN 15 DEGREES IN NORTHERN APLPALACHIA). HENCE, A HIGHWALL 1499 III-86 FTN'. 1414-1417 IF 11 FT 11 CREATED All TO 1111 TIE REQUIRED.TONNAGE OF COAL, 1599 1705 FT OF HIGHWALL (BENCH LENGTH) ARE GENERATED. THUS, FOR 1699 A SPOIL BANK WITH A MEAN HEIGHT OF 45 FT, THE PILE REACHES 1799 .95.9 FT DOWNSLOPE FROM THE OUTCROP AND ENCOMPASSES AN AREA 1899 OF'3.75 AC/1.OE12 BTU IN. 1999 THE DRAINAGE DITCH ABOVE THE HIGHVALL IS ASSUMED TO AFFECT 2099 50 FT UPSLOPE, HENCE, AN ADDITIONAL 1.96 AC/1.OE12 BTU IN 2199 OF LAND IS AFFECTED. 2299 CALCULATIONS FROM DATA COLLECTED IN EASTERN KENTUCKY (1029, 2399 1030,1031,1032,1033,1034) INDICATE THAT LAND AFFECTED BY 2499 LANDSLIDES AMOUNT TO 11.4 RC OF THE OUTSLOPE AREA COVERED BY 2599 THE SPOILS. THUS, AN ADDITIONAL LAND ACREAGE OF 0.428 AC/ 2699 1.OE12 BTU IN IS DAMAGED. (IT IS RECOGNIZED THAT THIS WILL 2799 NOT BE THE CASE FOR ALL MINES. SOME STATES REQUIRE PRACTICES 2899 THAT MINIMIZE THE OCCURRENCE OF LANDSLIDES. OBSERVATIONS .2999 INDICATE THAT THE OCCURRENCE OF LANDSLIDES IS- SIGNIFICANTLY 3099 REDUCII WHEN THE SPOIL PILES ARE STABILIZED.) 3199 ALTHOUGH RECLAMATION PRACTICES ARE EMPLOYED, NOT ALL STATES 3299 HAVE MANDATORY VEGETAL SURVIVAL RATE REQUIREMENTS (1028) NOR 3399 ARE THERE STIPULATIONS FOR RECLAMATION OF TOP SOIL. THUS, 3499 EXCEPT FOR COVERING THE EXPOSED SEAM AND.THE PIT FLOOR, NO 3599 REC@MATION IS ASSUMED. 3699 THE OTAL LAND USAGE IS 12.0 AC/1.OE12 BTU IN. THE TIME 3799 AVERAGED (OVER 25 YRS) LAND IMPACT IS THEREFORE 150 AC-YR/ 3899 1.OE12 BTU IN. 3999 1414 199 FOR,A SLOPE ANGLE OF 20 DEGREES, A BENCH WIDTH OF'150 FT AND 299 A 15 FT RIM OF BLOSSOM COAL (FOOTNOTE 1413), 4.19E5 T OF 399 EARTH ARE MOVED PER 1.OE12 BTU IN. 499 AS A REQUIREMENT OF BACKFILLING, IT IS ASSUMED THAT 4 FT OF @599 MATERIAL, ABOVE THE HEIGHT OF THE COAL, MUST BE REPLACED. 699 THUS,FOR A 3.9 FT SEAM THICKNESS (FOOTNOTE 1406), 5.12E4 @799 T/1.OE12 BTU IN SPOILS ARE REPLACED FOR BACKFILLING THE BENCH. 899 9,99 THE SOLID'WASTE PRODUCTION IS, THEREFORE,3.68E5 T PER 1099 I.OE12 BTU IN. 1199 1415 igg THE AVERAGE DISTANCE FROM MINE TO TIPPLE 19 THIS REGION is 7.3 299 MI. (0001,344) AND DATA FROM STUDIES CONDUCTED IN EAST ERN 399 KENTUCKY (1024,1031,1032,1033,1034) INDICATE A MEAN HAULAGE 499 ROAD RIGHT-OF-WAY OF 53 FT (6.4 AC/MI). THUS, THE HAULAGE -599 ROAD OCCUrIES.46.7 AC. ASSUMING AN ANNUAL PRODUCTION FROM 699 THE MINE OF 2 MMT (FOOTNOTE 1405), ?.1 PC OF THE ROAD USAGE 799 IS,ATTRIBUTED TO THE TRANSPORT.OF 1.OE12 BTU EQUIVALENT T. 899 THE LAND IMPACT IS, THEREFORE .990 AC-YR/1.OE12 BTU. 999 .1416 199 IN AN EASTERN KENTUCKY STUDY,THE SEDIMENT YIELD FROM A COAL HAUL 299 ROAD WAS DETERMINED TO BE 90 T/AC-YR (1020,C32). BECAUSE OF 399 THE CONDITIONS,THE YIELD WAS EXCEPTIONALLY HIGH. FOR THE 499 PRESENT COMPUTATION IT IS ASSUMED THAT THE SEDIMENT YIELD 599 AVERAGES To 35 T/AC-YR. THUS, 34.5 T/I.OE12 BTU OF SEDIMENT 699 IS YIELDED (FOOTNOTE 1415, LAND USE BY HAULAGE ROADS). 799 1417 199 IN 1969 THE AVERAGE TRUCK CAPACITY FOR THIS REGION WAS 22 T AND 299 THE AVERAGE HAULAGE DISTANCE FROM MINE TO TIPPLE WAS 7.;3 Mi 399 (0001,344). THE FUEL CONSUMPTION RATE IS ASSUMED TO BE 7 GAL/ 499 1000 TMI (0002'3-7). ASSUMING A GROSS TO TARE WEIGHT RATIO OF 599 2.5 . FOR T@E TRUCKS, A ROUND TRIP is 375 TMI. SINCE 1927 699 ROUND TRIPS ARE REQUIRED TO HAUL 1.OE12 BTU EQUIVALENT 115060 799 GAL OF DIESEL FUEL IS CONSUMED. THE EMISSIONS BREAKDOWN FOR A 899 111-87 FTN. 1418-1422 DIESEL POWERED TRUCK IS GIVEN IN REF. (OOO2,3-7). 999 DUSTING FROM HAULAGE ROADS IS CONTROLLED BY WATERING DOWN, 1099 OILING OR SOME OTHER METHOD 1199 1418 199 FUEL CONSUMPTION BY TH HAULAGE TRUCKS AMOUNTS TO 5060 GAL/1.OE12 299 BTU (FOOTNOTE 1417). THUS, THE ENERGY CONSUMPTION IS 7.02E8 399 BTU. 499 1419 199 THE CONVEYOR SYSTEM CONSUMES 1.03E6 KWH/YR OR ABOUT 21800 KWH/ 299 1.OE12 BTU (FOOTNOTE 1049). THE REAL ENERGY CONSUMPTION 399 (2.23E8 BTU) IS 3 TIMES THE ELECTRICAL ENERGY CONSUMPTION. 1420 199 A CRUSHER OPERATING AT 275 T/HR AND CRUSHING TO A TOPSIZE OF 1.5 299 IN. REQUIRES A 140 HP MOTOR (1014,7-14). THUS, 1.61E4 KWH OF 399 ENERGY ARE UTILIZED TO CRUSH 1.OE12 BTU EQUIVALENT T OF COAL. 499 THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT OF 599 THE ELECTRICAL POWER UTILIZATION. 699 1421 199 IT IS ASSUMED THAT 0.006 PC OF THE FEED TO THE PREPARATION PLANT 299 IS REMOVED AS TRAMP IRON. HENCE, 2.54 T OF TRAMP IRON IS 399 COLLECTED FOR EVERY 1.OE12 BTU EQUIVALENT TO PROCESSED. THE 499 PERCENTAGE OF TRAMP IRON IS ESTIMATED FROM INFORMATION IN 599 REF. (1059,6-31) ASSUMING THAT THE LARGE PLANT PROCESSED 1000 699 T/HR. OF CCAL. 799 1422 199 THE DENSE MEDIUM BATH IS ASSUMED TO BE WASHING AT A SPECIFIC 299 GRAVITY OF 1.6, AS FOR THE STEAM COAL PREPARATION PLANT (FOOT- 399 NOTE 1426).THE FEED TO THE BATH IS 1.5 X 3/8 IN. SIZED COAL 499 AND IS ASSUMED TO HAVE THE CHARACTERISTICS OF THE AVERAGE 599 UTILITY COAL FOR THIS REGION, I.E., 14.7 PC ASH AND 3.07 PC 699 SULFER (THI AVERAGE ALSO INCLUDES MARYLAND, (1O53, 9)). 799 SINCE THE CHARACTERISTICS OF THE LOWER KITANNING BED IN 899 ARMSTRONG COUNTY,PA, ARE SIMILAR TO THOSE OF TH REGIONAL 999 AVERAGE, THE WASHABILITY 1099 DATA FOR THIS COAL (1053, 147) ARE USED IN THIS ANALY- 1199 SIS, THE SCREN ANALYSIS WAS OBTAINED FROM REF, (1055), 1299 THE THEORETICAL CLEAN COAL RECOVERY IS 83 PC. THE AVERAGE 1399 RECOVERY EFFICIENCY FOR A DENSE MEDIUM VESSEL IS ABOUT 97 PC 1499 (1054). THUS, THE YIELD AT A WASH SPECIFIC GRAFITY IS ESTIMAT- 1599 ED TO BE 80.5 PC, WHICH IMPLIES A SOLID WASTE PRODUCTION OF 1699 8270 T/1.OE12 BTU EQUIVALENT T PROCESSED. 1799 THE SCREEN ANALYSIS FOR THIS COAL INDICATE THAT 1 PLC OF THE 1899 1.5 X 0 IN. CRUSHED COAL ARE CONTAINED IN THE SIZE FRACTION 1999 LESS THAN 100 MESH IN SIZE. A PORTION OF THIS SIZE FRACTION 2099 IS FED TO THE DENSE MEDIUM BATH DUE TO IMPERFECT SIZE SEPARA- 2199 TION. THUS, IT IS ASSUMED THAT 10 PC OF THE COAL LESS THAN 2299 100 MESH IN SIZE ENDS UP AS BLACKWATER DISCHARGE FROM THE 2399 DENSE MEDIUM CIRCUIT. THIS AMOUNTS TO A SUSPENDED SOLIDS DIS- 2499 CHARGE OF 42.4 T/1.OE12 BTU EQUIVALENT T PROCESSED. 2599 MAGNETITE LOSSES AMOUNT TO 0.9 LB/T OF CLEAN COAL PRODUCTED 2699 (1054). THUS, AN ADDITIONAL 15.4 T OF SOLID WASTE IS PRODUCED/ 2799 1.OE12 BTU PROCESSED. 2899 FTN. 1423-1427 1423 199 THE BTU WASHING EFFICIENCY FOR THE DENSE MEDIUM BATH, I.E., THE 299 RATIO OF THE CALORIC CONTENT OF THE INPUT COAL AND'THE OUTPUT 399 COAL MULTIPLIED BY THE YIELD, DEPENDS ON THE ASH CONTENT OF 499 THE FEED COAL AS WELL AS THE SPECIFIC GRAVITY OF THE WASH AND 599 THE SIZE DISTRIBUTION WASHED. THE FOLLOWING EFFICIENCY EQUA- 699 TION IS CEVELOPED FROM AVERAGED DATA IN (1010) USING A 799 SPECIFIC GRAVITY FOR WASHING OF 1.6 899 PC BTU EFFICIENCY -0.342(PC ASH) 100 999 1099 THUS, FOR AN ASH CONTENT OF 14.7PC(FCOTNOTE 1422) THE 1199 EFFICIENCY IS 95.0 PC. 1299 1424 199 ENERGY CONSUMPTION AT A CRUSHING AND SIZING'PLANT IS ABOUT 1.72E9 299 BTU/1.OE12 BTU EQUIVALENT T PROCESSEL. OF THE TOTAL CONSUMP- 399 TION,1.5f5 KWH IS ELECTRICITY (1064,12A-16,39) AND 2.42E8 BTU 499 IS OIL (1064,12A-16,39, ASSUMING ALL FUEL PURCHASEDTO BE OIL 599 AT A COST OF $0.20./GAL). THE TOTAL IS OBTAINED BY ADDING 3 699 TIMES THE BTU EQUIVALENT OF THE ELECTRICAL-CONSUMPTION TO THE 799 OIL USAGE. 899 1425 199 APPROXIMATELY 35 AC OF LAND IS UTILIZED FOR THE CRUSHING AND 299 SIZLNG PLANT AND A 1OC-00 T UNIT TRAIN LOADING FACILITY (1021). 399 THUS, THE LAND IMPACT IS 0.741 AC-YR/1.OE12 BTU. 499 IT IS ASSUMED THAT THE MODES OF TRANSPORT OTHER THAN UNIT 599 TRAINS HAVE SIMILAR LAND REQUIREMENTS. 699 1426 199 THE PREPARATION PLANT PROCESSES 500 T/HR OF R.O.M. COAL. THE COAL 299 IS CRUSHED TO A TOPSIZE OF 1.5 TN. THE 1.5 X 3/8 IN. SIZE 399 FRACTION IS WASHEDIN A DENSE MEDIUM VESSEL AT'A SPECIFIC 499 GRAVITY OF 1.6, WHILE THE COAL LESS THAN 3/8 IN. IN SIZE IS 599 NOT SUBJECTED TO ANY CLEANING. 699 THE WASHABILITY DATA FOR THE LOWER KITANNING BED IN ARMSTRONG 799 COUNTY, rA., ARE USED IN THIS ANALYSIS SINCE THE CHARACTERIS- 899 TICS OF THIS COAL ARE SIMILAR TO THE THAT OF THE AVERAGE 999 UTILITY COAL FOR THIS REGION, I.E., 14.7 PC ASH AND 3.07 PC 1099 SULFUR (FOOTNOTE, 1422) 1199 THE SCREEN ANALYSES FOR THIS COAL INDICATE THAT 28 PC OF THE 1299 CRUSHED COAL ARE LESS THAN 3/8 IN. IN SIZE. THUS, THE DENSE 1399 MEDI,IUM BATH WASHES 360 T/HR OF 1.5 X 3/8 IN. SIZED COAL. 1499 THE WASHABILITY DATA INDICATE A THEORETICAL RECOVERY OF 83 PC.1599 FOR A RECOVERY EFFICIENCY OF 97 PC (1054), THE ACTUAL WASHED 1699 COAL RECOVERY IS 80.5 PC. THIS IMPLIES THAT FOR EVERY 1.OE12 1799 BTU EQUIVALENT T OF COAL PROCESSED,5960 T OF REFUSE ARE 1899 GENERATEE. 1999' MAGNETITE LOSSES AMOUNT TO 0.9 LB/T OF CLEAR COAL OUTPUT FROM 2099 THE-BATH (1054). THUS, AN ADDITIONAL 11.0 T/I.OE12 BTU OF 2199 SOLID WASTE ARE PRODUCED THE COLLECTION OF TRAMP IRON AMOUNTS2299 TO 2.54 1/1.6E12 BTU BASiD ON .006 P OF THE FEED TO THE PREP 2399 PLAN,T. 2499 1427 199 THE LAND,REQUIRED FOR THE PREPARATION PLANT IS ABOUT 5 AC (1008j. 299 THE LOADING AREA FOR A 10000 T UNIT TRAIN IS ESTIMATED TO BE 399 ABOUT 40 AC (DATA ON THE MATTHEWS MINE, (1006,65)) AND THE 499 SETTLING POND OCCUPIES ABOUT 50 AC (10511@, THE PLANT PROCESSES 599 .2 MMT/YR. THUS THE LAND IMPACT IS 2.01 AC-YR/I.OE12 BTU. 699 IN A PILE 30 FT HIGH THE REFUSE (FCOTNOTE 1426) OCCUPIES 799 .0915 AC. THE TIME AVERAGED (OVER THE 25 YRS LIFE EXPECTANTCY 699 OF THE PLANT) LAND IMPACT IS 1.14 AC-YR/1.OE12 BTU. 999, 111-89 FTN. 1428-1431 1428 199 THE BTU EFFICIENCY OF THE DENSE MEDIUM BATH WHICH WASHERS 72 PC OF 299 THE FEED IS 95 PC, WHILE THE EFFICIENCY FOR THE UNWASHED 399 PORTION (28 PC) IS 100 PC (SEE FOOTNOTE 1423). THUS, THE 499 WEIGHTED AVERAGE EFFICIENCY FOR THE PLANT IS 96.4 PC. 599 1429 199 ENERGY CONSUMPTION AT THE PREPARATION PLANT IS 2.17E9 BTU/1.OE12 299 KWH ARE ELECTRICAL T PROCESSED, OF THE TOTAL CONSUMPTION 1.65E5 399 KWH ARE ELECTRICAL ENERGY AND 4.83E8 BTU ARE OIL (ASSUMING ALL 499 FUELS PURCHASED TO BE OIL AT $.20/GAL). THE TOTAL IS OBTAINED 599 BY ADDING 3 TIMES THE BTU EQUIVALENT OF THE ELECTRICITY CON- 699 SUMPTION TO THE OIL USE. 799 1430 199 A MAJORITY OF THE ACTIVE AND INACTIVE COAL WASTE BANKS SURVEYED 299 (1067,1068) WERE FOUND BURNING OR SMOLDERING, ADDING TO THE 399 PROBLEM OF AIR POLLUTION. IT IS ASSUMED THAT THE REFUSE BANK 499 IN THIS CASE IS BURNING. THE EMISSION FACTORS ARE DETERMINED 599 FROM INFORMATION IN REF. (0017) AND FROM THE KNOWLEDGE OF THE 699 SOLID WASTE PRODUCED (FOOTNOTE 1426). 799 SINCE THE INTERMEDIATE AND FINE SIZE COALS ARE NOT SUBJECTED 899 TO ANY CLEANING, THE ASSOCIATED PROBLEMS ARE NON-EXISTENT. 999 THE PROBLEM OF FUGITIVE DUST AT THE PREPARATION PLANT ISN OT 1099 SIGNIFICANT IN TERMS OF AIR POLLUTION BUT MAY BE AN OCCUPA- 1199 TIONAL HEALTH PROBLEM (1048). 1299 1431 199 THE SEEPAGE FROM THE THE REFUSE PILE IS ASSUMED TO OCCUR AT A RATE OF 299 1670 GAL/AC-DAY AND CONTAINS 0.091 LE OF ACIDITY/GAL, 0.144 399 LB SULFATE/GAL, 0.0258 LB IRON/GAL AND 3.78E-4 LB MANGANESE/ 499 GAL (1009). THE DISCHARGE IS THEREFORE CONSTITUTED AS FOLLOWS 599 (FOOTNOTE 1427). 699 T/1.0E12 BTU 799 FE 9.0 899 SO4 50.1 999 MN 0.1 1099 TOTAL 59.2 1199 1299 ACIDITY 31.6 1399 1499 THE SEDIMENT YIELD FROM THE REFUSE PILE OCCURS AT A RATE OF 1599 2.54 T/AC-YR-IN. OF RUNOFF. THUS, FOR A 20 IN. RUNOFF THE 1699 SEDIMENT YIELD IS 58.0 T/1.OE12 BTU. (FOOTNOTE 1427, LAND USE 1799 BY REFUSE PILE) 1899 OF THE RAW CRUSHED COAL 1 PC IS LESS THAN 100 MESH IN SIZE 1999 (1055). A PROPORTION OF THIS SIZE FRACTION ENDS UP IN THE 2099 FEED TO THE DENSE MEDIUM CIRCUIT. ASSUMING 10 PC OF THE COAL 2199 LESS THAN 100 MESH IN SIZE IS YIELDED AS BLACKWATER DISCHARGE, 2299 SUSPENDED SOLIDS ARE GENERATED AT A RATE OF 0.50 T/HR. IT IS 2399 UNREALISTIC TO ASSUME THAT ALL OF THE BLACKWATER IS DISCHARGED 2499 TO THE NATURAL DRAINAGE SINCE SOME PLANTS DO HAVE CONTROLS. 2599 IN THIS CASE IT IS ASSUMED THAT 37.5 PC OF THE PLANTS IN THIS 2699 REGION HAVE TREATMENT FACILITIES (AS IS THE CASE FOR THE 2799 COUNTRY (1112)). HENCE, ONLY 62.5 PC OF THE BLACKWATER GENE- 2899 RATED ENTERS NATURAL DRAINAGE. CONCEPTUALLY, FOR THIS SPECIFIC 2999 PLANT, THE BLACKWATER IS DISCHARGED THROUGH LEAKS, OVERFLOWS 3099 AND IMPROPER SETTLING. THE DISCHARGE OF SUSPENDED SOLIDS 3199 THEREFORE AMOUNTS TO .312 T/HR, OR 26.5 T/1.OE12 BTU 3299 (FOOTNOTE 1426). 3399 III-90 fTN. 1432-1437 1432 199 IN A STUDY OF UNIT TRAINS CONDUCTED BY THE BUR OF MINES (1006) THE 299 AVERAGE HAULAGE DISTANCE FROM MINES IN THIS REGION WAS ABdUT @399 320 MI. THIS FIGURE IS USED FOR THIS ANKLYSIS.1 499 ENERGY CONSUMPTION BY FREIGHT TRAINS, ASSURED TO APPLY AS WELL 599 TO UNIT TRAINS, IS 690 BTU/TMI (FOOTNOTE 1013), OR .005 GAL OF 699 DIESEL FUEL/TMI (5.825E6 BTU/BBL). FROM DATA IN (0021,31) THE 799 ENERGY CCNSUMPTION ASSUMES AN AVERAGE OF 3 LocbmOTIVES PER 899 TRAIN. THE GROSS To TARE WEIGHT RATIOS OF THE CARS IS 4 TO 1 999 (FOOTNOTE 1005). HENCE, THE HAULAGE FOR EACH ROUND TRIP IS 1099 5.34E6 TMI AND 1.13E5 GAL OF FUEL IS CONSUBED TO TRANSPORT 1199 1.OE12 BTU EQUIVALENT T. THE EMISSLON FACTORS ARE OBTAINED 1299 FFOM REF. (0002,3-7). (UNIT TRAIN CARRIES 10000 T/TRIP.) 1399 WINDAGE LOSSES AMOUNT TO .04 PC OF THE-TONNAGE HAULED AND ARE 1499 ACCOUNTED FOR MAINLY DURING HANDLING AT THE END POINTS. 1599 THUS, 17 T OF PARTICULATES ARE RELEASED/I.OE12 BTU. 1699 1433 199 THE FUEL CONSUMPTION BY UNIT TRAINS IS 1.13E5 GAL/1.OE12 BTU. 299 THUS, 1.58E10 BTU OF ENERGY IS CONSUMED. (FOOTNOTE 1432) 399 1434 199 THE TOTAL MILES OF RAILROAD OPERATED IN THE EASTERN DISTRICT 299 (DIVISIONS MADE BY ICC,(0033,II)) IS 54000 MI (0033,59). THUS, 399 FOR A RIGHT-OF-WAY OF 6 AC/MI (FOOTNOTE 1027) THE TOTAL LAND 499 USAGE IS 324,000 AC. 599 @Of THE TOTAL TONNAGE OF FREIGHT HAULED IN 1971, COAL ACCOUNTED 699 FOR 43 PC OR 214E6 TON. OF THIS 30.6 PC OR 65.5E6 TON- 799 ORIGINATED FROM THIS REGION (0039,27 AND 1004,52,53). HENCE, 899@ 27.6 AC-YR/1.OE12 BTU IS ATTRIBUTED TO THE HAULAGE OF COAL 999 FROM THIS REGION. 1099 1435 199 IN TH*E EASTERN DISTRICT (0033,11) RAILWAY ACCIDENTS CLAIMED 705 299 LIVES INJURED 9304 PERSONS (0006,17,54) AND AN AVERAGE OF 399 93 MA;-DAYS WERE LOST PER INJURY (0006,4). 499 OF THE TOTAL KILLED AND INJURED,0.0648 FATALITIES AND 0.856 599 RON-FATAL INJURIES ARE ATTRIBUTED TO THE TRANSPORT OF I.OE12, 699 BTU EQUIVALENT T FROM THIS REGION. FOR THE SAME HAULAGE'79.6 799 MAR-DAYS ARE LOST. (YOOTNOTE 1434, COAL TRANSPORTED) 899 1436 199 THE AVERAGE HAULAGE DISTANCE IS ASSUMED TO BE 320 MI AND FUEL 299 CONSUMPTION IS 0.005 GAL/TMI (FOOTNOTE 1432). ASSUMING 1000 T 399 COAL CARRIED PER MIXED TRAIN, ACCOUNTING FOR 20 PC OF THE 499 TOTAL'MIXED TRAIN SHIPMENT, A GROSS TO TARE WEIGHT RATIO OF 599 4/1 AND ONLY ONE WAY DIESEL FUEL CONSUMPTION ATTRIBUTED.TO 699 COAL, 90700 GAL OF DIESEL FUEL CONSUMPTION IS ATTRIBUTED To 799 THE HAULAGE OF 1.OE12 BTU EQUIVALENT T OF COAL. THE EMISSION 899 FACTORS ARE COMPUTED FROM INFORMATION ON DIESEL LOCOMOTIVES 999 IN ,(0002,3-7). 1099 THE WINDAGE LOSSES ARE ASSUMED TO BE APPROXIMATELY .08 PC OF 1199 4F THE TOTAL SHIPMENT. HENCE ABOUT 33.9 T ARE RELEASED TO THE 1@99 ATMOSPHERE AS PARTICULATES. (MOST OF THESE LOSSES OCCUR 1399 DURING HANDLING AT EITHER ENDPOINT.) 1499 1437 199 DIESEL FUEL CONSUMPTION AMOUNTS TO 90700 GAL/1.OE12 BTU. THUS, 2991 THE,ENERGY CONSUMPTION IS 1.26E10 BTU. (FOOTNOTE 1436) 399 111-91 FTN. 1438-1446 1438 199 THE AVERAGE CAPACITY OF A BARGE IS 25000 T (1005,34), AND THE 299 AVERAGE HAULAGE DISTANCE IS ASSUMED TO BE 800 MI (THE APPRO- 399 XIMATE DISTANCE FROM ERIE, PA. TO CHICAGO VIA THE GREAT 499 LAKES). THE EMISSION FACTORS ARE COMPUTED FROM DATA ON MOTOR- 599 SHIPS UNDERWAY IN (0002,3-11). 699 THE WINDAGE LOSSES (OCCURING MAINLY DURING HANDLING AT EITHER 799 END POINT) ARE ASSUMED TO BE .04 PC OF THE TOTAL SHIPMENT AS 899 IN THE CASE FOR UNIT TRAINS. THUS, 17 T OF COAL FINES ARE 999 EMITTED AS PARTICULATES. 1099 1439 199 THE BARGE CONSUMES 378 BTU/TMI (FOOTNOTE 7001). THUS, FOR AN AVERAGE 299 HAULAGE DISTANCE OF 800 MI (FOOTNOTE 1438), A BARGE CAPACITY 399 OF 25000 T AND ASSUMING A GROSS TO TARE WEIGHT RATION OF 4 TO 499 1, THE ENERGY CONSUMPTION IS 2,12E10 BTU FOR EACH 1.OE12 BTU 599 EQUIVALENT T TRANSPORTED. 699 1440 199 DURING THE TRANSORT OF FOSSIL FUELS BY RIVER BARGES IN 1971, 3 299 FATALITIE AND 5 NON-FATA INJURIES OCCURED (1049). IN THE 399 SAME YEAR 70P OF THE TOTAL TONNAGE OF FOSSIL FUEL SHIPPED WAS 499 COAL (0031,37,40). THUS, 1.93E-3/1.OE12 BTU FATALITIES AND 599 3.21E-3/1.0E12 BTU INJURIES ARE ATTRIBUTED TO THE TRANSPORT OF 699 COAL. 799 THE AVERAGE DAYS LOST PER INJURY PER MARINE CARGO HANDLERS FOR 899 THE PERIOD FROM 1965-1967 IS 75.7 (0038,375). HENCE 0.243 999 DAYS LOST/L.0E12 BTU HANDLED. 1099 THESE ARE NATIONAL AVERAGE FIGURES. NO REGIONAL DATA HAVE 1199 BEEN LOCATED. 1299 1441 199 WHEN TRUCKS ARE UTILIZED IT IS USUALLY FOR SHORT HAULING DISTANCES 299 THAT AVERAGE ABOUT 10 MI (1013). ASSUMING AN AVERAGE TRUCK 399 CAPACITY OF 20 T, A GROSS TO NET WEIGHT RATION OF 2.5 TO 1, AND 499 A FUEL CONSUMPTION RATE OF 7 GAL/1000 TMI, 6900 GAL OF DIESEL 599 FUEL IS CONSUMED. THE EMISSIONS FROM A DIESEL ENGINE ARE GIVEN 699 IN (0003,3-7). IT IS ASSUMED THAT.04 PC OF THE TOTAL SHIP- 799 MENT IS LOST DUE TO WINDAGE (FOOTNOTE 1432). THE AMOUNT RE- 899 LEASED AS PARTICULATES IS THEREFORE 17 T. 999 1442 199 THE LAND USE BY DIESEL FREIGHT TRUCKS IS 1.67E-6 AC/TMI (FOOTNOTE 299 7026). THUS, THE LAND IMPACT ATTRIBUTED TO THE HAULAGE OF THE 399 CCAL BY TRUCK IS 1.67 AC-YR/1.0E12 BTU (FOOTNOTE 1441). 499 1443 199 DIESEL FUEL CONSUMPTION AMOUNTS TO 6900 GAL/1.0E12 BTU. THUS, THE 299 ENERGY CONSUMPTION IS 9.58E8 BTU. (FOOTNOTE 1441) 399 1444 199 THESE OCCUPATIONAL HEALTH STATISTICS ARE NATIONAL AVERAGES (FOOT- 299 NOTE 1061). NO REGIONAL DATA HAVE BEEN LOCATED. 399 1445 199 IT IS ASSUMED THAT THE AVERAGE CONVEYOR LENGTH IS 5 MI (FOOTNOTE 299 1335). HENCE, FOR A RIGHT-OF-WAY OF 30 FT, 18.2 AC OF LAND IS 399 OCCUPIED. THE SYTEM TRANSPORTS 2 MMT/YR. THEREFORE IN TERMS 499 OF ENERGY, 0.386 AC-YR/1.OE12 BTU OF LAND IS IMPACTED. 599 1446 199 ELECTRICAL ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEY- 299 ERS IS 3.65E4 KWH/1.OE12 BTU (FOOTNOTE 1053). THE REAL ENERGY 399 CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT OF ELECTRICAL ENERGY 499 CONSUMPTION. 599 III-92 FTN., 1447-1452 1447 199 STORAGE OF THE COAL IN A PILE AVERAGING 30 FT.IN HEIGHT REQUIRES 299 THE USE OF 0.763 AC-YR/1.OE12 BTU. 399 IT IS ASSUMED THAT UNDERGROUND STORAGE ALSO REQUIRES THE SAME 490 AMOUNT OF LAND. 599 1448 199 GENERALLY, SILOS HAVE A DIAMETER OF 70 FT AND ARE ABOUT 150 FT IN 299 HEIGHT* THE STORAGE CAPACITY IS APPROXIMATELY 11000 T (1006). 399- THUS, 4 SILOS ARE.REQUIRED FOR STORING 1.OE12 BTU EQUIVALENT 499 T. THE LAND IMPACTED BY THE SILOS IS THEREFORE 0.354 AC-YR/ 599 1.OE12 BTU. 699 1449 199 ENERGY CONSUMPTION FOR THE MOVEMENT OF CCAIL BY CONVEYORS FOR 299 STORAGE AMOUNTS TO 1.155E4 KWH/1.OE12 BTU (FOOTNOTES 1058,1059, 399 106D). THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVA- 499 LENT OF THE ELECTRICAL ENERGY CONSUMED. 599 1450 199 THE OCCUPATIONAL HEALTH STATISTICS ARE OBTAINED FROM (1210,80/91 299 AND 1070) AND REPRESENT AN AVERAGE FOR 1969 AND 1970. THESE igg FIGURES DO NOT INCLUDE INJURIES RESULTING DURING HAULAGE, 499 1451 199 THE OCCUPATIONAL HEALTH STATISTICS FOR HAULAGE FROM MINE TO TIPPLE 299 ARE CBIAIVED FROM (1210,80/91 AND 1010) AND REPRESENT AN 399 AVERAGE FOR 1969 AND.1970. THESE FIGURES INCLUDE HAULAGE FROM 499 UNDERGROUND AND STRIP MINES. THE DATA COULD NOT BE, DISAGREGAT- 599 ED BY METHOD OF HAULAGE, AND THUS WERE SUMMED. THE AVERAGE 699 SEVERITY (MAN-DAYS LOST/INJURY) IS 26, WHICH 15 AN AVERAGE 799 BETREEN UNDERGROUND AND STRIP MINES. 899 1452 199 THE OCCUPATIONAL HEALTH STATISTICS ARE OBTAINED FROM (1210,80/91 299 AND 1070)AND REPRESENT AN AVERAGE FOR 1969 AND 1970. THESE 399 FIGURES INCLUDE ALL TYPES OF PREPARATION PLANTS. 499 111-93 TjlliTi A 5 a 9 .0 .3 11 11 ;20 2. 2R 1. .1 .1 FUEL "I"ON WATER POLLUTANTS (TONS/ 10" BTU, EX COL t2l Al. POLLUTANTS -(-e BTU, OCCUPATIONAL HEALTH POTE-AL I H.L 1"MRIES LAa NEAR, TL @T'L R. SOLIDS LAID NWE- AUIVITY PROCESS DISSOL-VED 30LIDS THERNAL PART- .0, TOTAL 81 DEATHS PC6 C@ N ULATE, WOO" 1 ARTU U) BTU I C'SCAL, ACIDS BASES NO OTHER TOTAL (0 dI 0 10 .0 RASTE. 2 3 4 lH, L L _2 INH 4i -1 1- 1 1 -2E.- 1-H IS -H -0 l117 HH HI d 11 1 1 1 H 20 HH HH lAN H 1 .11 1 "m 22 24 IN -1 11H -1 1 2. IM IN, H "I'l I H. 26 --fM HN -1 -1 UP ARS 31 321 331 Sol 34 35 36 T9 S. 3! AD 4. 44 45 AN 47 NOTE: ALL TABLE ENTRIES ME BASED OR 1012 BTU OF RESOUREE INTO EACH PROCESS OR ACIIVITY. TABLE 8. ENVIROMENTAL DAPACTS AM EFn--ffNCY FOR THE 1E FOOT OT "'D F* PEAS I ..AI.EllT1 Ill IBIZ BTU. SOLFUR AND ASH CONTNTS COWHOLLED NORTHEWN APPffZACMA REGION B, ORTHAERX MPALAC.I. CDAULA220 REGIONAL DESCRIPTION. OF COAL SMLY TOT"'$ C's PreceTing page blank FTN. 1455-1461 FCATNOTES FOR TABLE 8 1455 199 SEDIMENT RUNOFF FROM COAL HAULAGE ROADS CAN BE CONTROLLED BY 299 DITCHING ALONGSIDE THE ROADS AND DIVERTING THE RUNOFF TO 399 SMALL SETTLING PONDS. 499 1456 199 EMISSIONS ASSOCIATED WITH THE. BURNING COAL REFUSE PILE (FOOTNOTE 299 1430) ARE.COMPLETELY ELIMINATED BY RECLANATrON OF THE REFUSE 399 PILE. BAGHOUSES FOR CONTROL OF FUGITIVE DUST EMISSIONS ARE 499 USED IN THE CONTROLLED UTILITY PREP PLANT IN ORDER TO COMPLY 599 WITH THE 10P OPACITY LIMIT FOR VISIBLE EMISSIONS FROM NEW 699 PREP PLANTS (1121). 799 1457 199 SEEPAGE FROM THE REFUSE PILE IS ASSUMED TO'BE COMPLETELY 299 .ELIMINATED BY THE SOIL COVER ESTABLISHED IN RECLAIMING THE 399 REFUSE PILE. RUNOFF FROM THE REFUSE PILE CONTINUES HOWEVER, 499 BECAUSE OF THE 3 YEAR TIME LAG ASSOCIATED VITH ESTABLISHMENT 599 OF AN HERBACEOUS COVER (FOOTNOTE 1103). BASED ON 2.54 TON 699 SUSPENDEE SOLIDS/ACRE-YR-IN RUNOFF AND ON 20 IN RUNOFF (SEE 799 FOOTNOTE 1072) AND .215 ACRE-YR/1.OE12 BTU (FOOTNOTE 1460), 699 10.9 TON SUSPENDED SOLIDS/1.OE12 BTU ARE GENERATED IN RUNOFF 999 FROMP THE RECLAIMED REFUSE PILE. SUSPENDED SOLIDS GENERATED IN 1099 THE PREP PLANT ARE ELIMINATED BY THE USE OF A SETTLING POND. 1199 1458 199 IT HAS NOT BEEN POSSIBLE TO QUANTIFY FUGITIVE DUST EMISSIONS FROM 299 COAL PREP PLANTS. THUS IT IS NOT POSSIBLE TO QUANTIFY THE 399 INCREMENTAL SOLID WASTE GENERATED BY THE USE OF BAGHOUSES TO 499 CONTROL THESE EMISSIONS. THEREFORE, THE SOLID WASTE GENERATED 599 IN THE CONTROLLED UTILITY COAL PREP PLANT 1S.T;1Z SAME AS GIVEN 619 IN FOOTNOTE 1426, NAMELY 5970 TON/1.OE12 BTU. 199 1459 199 THE TOTAL POWER REQUIREMENT FOR THE 7 BAGHOUSES' IN A 500 TON/HR 299 PREP PLANT IS 175 HP (1080,73) OR 4.55EO5 KWH/YR (BASED ON 399 3480 HF/YR OPERATION). CONVERTING THIS BY 10200 BTU/KWH AND 499 SIZING THE RESULT FOR A I.OE12 BTU/YR PREP PLANT GIVES AN 599 ENERGY REQUIREMENT OF 1.13EO8 BTU/1.OE12 BTU. No INFORMATION 699 WAS AVAILABLE ON ENERGY REQUIREMENTS FOR REFUSE RECLAMATION. 799 THE ENERGY REQUIRED FOR THE CLOSED CIRCUIT SETTLING PONE IS 899 BASED ON .0457 $/TON SUSPENDED SOLIDS (FOOTNOTE 1126), 42.4 T 999 OF SOLIDS (FOOTNOTE 1431),.AND $.01/KWH To GIVE 1.935EO2 K.WH/ 1099 1.OE12 BTU OR 1.98EO6 BTU/1.OE12 BTU (CCNVERTING AT 10200 BTU 1199 ./KWH). THE SUM TOTAL INCREMENTAL ENERGY DEMAND ASSOCIATED WITH1299 CONTROLS ON A 1AE12 BTU/YR UTILITY COAL PREP PLANT IS THUS 1399 1.15E08 BTU/1.OE12 BTU. 1499 1460 199 BASED ON A SOLID WASTE PRODUCTION OF 5970 TON/I.OE12 BTU (FOOTNOTE 299 1426), A COMPACTED REFUSE DENSITY OF .06 TONICF, AND A 30 FT 399 HIGH REFUSE PILE, .076 ACRES OF LAND/1.OE12 BTU IS IMPACTED. 499 BASED ON A 3 YEAR TIME LAG TO ESTABLISH AN HERBACEOUS COVER 599 AND A 25 YR PLANT OPERATING LIFETIME, 2.82 TIMES THE YEARLY 699 LAND IMPACT REPRESENTS THE TIME AVERAGED LAND IMPACT (FOOTNOTE 799 1103). THUS .215 ACRE-YR/1.OE12 BTU IS THE TIME AVERAGED LAND 899 IMPACT. THE LAND REQUIREMENT FOR THE UTILITY COAL PREP PLANT 999 IS 2.01 ACRE-YR/1.OE12 BTU (FOOTNOTE 1427) SO THAT THE TOTAL 1099 LAND REQUIREMENT IS 2.23 ACRE-YR/1.OE12 BTU. 1199 1461 199 A HYDRATED LIME PROCESS IS UTILIZED FOR TREATMENT OF THE ACID 299 DRAINAGE FROM THE DEEP MINE , ASSUMING AN ACID LOAD OF 3000 399 PPM,THE PLANT WILL HAVE TO PROCESS ABOUT 1.9 MMG/DAY (FOOTNOTE 499 ProcediAg page blank FTN. 1462-1464 1404 MIN DRAINAGE POLLUTANT LOADS). THE TOTAL IRON CONCEN- 599 TRATION IS ABOUT 220 PPM. THUS, THE SOLID WASTE PRODUCTION IS 699 ABOUT 63.8 AC-FT/YR (1102,233). ASSUMING A PRECIPITATE DENSITY 799 OF 71 LB/CF (1114,288) SOLIDS WASTE IS GENERATED AT A RATE OF 899 98660 T/YR FOR A 2 MM TPY MINE. THUS, THERE IS AN ADDITIONAL 999 (TO THAT PRODUCED FROM THE MINING OPEATION) 1190 TON/1.OE12 1099 BTU IN FOR ROOM AND PILLAR MINES AND 1780 TON/1.OE12 BTU IN 1199 FOR LONGWALL MINING. 1299 1462 199 THE AVERAGE ANNUAL POWER EXPENSE FOR THE HYDRATED LINE SYSTEMS 299 UTILIZED IN OPERATION YELLOWBOY WAS ABOUT $16400/MMG/D (1102, 399 231). THUS AT A COST OF $0.05/KWH THE ENERGY REQUIREMENT TO 499 OPERATE THE 1.9 MMG/D HYDRATED LIME PLANT IS 2.07E6 KWH/YR, 599 OR 4.30E4 KWH/1.OE12 BTU OUT. THE REAL ENERGY CONSUMPTION IS 699 3 TIMES THE BTU EQUIVALENT OF THE ELECTRICAL ENERGY CONSUMED. 799 ON A 1.OE12 BTU IN BASIS, THE ENERGY CONSUMPTION IS 2.57E8 BTU 899 FOR ROOM AND PILLAR MINING AND 3L83E8 BTU FOR LONGWALL MINING. 999 1099 THIS ENERGY USE IS IN ADDITION TO THE ENERGY EXPENDED FOR THE 1199 MINING OPERATION, I.E., 4.21E9 BTU AND 5.65E9 BTU/1.OE12 BTU 1299 IN FOR THE ROOM AND PILLAR, AND LONGWALL MINING, RESPECTIVELY 1399 (FOOTNOTE 1411). 1499 1463 199 IT IS ASSUMED THAT THE FINAL DISCHARGE WILL BE IN COMPLIANCE WITH 299 THE GUIDELINES ESTABLISHED BY EP (1112). IN LIME TREATMENT 399 BECAUSE OF THE SOLUBILITY OF CALCIUM SULFATE, THE HARDNESS OF 499 THE WATER WILL INCREASE (1113,24). MOST OF THE METALLIC SALTS 599 WILL PRECIPITATE AS THE PH OF THE SOLUTION IS RAISED. THE 699 EFFLUENT BREAKDOWN IS AS FOLLOWS 799 ROOM AND PILLAR LONGWALL 899 PPM T/1.OE12 BTU IN T/1.OE12 BTU IN 999 SUSPENDED SOLIDS 30 0.595 0.887 1099 ACIDITY 0 0.00 0.00 1199 ALKALINITY 60 1.19 1.77 1299 1399 IRON 4 0.079 0.118 1499 MN 4 0.079 0.118 1599 AL 1 0.020 0.030 1699 CASO4 2000 39.7 59.0 1799 SUBTOTAL 39.9 59.4 1899 1999 THE ALKALINITY CONCENTRATION IS OBTAINED FROM DATA IN 2099 (1103), TH MN AND AL FROM SOLUBILITY CURVES, WHILE THE 2199 REMAINDER ARE IN COMPLIANCE WITH THE EPA GUIDELINES. THE VOL- 2299 UME OF THE DISCHARGE IS ABOUT 85 PC OF THE INFLOW VOLUME 2399 (l1102), I.E., 1.61 MMGAL/DAY, AND THE FACILITY OPERATES 2499 245 D/YR. 2599 1464 199 IT IS ASSUMED THAT THE TREATMENT FACILITY REQUIRES A 4 MMGAL RAW 299 WATER STORAGE POND AND A 4OO MMGAL SETTLING POND. THE LAND 399 IS ASSUMED AVAILABLE. FOR A DEPTH OF 20 FT FOR BOTH PONDS, 499 51.5 AC OF SURFACE AREA ARE REQUIRED. THE TREATMENT PLANT 599 OCCUPIES ABOUT 3 AC (1114). THUS, THE TOTAL LAND IMPACT IS 699 0.781 AC-YR/1.OE12 BTU IN FOR ROOM AND PILLAR MINING AND 1.16 799 AC-YR/1.OE12 BTU IN FOR LONGWALL MINING. 899 THIS IS IN ADDITION TO THE LAND IMPACTED DURING MINING, I.E., 999 129 AC-YR/1.OE12 BTU IN FOR ROOM AND PILLAR MINING (FOOTNOTE 1099 1402) AND 285 AC-YR/1.OE12 BTU IN FOR LONGWALL MINING (FOOT- 1199 NOTE 1403). 1299 III-98 FiN. 1465-1468 1465 199 A HYDRATED LIME PRGCESS IS UTILIZED FOR TREATMENT OF THE ACID 299 DEAINAGE FROM THE AREA STRIPPING OPERATION. ASSUMING AN ACID 399 LOAD OF 1000 PPM THE PLANT.WILL HAVE TO PROCESS 0.5 MMGA@/DAY 499 (FOOTNOTE 1407, MINE DRAINAGE POLLUTANT LOADS). THE TOTAL IRON 599 CONCENTRATION IS ABOUT 650 PPM. THE SOLID WASTE PRODUCTION 699 FOR THE PLANT AMOUNTS TO ABOUT 11.9 AC,-FT/YR (1102,233). 799 ASSUMING A PFECIPITATE DENSITY OF 71 LB/CF;(1114,288), SOLID 899, WASTE IS GENERATED AT A RATE OF 18400 T/YR,, OR 316 T/1.OE12 999 BTU,IN FOR A 2 MM TPY MINE.,, 1099 THIS IS IN ADDITION TO THE SOLID WASTE PRODUCED DURING MI.NING,1199 IA., 352 T/I-OE12 BTU IN (FOOTNOTE 1405). 1299 1466 199 THE'ENERGY REQUIREMENT TO OPERATE A O.5.MMG/DAY HYDRATED LIME 299 PLANT IS 0.550E6 KWH/YR, OR 9.39E3 KWH/I.OE12 BTU IN (FOOT- 399 NOTE 1462). THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU 499 EQUIVALENT OF THE ELECTRICAL ENERGY CONSUMED. 599 THE SPOILS ARE STACKED IN PILES ABOUT 50 FT HIGH.-ASSUMING @699 GEOMETRICALLY UNIFORM PARALLEL SPOIL PIL.ES-RESTING AT AN ANGLE 799 OF REPOSE OF 38 DEGREES, THE PEAK TO PEAK DISTANCE IS ABOUT 899 70 FT. THUS THE ENERGY CONSUMED DURING THE LEVELING OF THE 999 SPOIL BANKS AMOUNTS TO 1920 HP-HR/AC ((1222,67) AND ASSUMING 1099 A 6 PC PERFORMANCE EFFICIENCY), OR 2.8717 BTU/1.OE12 BTU IN 1199 (FOOTNOTE 1406, LAND TO BERECLAIMED). 1299 THE ENERGY UTILIZED FOR WASTE WATER TREATMENT AND RECLAMATION 1399 IS IN ADDITION TO THE ENERGY USED DURING THE MINING OPERATION 1499 5.82E9 BTU/I.OE12 BTU IN (FOOTNOTE 1408). 1599 1467 199 IT IS ASSUMED THAT THE FINAL DISCHARGE WILL BE IN COMPLIANCE WITH 299 THE GUIDELINES ESTABLISHED BY EPA (1112). THE VOLUME OF DIS@ 399 CHARGE IS ABOUT 85 PC OF THE INFLOW VOLUME (1103), I.E.$ 499 0.425 MMGAL/DAY. THE EFFLUENT BREAKDOWN IS AS FOLLOWS (F OOT- 599 NOTE 1463). @6'99 < 150 > 150 799 PPM T/1.OE12 BTU IN T/I.OE12 BTU IN 899 SUSPENDED SOLIDS 30 0.223 0.220 999 ACIDITY 0 0.0 0.0 100.9 ALKALINITY 60 0.446 0.441 1199 1299 IRON 4 0.030 0.029 1399 MN 4 0.030 0.029 14.99 AL 1 0.007 0.007 1599 CAS04 2000 .14.9 14.7 16'99 SUBTOTAL 15.0 14.8 17�9 1899 THE FACILITY OPERATES 245 D/YR. IT SHOULD BE NOTED THAT THE 1999 PRODUCTION FROM A CONTOUR STRIPPING OPERATION IS USUALLY 2099 SMALL,AND A HYDRATED LIME SYSTEM AS DESCRIBED IN THESE FOOT- 2199 NOTES MAY NOT BE ECONOMICALLY FEASIBLE. PROVIDING THE.ACID 2299 CONCENTRATION AND THE DIS.CHARGERATE IS LOW, A SODA ASH PRO- 2399 CESS OR SOME PORTABLE TYPE OF TREATMENT FACILITY MAY BE MORE 249.9 FEASIBLE. 2599 1468 199 FOR AREA STRIPPING (SLOPE LESS THAN .15 DEGREES) 5.87 AC OF LAND 299 ARE OVERTURNED/1.OE12 BTU IN @FOOTNOTE.1406)., 399 111-99 FTN. 1469-1470 IN TIME AVERAGING THE LAND IMPACT, THE EFECTS OF RECLAMATION 499 MUST BE CONSIDERED. RECLAMATION IN THIS CASE REQUIRES THE 599 RESTORATION OF THE LAND TO THE ORIGINAL CONTOUR (OR AS CLOSE 699 TO THE ORIGINAL CONTOUR AS POSSIBLE), AND STABILIZING THE 799 SURFACE AGAINST EROSION. MINIMIZING EROSION INVOLVES BENEFI- 899 CIAL GRADING (TERRACING, GOUGING, ETC) AND ESTABLISHING AN 999 HERBACEOUS COVER. IN APPALACHIA ABOUT 3 GROWING SEASONS ARE 1099 REQUIRED TO ESTABLISH A 95 PC COVER OF GRASS AND LEGUMES 1199 (1101). 1299 USING THE 3 YR CRITERION THE TIME AVERAGED LAND IMPACT IS 1399 16.6 AC-YR/1.OE12 BTUIN. THE LAND IMPACT DUE TO THE WASTE PILE 1499 IS ASSUMED TO BE NIL, WHICH IMPLIES INSTANTANEOUS RECLAMATION. 1599 1699 IT IS ASSUMED THAT THE TREATMENT PLANT REQUIRES A 4 MMGAL RAW 1799 WATER STORAGE POND AND A 79 MMGAL SETTLING POND. THE LAND IS 1899 ASSUMED AVAILABLE. FOR AN AVERAGE DEPTH OF 20 FT FOR BOTH 1999 PONDS, ABOUT 11.8 AC OF SURFACE AREA ARE REQUIRED. THE TREAT- 2099 MENT PLANT OCCUPIES APPROXIMATELY 3 AC (1114). THUS, THE LAND 2199 IMPACT IS 0.254 AC-YR/1.OE12 BTU IN. 2299 1469 199 FOR THE MODIFIED BLOCK CUT MINING TECHNIQUE, SOLID WASTE IS 299 PRODUCED ONLY DURING THE BOX CUT. HENCE, FOR A SLOPE ANGLE OF 399 20 DEGREES, A BENCH WIDTH OF 150 FT., A 15 FT RIM OF BLOSSOM 499 COAL, AND A BOX CUT OF 600 FT IN LENGTH, 0.148 MMT OR 100 T/ 599 1.OE12 BTU IN A SOLID WASTE ARE PRODUCED (SUBSEQUENT TO THE 699 BOX CUT 50 MMT OF COAL ARE REMOVED OVER A 25 YR PERIOD). THE 799 LENGTH OF THE BOX CUT IS BASED ON 250 FT LONG SECOND AND 899 THIRD CUTS (1104) AND ALLOWS FOR EXPANSION. 999 AN ADDITIONAL 312 T/1.OE12 BTU IN OF SOLID WASTE IS PRODUCED 1099 FROM THE HYDRATED LIME TREATMENT FACILITY WHICH IS IDENTICAL 1199 TO THE PLANT FOR THE AREA STRIPPING OPERATION (FOOTNOTE 1465). 1299 1470 199 FOR CONTOUR MINING (SLOPES GREATER THAN 15 DEGREES) IT IS ASSUMED 299 THAT THE MODIFIED BLOCK CUT METHO IS EMPLOYED 399 THE THICKNESS OF THE SEAM IS 3.9 FT (FOOTNOTE 1413), THUS 499 5.87 AC ARE OVERTURNED FOR EVERY 1.OE12 BTU IN. AT THE SAME 599 TIME, 1705 FT OF BENCH ARE CREATED (FOOTNOTE 1469). ASSUMING 699 50 FT STRIPS OF LAND ABOVE THE HIGHWALL AND ALONG THE OUT- 799 SLOPE ARE UTILIZED FOR THE DIVERSION DITCH AND FOR STOCK- 899 PILING THE TOPSOIL, RESPECTIVELY, ANOTHER 3.91 AC OF LAND ARE 999 EFFECTED PER 1.OE12 BTU IN. 1099 NOW, ASSUMING THAT 3 GROWING SEASONS ARE REQUIRED TO ESTABLISH 1199 AN HERBACEOUS COVER (FOOTNOTE 1460), THE TIME AVERAGED (OVER 1299 25 YRS) LAND IMPACT OF THE VARIABLE LAND USE (9.78 AC) IS 1399 27.6 AC-YR/1.OE12 BTU IN. 1499 THE SOLID WASTE GENERATED FROM THE BOX CUT (FOOTNOTE 1469) IS 1599 DISPOSED OF BY THE PARALLEL SLOPE METHOD. BY THE END OF 3 YRS 1699 THIS PLOT WILL BE RECLAIMED (AS MEASURED BY THE CRITERION IN 1799 FOOTNOTE 1460), THUS THE CONTRIBUTION TO THE OVERALL LAND 1899 IMPACT IS NEGLIBIBLE. THE LAND USE BY THE HYDRATED LIME 1999 TREATMENT FACILITY IS 0.251 AC-YR/1.OE12 BTU IN (FOOTNOTE 2099 1468). 2199 III-100 FTN. 1471-1472 1471 199 THE ENERGY REQUIREMENT FOR STRIPPING BY THE MODIFIED BLOCK CU T 299 IS NOT AVAILABLE,AND WAS ASSUMED TO BE THE SAME AS CONVEN- 395 TIONAL CONTOUR STRIPPING - 1.09E10 BTU/1.OE12 BTU IN (FOOT- 499 NOTE 1410). THE ENERGY CONSUMED BY THE HYDRATED LIM.E TREAT- 595 MENT FACILITY !S 9.27E3 KWH/1.OE12 BTU IN (FOOTNOTE 1466) OR, 699 9.49E7 BTU/1.OE12 BTU IN. 799 1472 199 IT IS ASSUMED THAT A SETTLING PONDIS REQUIRED FOR EACH MILE OF 299 ROAD AND THAT EACH POND USES AN ACRE..THUS, 7 AC ARE UTILIZED 399 OF THE SETTLING POND (THE HAUL ROAD IS 7.3 MI IN LE'NGTH, 499 FOOTNOTE 1415). THE LAND IMPACT IS 0.148 AC-YR/1.OE12 BTU. 599 F THIS IS IN ADDITION TO THE LAND IMPACTED BY THE ROAD .990 699 AC-YR/1-CE12 BTU (FOOTNOTE 1415) 799 III-101 LN Ub WK. 1 1 11 14 20 2, 2@ 24 2, FUEL RE TON POTENTI L MR POLLurA OCCUPATIONAL HEAL- M.CILL, IATER POLLUTANTS (TONS/ 10" BTU. E. C-12) V;x I-= - NNAL I R I co T TAL TONS' SIA SON -.ACTIWTY PROCE .,-ED MILID L. BOB COO NO,, so. -M IB. OU ICK 33 ACRIS BASES OT" TOTALR)S) -'D' SMRC' C-SS,7.. OR LATES CARSONS E- o*w VL- U -TER 3 .Lm- -------- "4 4 - ---------- L.L- -- ------- - - ----- Ln' 2-,", ARR NI ....... 1XITT&UPt is RN Arimmmin;z RRI 201 I A., IN on ARR AN 1-1 14 AN -L- n _j5 It 25 3, 3t NN 37 43 45 _L7 - 4; WSF.it- 4M TABLE ENTRIES ARE 5AStD,ON 1012 OR of KSMl 11110 EAM PROCtSS 02 A@XVITY. TABLE 9. ENVIRONMENTAL DIPACTS AM EMMEMCY MR THE m mmTE 160 FINEASUE EQUITAL"TS OF 1012 3-V.-S-.LFM @.D MR CONTENTS UNCONTROLLED CENTRAL APPAL&CMA BOGION MOM APPALACNI COAL AAD RESIOSM. OESMIFT!ft. OF COAL SUPPLY P ing, pagg Mad raced FTN. 1500-1502 FOOTNOTES FOR TABLE 9 1500 19 9 THE REGION OF CENTRAL APPALACHIA INCLUDES SOUTHERN WEST VIRGINIA, 299 VIRGINIA AND EASTERN KENTUCKY. THE AVERAGE CALORIC CONTENT OF 399 THE CCAL DELIVERED TO ELECTRIC UTILITIES IN THIS REGION DURING 499 THE 3RD QUARTER OF 1972 WAS 12100 BTU/LB (1212). THE AVERAGE 599 ASH AND SULFUR CONTENTSOF UTILITY COALS IN THIS REGION ARE 699 11.2 PC AND 0.93 PC, RESPECTIVELY ( (1053) , INCLUDING THE STATE 799 OF TENNESSEE, BUT NOT EASTERN KENTUCKY. THE AVERAGE SULFUR- 899 CONTENT OF COAL RECEIVED AT ELECTRIC UTILITIES DURING THE 3RD 999 QUARTE R CF 1972, WAS 1.20 PC (1212)). THE DENSITY OF THE COAL 1099, IS ABOUT 85 LB/CF. 1199 SINCE THE COAL FROM THIS REGION IS LOW IN ASH AND SULFUR,NO 1299 CLEANING IS NECESSARY FOR COAL USED FOR STEAM RAISING. 1399 FOR THE COAL OF THIS REGION,1.OE12 BTU IS EQUIVALENT TO 1499 APPROXIMATELY 41000 T OF COAL. 1599 1501 199 SOLID WASTE PRODUCTION FROM UNDERGROUND MINES IS IN GENERAL RELAT- 299 ED TO THE OPENING OF THE MINE (SHAFT SINKING FOR SHAFT AND 399 SLOPE MINES). ASSUMING AN AVERAGE MINE DEPTH OF 600 FT AND AN 499 ADIT OF 100 SF, 3000 T OF EARTH ARE REMOVED TO SINK.THE SHAFT. 599 SIZABLE UNDERGROUND MINES HAVE AN AVERAGE PRODUCTIVE LIFE OF 699 ABOUT 25 YRS AND PRODUCES ABOUT 2 MMI/YR (1016). HENCE, SOLID 799 WASTE IS PRODUCED AT A RATE OF 60 T/MMT OF COAL MINED, OR 899 1.40 T/1.OE12 BTU IN. 999 1502 199 THE AVERAGE SEAM THICKNESS OF COAL MINED UNDERGROUND IN THIS 299 REGION IN 1965 WAS 4.7 FT (1017). ASSUMING THIS VALUE STILL 399 APPLIES, 4.71 AC OF LAND ARE UNDERMINED/1.OE12 BTU EQUIVALENT 499 T IN. .599 OF THE ACREAGE UNDERMINED,APPROXIMATELY 25PC WILL SUBSIDE .699 (1019). THIS SUBSIDENCE RATE IS ACTUALLY FOR ALL UNDERGROUND 799 COAL MINES, BUT SINCE THE ROOM 9 PILLAR TECHNIQUE HAS BEEN 899 PREDOMINANT IN THE US, IT IS ASSUMED THAT THIS FIGURE CHARAC- 999 TERIZES THE SUBSIDENCE FOR ROOM & PILLAR MINING. EVENTUALLY 1099 ALL OF THE AREA UNDERMINED MAY SUBSILE, BUT THE TIME SCALE 1199 IS IN EXCESS OF A CENTURY. THE 25PC SUBSIDENCE RATE IS DERIVED 1299 FROM HISTORICAL OBSERVATIONS. 1399 1499 SUBSIDENCE AFFECTS A SURFACE AREA GREATER THAN THE AREA 1599 UNDERMINED.'THE WIDTH ON THE PERIMETER THAT IS AFFECTED BY 1699 SUBSIDENCE IS DETERMINED FROM 1799 1899 R=H.TANX 1999 2099 WHERE, R=WIDTH OF THE PERIMETER AREA AFFEC?ED; H=DEPTH OF 2199 MINE, AND X=ANGLE OF DRAW (ANGLE BETWEEN A VERTICAL LINE, AND 2299 A LINE CONNECTING THE FACE AND THE LIMIT OF SUBSIDENCE). THE 2399 ANGLE OF DRAW HAS BEEN CONSISTENTLY OBSERVED IN EUROPEAN COAL 2499 FIELDS TO FALL BETWEEN 35-39 DEGPEES (1027,232,233) 4. THUS, FOR 2599 AN ANGLE OF DRAW OF 37 DEGREES AND A MINE DEPTH OF 6'00 FT, THE2699 WIDTH OF THE AFFECTED PERIMETER AREA IS 452 FT. 2799 OF THE UNDERMINED AREA 1.18 AC SUBSIL29. ASSUMING A SQUARE 2899 AREA, THE SIDES ARE227 FT IN LENGTH. HENCE, AN ADDITIONAL 2999 9.4 AC ARE AFFECTED. THE TOTAL AREA AFFECTED BY'SUBSIDENCE 3099 ENCOMPASSES 10.6 AC. 3199 TIME AVERAGING THIS VARIABLE LAND USAGE OVER 25 YRS (FOOTNOTE 3299 1501) THE LAND IMPACT IS 132 AC-YR/1.OE12 BTU IN. 3399 3499 Preceding page blank FTN. 1503-1506 IN A PILE 30 FT IN HEIGHT, 4.59-2 AC OF LAND IS OCCUPIED BY 3599 THE REFUSE PILE (FOOTNOTE 1501, SOLID WASTE PRODUCTION). FOR 3699 AN ANNUAN PRODUCTION OF 2 MMT, THE LAND IMPACT IS 5.35E-4 3799 AC-YR/1.OE12 BTU IN. 3899 1503 199 THE ACID DRAINAGE FROM ACTIVE DEEP MINES IN CENTRAL APPALACHIA 299 COOURS AT A RATE OF 203 T OF ACIDITY/DAY, OR 4.OE-4 T/T OF 399 COAL MINED. (THE ACIDITY IS COMPUTED FROM DATA ON SUB-AREAS 499 12,14,15 AND 17-18 IN REF. (1039,5,8,9) ASSUMING THE CONTRI- 599 BUTION FROM THE DIFFERENT SOURCES ARE IN THE SAME PROPORTION 699 AS FOR ALL OF APPALACHIA. THE PRODUCTION FIGURES ARE OBTAINED 799 FROM REF. (0001).) THE SULFA LOADING IS ABOUT TWICE AS MUCH 899 AS THE ACID LOADING (1039). 999 THE CHEMICAL COMPOSITION OF THE DRAINAGE FROM TH ACTIVE MINES 1099 ARE ESTIMATED FROM DATA ON THE MONOGAHELA RIVER BASIN (1039, 1199 133/139). THE DATA FROM 10 GAGING STATIONS WERE USED IN THE 1299 ESTIMATION AND THE COAL PRODUCTION FIGURES WERE OBTAINED FROM 1399 REF. (0001). IN DETERMINING THE HARDNESS A CONCENTRATION OF 1499 100 MG/L WERE ASSUMED TO OCCUR NATURALLY, WHILE THE METALLIC 1599 CONSTITUENTS ARE ASSUMED TO ORIGINATE FROM THE MINES. THE 1699 RELATIVE CONTRIBUTION FROM THE DIFFERENT SOURCES WAS ASSUMED 1799 TO BE THE SAME AS FOR ALL OF APPALACHIA. THE EFFLUENT 1899 BREAKDOWN IS AS FOLLOWS 1999 T/1.OE12 BTU IN 2099 HARDNESS 285.0 2199 FE 5.0 2299 MN 2.1 2399 AL 0.63 2499 SO4 18.7 2599 TOTAL 331.4 2699 2799 ACIDITY 9.35 2899 2999 THE SEDIMENT YIELD FROM THE SOLID WASTE PILE OCCURS AT A RATE 3099 OF 2.4 T/AC-YR-IN OF RUNOFF (COMPUTED FROM DATA IN REF. 3199 1020)). THE RUNOFF IN THIS REGION AVERAGES ABOUT 20 IN., 3299 THUS, THE SEDIMENT YILD AMOUNTS TO 2.72E-2 T/1.OE12 BTU IN 3399 (FOOTNOTE 1502, LAND USE BY REFUSE PILE). 3499 1504 199 THE OCUPATIONAL HEALTH STATITICS ARE OBTAINED FROM (1210, 80/91 299 AND 1070) AND REPRESENT AN AVERAGE FOR 1969 AND 1970. THESE 399 FIGURES DO NOT INCLUDE INJURIES THAT RESULT HAULAGE 499 1505 199 THE EXPENSE INCURRED FOR ELECTRICAL POWER IS ESTIMATED TO BE 299 $0.17/T AT $0.01/KWH (1079). THUS. THE ENERGY REQUIREMENT FOR AN UNDERGROUND MINING OPERATION (USING A CONTINUOUS MINER) IS 6.975E5 KWH/1.OE12 BTU EQUIVALENT T EXTRACTED (AT 12100 BTU/ LB, FOOTNOTE 1500). THE REAL EVERGY CONSUMPTION IS 7.15E9 BTU/ 1.OE12 BTU (3 TIMES THE BTU EQUIVALENT OF THE ELECTRICAL ENERGY CONSUMPTION). ON A 1.OE12 BTU IN BASIS THE ENERGY CON- SUMPTION IS 4.07E9 BTU. 999 1506 199 THE AVERAGE THICKNES OF COAL SEAMS AUGER MINED IN THIS REGION IN 299 1965 WAS 4.2 FT (1017,7). THUS FOR EVERGY 1.OE12 BTU EQUIVALENT 399 T, 5.27 AC OF SURFACE AREA ARE UNDERMINED (DENSITY IS 85 LB/CF 499 (FOOTNOTE 1500)). UNDER THE ASSUMPTION THAT THE RATIO OF LAND 599 SUBSIDED TO LAND UNDERMINED IS THE SAME AS FOR FOOM AND PILLAR 699 UNDERGROUND MINES (FOOTNOTE 1502), 1.32 AC OF SURFACE AREA 799 SUBSIDES. BECAUSE OF THE SHALLOW OVERBURDEN DEPTH, THE PERI- 899 METER EFFECT IS NEGLIBIBLE. 999 FOR AN AUGER LENGTH OF 150 FT, ABOUT 1531 FT OF WORKING BENCH 1099 III-106 FTN 15071-1511 ARE CREATED FOR EACH I.OE12 BTU IN. THUS FOR'A BENCH WIDTH 1199 OF 35 FT (1052); 1.2, AC/1.OE12 BTU IN OF LAND ARE-,DISTURBED..1299 1399 IT IS ASSUMED THAT THE EXCAVATED OVERBURDEN IS DUMPED ON THE 1499 OUTSLOPES. THUS, IN A PILE AVERAGING 15 FT IN HEIGHT THE 1599 SPOIL BANK EXTENDS 34.3 FT DOWNSLOPE FROM THE OUTCROP COVER- 1699 ING AN AREA OF 1.21 AC/I.OE12 BTU IN (FOOTNOTE 1507, SOLID 179S WASTE PRODUCTION). 1899 CALCULATIONS FROM DATA COLLECTED IN EASTERN KENTUCKY (1029, 1999 .0,1031,1032,1033,1034) INDICATE THAT LANDS AFFECTED BY 2099 LANDSLIDES AMOUNT TO 11.4 PC OF THE OUTSLOPE- COVERED BY THE 2199 SPOILS. HENCE, AN ADDITIONAL LAND ACREAGE OF 0.138 AC/1.OE12 2299 BTU IN IS DAMAGED. 2399 THE TOTAL LAND DAMAGED DURING AUGERING AMOUNTS TO 3.90 AC/ 2499 1.OE12 BTU IN. THE TIME AVERAGED (OVER 25 YRS) LAND IMPACT IS 2599 48.8 AC-YR/1.OE12 BTU IN. 2699 1507 199 ASSUMING A TOPOGRAPHIC SLOPE OF 40 DEGREES (ON SLOPES LESS STEEP 299 IT IS MORE THAN LIKELY THAT CONTOUR STRIPPING WILL BE EMPLOY- 399 ED. AUGERING MAY THEN FOLLOW AFTER THE ECONOMIC STRIPPING 4039 LIMIT IS REACHED.), 39300 T OF SOLID WASTE ARE PRODUCED FOR 599 EVERY 1.OE12 BTU EQUIVALENT T (BENCH WIDTH OF 35 FT AND 699 LENGTH OF 1531 FT. FOOTNOTE 1506). 799 199 1508 DIESEL FUEL CONSUMPTION AMOUNTS TO 6220 GAL/1.OE12 BTU IN (FOOT- 299 NOTE 1010). THE AIR EMISSION FACTORS ARE OBTAINED FROM REF. 399 (0002,3-7) ASSUMING THE CHARACTERISTICS OF A DIESEL TRUCK 499 ENGINE. 599 1509 199 THE COMPOSITION OF THE DRAINAGE FROM AUGER MINES IS ASSUMED TO BE 299 1 51 A I r THE SAME AS FOR CONTOUR 'FOOTNOTE -t) EXCEPT FOR THE 39@ DIFFERENCE IN PRIMARY EFFICIENCIES. THE SEDIMENT YIELD OCCURS 499 AT A RATE OF.2.54 T/AC-YR-IN. OF RUNOFF. THE AVERAGE RUNOFF .599 FOR THIS REGION IS ABOUT 20 IN, THUS,.THE SEDIMENT YIELD IS 699 859 T/1.OE12 BTU IN (FOOTNOTE 1506). 799 1510 199 THE AVERAGE SLOPE ANGLE FOR THIS REGION IS ABOUT 28 DEGREES 299 ((1028,51), USING THE DATA FOR THE ECONOMIC AREAS 50,51,52 AND 399 53). ASSUMING A BENCH WIDTH OF 150 FT AND A 15 FT RIM OF 499 BLOSSOM COAL, 5.5OE5 T OF EARTH A,RE MOVED PER 1.OE12 BTU COAL 599 IN THE GROUND. 699 AS A REQUIREMENT OF BACKFILLING, IT IS ASSUMED THAT 4 FT OF 799 MATERIAL, ABOVE THE HEIGHT OF THE COAL SEAM,'MUST BE REPLACED. 899 THUS, FOR A 4.2 FT SEAM THICKNESS 4.59EO4- T OF SPOILS/1.OE12 BTU ARE REPLACED FOR BACKFILLING THE BENCH. 1099 THE SOLID WASTE PRODUCTION IS-THEREFORE 5.04,E5 T/1.0'-712 BTU, 1199 IN. 1299 1511 1,99 FOR A COAL SEAM THICKNESS OF 4.2 FT (1017) AND A COAL DENSITY OF --2199 85 LB/CF, 5.27AC OF LAND IS OVERTURNED PER 1.OE12 BTU IN. 399 499 ON SLOPES GREATER THAN 15 DEGREES,TECHNIQUES OF CONTOUR STRIP- 599 PING ARE EMPLOYED. IT IS ASSUMED THAT THE CONVENTIONAL CONTOUR 699 MINING IS USED. EXCEPT FOR ThE MATERIAL USED TO BACKFILL THE 799 BENCH, ALL OF THE OVERBURDEN IS DEPOSITED ON THE OUTSLO-PE AND 899 ASSUMED TO REST AT THE ANGLE 0? REPOSE (ABOUT j7,DEGREES). IT 999 IS ALSO ASSUMED THAT A 15 FT RIM 0- BLOSSOM COAL IS LEFT IN 1099 PLACE. THE MEAN SLOPE ANGLE AND THE BENCH WIDTH ARE ASSUMED 1199 TO BE 28 DEGREES (1028,51) AND.150 FT RESPECTIVELY: (THE 28 1299 DEGREE SLOPE ANGLE IS THE AVERAGE FOR SLOPES GREATER THAN 15 1399 DEGREES IN CENTRAL APPALACHIA). HENCE, A HIGHWALL OF87.8 FT IS 1499 CREATED AND TO MINE THE REQUIRED TONNAGE OF COAL 1531 FT OF 1599 111-107 TN. 1512-1514 HIGHWALL (BENCH LENGTH) ARE GENERATED. THUS, FOR A SPOIL 1699 BANK WITH A MEAN HEIGHT OF 30 FT, THE PILE REACHES 219 FT 1799 DOWNSLOPE FROM THE OUTCROP AND ENCOMPASSES AN AREA OF 7.71 1899 AC/1.011112 13TU IN (FOOTNOTE 1510, SOLID WASTE PRO'DUCTION). 1999 2099 THE DRAINA13E DITCH ABOVE THE HIGHWALL IS ASSUMED TO AFFECT 2199 50 FT UPSLOPE. HENCE, AN ADDITIONAL 1.76 AC/I.OE12 BTU IN 2299 IS AFFECTED. 2399 CALCULATIONS FROM DATA COLLECTED IN EASTERN KENTUCKY (1029, 2499 1030,1031,LO32,1033,1034) INDICATE THAT LAND AFFECTED BY 2599 LANDSLIDES AMOUNT TO 11.4 PC OF THE OUTSLOPE AREA COVERED BY 2699 THE SPOILS, THUS, AN ADDITIONAL LAND ACREAGE OF 0.879 AC/ @27.99' 1.OE.12 BTU IN IS DAMAGED. (IT IS RECOGNIZED THAT THIS WILL 2899 NOT BE THE CASE FOR ALL MINES. SOME STATES REQUIRE PRACT'LCES 2999 THAT MINIMIZE THE OCCURRENCE OF LANDSLIDES. OBSERVATIONS INDI.-3099 CATE THAT THE OCCURRIENCEOF LANDSLIDES IS SIGNIFICANTLY. 3199 REDUCED WHI:N THE SPOIL PILES ARE STABILIZED.) 3299 ALTHOUGH RECLAMATION PRACTICES ARE EMPLOYED, NOT ALL STATES 3399 HAVE MANDATORY VEGETAL SURVIVAL RATE REQUIREMENTS (1028) NOR 3499 APE THERE STIPULATIONS FOR RECLAMATION OF TOP SOIL. THUS, 3599 EXCEPT FOR COVERING THE EXPOSED SEAR AND THE PIT FLOOR NO 3699 RECLAMATICN IS ASSUMED. 3799 THE TOTAL I-AND USAGE IS 15.6 AC/I.OE12 BTU M THE TIME AVER- 3899 AGED (OVER 25 YRS) LAND IMPACT IS THEREFORE 195 AC-YR/1.OE12 3999 BTU IN. 4099 15 12 199 INTERPOLATING THE DATA IN REF. (1041,12,23), ANE 299 ASSUMING,l'AE OILS TO BE DIESEL FUEL COSTING S0.20/GAL AND BY LINEARLY 399 COST OF PO@4ER'TO BE $0.015/KWH THE TOTAL ENERGY CONSUMPTION 499 FOR A 2 MMT/YR CONTOUR STRIPPIMG OPERATION IS ABOUT 1.33910 599 BTU FOR EV:'RY I.OE12 BTU EQUIVALENT T EXTRACTED..THE TOTAL IS 699' COMPOSED 0? 1.82E9 BTU OF FUEL AND 1.13E6 KWH OF ELECTRICAL 799 ENERGY. 'IRE TOTAL'IS OBTAINED BY ADDING 3 TIMES THE BTU 899 EQUIVALENT OF THE ELECTRICAt POWER USAGE TO THE FUELCO.NSUMP- 999 TION. ON A 1.OE12 BTU IN BASIS THE TOTAL IS 1.06E10. BTU. 1099 1513 199 DIESEL FUEL CONSUMPTION AMOUNTS TO 10500 GAL/1.OE128TU IN (FDOTNOTE299 1512). THE EMISSION FACTORS ARE OBTAINED FROM REP. (000-2,3-7) 399 USING THE CHARACTERISTICS FOR A DIESEL TRUCK ENGINE. 499 599 SINCE ADEQUATE MOISTURE IS AVAILABLE IN THIS REGION,FUGITIVE DUST IS NOT EXPECTED TO BE A SERIOUS PROBLEM. 699 1514 199 T il ACID DRAINAGE FROM ACTIVE SURFACE MINES IN CENTRAL APPALACHIA @299 OCCURS AT A RATE OF 11 T OF ACIDITY/DAY, OR 1.OE-4 T/T OF COAL 399 MINED (1033,5,8,9, SEE,ALSO FOOTNOTE 1503). THE SULFATE LOAD- 499 ING IS AEOUT TWICE THE ACID LOADING (1039). THE CHEMICAL 5991, COMPOSITION OF THE DRAINAGE WAS DETERMINED FROM DATA ON THE 699 MONONGAHELA RIVER BASIN (FOOTNOTE 1404). THE EFFLUENT 799 BREAKDOWN IS AS FOLLOWS 899 T/I.OE12 BTU IN 999 HARDNESS 29.5 1099 FE 0.518 1199 MN 0.219 1299 AL 0.0650 1399 S04 6.56 1499 TOTAL 36.9 1699 ACIDIT'f 3.28 1799 1899 THE SEDIMENT IS YIELDED AT A RATE OF 2.54 T/AC-YR-IN. OF RUN- 1999 OFF. THE AVERAGE RUNOFF FOR THIS REGION IS ABOUT 20 IN. 2099 ITT-lnR PTN. 1515-1523 THUS, THE SEDIMENT YIELD IS 5450 Tll.OE12 BTU IN (FOOTNOTE 2199 1511, LAND USE BY SPOIL BANK). 2299 -1515 199 THE AVERAGE DISTANCE FROM MINE TO TIPPLE IN THIS REGION IS 4.7 299 Mi. (0001,344) AND DATA FROM STUDIES CONDUCTkD IN EASTERN 399 KENTUCKY (1024,1031,1032,1033,1034) INDICATE A MEAN @AULkGE 499 ROAD RIGHT-OF-WAY OF 53 FT (6.4 AC/MI). THUS, THE HAULAGE 599 RCAD OCCUPIES 30.1 AC. ASSUMING AN ANNUAL PRODUCTION FROM 699 THE MINE OF 2 MMT (FOOTNOTE 1405), 2.1 PC Ok THE ROAD USAGE 799 IS ATTRIBUTED TO THE TRANSPORT OF 1.OE12 BTU EQUIVALENT T. 899 THE LAND IMPACT IS, THEREFORE 0.632 AC-YR/I.OE12 BTU. @999 1516 199 THE SEDIMENT YIELD FROM COAL HAULAGE ROADS OCCURS AT A RATE OF 299 35 T/AC-YR (FOOTNOTE 1416). THUS, 22.2 T/1.OE12 BTU OF S,EDI- 399 MENT IS YIELDED (FOOTNOTE 1515, LAND U.SE BY THE HAULAGE ROAD). 499 1517 . . 199 IN 1969 THE AVERAGE TRUCK CAPACITY FOR THIS REGION WAS 24 T AND 299 THE AVERAGE HAULAGE DISTANCE FROM MINE TO TIPPLE WAS 4.7 MI 399 (0001,344). THE FUEL CONSUMPTION RATE IS ASSUMED TO BE 7 GAL/ 499 1000 TMI (0002,3-7). ASSUMING A GROSS To TARE WEIGHT RATIO OF 599 2.5 TO I FOR THE TRUCKS, A ROUND TRIP IS 263 TRI. SINCE 1710 699 RCUND TRIPS ARE.REQUIRED TO HAUL 1.OE12 BTU EQUIVALENT T, 3160 799 GAL OF DIESEL FUEL IS CONSUMED. THE EMISSIONS BREAKDOWN FOR A 899 DIESEL POWERED TRUCK IS GIVEN IN REF.,(0002,3-7). 999 DUSTING FROM HAULAGE ROADS ARE CONTROLED BY WATERING DOWN, 1099 OILING OR SOME OTHER METHOD. .1199 1518 1,99 FUEL CONSUMPTION BY THE HAULAGE TRUCKS AMOUNTS TO 3160 GAL/1.OE12 299 BTU (FOOTNOTE 1517). THUS, THE ENERGY CCNSUMPTION IS 4.38E8 399 BTU. 499 1519 199 THE CONVEYOR SYSTEM CONSUMES 1.03E6 KWH/YR OR ABOUT 21300 KWH/ 299 I.OE12 BTU (FOOTNOTE 1049). THE REAL ENERGY CONSUMPTION 399 (2.18EB BTU) IS 3 TIMES THE ELECTRICAL ENERGY CONSUMPTION., 499 1520 199 A CRUSHER OPERATING AT 275 T/HR AND CRUSHING TO A TOPSIZE OF,1.5 299 IN. FECUIRES A 140 HP MOTOR (1014,7-14). THUS, 1.56E4 KWH OF 399 ENERGY ARE UTILIZED TO CRUSH 1.OE12 BTU EQUIVALEWT OF COAL. 499 THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT OF 599 THE ELECTRICAL ENERGY UTILIZATION. 699 1521 199 IT IS ASSUMED THAT 0.006 PC OF THE FEED TO THE PREPARATION PLANT .299 IS REMOVED AS TRAMP IRON. HENCE, 2.46 T OF TRAMP IRON IS 399 COLLECTED FOR EVERY 1.OE12 BTU EQUIVALENT T PROCESSED. THE 499 PERCENTAGE OF TRAMP IRON IS ESTIMATEE FRON INFORMATION IN '599 REF. (1059,6-31) ASSUMING THAT THE LARGE PLANTPROCESSED 1000 699 T/HR. 1522 199 ENERGY CONSUMPTION AT A CRUSHING AND SIZING PLANT IS ABOUT 1.68E9 BTU/I.OE12 BTU EQUIVALENT T PROCESSED. OF THE TOTAL CONSUMP- 399 TICN,1.46E5 KWH ARE ELECTRICITY AND 2.36ES BTU ARE OIL (1064, 499 12A-16,39, ASSUMING ALL FUEL PURCHASED TO BE OIL AT :A COST OF 599 THE TOTAL IS OBTAIdED BY ADDING 3 TIMES THE BTU 699 EQUIVALENT OF THE ELECTRICAL CONSUMPTION TO THE OIL USAGE. 799 1523' 1@9. APPROXIMATELY 35 AC OF LAND ARE UTILI'*zr FOR THE CRUSHING AND 299 SIZING PLANT AND A 10000 T UNIT TRAIN LORDING FACILITY (1021). 399 THUS, THE LAND IMPACT IS 0.724 AC-YR/I.OE12 BTU. @ 499 IT IS ASSUMED THAT THE THE MODES OF TRANSPORT OTHER THAN UNIT 599 TRAINS HAVE SIMILAR LAND REQUIREMENTS. 609 111-109 F T'R. 1524'- 1529 1524 199 I N ASTUDY OF UNIT TRAINS CONDUCTED BY THE BUR OF MINES (1006) THE 299 FOR MINES IN THIS REGION WAS 395 MI. 399 AVERAGE HAULAGE-DISTANCE THIS FIGURE IS USED FOR THIS ANALYSIS. 49-9 ENERGY CONSUMPTION BY FREIGHT TRAINS, ASSUMED TO APPLY AS VELL 599 TO UNIT TRAINS, IS.1690 BTU/TMI (FOOTNOTE 7013), OR 0.005 GAL ' 699 OF DIESEL ?UEL/TMI (5.825E6 BTU/BBL). FROM DATA IN (0021,,31) 799 THE ENERGY CONSUMPTION ASSUMES AN AVERAGE OF 3 LOCOMOTIVES PER 899 TRAIN. THE GROSS TO TARE WEIGHT RATIO OF THE CAR IS 4 TC 1 999 AND THE UNIT TRAIN CARRIES 10000 TON/TRIP (FOOTNOTE 1005). 1099 HENCE, THE HAULAGE FOR EACH ROUND TRIP IS 6.59E6 TMI AND 1199 1.35E5 GAL OF FUEL IS CONSUMED TO TRANSPORT I.OE12 BTU EQUIVA-1299 LENT T. THE EMIS510N FACTORS ARE OBTAINED FROM REF. (000293-7)1399 WINDAGE LOSSES AMOUNT TO .04 PC OF THE TONNAGE HAUL-ED AND ARE 1599 1499 ACCOUNTED FOR PRIMARILY DURING HANULING AT EITHER END.POINT. 1699 THUS, 16.4 T OF PARTICULATES ARE RELEASED/1.OE12 BTU. 1799 1525' 199 .DIESEL FUEL CONSUMPTION AMCUNTS TO 1.35E5 GAL/1.OE12 BTU (FOOTNOTE 299 1524). THUS, THE ENERGY CONSUMPTION IS 1.87E10 BTU. 399 1526 199 THE TOTAL MILES CF RAILROAD OPERATED IN THE EA.STERN BIS.TRICT 299 (DIVISION MADE BY ICC, (0033, 11) ) IS 54000 MI (0033, 59) . THUS, 399 FOR A RIGH,r-OF-WAY OF 6 AC/MI (FOOTNOTE 1027) THE TOTAL LAND ' 499 USAGE is 324,000 AC. 599 OF THE TOTAL TONNA-GE OF FREIGHT HAULED IN 1971, COAL ACCOUNTED 699 FOR 43 PC, OR 214E6 TONS, OF WHICH 53.8 PC9 OR 115E6 TONS,. .799 ORIGINATED FROM THIS REGION (0039.27 AND 1004,52,53). H:ENCE,, 899 26.6 AC-YR/1.OE12 BTU IS ATTRIBUTED TO THE* HAULAGE OF COAL 999 FROM THIS REGION. 1099 1527 199 IN THE EASTEFN DISTRICT .(0033,11) RAILWAY ACCIDENTS CLAIMED 705 299 F 399 LIVES, INJURED 9304 PERSONS (0006,17,54) AND AN AVERAGE 0 93 MAN-DAYS WERE LOST PEP INJURY (0006,4) . 499 OF THE TOTAL KILLED AND INJURED,0.0618 FATALITIES AND 0.767 599 NON-FATAL INJURIES ARE ATTRIBUTED TO THE TRANSPORT OF 1.OE12 699 BTU EQUIVPLENT T FROM THIS REGION. FCR THE SAME HAULAGE 71.4 799 MAN-DAYS LRE LOST. (FOOTNOTE 1526, CCAL TRANSPORTED). 899 1528 199 li EAVERAGE HPULAGE DISTANCE 18 ASSUMED TO BE 275 MI, WHICH IS 299 THE APPR0IMATE DISTANCE FROM THE COAL FIELDS OF THIS REGION 399 TO ALEXANrlRIA AND NORFOLK, VA., AND ATLANTA, GEO.RGIA. FUEL 499 CONSUMPTION IS 0.005 GAL/TMI (FOOTNOTE 1524). ASSUtlING 1000 T 599 OF COAL ABE SHIPPED. PER TRAIN, ACCOUNTING FOR.20 PC OF THE 699 TOTAL,TONNAGE OF ANY ONE SHIPMENT, A GROSS TO TARE WEIGHT 799 RATIO OF 4/1 AND ONLY ONE WAY DIESEL FUEL CONSUMPTION ATTRI- 899 BUTED TOICOAL, 77100 GAL OF DIESEL FUEL CONSUMPTION ARE ATTRI- 999 BUTED TO IHE HAULAGE OF 1.OE12 BTU EQUIVALENT T OF COAL. THE 1099 .EMISSION FACTORS ARE COMPUTED FROM INFORMATION ON DIESEL LOCO-1199 MOTIVES IN (0002,34). 1299 THE WINDAGE LOSSES ARE ASSUMED TO BE APPROXIMATELY .08 PC OF 1399 THE TOTAL SHIPMENT. HENCE, ABOUT 32.8 T OF PARTICULATES ARE ,1499 RELEASED 10 THE ATMOSPHERE/1.OE12 BTU. (MOST OF THE.SE'LOSSES 1599 OCCUR DURING HANDLING AT EITHER END POINT.) 15,29 199 '9.1'ESEL FUEL CONSUMPTION AMOUNTS -TO 77100 GAL/1.OE12. BTU (FOOTNOTE 299 1528). THUS, THE,ENERGY. CONSUMPTION IS 1.07E10 BTU. 399 FTN. 1530-1539 1530 199 THE AVERAGE CAPACITY OF A BARGE IS 25000 T.(1005,34), AND THE 299 AVERAGE HAULAGE DISTANCE IS ASSUMED TO BE 300 MI (THE APPRO- 399 XIMATE DISTANCE TO CINCIN ATI, OHIO CR PITTSBURGH, PA., VIA 499 THE'KANAWHA AND OHIO FIVERS). THE EMISSION FACTORS ARE COMPUT- 599 ED FROM DATA CN MOTORSHIPS UNDERWAY IN (0002,3-11)i 699 THE WINDAGE LOSSES (OCCURING MAINLY DURING HANDLING AT THE 799 END,POINTS) ARE ASSUMED TO BE .04 PC OF THE TOTAL SHIPMENT AS 899 IN THE CASE FOR UNIT TRAINS. THUS, 16-.4 T OF COAL FINES ARE 999 EMITTED AS PARTICULATES/1.OE12 BTU. 1099 1531 199 I BARGE CONSUMES-378 BTU/TMI (FOOTNOTE 7001). THUS FO R AN AVERAGE 299 HAULAGE DISTANCE OF 300 MI (FOOTNOTE 1530) . A BARGE CAPACITY 399 OF 25000 T AND'ASSUMING A GROSS TO TARE WEIGHT RATIO OF 4 TO 499 1, THE ENERGY CONSUMPTION is 7.76E� BTU FOR EACH 1.CE12 BTU 599 EQUIVALENT T OF COAL TRANSPORTED. 699 1532 199 WHEN TRUCKS ARE UTILIZED IT IS USUALLY FOR SHORT HAULAGE DISTANCES 299 THAT AVERAGE ABOUT 10.MI (1013). ASSUMING AN AVERAGE TRUCK 399 CAPACITY OF 20 T, A GFOSS TO NET WEIGHT RATIO OF 2.5 TO 1, AND 499 A FUEL CCNSUMPTION RATE OF.7 GAL/1000 THI, 6700 GAL OF DIESEL 599, FUEL ARE CONSUMED. THE EMISSIONS FROM A DIESEL ENGINE ARE 699 GIVEN IN (0002,3-7). 799 IT I'S ASSUMED T HAT .04 PC OF THE TOTAL SHIPMENT IS LOST DUE TO 899 WINDAGE AND HANDLING AT EITHER END POINT (FOOTNOTE 1524). THE 999 AMOUNT RELEASED AS PARTICULATESIS THEREFORE 16.4/1.OE12 BTU. 1099 1533 199 D CO rESEL FUEL NSOMPTION AMOUNTS To 67CO GAL/1.OE12 BTU. THUS, THE 299 ENERGY CCNSUMPTION IS 9.3OE8 BTU (FOOTNOTE 1532). 399 1534 199 THE LAND-USE BY DIESEL TRUCKS IS 1.67E-6 AC/TMI (FOOTNOTE 299 7026). THUS, THE LAND.LAND.IMPACT ATTRIBUTED TO THE HAULAGE 399, OF THE CCAL BY TRUCK IS 1.60 AC-YR/1.0E12 BTU (FOOTNOTE 1532). 499 1535 199 IT IS ASSUMED THAT THE AVERAGE CONVEYOR LENGTH IS 5 MI (FOOTNOTE 299 1335)..HENCE, FOR A RIGHT-OF-WAY OF 30 FT - 18.2 AC OF LAND IS 399 OCCUPIED. THE SYSTEM TRANSPORTS 2 MMT/YH. THEREFORE IN TERMS 499 OF ENERGY, 0.376 AC-YR/1.CE12 BTU OF LAND IS IMPACTED. 599 1536 199 ELECTRICAL ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEY- 299 ERS IS 3.56E4'KWH/1.OE12 BTU (FOOTNOTE 1053). THE REAL ENERGY 399 CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT OF ELECTRICAL ENERGY 499 CONSUMPTION. 599 1537 199 STORAGE OF THE COAL IN A PILE AVERAGING 30 FT IN HEIGHT REQUIRES 299 THE USE CF 0.762 AC-YR/1,.OE12,BTU 399 IT IS ASSUME .D THAT UNDER GROUND ST;RAGE ALSO.HAS THE SAME 499 LAND RE-QUIRtMENTS. 599 1538 199 GENERALLY, SILOS HAVE A DIAMETER OF 70 FT AND ARE A-BOUT 150 FT IN 299 HEIGHT. THE STORAGE.CAPACITY IS APPROXIMATEY 11000 T (1006). 399 THUS,-4 SILOS ARE REQUIRED FOR STORING 1.OE12 BTU EQUIVALENT 499 T..THE LAND IMPACTED BY THE SILOS IS THEREFORE 0.345 AC-YR/ 599 1,0E12 BTU. 699 1539 199 ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEYORS FOR 299 STORAGE AMOUNTSTO 1.51E4 KWH/1.OE12.BTU (FOOTNOTES 1058,1059, 399 1060). THE REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVA- 499 LENT OF THE ELECTRICAL ENERGY CONSUMED. .599 Is :4 15 Is @o 24 OTER.- SOLID3 LAAH) L, IATER POLLUTANTS (TUNN/ 10 -. 1. C- .2) AIR POLLUTANTS (TONSIle M) OCCUPATIONAL .[.LT. Iss- SOLIDS HUED -----FT-OTAL BoD col) THE -1. - Noi so. -.RO- AL XT-@Mj TOTAL TO-st lNjURlF5 ABAR-DA'S C ACTIVITY PROCE63 AEH,$ --P-O, --T NO, OTHER TOTALM) ftsm- CS .... m sn, ANCH ON"Nics C-, -1 ULAT cARROAs co NU.M 2 A 4 ------ m-_ Im 4 .0 .4 1.1 13 14 15 -@NH IS IT "P IN, ANN ---------- -A, 1- 221 t It, 3 .2 33 34 36 3 39 4 4. 42 V. @-i @L4 TABLE 10. ENVIRONNIENTAL DRACTS AND EFFK-1ENCY FOR THE NOTE: ALL TABLE ENTRIES ARE BASED ON 1012 STU OF INTO EACH PROCESS OR ACTIVITY. CONTROLLED CENTRAL APPAI AlCHIA REGION SEE 1111111TE 111D lot MEASURE EQUITALENTS Or TOE 111 SULFUR ANVASH CONTENTS OF COAL SUPPLY UP CENT KA, WALACRI A. COAL AND RESIMMAL MCA-, Us. NTIRO- CARBON S ANN 7 7 IS Be 4. 4. Preceding p2p b!q,,@k FTN. 1550-1554 FOOTNOTES FOR TABLE 10 1550 199 A HYDRATED LIME PROCESS IS UTILI.FD FOR TREATMENT OF THE ACID 299 DRAINAGE FROM UNDERGROUND MINES. ASSUMING kN ACID LOAD OF 1000 399 PPM THE@PLANT WILL HAVE TO PROCESS ABOUT 0.8 MMG/DAY (FOOTNOTE 499 1503 MINE DRAINAGE POLLUTANT LOADS). THE TOTAL IRON CONCENTRA- 599 TION IS ABOUT 85 PPM. THUS, THE SOLID WASTE PRODUCTION IS 699 ABOUT 13.7 AC-FT/YR (1102,233). ASSUMING A PRECIPITATE DENSITY 799 OF 71 LB/CF (1114,288) SOLID WASTE IS GENERATED AT A RATE OF 899 21200 T/YR OR 248 T/1.OE12 BTU IN. THIS ISIN ADDITION TO THE 999 REFUSE'PR06UCED FROM THE MINING OPERATION-1.40 T/I.OE12 BTU 1099 IN (FOOTNOTE.1501). 1199 1551 199 THE AVERAGE ANNUAL POWER EXPENSES FOR A HYDRATED LIME SYSTEM 299 UTILIZED IN OPERATION YELLOWBOY WAS ABOUT S164CO/MMGAL/D 399 (1102,231). THUSe AT A COST OF $0.015/KWH,THE ENERGY REQUIRE- 499 MENT TO OPERATE THE 0.8 MMGAL/D TREATMENT PLANT IS 8.75E5 599 KWH/YR_ Ch 1.8_1E4 KWH/1.OE12 BTU. THE REAL ENERGY CONSUMPTION 69() IS 3 TIMES THE BTU EQUIVALENT OF THE ELECTRrCAL ENERGY CON- 799 'SUMED. ON A I.OE12 BTU IN BASIS THE-TOTAL ENERGY CONSUMPTION 899 IS I.OtEg BTU. THIS ENERGY USE IS IN ADDITION TO THE ENERGY 999 EXPENDED FOR THE MINING OPERATION, I.E., 4.07E9 BTU (FOOTNOTE 1099 1505). 1199 1552 199 IT IS ASSU MED THAT THE FINAL DISCHARGE WfLL BE IN COMPLIANCE WITH 299 THE GUIDELINES ESTABLISHED BY EPA (1112) ' IN LIME TREATMENT, 399 BECAUSE OF THE SOLUBILITY OF CALCIUM SULFATE, THE HARDNESS OF' 499 THE WATER WILL INCREASE (1113,24). MOST OF THE METALLIC SALTS 599 WILL PRECIPITATE AS THE PH OF THE SOLUTION IS RAISED. THE 699 EFFLUENT BREAKDOWN IS AS FOLLOWS. 799 PPM T/1.OE12 BTU IN 899 SUSPENDED SOLI DS 30 0.243 999 ACIDITY 0 0.00 1099 ALKALINITY 60 0.486 1199 1299 IRON 4 0.032 1399 MN 4 0.032 1499 AL 1 0.008 1599 CAS04 16-2 1699 SUBTOTAL 16.3 1799 1899 THE ALKALINITY CONCENTRATION IS OPTAINED FROM DATA IN REP. 1999 (1103), THE MN AND AL FROM SOLUBILITY CURVES, WHILE THE 2099 REMAINDER ARE IN COMPLIANCE WITH THE EPAGUIDELrNES. THE VOL- 2199 UME OF; THE DISCHARGE IS ABOUT 85 PC OF THE INFLOW VOLUME 2299 (1103), I.E., 0.68 MMGAL/DAy AND THE FACILITY OPERATES 245 2399 D/YR.' 2499 1553 199 IT IS ASSU7MED THAT THE TREATMENT FACILITY REQUIRES A 2 MMGAL RAW 299 WATER-STC-PAGE POND AND A 80 MMGAL SETTLING POND.; THE LANDIS 399 ASSUMED AVAILABLE. FOP A DEPTH OF 20 FT FOR B07H PONDS, 12.5 -499 AC OF:SUSFACE AREA ARE REQUIRED. THE TREATMENT PLANT OCCUPIES 599 ABOUT 3 AC (1114). THUS, THE TOTAL LAND 'IMPACT IS 0.181'AC,YR/ 699 1.OE12 BTU IN. 799 Tills IS IN ADDITION TO THE LAND IMPACTED.DURING MINING, I.E.,, 899 132 AC-YR/1.OE12 BTU IN (FOOTNOTE 1502). 999 1554 199 BECAUSE OF THE RELATIVELY LOW ACIDITY CONCEFT-RATION AND FLOW RATE, 299 A SODA ASH FACILITY IS UTILIZED TO NEUTRALIZE THE ACID DRAIN- 399 .AGE. SODIUM BASED ALKALIS EFFECTIVELY REMOVE AU.1-D-1-TY.- IR6N.' 499 ITT-115 Preceding page blank. FTN. 1555-1557 ALUMINUM AND OTHER OXIDES, BUT WILL NOT REMOVE THE SULFATES 599 AS SODIUM SULFATE IS A HIGHLY SOLUBLE SALT (1102, 130). 699 THE FACILITY TREATS A DRAINAGE OF 0.4 MMGAL/D WITH AN ACIDITY 799 CONCENTRATION OF 500 PPM, IRON CONCENTRATION OF 85 PPM AND 899 SULFATE LOAD OF 8.2 T/1.OE12 BTU OUT (FOOTNOTE 1514, POLLUTANT 999 LOAD). THUS, THE EFFLUENT BREAKDOWN IS AS FOLLOWS 1099 T/1.OE12 BTU IN 1199 PPM AUGER CONTOUR 1299 SUSPENDED SOLIDS 30 0.115 0.200 1399 ACIDITY 0 0.00 0.00 1499 ALKALINITY 88 0.339 0.589 1599 1699 IRON 0.9 0.0035 0.0060 1799 MN 1.5 0.0058 0.0100 1899 AL 0.5 0.0019 0.0033 1999 SO4 3.77 6.56 2099 NA 1.34 2.34 2199 SUBTOTAL 5.12 8.92 2299 2399 THE SUSPENDED SOLIDS, ACIDITY AND IRON ARE IN COMPLIANCE 2499 WITH THE GUIDELINES ESTABLISHED BY EPA (1112), WHILE THE 2599 CONCENTRATION OF THE OTHERS ARE BASED ON THE RESULTS ON AN 2699 ACTUAL READING (1106). 2799 1555 199 THE SLUDGE PRODUCED FROM THE SODA ASH TREATMENT PROCESS IS ABOUT 299 4 PC BY VOLUME (1106). THUS, FOR THE TREATMENT OF 0.4 MMGAL/D 399 AND AN ASSUMED SLUDGE DENSITY OF 0.04 T/CF, SOLID WASTE IS 499 GENERATED AT A RATE OF 148 T/1.OE12 BTU IN. 599 THIS IS IN ADDITION TO THE SOLID WASTE PRODUCED DURING THE 699 AUGERING OPERATION, I.E., 3.93E4 T/1.OE12 BTU IN (FOOTNOTE 799 1507). 899 1556 199 DURING AUGER MINING A TOTAL OF 2.58 AC/1.OE12 BTU IN OF LAND ARE 299 COVERED BY THE BENCH AND SPOIL PILE AND 1.32 AC/1.OE12 BTU IN 399 ARE AFFECTED BY SUBSIDENCE (FOOTNOTE 1506). 499 IN TIME AVERAGING THE LAND IMPACT, THE EFFECTS OF RECLAMATION 599 MUST BE CONSIDERED. RECLAMATION IN THIS CASE REQUIRES THE 699 RESTORATION OF THE LAND TO TH ORIGINAL CONTOUR (OR AS CLOSE 799 TO THE ORIGINAL CONTOUR AS POSSIBLE), AND STABILIZING THE 899 SURFACE AGAINST EROSION. MINIMIZING EROSION INVOLVES BENEFI- 999 CIAL GRADING (TERRACING, GOUGING, ETC.) AND ESTABLISHING AN 1099 HERBACEOUS COVER. IN APLPALACHIA ABOUT 3 GROWING SEASONS ARE 1199 REQUIRED TO ESTABLISH A 95 PC COVER OF GRASS AND LEAGUMES 1299 (1101). 1399 USING THE 3 YR CRITERION THE TIME AVERAGED LAND IMPACT IS 1499 7.28 AC-YR/1.OE12 BTU IN FOR THE BENCH AND SPOIL PILE AND 1599 16.5 AC-YR/1.OE12 BTU FOR THE SUBSIDED AREA. 1699 IT IS ASSUMED THAT A 20 MMGAL SETTLING BASIN IS REQUIRED FOR 1799 THE TREATMENT FACILITY. TH LAND IS ASSUMED AVAILABLE. FOR 1899 A DEPTH OF 10 FT, 6.1 AC OF LAND ARE NEEDED. THE FACILITY 1999 ITSELF REQUIRES VERY LITTLE LAND (1106). HENCE, AN ADDITIONAL 2099 0.058 AC-YR/1.OE12 BTU IN OF LAND IS IMPACTED. 2199 1557 199 THE ENERGY REQUIREMENT FOR A SOADA ASH OPERATION IS 6.666 KWH/1000299 GAL OF WATER TREATED (FROM INFORMATION IN REF. (1106)). THUS 399 FOR A 0.4 MMGAL/D OPERATION THE ENERGY CONSUMED AMOUNT TO 499 1.32E4 KWH/1.OE12 BTU. THE REAL ENERGY CONSUMPTION IS 2 TIMES 599 III-116 fTN,. 1558-1562 THE BTU EQUIVALENT OF THE ELECTRICITY CONSUMED. ON A4.OE12 699 BTU IN BASIS THE ENERGY.CONSUMPTION IS 6.29E7 BTU _. THIS IS IN 799 ADDITION TO THE ENERGY UT T'_IZATION DURING THE AUGERING 899 OPERATION, I.E., 8.63E8 BlU/1.OE12 BTU IN (FOOTNOTE 1010). 999 1558 199 FOR THE MODIFIED BLOCK CUT MINING TECHNIQUE, SOLID WASTE IS 299 PRODUCED ONLY DURING THE BOX CUT. HENCE, FOR A SLOPE ANGLE OF 399 28 DEGREES, A BENCH WIDTH OF 150 FT, A 15 FT RIM OF BLOSSOM 499 COAL, AND A BOX CUT OF 600-FT IN LENGTH, 0.216,-MMT OR 141 599 T/1.OE12 BTU IN OF SOLID WASTE ARE PRODUCED (SUBSEQUENT TO THE 699 BOX CUT 50 MMT OF COAL ARE REMOVED OVER A 25 YR PERIOD). THE 799 LENGTH OF THE BOX CUT IS BASED ON 250 FT LONG SECOND AND THIRD 899 CUTS (1104) AND ALLOWS FOR EXPANSION. 999 THE SOLID WASTE PRODUCED FROM THE SODA ASH TREATMENT FACILITY 1099 AMOUNTS TO 257 T/1.OE12 BTU IN (FOOTNOTE 1555). 1199 1559 199 FOR CONTOUR MINING (SLOPES GREATER THAN 15 DEGREES)'IT IS ASSUMED 299 THAT'THE MODIFIED BLOCK CUT METHOD IS EMPLOYED. 399 THE THICKNESS OF THE SEAM IS 4.2 FT (FOOTNOTE 1511), THUS 499 5.27 AC ARE OVERTURNED FOR EVERY 1.OE12 BTU EQUIVALENT TON IN 599 (FOOTNOTE 1511). AT THE SAME TIME 1531 FT OF BENCH ARE CREATED.699 ASSUMING 50 FT STR TPS OF LAND ABOVE THE HIGHWALL AND ALONG 799 THE'OUTSLOPE ARE UTILIZED FOR THE DIVERSION DITCH AND FOR 899 STOC KPILING THE TOPSOIL, RESPECTIVELY., ANOTHER 3.51 AC OF LAND' 999 AREAFFECTED/I.OE12 BTU IN. 1099 NOW ASSUMING 3 GROWING SEASONS ARE REQUIRED TO ESTABLISH AN ligg HERBACEOUS COVER (FOOTNOTE 1556), THL TIME AVERAGED (OVER 1299 25 YRS) LAND IMPACT OF THE VARIABLE LAND USE (8.78 AC) IS 1399 24.8 AC-YR/1.OE12 BTU IN. 1499 THE SOLID WASTE GENERATED FROM THE BOX CUT (FOOTNOTE 1558) IS 1599 DISPOSED OF BY THE PARALLEL SLOPE METHOD. BY THE END OF 3 YRS 1699 THIS PLOT WILL BE RECLAIMED (AS MEASURED BY T'@E CRITERION IN 1799 FOOTNOTE 1556), THUS ITS CONTRIBUTION TO THE @.;VERALL LAND IM- 1899 PACT IS NEGLIGIBLE. THE LAND USE BY THE SODA ASH TREATMENT 1999 FACILITY IS 0.100 AC-YR/1.OE12 BTU IN (FOOTNOTE 1556). 2099 IT SHOULD BE NOTED THAT ALTHOUGH CONTOUR BACKFILLING IS AN 2199 INTEGRAL PART OF RECLAMATION IN.THIS ANALYSIS. IN PRACTICE 2299 THIS MAY NOT BE THE RECOMMENDED APPROACH ON STEEPER SLOPES. 2399 IN SUCH A SITUATION EROSION OF THE CONTOUR BACKFILLED AREA 2499 MAY BE DIFFICULT TO PREVENT 2599 1560 199 THE ENERGY CONSUMPTION FOR STRIPPING BY THE MODIFIED BLOCK CUT 299 METHOD IS NOT AVAILABLE AND WAS ASSUMED TO BE THE SAME AS 399 CONVENTIONAL CONTOUR STRIPPING-1.06EIO BTU/I.0!:`I2 BTU IN 499 (FOOTNO*rE 1512). THE ENERGY CONSUMED BY THE S3DA ASH TREAT- 599 MENT FACILITY IS 1.32E4 KWH/1.OE12 BTU OUT (FCOTNOTE 1557) 699 OR 1.08E8 BTU/I.OE12 BTU IN. 799 1561 199 TO CONTROL SILTATION, THE RUNOFF FROM THE HAUL RO..DS IS DIVERTED 299 TO SETTLING PONDS PLACED ALONG THE ROADWAY (1'30). IT IS 399 ASSUMED THAT ALL THE SEDIMENT IS REMOVED. 499 1562 199 IT IS ASSUMED THAT A SETTLING POND IS REQUIRED POF EACH MILE OF 299 ROAD AND THAT EACH POND USES AN ACRE. THUS, 5 AC ARE U11LIZED 399 FOR THE SETTLING POND (THE HAUL ROAD IS'4.7 M: IN LENGTH, 499 FOOTNOTE 1515). THE LAND IMPACT IS O.lb3 AC-Y@/I.OE12 BTU. 599 THIS IS IF ADDITION TO THE LAND IMPACTED BY T:IZ ROAD 0.632 699 AC-YR/1.OE12 BTU (FOOTNOTE 1515). 799 III-L17 A IS IS 7 It 10 .1 IN is IS 11 HIS 19 22 Z' 24 25 21 .1. POTT- L ME' =E WATER POLLUTANTS I ... S1 BTU. IN, I AIR POLLUTANTS 4TONSfIe IFTU) - SOLIDS IRS -- T. L SEE TO-TAL -D..- co ALDEN T se LE DIMANDL@13 SOLIDS SUSPENDED DOD COD T I- Pio,, so. TOTAL RES NWE- ACTIVITY PROCESS CID' BASED , SOLIDS .'N"' COLS mmlerv ULAtES C-s ETC HOW STU IQWT@O'B@ -Aslf. PD. OTHER TOTALWS g 3 4 -mt 4 s INN ------- 0- ion -0 L- -------- IN. IS 14 ON Is is 11 .7 7 IS 24 71- i's IRS DE SIR st 25 -Lo AID 42 73 45 ADD 48 4. f Do TAELL 11. MWMNKWrAL IWACTEL AND -R"MXY FOR TM NOTE: ALL TABLE ENTRIES ARE BASED 04 1012 BTU OF RESOURCE LISTS EAU PROCESS OR ACTIVITY. UNCONTROLLED SOUTEMM REGEM 113' SEE To TKOTE 16N FOR MEASURE EQUIVAILERTS 01 lot, 9TE, M70 ADD ASH CONTENTS COAL SM-ny or SOUTHWESTERN COAL AND REGIO." DESUIPTIO4. L m 7 *rf-u --I..- so preceffing Pap FTN. 1600-1603 FOOTNOTES FOR TABLE 11 1600 199 FOR THIS STUDY THE SOUTHWEST REGION IS COMPRISED SOLELY BY THE 299 1w STATE OF NEW MEXICO. THE FOCUS IS ON THE SAN JUAN BASIN, AND 399 IN PARTICULAR, THE NAVAJO AND THE MCNINLEY MINES SUPPLYING THE 499 FOUR CORNERS AN'D THE CHOLLA POWER PLANTS, RESPECTIVELY. 599 THE AVERAGE CALORIC CONTENT OF THE COAL 'FROH THESE TWO MINES 699 IS ABOUT 9820 BTU/LB, AND THE MEAN ASH AND SULFUR-CONTENT IS 799 15.7 PC AND 0.6 PC, RESPECTIVELY. THE FOUR CORNERS PLANT 899 REQUIRES BY CONTRACT,A HEATING VALUE OF 9000 BTU/LB AND THE 999 AVERAGi ASH CONTENT OF COAL RECEIVED.IS 23.5 PC (1066,3-12,6- 1099 10). THE AVERAGE SULFUR CONTENT OF THE COAL FROM THE NAVAJO 1199 MINE IS ABOUT 0.8 PC (1066,6-9). THE TIPPLE ANALYSIS OF THE 1299 COAL FROM THE MCKINLEY MINE INDICATES-A CALORIC CONTENT OF 1399 10640 BTU/LB, 7.9 PC ASH AND 0.42 PC SULFUR (1040,19). THE 1499 DENSITY CF.THE COAL IS ABOUT 81 LB/CF (1050). 1599 FOR THE GIVEN HEAT VALUE,1.OE12 BTU ARE EQUIVALENT TO.51000 T 1699 OF COAL. 1799 1601 199 THE AVERAGE DEPTH OF THE OVERBURDEN IN 1965 -WAS 47.9 FT (1017), 299 WHICH IS THE APPROXIMATE DEPTH OF THE OVERBURDEN REMOVED 399 DURING 'BOX CUTTING (104.0, 13.#2c3@) . IN AREA STRIPPING ALL OF THE 499 OVERBURDEN, EXCEPT THAT WH:?CH IS REMOVED DDRING THE BOX CUT, 599 IS SPOILED IN BANKS WITHIN THE PIT. HENCE,. THE SOLID.WASTE 699 IS PRODUCED ONLY DURING THE INITIAL EXCAVATION. 799 DUE TO THE VARIABILITY OF THE COAL CHARACTERISTICS,WITHIN THE 899 SEAM AT THE NAVAJO MINE, ABOUT 5 PITS ABE MINED SIMULTANEOUSLY 999 AND THE COAL FROM THE DIFFERENT PITS ARE BLENDED TO MEET 1099 CONTRACT SPECIFICATIONS (1040,13). THUS, 5.BOX CUTS ARE 1199 FECUIRED. 1299 ASSUMING THAT,ON THE AVERAGE,5 AC (PIT SIZE OF ROUGHLY 100 FT 1399 BY 2000 FT,(1007))ARE EXCAVATED FOR THE BOX CUT, ABOUT 2.61E6 1499 T OF SOLID WASTE ARE PRODUCED. APPROXIMATELY 260 MMT OF COAL 1599 FROM THE NAVAJO MINE ARE COMMITTED TO THE FOUR CORNERS PLANT 1699 (1040,12). THUS, THE SOLID WASTE IS GENERATED AT A RATE OF. 1799 414 T/I,.OE12 BTU IN THE GROUND. 1899 1602 199 THE AVERAGE SEAM THICKNESS OF COAL SURFACE MINED IN NEW MEXICO 299 DURING 1965 WAS 11.8 FT (1017). THIS IS 'ASSUMED TO APPLY FOR 399 CURRENT MINING. 499 IN THIS FEGION,AREA STRIPPING IS THE PREDOMINANT MINING. 599 TECHNIQUE EMPLOYED. SINCE RECLAMATION HAS NOT BEEN SUCCESSFUL, 699 NO RECLAMATION IS ASSUMED. 799 FOR 1.OE12 BTU EQUIVALENT T IN 2.45 AC OF LAND 899 ARE OVERTURNED. THE TIME AVERAGED (OVER 25 YRS) LAND IMPACT 999 IS THEREFORE, 30.6 AC-YR/.l.OE12 BTU IN. .1099 1199 IN A PILE AVERAGING 30 FT IN HEIGHT,39.9 AC ARE OCCUPIED BY 1299 THE SOLID WASTE PILE. THUS, FOR AN ANNUAL PRODUCTION OF ABOUT 1399 8.5 MMT (REQUIREMENT FOR THE FOUR CORNERS PLANT (1040,143). 1499 THIS FIGURE IS USED SINCE THE SOLID WASTE IS BASED ON THE 1599 OPERATIONS AT THE NAVAJO MINE.)THE LAND IMPACT is 0.194 .1699 AC-YF/1.CE12 BTU IN (FOOTNOTE 1601). 1799 1603 199 B.Y LINEARLY INTERPOLATING THE DATA BETWEEN A 1 AND A 5 MMT/YR 299 AFEA STRIPPING OPERATION IN THE SOUTHWEST (1041,74,82) THE 399' ENERGY REQUIREMENT FOR A 2 MMT/YR OPERATION IS ESTIMATED. DIE- 499 SEI. FUEL IS ASSUMED TO.COST $0.20/GAL AND ELECTRICAL POWER 599 $0.015/KWH. THUS, FOR DIESEL FUEL AND EL EC TRICAL EXPENSES .111-121 Preceding page blank FTN. 1604-@1610 AMOUNTING TO $0.0275/T AND $0.153/T, RESPECTIVELY, THE TOTAL 799 ENERGY CONSUMPTION IS 6.28E9 BTU/I.OE12 BTU EQUIVALENT T 899.. EXTRACTED. THE TOTAL.IS OBTAINED BY ADDING 3 TIMES THE BTU 999 EQUI,VALENT OF THE ELECTRICAL ENERGY CONSUMPTION TO THE FUEL 1099 USAGE. ON A I.OE12 BTU-IN BASIS,THIS IS 5.09E9 BTU CONSUMED. 1199 .1604 199 DIESEL FUEL CONSUMPTION FOR AN AREA STRIPPING OPERATION IS ESTI- 299 MATED TO BE 5680 GAL/I.OE12 BTU IN @(FOOTNOTE 1603). THE 399 EMISSION FACtORS ARE OBTAINED FROM REF. (0002,3-7) ASSUMING 499 THE CHARACTERISTICS OF A DIESEL TRUCK ENGINE. BEING AN ARID 599 AREA, WIND EROSION AND FUGITIVE DUST ARE PROBLEMS TO CONTEND 699 IT IS ASSUMED THAT PARTICULATES ARE EMITTED AT A RATE 799 WITH. OF 428 LB/AC-YR,WHICH IS THE RATE. OF WIND EROSION FOR THE MORE 899 ERROSIVE REGION OF THE SOUTHERN GREAT PLAINS (1211,18). HENCE, 999 6 5 T OF PARTICULATES ARE EMITTED FOR EVERY 1.OE12 BTU IN 1099 .5 (FOOTNOTE 1602). 1199 1605 199 @DUE -10 THE HIGH'ALKALINE CONTENT OF THE CVERBURDEN, ACID WATER 291 -FORMATION-IS PREVENTED 'AND DISPOSAL OF WATER ACCUMULATED IN THE PITS SHOULD PRESENT NO PROBLEM. THE MORE USUAL PRACTICE 499 IN THIS AREA IS TO ALLOW THE WATER TO EVAPORATE OR SEEP INTO 599 THE SPOILS (1040,65) 699 SINCE RAINFALL It VERY LIMITED,THE RUNOFF CAN EASILY BE 799 DIVERTED AWAY FROM THE PIT. THE NINE PITS HAVE NOT INTERSECTED 899 AVY.GROUNDWATER TO DATE, BUT MAY DO SO IN THE FUTURE. DISPOSAL 999 OF GROUNDWATER., WHEN ENCOUNTERED, SHOULD NOT PRESENT ANY 1099 PROBLEM. ASIDE FROM ALLOWING THE WATER TO EVAPORATE, IT COULD 1199 .BE UTILI2ED FOR DUST SUPPRESSION OR IRRIGATION OF THE RESEEDED1299 SPOIL BANKS. 1399 1606 199 THE AVERAGE DISTANCE FROM MINE TO TIPPLE IS ABOUT 3.25 Mi (3.5 MI 299 FOR THE NAVAJO MINE AND 3.0 MI FOR THE MCKINLEY MINE (1040,21, 399 148)),. DATA FROM STUDIES CONDUCTED IN EASTERN KENTUCKi (1024, 499 1031,1032,1033,1034) INDICATE AN AVERAGE HAUL ROAD RIGHT-OF- 599 WAY OF 6.4 AC/MI. ASSUMING A PRODUCTION OF 2 MMT/YR '2.55 PC 699 OF TH 1; RCAD USAGE IS ATTRIBUTED TO THE THE TRANSPORT OF 799 1.OE,12 BTU EQUIVALENT T. HENCE, THE LAND IMPACT IS 0.529. AC- 899 1607 199 YR/1.OE12 BTU. 999 T HE AVERAGE TPUCK CAPACITY IS 79.5 T (1040,21,148) AND THE MEAN 299 HAULAGE LISTANCE IS 3.25 MI (FOOTNOTE 1606). ASSUMING A GROSS 399 TO TARE %EIGHT RATIO OF 2.5. TO 1, A BOUND TRIP AMCUNTS To 603 499 599 -7). TMI. PUEL CONSUMPTION IS 7 GAL/lCCC TMI (0002,3 HENCE, 21710,(;AL OF LIESEL FUEL ARE CONSUMED FOR THE HAULAGE OF 1.OE12 699 BTU EQUIVALENT T: THE EMISSION FACTORS ARE OBTAINED FROM PEF. 79 000,2, 3 - 7) 899 FUGITIVE DUST FROM THE HAUL ROADS IS ASSUMED TO BE SUPPRESSED 999 BY WATERING DOWN THE ROADS WITH OR WITHOUT CHEMICAL ADDITIVES-1099 1608 199 DIESEL FUEL CONSUMPTION AMOUNTS To 2710 GAL/I.OE12 BTU. THUS, THE 299 IS 3.76E8 BTU (FOOTNOTE 1607),. 399 .ENERGY CCNSUMPTION 16'09 199 ALL CONVEYORS AND CRUSHING FACILITIES ARE ENCLOSED AND WATER SPRAY 299 SYSTEMS APE EFFECTIVE IN CONTROLING DUST (1040,148). 39q 1610 liq A CRUSHt� OFERATING AT 275 T/HR AND CRUSHING TO A TOPSIZE OF 1.5 IN. REQUIRES A 140 HP MOTOR (1014,7-14) THUS, 1.94E4 KWH OF A9, ENERGY AFE UTILIZED TO CRUSH 1.OE12 BTU EQUIVALENT T OF COAL. 1499. THE REAL ENERGY CON-SUMPTION -IS 3 TIMES THE BTU EQUIVALENT' OF ,THE,ELECTRICAL ENERGY CONSUMED. 111-122 FTN. 1611-1619 1611 199 'ENERGY CONSUMPTION AT A CRUSHING AND SIZING PLANT IS ABOUT 2.07E9 299 BTU/1.OE12 BTU EQUIVALENT T PROCESSED. OF THE TOTAL CONSUMP- 399 TION,1.81E5 KWH IS ELECTRICIT" AND 2.91EB BT11 IS OIL (1064, 499 12A-16,39). THE TOTAL IS OBTAINED BY ADDING 3 TIMES THE BTU 599 EQUIVALENT OF THE ELECTRICAL CONSUMPTION TO THE OIL USAGE. 699 1612 199 THE HAULAGE DIS'fANCE FOR TRANSPORT BY UNIT TRAIN IS 100 MI, WHICH 299 IS THE HAULAGE DISTANCE BETWEEN THE MCKINLEY MINE AND THE 399 CHOLLA POWER PLANT (THE CRUSHING PLANT FOR THE NAVAJO MINE IS 499 ADJACENT TO THE FOUR CORNERS PLANT AND CONVEYORS ARE USED TO 599 TRANSPORT THE.COAL FROM THE BLENDING AREA TO THE POWER PLANT. 699 (1060,7-9)). THE ENERGY CONSUMPTION IS 690 BTU/TAI, 799 (FOOTNOTE 7013), OR 0.005 GAL OF DIESEL FUEL/TMI. EACH TRAIN 899 IS ASSUMED TO CARRY A 9000 T LOAD (100 CARS AT 90 T/CAR (1040, 999 21) AND THE GROSS TO TARE WEIGHT RATIO OF THE CARS IS 4 TO 1 1099 (FOOTNOTE 1005). THUS, EACH ROUND TRIP AMOUNTS TO 1.5E6 TMI, 1199 AND 4.25E4 GAL.O? FUEL ARE CONSUMED FOR EACH 1.OE12 BTU EQUI- 1299 VALENT T TRANSPORTED. THE EMISSION FACTORS ARE OBTAINED FROM 1399 FEF. (0002.3-7). 1499 WINDAGE LOSSES AMOUNT TO .04 PC OF THE TOTAL SHIPMENT AND ARE 1599 ATTRIBUTED MAINLY TO HANDLING AT EITHER END POINT. 1699 THUS, 20.4 T OF PARTICULATES ARE RELEASED. 1799 1613 1.99 DIESEL FUEL CONSUMPTION BY THE UNIT TRAIN IS 4.25E4 GAL/l..OE12 299 BTU. THUS, THE ENERGY CONSUMPTION AMOUNTS TO 5.89E9 BTU. 399 FOOTNOTE 1612). .499 1614 199 THE TOTAL MILES OF RAILROAD OPERATED WEST OF THE MISSISSIPPI IN 299 1971 WAS 119000 MI (0033,59) AND OF:THE TOTAL TONNAGE OF 399 -FREIGHT HAULED DURING THE SAME YEAR IN THIS DISTRICT, COAL 499 ACCOUNTED FOR 9 PC (0039,27), OR 48.8EO6 TONS. OF THIS 16.7 599 PC ORIGINATED IN NEW MEXICO. ASSUMING A RIGHT-OF-WAY OF 6 699 AC/Ml, THE LAND IMPACT IS 67.2 AC-YR/1.OE12 BTU. 799 1615 199 IN THE STATES WEST OF THE MISSISSIPPI,RAILWAY ACCIDENTS CLAIMED 299 714 LIVES AND INJURED 5700 PERSONS (0006,17,54), AND AN AVE- 399 RAGE OF 93 MAN-DAYS WERE LOST PER INJURY (0006,4) 499 FOR EVERY 1.OE12 BTU EQUIVALENT T OF COAL TRANSPO@TED 0.0669 599 FATALITIES AND 0.534 NON-FATAL INJURIES OCCURED IN THIS 699 REGION AND 49.6 MAN-DAYS WERE LOST.. (FOOTNOTE 1614, COAL 799 TRANSPORTED) 899 1616 . 199 THE OCCUPATIONAL HEALTH STATISTICS FOR HAULAGE FROM MINE TO TIPPLE 299 ARE OBTAINED FROM (1210,80/91 AND 1070) AND REPPESENT AN 399 AVERAGE FOR 1969 AND 1970. 499 1617 199 THERE WERE NO INJURIES, FATAL OR NON-FATAL, AT ANY OF THE 299 PREPARATION PLANTS IN NEW MEXICO DURING 1969 AND 1970. 399 1618 199 IT IS ASSUMED THAT 0.006 PC OF THE.FEED TO THE CRUSHING PLANT IS 299 TRAMP IRON AND IS REMOVED PRIOR TO CRUSHING. TIVIS,-3.06 T OF 399 TRAMP IRON ARE COLLECTED FOR EVERY 1.OE12 BTU PROCESSED. THE 499 PERCENTAGE OF TRAMP IRON IS ESTIMATED FROM INFORMATION IN 599 REF. (1059,6-31) ASSUMING THAT THE LARGE PLANT PROCESSES 1000 699 T/HR. 799 1619 199 ABOUT 35 ACRES APE REQUIRED FOR THE CRUSHING PLANT ANE THE SUPPORT- 299 ING FACILITIES. ASSUMING THE PROCESSING OF 2 MMT/YR, THE LAND 399 IMPACT IS 0.893 AC-YR/1.OE12 BTU. 499 111-123 FTN. 1620-1622 1620 199 THE COAL IN THIS AREA IS USUALLY STORED ABOVE GROUND. AT THE FOUR 299 CORNERS POWER PLANT, THE COAL IS STACKED BY CONVEYORS IN PILES 399 90 FT WIDE AND 800 FT LONG, EACH CONTAINING ABOUT 30000 T OF 499 BLEACHED COAL (1040,148). THUS, THE LAND IMPACT IS 2.80 AC-YR/ 599 1.OE12 BTU. 699 1621 199 AS IN THE CASE FOR THE MINES, IT IS ASSUMED THAT 428 LB/AC-YR OF 299 COAL FINES WILL BECOME AIRBORNE AS PARTICULATED DUE TO THE 399 WINDAGE. THUS, 0.6 T/1.OE12 BTU OF PARTICULATES ARE EMITTED. 499 1622 199 ENERGY CONSUMPTION FOR THE MOVEMENT OF COAL BY CONVEYORS FOR 299 STORAGE AMOUNTS TO 1.86E4 KWH/1.OE12 BTU (FOOTNOTE 1058). THE 399 REAL ENERGY CONSUMPTION IS 3 TIMES THE BTU EQUIVALENT OF THE 499 ELECTRICAL ENERGY CONSUMED. 599 III-124 III-124 7--l- fl 2 3 is I. is Is is 2. 2, gs U I ME" WATER POLLUTANTS (TONS/ lop m. E. E-@) AIR POLLUTANTS MU) ? OCCUPATIONAL HEALTH RoTTWTUUL Wili .--TV -.C.- DISSOLVED SOLIDS SUSPENDED TOTAL so @@Z:ILU-ft.Tw:- so. Hmo- ALDEHYDES s' DEATHS Mm"its L 6: IV _,oWR_ 'WL 'o ETC 8M D $CA EM V BASES PZ@@WI OTHER ToT@mw SELMs C.- C ULATE$ --s loTAL T T a am VOW . ... ......I 4 -4 WN I. I. WII _7 VAA -4 IVV Wo VAN I_ 4 Hii I Ull 1. -01 1 1- 1 ..1, 1 -1 .2 VV@ WIN TT T7 19 so. t2 24 t7 .7 a -is 31 SO 31 S? a 3. 4" i -A- 4. 44 45 77 INS 7 z@- NOTE: ALL TAR E ENTRIES ARE MED ON 1012 %- OF "ME IRTO EACH PROCESS OR ACTIVITY. ,EEIF011140TE 1600 FOR "EASUIVE EQUIVA@n oP U12 61t, SULFUR AAD ASH CONTENTS TABLE 12. ENVIRONMENTAL UWACTS AM EWF%C0MFff FM THE OF M'SYTIUR CQAt: ARM USMAL USCMlYTIUHK. 16 CONTROLZIED SOUTHwwr HEMN OF COAL SUMY 1 o -.7 so 1625-1629 FT.N. FOOTNOTES FOR TABLE 12 1625 199 IN THE SAN JUAN BASIN, 2.45 AC OF LAND ARE OVERTURNED PER 299 1.OE12 BTU IN (FOOTNOTE 1602). 399 IN TIME AVERAGING THE LAND IMPACT, CONSIDERATION MUST BE GIVEN 499 TO THE EFFECTS OF RECLAMATION, WHICH IN THIS CASE IMPLIES 599 CONTOUR BACKFILLING, REDISTRIBUTION OF TOPSOIL, SEED BEE PREP- 699 ARATION, TERRACING (GOUGING) AND REVEGETATION. THE CRITERION 799 FOR REVEGETATION IS THE ESTABLISHMENT OF AN HERBACEOUS COVER 899 SUFFICIENT TO STABILIZE THE SURFACE AGAINST EROSION. FOR THE 999 PURPOSE OF QUANTIFICATION,5 YRS ARE ASSUMED TO BE SUFFICIENT 1099 TO RECLAIM THE LAND TO THE ABOVE CRITERION (SEE FOOTNOTE 1199 1230). THIS DOES NOT IMPLY THAT 5 YRS ARE ADEQUATE IN PRAC- 1299 TICE. RECLAMATION STUDIES FOR THIS AREA HAVE BEGUN ONLY 1399 RECENTLY AND NO CONCLUSIVE RESULTS HAVE BEEN PRESENTED. 1499 THE TIME AVERAGED IMPACT IS THEREFORE 11.0 AC-Y*R/1.OE12 BTU IN 1599 (THE LAND USED FOR STORAGE OF THE WASTE IS ASSUMED TO BE ZERO,1699 I.E., INSTANTANEOUS RECLAMATION) 1799 1626 199 ASSUMING A SPOIL PILE HEIGHT OF 75 FT AND GEOMETRICALLY UNIFORM 299 PARALLEL SPOIL BANKS RESTING AT AN ANGLE OF REPOSE OF 38 399 DEGREES, THE PEAK TO PEAK DISTANCE IS ABOUT 100 FT. THUS, THE 499 ENERGY CONSUMED TO LEVEL THE SPOIL PILE AMOUNTS TO 3920 HP-HR/ 59.9 AC ((1222,67) AND ASSUMING A 6 PC PERFORMANCE EFFICIENCY). 699 THUS, 2.45E7 BTU/1.OE12 BTU IN ARE EXPENDED (FOOTNOTE 1602, 799 LAND TO BE RECLAIMED). 899 THIS ENERGY USE IS IN ADDITION TO THE ENERGY REQUIRED FOR THE 999 MINING OPERATION--5.09E9 BTU/1.OE12 BTU IN (FOOTNOTE 1603). .1099 1627 199 TO CONTROL SEDIMENTATION,THE RUNOFF FROM THE HAUL ROADS IS 299 DIVERTED TO SETTLING PONDS PLACED AT INTEFVALS,ALONG THE 399 9� ROADWAY (1100). FOR THE 3.25 MI LONG HAUL ROADS (FOOTNOTE 4 1606) 2 1SETTLING PONDS ARE ASSUMED TO BE ADEQUATE AND, 599 BECAUSE OF THE LOW RAINFALL, SUFFICIENT TO CONTAIN ALL CF 699 THE RUNOFF. THE WATER CAN BE USED TO SUPPRESS THE DUST FROM. 7qq THE HAUL ROADS, OR ALLOWED TO EVAPORATE. 899@ 1628 199 THE.HAUL ROAD LAND IMPACT is C.529 AC-YR/1.OE12 BTU (FOOTNOTE 299 16C6). THE SETTLING PONDS ARE ASSUMED TO OCCUPY 2 AC (1 AC 399 FER FOND). THUS, THE LAND IMPACT@FOR THE SETTLING PONDS IS 499 0.0509 AC-YR/1.OE12 BTU (2 MMT/YR HAULED ON THE ROADS). 599 THE TOTAL LAND IMPACT Is 0.580 AC-YR/1.OE12 BTU. 699 1629 199 BASED ON AN EROSION RATE OF 428 LB/AC-YR (FOOTNOTE'1604) AND A 299 TIME AVERAGED LAND IMPACT OF 11.0 AC-YP,/l.OE12 BTU IN j99 (FOOTNOTE 1625), 2.35 TON PART/I.OE12 BTU IN ARE GENERATED. 499 THIS IS IN ADDITION TO THE PARTICULATES FROM THE DIESEL FUEL 59.9 CONSUMED (FOOTNOTE 1604). 699 111-127 Preceding page blank IV. OIL SUPPL A. Introduction The enviro uirements, and costs nmental impacts, energy:,req associated with the.productiont transportation, processing, and distribution of crude oil.and refinery products are presented on a national average basis for the "uncontrolled" and "controlled" petroleum supply cases. Also presented are five regional analyses, with and without environmental controls, which reflect the use of specific crude or residual fuel oils. The regional analysis is based primarily on the different sulfur contents of the crudes and is generally constrained by the lack of regional data. Many re- fineries run a blend of crude feedstocks which precludes an environmental impact assessment of any specific crude oil. The crude oil processing activity of the petroleum supply system is comprised of a national average refinery row and rows representing the constituent process components contained in the national average refinery. However, in keeping with the table entry format, the elements in each row are based on an energy in- put of 1012 Btu/yr. Thus, for example, the entries in the row labeled Catalytic Cracking have been computed based on an input of 1012 Btu/yr to this process (equivalent to 176,000 bbl of feedstock for this process). In contrast, the entries in the row labeled National Average Refinery have been computed based on an input of 1012 Btu/yr to the refinery (equivalent to 178,000 bbl of crude feedstock). The national average refinery, of course, is comprised of the component processes but the process capacities are as shown in Figure 11. It should also be understood, as noted above,'that 1012 Btu/yr input to each process in not equivalent toil78,OOO bbl of crude feedstock to each process. Rather, the appropriate petroleum derived feedstock (and heating value) is used as the basis for computing the bbl equivalents of 1012 level. This information is provided in Btu/yr at the process, the footnotes. The level of environmental control forthe "uncontrolled" petroleum supply is taken as the application of present day en- vironmental controls for the extraction, transportation, dis- tribution, and-donversion activities. The processing activity, on the other hand, represents a minimal level of environmental control for the "uncontrolled" case because of the lack of available data delineating the present degree of control in the refining industry. Also, using a minimum level of environ- mental control in the uncontrolled processing activity provides a better baseline for the application.of controls to the re- fining industry. Consequently, the "uncontrolled" national IV-1 GASES GASOLINE NAPHTHA =K,.zc.t KEROSINE .-,,P.AROMATICS GASOLINE @RIALCFIACKING [email protected] RE'...-G (4t,000) NAPHTHA GASOLINE TIIUEL ------------- W CO-6 FURNACE OIL 0,000) Msoo) ROMATICS KEROSINE --.*.ALKYLATg CATALYTIC CRACKING FEED FUFURAL FURNACE OIL L .0. REFMIN@ RAFFINATE A! CRUDE OIL T GASOLINE "I . GASOLINE (LOV0 OCTANE) .0_) STORAGE OCTANE) C23,010.) GASOLINE ISE DID l...ACE OIL LU.5,Emo.,.AL,, ...ER.t OILS LU L CXUe6 :F. (. .,.E LUBRICATING 04LS GAS OIL ISOBUTAMEALT. OLEFINS KE&B@Alf (mYDROT EA11.1) FLUID@CAAT C GASOLINE ALKYLATE (4,000) CR C C@I I FURNACE OIL ALKYLATIO@ (50,ooo) KAXING 0E.- OIL ATMOSFNERM &1@0 A. CUT rF WAX Z-S-Gf Cuuu 0) 1@(IIASE NUIAC FRACTIONATION HEA@Y GASES (100 ,1 DISTILATE KIDROTREAT.NG (200) (.0,000) CATALYTIC CRACKING & I I DEASPHALTED OIL T'SE@ MICROCIFYSTALLIME YFAW :(71@D-R AT IG PARAFFIN WAX ('0.) (500) I.- P .:lDR,oUCFACIUNG L GASES GASOLINE (14,000) FURNACE OIL I.E. JlPHALT Al"ALT IN Nor; IN M WTHESES REPRESENT P CAPACITIES IN IIAMRPE 3 [A $T*E.. "I EL MTPOTNITICAL 9006000 isesD mermicm. @4q .1 1 -7@ H4 -AXE. W!A =X=l OL @FM@ACE FIGURE 11. NATIONAL AVERAGE REFINERY average petroleum refinery has only an API separator for the treatment of wastewater effluents, has no control for CO or par- ticulates from catalytic cracking regenerators, uses fixed roof tanks for the storage of all crude and petroleum products, flares all H2S from sour process gas streams, and releases thermal discharges associated with once-through river cooling systems. The "controlled" refinery, in contrast, requires the use of best practical control technology currently available for the treatment of wastewater effluents, the use of demonstrated air pollution control technology for compliance with the New Source Performance Standards for petroleum refineries, and the use of mechanical draft wet cooling towers to abate thermal discharges. It should be noted that end-of-pipe treatment (to reduce water effluents and thermal discharges) is shown only for the national average refinery row whereas specific air pollutant sources (process rows) are shown controlled at both the process and national average refinery levels. Generally speaking, the requirement for use of control technology in the "controlled" processing activityis mandated by existent or soon-to-be-implemented federal or state regulations. On the other hand, the existence of the "controlled" extraction, transportation, distribution, and conversion activities represents the use of control technology which merits consideration for future more comprehensive environmental regulation. This. includes the use of double bottom construction on tankers to pro-@ vide clean ballast storage and to reduce the risks of oil spills should a grounding occur a -nd the use of a compression-liquefaction vapor recovery system for the control of hydrocarbon emissions from gasoline service stations. The five regional analysis supply tables presented are based on the use of domestic onshore crude, domestic offshore crude, imported Canadian crude, imported middle East crude, and im- ported South.American residual fuel oil. The activity most sensitive to the regional characteristics of the crude is that of processing and, due to the lack of available data, only the sulfur content of the crudes has any discernible impact on refinery emission characteristics given in the tables. Figure 12 summarizes the crude oil properties used for the national and regional analyses. The approach used in this analysis has been to alter refinery SOx emissions or product sulfur contents according to the varying sulfur contents of the crude feedstock. It is realized, of course, that hydrodesulfurization of petroleun feedstocks can circumvent this result and is in fact being practiced today by refineries running sour crudes. This has not been employed in our analysis. In cases where,a process within an activity predominates, only that process is included in the regional table. This is illustrated, for example, in the imported Canadian crude regional case by pipeline transport in the transportation activity. IV-3 12 10 Btu Sulfur Region Equivalent Density Content (BBL) (lb/BBL) M Domestic Onshore 178000 305.6 0.81 Domestic offshore 178000 305.6 0.61 Imported Canadian Crude 178000 30-9.6 0.59 Imported Middle East 178000 305.6 1.92 Crude Imported South American 159000 331.1 1.50 Residual National Average 178000 305.6 0.7.9 Figure.12. National and Regional Crude Oil Analy s6s 117-3A Impact Data Tables and Footnotes. IV-4 3 4 13 1. .4 17 1. 1. 1. 22 a 1. 25 FUEL WATM KLLUTAMTS (TQMI,CN STU, ER. Cft. 1) R "ll POTEMIAL co (jj: 'HOED mA, L1. DUSM-10 UQ%.URs 'Qv@ I-TI -1138 1T A-. U -1--, J. 3 -6 7 M ------ 10 Ui 14 :t: P 7: RR R, a'- 49 IIEI BU -1 M 71 t% A@ TABLE MKIES ARE BASED OR 1012 BTU OF R15MRCE IBM EACH PROCESS OR ACTIVITY. LE 13 ENVIRONMENTAL IMPACTS. EMCIENCV AND CWr FlOft 5CE FCOTRIDIFU 200 FG1 NEASU.E EQUIVALEXTS OF 1012 BTU. UNCONTROLLED NATIONAL OIL SUPPLy bad I @ :-@ RIM zq, Jv-5 FOOTNOTES FOR TABLE 13 FTN. 2000-2005 2000 199 ENTRIES IN THE TABLE ARE BASED ON AN ENERGY INPUT TO EACH PROCESS 299 OF 1.OE12 BTU/YR. ADDITIONAL-Y, THE BBL/YR OF CRUDE OR REFINED 399 PETROLEUM EQUIVALENT TO 1.OE12 BTU/YR WERE DETERMINED ON THE 499 BASIS OF THE HEATING VALUE MOST CLOSELY REPRESENTATIVE OF THAT 599 CRUDE OR REFINED PETROLEUM (0005,38) . THE CRUDE. OIL SUPPLY OF 699 THE U.S. COMES FROM THE FOLLOWING AREAS-DOMESTIC ONSHORE PROD- 799 UCTION 69.8P,DOMESTIC OFFSHORE PRODUCTION 15. 1P AND FOREIGN 899 IMPORTS 15.1P BASED ON DATA FROM (2005,8/9). THE COMPOSITE 999 SULFUR CONTENT OF THE ENTIRE SUPPLY IS 0.79P BASED ON THE 1099 DISTRIBUTION ABOVE AND THE SULFUR CONTENT OF DIFFERENT DOMES- 1199 TIL AND FOREIGN GRADES FROM (2018,59) AND (2019,1/13). 1.OE12 1299 BTU OF CRUDE OIL IS EQUTVALENT TO 178,000 BBL. 1399 2001 199 BASED ON 1963 DATA, 587777 PRODUCING OIL WELLS (0010,47),INCLUDING 299 2321 OFFSHORE WELLS (0010,53),TOTAL PRODUCTION OF 2.75E9 BBLS 399 (0010,70)INCLUDING 1.75E8 BBLS FROM OFFSHORE WELLS (0010,53). 499 ON THIS BASIS AV PRODUCTIONS PER WELL ARE 4.4E3 BBL ONSHORE 599 AND 7.54E4 OFFSHORE,ANNUALLY. ASSUMING LAND REQUIREMENT OF 699 1/4 AC/ONSHORE WELL AND 1/2 AC/OFFSHORE WELL, THE IMPACTS ARE 799 3.03 AC-YR/1.OE12 BTU IN ONSHORE AND .354 AC-YR/1.OE12 BTU IN 899 OFFSHORE. IF OIL PRODUCTION FROM WELLS PRODUCING OIL AND GAS 999 IS CONSIDERED THE LAND IMPACTS SHOULD BE CHANGED TO 2.35 AC- 1099 YR/1.OE12 BTU IN ONSHORE AND .274 AC-YR/1.OE12 BTU IN OFFSHORE.1199 THESE VALUES *ARE BASED ON 1963 DATA, TOTAL GAS PRODUCTION FROM 1299 OIL WELLS OF 4.367E12 CF (0010,108) INCLUDING 2.79E11 CF FROM 1399 OFFSHORE OIL WELLS (0010,63). ON THIS BASIS AV PRODUCTION OF 1499 GAS PER OIL WELL IS 6.98E6 CF GAS FOR ONSHORE AND 1.20E8 CF 1599 GAS FOR OFFSHORE. ON THIS BASIS APPROXIMATELY 2.92E11 BTU/YR 1699 OF GAS ARE PRODUCED IN ADDITION TO THE 1.OE12 BTU/YR OF OIL 1799 FOR ONSHORE WELLS AND 2.93E11 BTU/YR OF GAS ARE PRODUCED IN 1899 ADDITION TO THE 1.OE12 BTU/YR OF OIL FROM OFFSHORE WELLS. THE 1999 ALLOCATION OF ACREAGE TO OIL PRODUCTION IS BASED ON THE OIL 2699 FRACTION OF THE TOTAL PRODUCTION/WELL EXPRESSED IN BTU EQUI- 2199 VALENTS. USING 1031 BTU/SCF GAS (0005,38), THE OIL FRACTIONS 229.9 ARE .774 FOR ONSHORE AND .773 FOR OFFSHORE. AT 1/4 AC/ONSHORE 2399 WELL AND 1/2 AC/OFFSHORE WELL,THE IMPACTS GIVEN ABOVE ARE OB- 2499 TAINED. 2599 2002 LAND IMPACT FOR PIPELINE TRANSPORT OF CRUDE OIL IS BASED ON 1971 TOTAL CRUDE OIL TRUNK AND GATHERING LINE MILEAGE OF 146200 MT 399 (2001,2) AND TOTAL CRUDE OIL TRANSPORTED BY PIPELINE 499 IN 1971 OF 3.095E9 BBL (0005,14). ASSUMING AN AV PIPELINE 599 RIGHT-OF-WAY OF 62.5 FT (2002,14), ABOUT 63.6 AC ARE AFFECTED 699 PER I.OE12 BTU SHIPPED. 799 2003 199 APPROXIMATELY 0.006P(VOL) OF THE OIL MOVED BY PIPELINE IS LOST IN 299 LEAKAGE (0012,71) ASSUMING THAT 5P EVENTUALLY SEePS INTO WATER 399 BODIES, 0.08TONS/YR ARE LOST. BASED ON 178000 BZL/YR CRUDE. 499 2004 199 THE OIL EMITTED TO WATERBODIES FROM ONSHORE PRODUCTION IS THAT OIL 299 RELEASE BY THE INCOMPLETE SEPARATICN OF BRINE AND OIL AT THE 399 WELL. BASED ON BRINE PRODUCTION OF 2.7 BBL PER BBL CRUDE OIL 499 AND 12P CF THE BRINE DISPOSED OF IN NONPOTABLE OR SALINE WATE 9 BODIES(2003,147)AND 0.005P OIL CONTENT IN THE BRINE(2003,102). 699 THE BRINE DISCHARGE ITSELF IS NOT CONSIDERED A POLLUTANT TO' 799 THE RECEIVING WATERBODY. 899 2005 199 ELECTROSTATIC DESA0LTING 299 BBL FEED EQUIVALENT TO 1.2OE12 BTU IS 178000(0005,38 AND FOOT- 399 N0TE 2000). ELECTRIC ENERGY REQD. IS .006 KWH/BBL (2006, 189) 499 WATER PCLLUTANTS IV-7 599 Preceding, page blank BTN. 2006 THERMAL-GALLONS COOLING WATER/BB FEED IS 0.0 AND NO DELTA T 699 (2006,189) 799 ORGANICS INCLUDE OIL AT 0.012 LB/BBL FEED (2011, 899 11), PHENOL AT 0.00005 LB/BBL FEED (2009, A-4/A-5) 999 OTHER DISSOLVED SOLIDS INCLUDE SALT AT 0.097 LB/BBL FEED (2008, 1099 104/113), HYDROGEN SULFIDE AT 0.008 LB/BBT FEED (2011,11) AND 1199 AMONIA AT 0.009 LB/BBL FEED (2011,11) 1299 BOD LOAD IS 0.003 LB/BBD FEED (2011,11) 1399 COD LOAD IS 0.032 LB/BBL FEED (2011,11) 1499 TDS LOAD IS 0.25 LB/BBL FEED (2011,11) 1599 **AIR POLLUTANTS** 1699 ELECTROSTATIC DESALTING IS CONSIDERED AN INTEGRAL PART OF THE 1799 ATMOSPHERIC/VACUUM DISTILLATION PROCESS AND, AS SUCH, ITS AIR 1899 IMISSIONS ARE INCLUDED WITH THOSE OF THE DISTRILLATION PROCESS 1999 2006 199 ATMOSPHERIC/VACUUM DISTILLATION 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 178000(0005,38 AND FOOT- 399 NOTE 2000) 499 **WATER POLLUTANTS** 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 290 AND DELTA T IS 699 35F (2006, 217) 799 ORGANICS INCLUDE OIL AT 0.017 LB/BBL FEED (2011, 899 11), PHENOL AT 0.001 LB/BBL FEED (2009, A-4/A05) 999 OTHER DISSOLVED SOLIDS INCLUDE HYDROGEN SULFIDE AT 0.001 LB/ 1099 BBL (2011,11) 1199 BOD LOAD IS 0.0002 LB/BBL FEED (2011,11) 1299 COD LOAD IS 0.004 LB/BBL FEED (2011,11) 1399 TDS LOAD IS 0.35 LB/BBL FEED (2011,11) 1499 **AIR POLLUTANTS** 1599 THE AIR POLLUTANTS FOR THIS PROCESS ALSO INCLUDE THOSE FOR THE 1699 ELECTROSTATIC DESALTER. 1799 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1899 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES, VESSEL 1999 RELIEF VALVES, PUMP AND COMPRESSOR SEALS, VACUUM JETS AND PRO- 2099 CESS DRAINS. AIR POLUTANT EMISSION FACTORS FROM (0002,1-9, 2199 9-3/9-4). NATURAL GAS WAS ASSUMED TO BE THE FUEL USED IN THE 2299 BOILERS AND PROCESS HEATERS. 2399 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 1.759E7 2499 BASED ON (2006, 217) AND 1031 BTU/SCF(0005,38). 2599 SCF FUEL REQUIRED FOR THE PRODUCTION OF STEAM IS 3.10E6 2699 BASED ON (2006,217), FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF 2799 (0005,38) ALSO ELECTRIC AT 0.4 KWH/BBL (2006/217) 2899 WASTEWATER FLOW FOR ELECTROSTATIC DESALTER IS 2.1 GAL/BBL 2999 FEED AND FOR SIDTILLATION 26.0 GAL/BBL FEED (2011,11). 3099 *AIR EMISSIONS (TON/YR) ** 3199 PROCESS STEAM OTHER 3299 COMPONENT HEATERS BOILERS SOURCES 3399 PARTICULATES 1.76E-01 3.10E-02 - 3499 NO- 2.02E+00 3.56E-01 - 3599 SO- 5.28E-03 9.30E-04 - 3699 HC 2.64E-01 4.65E-02 2.79E+01 3799 CO 3.52E-03 6.20E-04 - 3899 NH3 0.00E+00 0.00E+00 - 3999 OTHER ORGANICS 8.80E-02 1.56E-02 - 4099 BASED ON (2009, FIG 3), FOR A REFINERY WITH A CAPACITY OF 4199 100000 BPSD, THE PROCESSING CAPACITY OF THE ELECTROSTATIC 4299 DESALTER AND ATMOSPHERIC/VACUUM DISTILLATION UNTIL IS 100000 4399 BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY IS 4499 306700 BPSD (THAT IS, THE SUM OF THE CAPACITIES OF THE INDIVID- 4599 UAL PROCESSES). THUS, THE FRACTION OF TOTAL PROCESSING CAPA- 4699 CITY ATTRIBUTABLE TO THE DESALTING AND DISTILLATION PROCESSES 4799 IV-8 FTN 2007-2008 IS 0.326C5. USED TO OBTAIN TOTAL OTHER REFINERY EMISSIONS AT 4a99 4999 PROCESS LEVEL. 2007 199 CATALYTIC CRACKING AND CATALYST REGENERATION 299. BBL FEED EQUIVALENT TO 1.OE12 BTU IS 176000(0005,38 AND FOOT- 399 NOTE 2000) 499 ** WATER POLLUTANTS 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 415 AND DELTA T IS 699 25F(2006,131/138) 799 ORGANICS INCLUDE OIL AT .10 LB/BBL FEED (2011-11) 899 -4/A-5) AND PHENOL AT 0.005 LB/BBL(2009,A 999 OTHER DISSOLVED SOLIDS INCLUDE SULFIDES(AS H2S) AT 0.036 LB/ 1099 BBL FEED AND NITRATES(AS NH3) AT 0.04 LB/BBL FEED(2011,11) 1199 BOD LOAD IS 0.015 LB/BBL FEED (2011,11) 1299 CCD LOAD IS 0.016 LB/BBL FEED (2011,11) 1399 TDS LOAD IS 0.09 LB/BBL FEED (2011,11) 1499 AIR POLLUTANTS 1599 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1699 HEATERS,FLOW DOWN SYSTEMS, PIPELINE VALVES AND FLANGES, VESSEL 1799 RELIEF VALVES, PUMP AND COMPRESSOR SEALS,PROCESS DRAINS AND, 1899 FOR THIS PROCESS ONLY,THE CONVERSION OPERATION. AIR POLLUTANT1999 'EMISSION FACTORS FROM(0002,1-9,9-3/9-4)EXCEPT FOR CONVERSION 2099 SOX EMISSIONS WHICH APE DETERMINED AS FOLLOWS- 3.2P OF TOTAL 2199 SULFUR IN CRUDE IS ATTRIBUTABLE TO REFINERY CAT CRACKER SOX 2299 EMISSIONS (2024) AND NATIONAL AVERAGE CRUDE HAS .79P SULFUR 2399 (FOOTNOTE 2000). THESE REFINERY CAT CRACKER CONVERSION SOX 2499 EMISSIONS ARE THEN OBTAINED FOR 1.OE12 BTU INPUT TO CAT 2599 CRACKER BY MULTIPLYING BY RATIO OF BEL OF FEED EQUIVALENT 2699 TO 1.OE12 BTU TO BBL OF CRUDE EQUIVALENT TO 1.OE12 BTU AND 2799 THEN MULTIPLIED BY RATIO OF BBL OF CRUDE PROCESSED/DAY IN THE2899 REFINERY TO BEL OF FEED/DAY TO CAT CRACKER FROM(2009FIG.3).12999 NATURAL GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS 3099 AND PROCESS HEATERS. SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU 3199 FEED IS 2.416E7 BASED ON(2006,131/8)AND 1031 BTU/SCF(0005,38)3299 SCF FUEL REQUIRED FOR THE PRODUCTICN OF STEAM IS 6.5OE6 3399 BASED ON(2006,137/8)FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF 3499 (0005,38) ELECTRIC AT 1.04 KWH/BBL(2006,131/138) 3599 WASTEWATER FLOW FOR THE.CAT. CRACKING AND REGEN. PROCESS IS 3699 15.0 GAL/BBL FEED(2011,11) 3799 AIR EMISSIONS (TONS/YR) 3899 PROCESS STEAM OTHER 3999 CCMPONENT CONVERSION 'HEATERS BOILERS SOURCES 4099 PARTICULATES 5.37E+00 2.42E-01 6.50E-02 4199 NOX 5.54E+00 2.78E+00 7.48E-01 4299 SOX 2.63E+01 7.259-03 1.95E-03 4399 HC 1.94E+01 3.63E-01 9.75E-02 1.73E+01 4499 CO 1.21E+03 4.83E-03 1.30E-03 4599 NH3 -4.75E+00 0 .00E +00 O.OOE+00 469-9 OTHER ORGANICS- 1-67E+00 1.21E-01 3.73E-,02 479 BASED ON (2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 4899 100000 BPSD, THE PROCESSING CAPACITY OF THE CATALYTIC CRACK- 4999 ING AND CATALYST REGENERATION IS 50000 BPSD. THE TOTAL PRO- 5099 CESSING CAPACITY OF THE REFINERY IS 306700 BPSD(THAT IS, THE 5199 SUM OF THE CAPACITIES OF THE INDIVIDUAL PROCESSES). THUS,THE 5299 FRACTION OF THE TOTAL PROCESSING CAPACITY ATTRIBUTES TO 5399 THE CAT. CRACKING PROCESS IS 0.16303 AND IS USED TO OBTAIN HC5499 EMISSION FOR OTHER SOURCES AT THE PROCESS LEVEL. 5099 2008 199 CATALYTIC REFORMING 299 BEL FEED EQUIVALENT TO 1.08E12 BTU IS 1900OO(OO05,38 AND FOOT- 399 NOTE 2000) 499 IV-9 FTN. 2009 **WATER POLLUTANTS** 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 150 AND DELTA T IS 699 25F (2006,117/118) 799 ORGANICS INCLUDE OIL AT .05 LB/BBL FEED (2011,11) 899 AND PHENOL AT 0.0007 LB/BBL FEED (2009,A-4/A-5) 999 OTHER DISSOLVED SOLIDS INCLUDE SULFIDES (AS H2S) AT 0.001 LB/ 1099 BBL FEED (2011,11) 1199 COD LOAD IS 0.04 LB/BBL FEED (2011,11) 1299 TDS LOAD IS 0.125 LB/BBL FEED (2011,11) 1399 **AIR POLLUTANTS** 1499 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1599 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND PLANGES, VESSEL 1699 RELIEF VALVES, PUMP AND COMPRESSOR SEALS, AND PROCESS DRAINS. 1799 AIR POLLUTANT EMISSION FACTOR FROM (0002, 1-9, 9-3/9-4). NATURAL 1899 GAS WAS ASSUMED TO BE THE FUEL USED IN THE FUEL USED IN THE BOILERS AND PROCESS 1999 HEATERS. 2099 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 3.32E7 2199 BASED ON (2006,117/118) AND 1031 BTU/SCF (0005,38) 2299 NO STEAM REQUIRED. ELECTRIC AT 4.75 KWH/BBL 2399 WASTEWATER FLOW FOR THE CAT. REFORMING PROCESS IS 6.0 GAL/ 2499 BBL FEED (2011,11) 2599 **AIR EMISSIONS (TONS/YR)** 2699 PROCESS STEAM OTHER 2799 COMPENENT HEATERS BOILERS SOURCES 2899 PARTICULATES 3.32E-01 - - 2999 NOX 3.82E+00 - - 3099 SOX 9.97E-03 - - 3199 HC 4.98E-01 - 1.43E+01 3299 CO 6.65E-03 - - 3399 NH3 0.00E+00 - - 3499 OTHER ORGANICS 1.56E-01 - - 3599 BASED ON (2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 3699 100000 BPSD, THE PROCESSING CAPACITY OF THE CATALYTIC REFORM- 3799 ING PROCESS IS 23000 BPSD. THE TOTAL PROCESSING CAPACITY OF 3899 THE REFINERY IS 306700 BPSD(THAT IS, THE SUM OF THE CAPA- 3999 CITIES OF THE INDIVIDUAL PROCESSES.) THUS, THE FRACTION OF 4099 THE TOTAL PROCESSING CAPACITY ATTRIBUTABLE TO THE CATALYTIC 4199 REFORMER IS 0.07499 AND IS USED TO OBTAIN HC EMISSION FOR 4299 OTHER SOURCES AT THE PROCESS LEVEL. 4399 2009 199 DISTILLATE HYDROTREATING 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 172000(0005,38 AND FOOT- 399 NOTE 2000). 499 **WATER POLLUTANTS** 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 150 AND DELTA T IS 699 25F(2006,164) 799 ORGANICS INCLUDE PHENOL AT 0.0001 LB/BBL FEED 899 (2009,A-4/A-5) 999 OTHER DISSOLVED SOLIDS INCLUDE SULFIDES (AS H2S) AT 0.002 LB/ 1099 BBL FEED AND NITRATES (AS NH3) AT 0.03 LB/BBL FEED (2011,11) 1199 BOD LOAD IS 0.01 LB/BBL FEED (2011,11) 1299 COD LOAD IS 0.05 LB/BBL FEED (2011,11) 1399 TDS LOAD IS 0.035 LB/BBL FEED (2011,11) 1499 **AIR POLLUTANTS** 1599 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1699 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND -LANGES, VESSEL 1799 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1899 AIR POLLUTANT EMISSION FACTORS FROM (0002,1-9,9-3,9-4). NATURAL 1999 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND PROCESS 2099 HEATERS. 2199 SCF FUEL REQUIRED TO PRCESS 1.OE12 BTU FEED IS 1.02OEO6 2299 IV-10 FTN.2010 BASED ON(2006,164) AND 1031 BTU/SCF(CO05,38) 2399 SCF FUEL REQUIRED FOR THE PRODUCTION OF STEAM IS 4.35EO5 2499 BASED ON(2006,164), FUEL EFFICIENCY OF 85P AND 1031.BTU/SCF 2599 (0005,3.8) ELECTRIC AT 0.05 WH/BBL 2699 WASTEWATER FLOW FOR THE DISTILLATE HYDROTHEATER IS 8.0 GAL/ 2799 BBL FEED(2009,A-4/A-5) 2899 AIR EMISSIONS (TONS/YR) 2999 PROCESS STEAM OTHER 3099 COMPONENT HEATERS BOILERS SOURCES 3199 PARTICULATES 1.02E-02 4.35E-03 3299 NOX 1.17E-01 5.OOE-02 3399 sox, 3.06E-04 1.31E-04 3499 HC 1.53E-02 6.53E-03 1.38E+01 3599 CO 2.04-04 6.70E-05 3699 NH3. O.00qE+00 O.OOE+00 3799 OTHER ORGANICS 5.10E-03 2.17E-03 3899 BASED CN(2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 3999 100000 BPSD, THE PROCESSING CAPACITY OF THE DISTILLATE 4099 HYDROTREATER IS 4000C BPSD. THE TOTAL PROCESSING CAPACITY OF 4199 THE REFINERY IS 306700 BPSC(THAT IS, THE SUM OF THE CAPACIT- 4299 IES OF THE INDIVIDUAL PROCESSES). THUS, THE FRACTION OF THE 4399 TOTAL PROCESSING CAPACITY ATTRIBUTABLE TO THE DISTILLATE 4499 HYDROTOTREATER IS 0.13042 AND IS USED TO OBTAIN HC EMISSION FOR4599 OTHER SCURCES AT THE PROCESS LEVEL. 4699 2010 199 DELAYED COKING 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS'159000(0005,38 AND FOOT- 399 NOTE 2000). 499 POLLUTANTS 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 520 AND DELTA T IS 799 ORGANICS INCLUDE OIL AT 0.006 LB/BBL FEED (2011, 899 11) AND EHENOL AT O.0002 LB/BBL FEED(2009,A-4/A-5) 999 COD LOAD IS 0,032 LB/BBL FEED(2011,11) 1099 TDS LOAD IS 0.030 LB/BBL FEED(2011,11) 1199 AIR POLLUTANTS 1299 THE AIR POLLUTANT SOURCES-INCLUDE STEAM BOILERS AND,PROCESS 1399 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES, VESSEL1499 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1599 AIR POLLUTANT EMISSION FACTCRS FROM(0002,1-9,9-3/9-4).NATURAL 1699 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND PROCESS1799 HEATERS. 1899 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 4.85EO7 1999 BASED ON(2005,181) AND 1031 BTU/SCF(0005,38) 2099 SCF FUEL REQUIRED FOR THE PRODUCTION OF STEAM IS 1.11E07 2199 BASED ON(2CO5,181),-FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF 2299 (0005,38). ELECTRIC AT 5 KWH/BBL. 2399 WASTEWATER FLOW FOR THE DELAYED COKER IS 1.0 GAL/BBL FEED 2499 (2011,11) 2599 AIR EMISSIONS (TONS/YR) 2699 PROCESS STEAM OTHER 2799 COMPONENT HEATERS BOILERS SOURCES 2899 PARTICULATES 4.09E-01 .1.11E-01 NOX 4.70E+00 1.27E+00 3099 Sox 1.23E-02 3.33E--03 3199 HC 6.14E-01 1.67E 1.OOE+01 3299 CO 8.17E-03 2.22E-03 3399 NH3 0.00E+00 O.OO0E+00 3499 OTHER ORGANICS 2.04E-01 5.56E-02 3599 BASED ON(2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 3699 100000 EPSD, THE PROCESSING CAPACITY OF THE DELAYED COKER is 3799 IV-11 FTN.2011-2012 10000 BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY IS 3891 306700 BPSD(THAT IS, THE SUM OF THE CAPACITIES OF THE INDI- 3991 VIDUAL PROCESSES) . THUS, THE FRACTICN OF THE TOTAL PROCESSING409-4 0.03261 AND IS 4199 CAPACITY ATTRIBUTABLE TO THE DELAYED COKER IS USED TO OBTAIN HC EMISSION FOR OTHER SOURCES.AT THE PROCESS 4299 LEVEL. 4399 2011 199 DISTIiLLATE HYDROCRACKING 299 BEL FEED EQIVALENT TO 1.OE12 BTU IS 172000(0005,38 AND FOOT- 399 NCT3. 2000) 499 WATER POLLUTANTS 599 THERMAL-GALLONS COOLING WATER/BBL FEED Is 250 AND DELTk T IS 699 40F(2006,146) 799 OTHER DISSOLVED SOLIDS INCLUDE SULFIDES(AS H2S) AT 0.002 LB/ 899 BEL FEED(2011,11) 999 ROD LOAD IS0.002 LB/BBL FEED)(2011,11) 1099 CCD LOAD IS 0.045 LB/BBL FEED(2011,11) 1199 TDS LOAD IS 0.002 LB/BBL FEED(2011,11) 1299 AIR POLLUTANTS 1399 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1499 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES, VESSEL159,9 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1699 AIR POLLUTANT EMISSION FACTORS FROM(0002,1-9,9-3/9-4).NATURAL 179.9 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND PROCESS1899 HEArERS. 1999 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 2.719E07 2099 BASED ON(2006,146) AND 1031 BTU/SCF(0005,38). 2199 NO STEAM REQUIRED(2CC6,146) ELECTRIC AT 10 KWH/B.BL. 2299 wAsrEWATER FLOW FOR THE DISTILLATE HYDROCRACKER IS 5.0 GAL/ 2399 BBL FEED(2009,A-4/A-5) 2499 **AIR EMISSIONS (TONS/YR)** 2599 PROCESS STEAM OTHER 2699 COMPONENT HEATERS BOILERS SOURCES 2799 PARTICULATES 2.72E-01 - 2899 NOX 3.13E+00 - 2999 sox 8.16E-03 - 3099 HC 4.08E-01 - 1.26E+01 3199 cO 5.44E-03 - 329 9 N-3 O.OOE+00 - 3399 OTHER OGANICS 1.36E-01 - 3499 BASED ON(2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 3591) 100000 BPSD., THE PROCESSING CAPACITY OF THE DISTILLATE 369 HYDROCRACKER IS 14000 BPSD. THE TOTAL PROCESSING CAPACITY OF 3 79 4 THE REFINERY IS 306700 BPSD(THAT IS, THE SUM OF THE CAPACIT- 3 IES OF THE INDIVIDUAL PROCESSES). THUS, THE FRACTION OF THE 3 TOTAL PROCESSING CAPACITY ATTRIBUTABLE TO THE HYDROCRACKER 4041 IS 0.04565 AND IS USED TO OBTAIN HC EMISSION FOR OTHER 414 SOURCES AT THE PROCESS LEVEL. 429 2012 199 ISOMERIZATION 299 39 BBL. FEED EQUIVALENT TO 1.OE12 BTU IS 216000(0005.,18 AND FOOT NOTE 200O) 49) **WATER POLLUTANTS** 19 THERMAL-GALLONS COOLING WATER/BBL FEED IS 50 AND DELTA T IS 25F(2006,125) 799 4q899 AIR POLLUTANTS T IHE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 0q999 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES, VESSEL 1098qq RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS- AIR POLLUTANT EMISSION FACTORS FROM (0002, 1-9,9-3/9-4) NATURAL GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND PROCESS 1199 I V-1 2 FTN. 2013 HEATERS. 1499 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 1.067EO7 1599 BASED ON(2006,125) AND 1031 BTU/SCF(0005,38) 1699 SCF FUEL REQUIRED FOR THE PRODUCTION OF STEAM IS 8.76EO6 1799 BASED ON(2006,125),FUEL EFFICIENCY OF 85P kND 1031 BTU/SCF 1899 (0005,38) ELECTRIC AT 1.5 KWH/BBL 1999 AIR EMISSIONS (TONS/YR) ** 2099 PROCESS STEAM OTHER 2199 COMPONENT HEATERS BOILERS SOURCES 2299 PARTICULATES l.C7E-01 8.76E-02 2399 NOX 1.23E+00 1.0E+01 2499 sox 3.20E-03 2.63E-03 2599 HC 1.61E-01 1.31E-01 1.312+01 2699 Co 2.13E-03 1.75E-03 2799 NH3 O.OOE+00 O.OOE+00 2899 OTHER ORGANICS 5.34E-02 4.38E-02 2999 BASED ON(2009,FIG.3),FOR A REFINERY WITH A CAPACITY OF 3099 1000OO EPSD, THE PROCESSING CAPACITY OF THE ISOMERIZATION 3199 UNIT IS 1000 BPSD. THE TOTAL PROCESSING CAPACITY OF THE 3299 REFINERY IS 306700 BPSD(THAT IS, THE SUM OF THE CAPACITIES 3399 OF THE INDIVIDUAL PROCESSES). THUS, THE FRACTION OF THE 3499 TOTAL PROCESSING CAPACITY ATTRIBUTABLE TO THE ISOMERIZATION 3599 UNIT IS 0.003.26 AND IS USED TO OBTAIN HC EMISSION FOR OTHER 3699 SOURCES AT THE PROCESS LEVEL. - 3799 2013 199 H2SO4 ALKYLATION 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 237000(0005,38 AND FOOT- 399 NOTE 200C). ELECTRIC AT 2 KWH/BBL. 499 ** WATER POLLUTANTS ** 1 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 1500 AND DELTA T IS 699 35F(2006,127) 799 ORG NICS INC UDE PHENOL AT 0.0001 LB/BBL FEED 899 (2009,A-4/A-5) 999 OTHER DISSOLVED SOLIDS INCLUDE SULFIDES(AS H2S) AT 0.02 LB/BBL1099 (2009,A-4/A-5) AND NITRATES(AS NH3) AT 0.00 LB/BBL(201,11) 1199 BOD LOAD IS 0.001 LB/BBL FEED(2011,11) 1299 COD LOAD IS 0.01 LB/BBL FEED(2011,11) 1399 IDS LOAD IS 0.30 LB/BBL FEED(2011,11) 1499 ** AIR POLLUTANTS ** 1599 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1699 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES, VESSEL1799 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1899 AIR POLLUTANT EMISSION FACTORS FROM(0002,1-9,9-3/9-4).NATURAL 1999 GAS WAS ASSUMED TO BE THE FUEL USED IN THE HEATERS AND BOILERS2099 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 0(2006,127) 2199 SCF FUEL REQUIRED FOR STEAM PRODUCTION IS 8.25LO7. BASED ON 2299 (2006,127), FUEL EFFICIENCY OF 85P AND 1031 BTU,/SCF(0005,38) 2399 AIR EMISSIONS (TONS/YR) 2499 PROCESS STEAM OTHER 2599 COMPONENT HEATERS BOILERS SOURCES 2699 PARTICULATES - 8.25E-01 2799 NOX - 9.50E+00 2849 sox - 2.48E-03 2999 HC - 1.24E+00 4.99E+01 3099 Co - 1.65E-02 3199 NH3 - O.O8OE+00 3299 OTHER OFGANICS 4. 1 3E-0 1. 3399 WASTEWATER FLOW FOR THE A,LKYLATION UNIT IS 60 GAL/BBL FEED 3499 (2011,11) 3599 BASED ON(2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 3699 100000 BPSD, THE PROCESSING CAPACITY OF THE ALKYLATION UNIT 3799 IV- 131 FTN. 2014-2015 IS 6000 BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY 3899 IS 306700 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS 3999 CAPACITIES). THUS, THE FRACTION OF THE TOTAL PROCESSING CAPA-4099 CITY ATTRIBUTABLE. TO ALKYLATION IS 0.01956 'AND IS USED TO 4199 0BTAIN HC EMIS SION FOR OTHER SOURCES AT THE PROCESS LEVEL. 4299 2014 199 AROMATICS 'EXTRACTION(RECOVERY) 299 BBL FEED EQUIVALENT 'TO 1 . OE 12 BTU IS 2.00000 (0005, 38 A ND FOOT- 399 NOTE 2000) 499 ** WATER POLLUTANTS ** 599 THERMAL-GALLONS COOLING -WATER/BBL FEED IS 1000 AND DELTA T IS 699 25F(2006,185) 799 NO OTHER WATER POLLUTANT INFORMATION AVAILABLE 899 AIR POLLUTANIS 999. THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1099 HEATERS,, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES VESSEL 1199 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1299 AIR POLLUTANT EMISSION FACTORS FROM (0002,9-3/-4) . NO DATA 1399 ON FUEL OR STEAM REQUIREMENTS AVAILABLE. 1499 ** AIR EMISSIONS (TONS/YR) ** 1599 NO BOILER OR HEATER EMISSIONS. EMISSIONS FOR 'OTHER SOURCES 1699 ONLY. ONLY COMPONENT IS HC 1799 HC EMISSIONS - 1.61E+01 1899 WASTEWATER:FLOW IS 8.C GAL/BBL FEED(2009,A-4/A-5) 1999 EASED ON(2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 2099 100000 BPSD, THE PROCESSING CAPACITY OF THE AROMATICS UNIT 2199 OF THE REFINERY 2299 IS 2500 BPSD.. THE TOTAL PROCESSING CAPACITY IS 306700 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS 2399 CAPACITIES). THUS, THE FRACTION OF THE TOTAL PROCESSING 2499 CAPACITY ATTRIBUTABLE TO THE AROMATICS UNIT IS 0.00816 AND IS2599 USED TO OBTAIN HC EMISSION FOR OTHER SOURCES AT THE PROCESS 2699 LEVEL. 2799 .201.5 199 FURFURAL REFINING 299 BEL FEED EQUIVALENT TO 1.OE12 BTU IS 165000(0005,88 AND FOOT- 399 NOTE 2000) 'ELECTRIC AT 1.0 KWH/BBL ( 2 006, 191) 499 ***.WATER POLLUTANTS ** 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 1000 AND 'DELTA T IS 699 25F(2006,191) 799 ORGANICS INCLUDE PHENOL AT .003 LB/BBL (2009,A-4, 899 A-5) 999 **AIR POLLUTANTS ** 1099 THE AIR POLLUTANT. SOURCES INCLUDE STEAM B0ILERS AND PROCESS 1199 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES,VESSEL 1299 RELIEF VALVES,- PUMP AND COMPRESSOR SEALS 'AND PROCESS DRAINS. 1399 .AIR POLLUTANT EMISSION FACTORS FROM (0002,19,9-3/9-4) NATURAL 1499 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND HEATERS1599 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU -FEED IS 4.65EO7. 1699 BASED ON(200,6,191) AND 1031 BTU/SCF(0005,38) 1799 SCF FUEL REQUIRED FOR STEAM BOILERS 'IS 7.65EO6. BASED 'ON 1899 (2006,191), FUEL-EFFICIENCY OF 85P AND 1031 BTU/SCF(0005,38) 1999 ** AIR EMISSIONS (TONS/YR) ** 2099 PROCESS STEAM OTHER 149 COMPONENT HEATERS BO.ILERS SOURCES 2299 PARTICULATES 4.65E-01 7.65E-02 2399 NOX 5.35E+00 8.80E-01 2499 sox 1.39E-02 2.830E-03 2599 HC 6.98E-01 1.15E-01 1.4413E+601 2699 c6 9.289E-02 1.53E-03 2709 N23- O.OOE+00 0.00E+0.0 2899+ OTHER ORGANICS 2.33E-01 3.83E-02 2999 IV-14 FTN. 2016-2017 WASTEWATER FLOW FOR THE FURPURAL UNIT IS 8.0 GAL/BBL FEED 3099 (2009,A-4/A-5) 3199 BASED ON(2009.FIG.3), FOR A REFINERY OF 100000 BPSD CAPACITY 3299 THE PROCESSING CAPACITY OF T_iE FURFURAL REFINING UNIT IS 35003399 BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY IS 3499 306700 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS CAPA- 3599 CITIES). THUS, THE FRACTION OF THE TOTAL PROCESSING CAPACITY 3699 ATTRIBUTABLE TO THE FURFURAL UNIT IS 0.01141 AND IS USED TO 3799 OBTAIN HC EMISSION FOR OTHER SOURCES AT THE PROCESS LEVEL. 3899 2016 199 SOLVENT DEWAXING 299 BBL FEED EQUIVALENT TO I.OE12 BTU IS 365000(0005,38 AND FOOT- 399 NOTE 2000) ELECTRIC AT 12 KWH/BBL(2006,200) 499 WATER POLLUTANTS 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 2300 AND DELTA T IS 699 25F(2006,200) 799 ORGANICS INCLUDE PHENOL AT 0.0015 LB/BBL FEED 899 (2009,A-4/A-5) 999 BOD LOAD IS 0.25 LB/BBL FEED(2009,A-4/A-5) 1099 AIR POLLUTANTS 1199 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1299 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES,VESSEL 1399 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1499 AIR POLLUTANT EMISSION FACTORS FROM(0002,1-9,9-3/9-4).NATURAL 1599 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND HEATERS1699 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 4.73EO7. .1799 BASED ON(2006,200) AND 1031 BTU/SCF(0005,38) 1899 SCF FUEL FEQUIRED FOR STEAM PRODUCTION is-7.65EO6. BASED ON 1999 (2006,200), FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF(0005,38) 2099 AIR EMISSIONS (TONS/YR) ** I .2199 PROCESS STEAM OTHER 2299 COKPONENT HEATERS BOILERS SOURCES 2399 PARTICULATES 4.73E-01 7.65E-02 2499 NOX 5.44E+00 8.80E-01 2599 sox 1.42E-02 2.30E-03 2699 HC 7.10E-01 1.15E-01 1.82E+01 2799 Co 9.46E-03 1.53E-03 2899 NH3 O.OOE+00 O.OOE400 .2999 OTHER OPGANICS 2.36E-01 3.83E-02 3099 WASTEWATER FLOW FOR THE DEWAXING UNIT IS 20 GAL/BBL FEED 3199 (2009,A-4/A-5) 3299 BASED ON(2009,FIG.3), FOR A REFINERY OF 100000 BPSD CAPACI- 3399 TY, THE PROCESSING CAPACITY OF THE SOLVENT DEIAXING UNIT IS, 3499 400C BPSD. THE TOTAL PROCESSING CAPACITY OF TEE REFINERY 3599 IS 30670C BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS 3699 CAPACITIES). THUS, THE FRACTION OF THE TOTAL PROCESSING 3799 CAPACITY ATTRIBUTABLE TO THE DEWAXING UNIT IS 0.01304 AND IS 3899 USED TO OBTAIN HC EMISSION FOR OTHER SOURCES IT THE PROCESS 3999 LEVEL. 4099 2017 199 PROPANE DEASPHAtTIWG 299, BBL OF FEED EQUIVALENT TO 1.OE12 BTU IS 1590COqOO05,38 AND 399 FOOTNOTE 2000) ELECTRIC AT 2.7 KWH/FBL (2006,155). 499 WATER POLLUTANTS 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 1500 AND DELTA T IS 699 25F(2006,195) 799 AIR POLLUTANTS 899 THE AIR rOLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS@ 999 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVEL AND FLANGES,VESS-EL 1099 RELIEF VALVES, PUMP AND-COMPRESSOR SEALS AND PROCESS DRAINS. 1199 AIR POLLUTANT EMISSION FACTORS FROM(0002,1-9,9-3/9-4).NATURAL 1299 IV-15 FTN 2018-2019 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND HEATERS1399 SCF FUEL REQUIRED TO PROCESS 1.OE12 BTU FEED IS 3.33EO7 1499 BASED ON (20,06,19.5) AND 1031 BTU/SCF (0005, 38) 1599 SCF FUEL REQUIRED FOR STEAM PRODUCTION IS 6.75EO7. BASED ON 1.699 (201)6,195),FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF(0005,38) 1799 AIR EMISSlONS (TONS/YR) 1894 PROCESS STEAM OTHER 1999 COMPONENT HEATERS BOILERS SOURCES 2099 FARTICULATES 3.31E-01 6.75E-01 2199 NOX 3.83E+00 7.75E+00 2299 sox 1.OOE-02 2.03E-02 2399 HC 5.OOE-01 1.01E+00 9.62E+00 CO 6.66E-03 1.35E-02 2599 NH3 O.OOE+00 O.OOE+00 2699 OTHER ORGANICS 1.67E-01 3.37E-01 2799 BASED ON(20,09,FIG.3),FOR A REFINERY OF 100000 BPSD CAPACITY, 2899 THE PROCESSING CAPACITY OF THE PROPANE DEASPHALTING UNIT IS 2999 'THE TOTAL PROCESSING CAPACITY OF 3000 BPSD. THE REFINERY IS 3099 3000 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS CAPA- 3199 CITIES).THUS,THE FRACTION OF THE TOTAL PROCESSING CAPACITY, 3299 ATTRIBUTABLE TO THE DEASPHALTING UNIT IS 0.0097 AND IS USED 3399 TO OBTAIN HC EMISSION FOR OTHER SOURCES AT THE PROCESS LEVEL. 3499 2018 199 SOUR GAS TREATING (LP-GAS) 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 249000(0005,38 AND FOOT- 399 NOTE 2000). 499 **WATER POLLUTANTS** 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 15.5 AND DELTA T IS 699 20F(2005,257 AND 3002,4-88) 799 ORGANICS INCLUDE PHENOL AT 0.01 LB/BBL FEED 899 2009.4-4/4-5). 999 BOD LOAD IS 0.05 LB/BBL FEED(2009,A-4/A-5) 1099 AIR POLLUTANTS 1199 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1299 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES,VESSEL 1399 RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1499 AIR POLLUTANT EMISSION FACTORS FROM(O002,1-9,9-3/9-4).NATURAL 1599 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND PROCESS1699 HEATERS. 1799 SCF FUEL REQUIRED FOR STEAM PRODUCTION IS 8.OE05. BASED ON 1899 (2005,257),FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF(0005,38) 1999 NO PROCESS HEATING REQUIRED. ELECTRIC AT 0.33 KWH/BBL 2099 **'AIR EMISSIONS (TONS/YR) 2i99 STEAM PROCESS OTHER 2299 COMPONENT BOILERS. HEATERS SOURCES 2399 PARTICULATES. 8.OOE-03 2499 NOX 9.20E-02 2599 sox 2.40E-04 2699 HC 1.20E-02 4.OOE+01 2799 Co 1.60E-04 2899 NH3 0.00E+oo 2999 OTHER ORGANICS 4.OOE-03 3099 WASTEWATER FLOW IS 4C.GAL/BBL FEED.(2009,A-4/A-5). BASED ON 3199 (2009,FIG.3) FOR A REFINERY WITH.A CAPACITY OF 100000 BPSD,THE32)9 PROCESSING CAPACITY OF THE GAS TREATING UNIT IS 3000 BPSD.THE 3399 TOTAL PROCESSING CAPACITY OF THE REFINERY IS 306700 BPSD(THAT 3499 IS THE SUM OF THE INDIVIDUALPROCESS CAPACITIES).THUS THE 3599 FRACTION ATTRIBUTABLE TO GAS TREATING IS 0.00978 AND IS USED 369 TO-OBTAIN HC EMISSION FOR OTHER SOURCES AT THE PROCESS LEVEL. 37910q). 2019 1490q9 GASOLINE TREATING 2360 IV-16 FTN. 2020-2021 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 200000(0005,38 AND FOOT- 399 NOTE 2000) 499 ** WATER POLLUTANTS 599 THERMAL- NO COOLING WATER REQUIRED(2006,193) 699 ** AIR POLLUTANTS ** 799 NO STEAM OR PROCESS HEATING REQUIRED. ONLY EMISSIONS ARE HC 899 AND PROBABLY SOME ORGANIC DISULFIDES. 999 HC EMISSIONS(TONS/YR) 1.21E+01. EMISSION FACTORS FROM(0002, 1099 9-3/9-4) 1199 BASED ON (2009,FIG.3), FOR A REFINERY WITH A CAPACITY OF 1299 1000 BPSD, THE PROCESSING CAPACITY-OF THE GASOLINE TREATING1399 UNIT IS 42000 BPSD. THE TOTAL PROCESSING CAPACITY OF THE 1499 REFINERY IS 306700 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL 1599 PROCESS CAPACITIES). THUS, THE FRACTION OF THE TOTAL PROCESS1699 ING CAPACITY ATTRIBUTABLE TO GASOLINE TREATING IS 0.13694 AND1799 IS USED TO OBTAIN HC EMISSION FOR OTHER SOURCES AT THE 1899 PROCESS LEVEL. 1999 2020 199 LUBE OIL HYDROTREATING 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 165000(0005,38 AND FOOT- 399 NOTE 200O) 499 ** WATER POLLUTANTS 599 THERMAL-GALLCNS COOLING. WATER/BBL FEED IS 610 AND DELTA T IS 699 25F (2006 l 56). 799 ORGANICS INCLUDE PHENOL AT 0.00001 LB/BBL FEED 899 (2009,A-4/A-5) I 999 OTHER DISSOLVED SOLIDS INCLUDE SULFIDES(AS-H2S) AT 0.002 LB/ 1099 BBL FEED AND NITRATES(AS NH3) AT 0.03 LB/BBL FEED (2011,11) 1199 BCD LOAD IS 0.01 LB/BBL FEED(2011,11) 1299 CCD LOAD IS 0.05 LB/BBL FEED(2011,11) 1399 TDS LOAD IS 0.035 LB/BBL FEED(2011,11) 1499 AIR POLLUTANTS 1599 THE AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS AND PROCESS 1699 HEATERS, BLOWDOWN SYSTEMS, PIPELINE. VALVES AND FLANGES,VESSEL 1799 BELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS. 1899 AIR POLLUTANT EMISSION FACTORS FROM (0002,1-9,9-3/9-4)NATURAL1999 GAS WAS ASSUMED TO BE THE FUEL USED IN THE BOILERS AND HEATERS2099 SCF GAS REQUIRED FOR HEATERS 2.495EO7.BASED ON(2006,156)AND 2199 031 BTU/SCF(0005,38) ELECTRIC AT 2.3 KWH/BBL 2299 SCF GAS REQUIRED FOR STEAM PRODUCTION 1.12EO7. BASED ON(2006,2399 156),FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF(0005,38). 499 WASTEWATER FLOW IS 8.0 GAL/BBL FEED(2009,A-4/A-5) 2599 AIR EMISSIONS (TONS/YR) 2699 PROCESS STEAM OTHER 2799 COMPONENT HEATERS BOILERS SOURCES 2699 PARTICULATES 2.50E-01 1.12E-01 2999 NOX 2.88E+00 1.28E+00 3099 sox 7.85E-03 3.36E-03 3199 HC 3.75E-01 .68E-01 1.33E+01 3299 Co 4.99E-03 2.24E-03 3399 NH3 O.00E+00 0.00E+00 3499 OTHER ORGANICS 1.25E-01 5.60E-02 3599 BASED ON(2009,FIG.3),FOR A REFINERY WITH A CAPACITY OF 100000 3699 BPSD, THE PROCESSING CAPACITY OF THE LUBE OIL HYDROTREATER Is 3799 4O0O BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY IS 32q699 306700 BPSD(THAT 15, THE SUM OF THE INDIVIDUAL PROCESS CAPA- 3999 CITIES).THUS, THE FRACTION OF THE TOTAL PROCESSING CAPACITY 4099 ATTRBUTABLE TO LUBE OIL HYD0RTREATING IS 0.014304 AND IS USED 4199 T0 BTAIN HC EMISSION FOR OTHER SOURCES AND THE PROCESS LEVEL. 4299 2021 199 GREASE MANUFACTURE 299 IV-17 FTN. 2022-2023 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 165000(0005,38 AND FOOT- 399 NCTE 20OO) 499 NO INFORMATION AVAILABLE REGARDING WATER POLLUTANTS. 599 AIR POLLUTANTS 699 CNLY INFORMATION REGARDING HC AIR PCLLUTANTS AVAILABLE FROM 799 (0002,9-3/9-4). HC EMISSIONS ARE 9.94+00 TONS/YR BASED ON 399 THE ALLCCATION PROCEDURE DESCRIBED BELOW. 999 (2009,FIG.3) FOR A REFINERY WITH A CAPACITY.OF BASED ON 1099 1000010 EPSD, THE PROCESSING CAPACITY OF THE GREASE PLANT IS 1199 200 BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY IS 1299 306100 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS. CAPA- 1399 CITIES).THUS,THE FRACTION OF THE TOTAL PROCESSING CAPACITY 1499 ATTRIBUTABLE TO GREASE MANUFACTURE 1S O.0O065 AND ISUSED TO 1599 OB,TAIN HC EMISSION FOR OTHER SOURCES AT THE PROCESS LEVEL. 1699 2022 199 WAX DICILING, MIBK 299 BBL FEED EQUIVALENT TO 1.OE12 BTU IS 181000(O005,8 AND FOOT- 399 NCTE 2000) 499 WATER POLLUTANTS 599 THERMAL-GALLONS COOLING WATER/BBL FEED IS 250C. AND DELTA T IS 699 10F(2006,206) 799 NC OTHER WATER POLLUTANT INFORMATION AVAILAbLE. 899 AIR POLLUTANTS 999 THE, AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS ANr PROCEss 1099 HEATERS, BLOWDOWN SYSTEMS, PIPELINE VALVES AND FLANGES,VESSEL 1199 RFELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS DRAINS.. 1299 AIR POLLUTANT EMISSION FACTORS FROM(O002,1-9,9-3/9-4).NATURAL 1399 GAS WAS ASSUMED TO BE THE FUEL USED IN 'THE BOILERS AND HEATERS 1499 SCF GAS REQUIRED FOR HEATERS 15 5.26E07. BASED ON(2066,206) 1599 AND 1031 BTU/SCF(0005,38) ELECTRIC AT 9 KWH/BBL 1699 SCF GAS REQUIRED FOR BOILERS IS 1.28E07. BASED ON(2006,20b), 1799 FUEL EFFICIENCY OF 85P AND 1031 BTU/SCF (0005,38). 899 QIR EMIS51ONS (TONS/YR) 1999 PROCESS STEAM OTHER 2099 CoMPONENT HEATERS BOILERS, SOURCES 2199 PARTICULATIES 5.26E-01 1.28E-01 229 NOX 6.05E+00 1.47E+00 2399 sox 1.58E-02 3.85E-03 2499 HC 7.91E-01 1.93E-00 1.09E+01 2599 cc 1.05E-02 2.56E-01 2699 NH3 0.00E+00 O.0OE+00 2799 0THER ORGANICS 2.63E-01 6.41E-02 2999 BASED CN (2009,FIG.3) FOR A REFINERY WITH A CAPACITY OF 100000 BPSD, THE PROCESSING CAPACITY OF THE DEOILING UNIT IS 3099 500 BPSD. THE TOTAL PROCESSING CAPACITY OF THE REFINERY IS 3199 306700 BPSD(THAT IS, THE SUM OF THE INDIVIDUAL PROCESS CAPA- 3299 CITIES) . THUS, THE FRACTION OF THE TOTAL PROCESSING CAPACITY 3399 ATTRIBUTABLE TO THE DEOILING UNIT IS 0.00163 AND IS USED TO. 3499 OBTAIN HC EMISSION FOR OTHER SOURCES AT THE PROCESS LEVEL. 3599 2023 199 HYDROGEN MANUFACTURE (STEAM REFORMING) 299 SCF OF NATURAL GAS FEED EQUIVALENT TO 1.OE12 BTU IS 9.69EO8. 399 (0005,36 AND FOOTNOTE 200C) 499 WATER POLLUTANTS 599 THERMAL.-GALLONS COOLING WATER/MSCF H2 IS 650 AND DELTA T IS 699 25f(2005,270) 799 NO OTHER WATER POLLUTANT INFORMATION AVAILABLE. 899 AIR POLLUTANTS 999 THE AIR POLLUTANT SOURCES INCLUDE STEAM REFORMER. AND WASTE 1099 HEAT BOILER, BLOWDOWN SYSTEM, PIPELINE VALVES AND FLANGES, 10199 VESSE L RELIEF VALVES, PUMP AND COMPRESSOR SEALS AND PROCESS 12 99 IV-18 FTN 2024-2025 .DRAINS. AIR POLLUTANT EMISSION FACTORS FROM(0002,1-9,9-3/9-4) 1399 NATURAL GAS WAS ASSUMED TO BE THE FUEL USE IN THE REFORMER 1499 AND BOILER. 1599 SCF FUEL REQUIRED IN REFORMER is 4.947E08. BASED ON (2005, 1699 270) AND 1031 BTU/SCF(0005,38) ELECTRIC AT 0.4 KWH/1000SCF 1799 SCF FUEL REQUIRED IN WASTE HEAT BOILER IS 0.0. BOILER. USES 1899 WASTE GASES FROM REFORMER(2005,270) 1999 AIR EMISSIONS (TONS/YR) 2099 STEAM WASTE HEAT OTHER 2199 COMPONENT REFORMER BOILER SOURCES 2299 PARTICULATES 4.45E+00 2399 NOX 5.67E+01 2499 sox 1.49E-01 2599 HC 9.89E+00 2699 Co 9.89E-02 2799 NH3 O.OOE+00 2899 OTHER ORGANICS 2.48E+00 2999 WITH A NATURAL GAS FEED OF 1.OE12 bTU/YR, THE HYDROGEN PLANT 3099 CAN MAKE l . 83EO9 SCF H2/YR (2005,270). A 100000 BPSD REFINERY3199 USES APPROXIMATELY 100MMSCFD H2. 3299 2024 199 IMPORTED OIL TRNSPORT 299 THE FOLLOWING APPROACH WAS USED IN CALCULATING THE AIR 399 FOLLUTANT ASSOCIATED WITH IMPORTING OIL. 499 1. ALL IMPORED OIL IS TRANSPORTED BY TANKER 599 2. TANKER SIZE IS IN THE 45000 DWT CLASS. BASED ON(2037,10-7). 699 THE TANKER CAPACITY IS 396000 BBLS, SPEED IS 16 KNOTS, 799 UNLOADING CAPACITY IS 20000 BPH, UNLOADING TIME IS 19.8 HRS 899 3. ONE-WAY MILEAGE IS 10000 NAUTICAL MILES,THIS IS BASED ON 999 THE WEIGHTED AVERAGE ROUNDTRIP MILEAGE FOR CRUDE OIL IMPORT1099 (0005,9) 1199 4.EMISSION FACTORS FOR STEAMSHIPS UNDERVAY AND IN-BERTH FROM 1299 2002,3 -11) 1399 5. FUEL OIL FOR POWERING SHIP CONTAINS 1P SULFUR 1499 6. IT WAS ASSUMED THAT ONLY THOSE EMISSIONS ASSOCIATED WITH 501599 MILES OF TRAVEL(10C MILES FOR ROUNDTRIP) WITHIN THE COASTAL1699 WATERS OF THE CONTINENTAL U.S. WOULD HAVE ANY ENVIRONMENTAL1799 IMPACTS. 1899 7. BASED UPON THE UNLOADING TIME OF 19.8 HRS, IT WAS ASSUMED 1999 THAT APPROXIMATELY 48 HRS WERE SPENT IN-BERTH. HOWEVER, 2099 THIS IS FOR UNLOADING 396000 BBL OIL. TO UNLOAD 178000 2199 BBL OIL (EQUIVALENT TO 1.OE12 BTU) APPROXIMATELY 24 HRS 2299 ARE SPENT IN-BERTH 2399 8. IT WAS ASSUMED THAT TWO DIESEL-POWERED TUGBOATS WOULD BE 2499 REQUIRED TO MANEUVER THE TANKER INTO PLACE. IT WAS ALSO. 2599 ASSUMED THAT A TOTAL OF 10 NAUTICAL MILES WOULD BE COVERED 2699 IN A POUNDTRIP OPERATION. EMISSION FACTORS FOR DIESEL SHIPS 2799 (0002,3-11) WERE USED IN COMPUTING AIR POLLUTANTS DUE TO 2899 TUGBOATS. 299 AIR EMISSIONS (TONS/YR) 3099 COASTAL IN-BERTH TUGBOAT 3199 COMPONENT EMISSIONS EMISSIONS EMISSIONS 3299 PARTICULATES 2.OOE-02 7.50E-63 1.OOE-02 399 sox 3.55E-01 1.52E-01 7.50E-03 3499 CO 1.OOE-04 4.OOE-05 6.00E-03 3599 HC 1.O0OE-02 4.50E-03 4.50E-03 3699 NOX 2.30E-01 1.00E-Ol 7.OOE-03 3799 ALDEHYDES 2.OOE-03 1.00E-03 3.50E-04 3899 2025 199 IT WAS ASSUMED THAT THE AIR EMISSIONS FOE SUPERTANKERS(OVER 100000 299 EWT) WERE THE SAME AS THOSE FOR SMALLER-TANKERS 399 IV-19 FTN. 2026-2032 2026 199 FROM(0020,1/8), TANKERS lose APPROXIMATELY 0.11P OF THEIR CARGOES 299 IN DISCHARGES. LEaKS AND SPILLS. THIS IS ASSUMED TO OCCUR 399 WITHIN THE'COASTAL WATERS OF THE U.S. 499 2027 199 FROM (0020, 1/8) , BARGES LOSE APPROXIMATELY 0.028P OF THEIR CARGOES 299 IN DISCHARGES, LEAKS AND SPILLS. 399 2028. 199 THE FOLLOWING APPROACH WAS USED COMPUTING THE EMISSIONS FOR 299 DOMESTIC TRANSPORT OF CRUDE OIL BY BARGE. 399 1. BARGES ARE ASSUMED TO BE IN THE 10000 TON CLASS(CARRYING 499 CAPACITY). THIS IS BASED ON THE MAXIMUM 125 FT BOTTOM WIDTH 599 ALONG THE GULF INTRACOASTAL WATERWAY (2007,11-5) 699 2. ROUNDTRIP MILEAGE is 3000 MILES. THIS IS BASED ON THE 799 AVERAGE ROUNDTRIP DISTANCE BETWEEN PETROLEUM SHIPPING 899 CENTERS AND CITIESON THE MISSISSIPPIAND GULF INTRACOASTAL 999 WATERWAYS. (2007,11-5) 1099 3. FOR SHIPPING 178000 BBL CRUDE OIL(EQUIVALENT TO 1.OE12 STU 1199 AND 27200 TONS), AN INTEGRATED TOWBARGE CONSIST-LNG OF THREE 1299 1OOO TON -BARGES AND TOWBOAT WOULD BE USED. A TOWBARGE OF 1399 THIS SIZE WOULD TYPICALLY HAVE AN OFF-LOADING RATE OF 2000 1499L BPH/BARGE. IT WILL HAVE AN UPSTREAM SPEED OF 6MPH AND A 1599 DOWNSTREAM SPEED OF 12.5 MPH. (2007,011-11) 1699 4. A LOADING RATE OF 5000 BPH IS USED FOR PETROLEUM PRODUCTS. 1759 (2007,11-11) 1899 5. TOWNBARGES ARE DIESEL POWERED 1999 6. APPROXIMATELY THREE HOURS EACH IS ALLOWED FOR, HOOKING UP 2099 AND TAKING DOWN PUMP LINES. 2199 7. ALL OF THE ABOVE RESULT IN A TRAVELLING TIME OF 15.5 DAYS 2299 AND AN IN-BERTH TIME OF 2.7 DAYS. EMISSION FACTORS PROM 2399 (0002,3-11) FOR DIESEL MOTORSHIPS. 24 9 ** AIR EMISSIONS (TONS/YR) ** 2599 UNDER-WAY IN-BERTH 2699 COMPONENT EMISSIONS EMISSIONS 2799 PARTICULATES 3.00E+OO 2.20E-02 2899 SOX 2.25E+00 5.80E-02 2999 CO 1.80E+00 6.20E-02. 3099 BC 1.35E+60 4 . 50EL-0 2 3199 NOX 2. 10E+00 6.80E-02 3299 ALDEHYDES 1.05E-01 4.0OE-03 3399 2029 199 .TRANSPORT OF CRUDE OIL BY TRUCK BASED CN DIESEL POWERED TRACTOR- 299 TRAILER COMBINATION WITH 8500 GAL PAYLOAD. PAYLOAD AT 62P OF 399 GROSS WT.. 150 TON-MI/GAL FUEL CONSUMPTION. ROUNDTRIP DISTANCE 499 OF,500 MILES. EMISSION FACTORS FROM(O002,3-7) 599 2030 199 .BASED ON (0021,31/32) THE AVERAGE FREIGHT TRAIN TRANSPORTS 1791 299 TONS OF CARGO, HAS 70 CARS AND 3 LOCOMOTIVES. TO TRANSPORT 399 178000 BBL/YR CRUDE OIL, APPROXIMATELY 16 TRAIN TRIPS ARE 499 REQUIRED. EMISSIONS BASED ON AN ENERGY REQUIREMENT OF 690 599 BTU/TON-MI(FOOTNOTE 7013),5.83EO6 BTU/BBL(O005,38) AND A 500 699 MILE ROUNDTRIP. EMISSION FACTORS FROM FOOTNOTE 7020. 799 2031 199 BASED ON EMISSIONS FACTORS FOR HEAVY TRUCKS AND BUSES(0002,3-7) 219 AND AN ENERGY REQUIREMENT OF 450 BTU/TON-MI (7012,6). 'PIPE-. 39 9 LIKE MOVEMENT AVERAGES 300 MILES (0010,244). 4,99 2032 199 EMISSIONS FOR PRODUCT TRANS IPORT, ON THE AVERAGE, ARE THE SAME AS 299 THOSE FOR CRUDE OIL. THIS IS BASED ON THE AVERAGE VOLUME OF PRODUCT EQUIVALENT TO 1.8OE12BTU(0005,38). FOR SPECIFIC FRO- 499 DUCTS THE FOLLOWING MULTIPLIERS CAN BE APPLIED TO THE EMIS- 599 IV-20 FTN. 2033-21037 SIONS FOR A PARTICULAR MODE OF TRANSPORTATION. 699 REFINERY PRODUCT EMISSION MULTIPLIER 799 GASOLINE 0.934 899 LPG 0.714 999. KEROSINE 1.009 1099 DISTILLATE FUEL OIL 1.037 1199 RESIDUAL FUEL OIL 1.119 1299 COKE 1.071 1399 ASPHALT 1.181 1499 PETROCHEMICAL FEEDSTOCKS 0.934 1599 TRANSPORT MODE REFERENCE FOOTNOTE 1699 PIPELINE 2031 1799 TANKER 2024,2026 1899 SUPERTANKER 2024,2025,2026, 1999 BARGE 2027,2028 2099 TANK TRUCK 2029 2190 TANK CAR 2030 2299 2033 199 BASED ON 1971 DATA FOR PRODUCTION OF OIL AND GAS(0035,4), 595 299 DISABLING WORK INJURIES, 20235 MAN-DAYS LOST, 13 DEATHS. 399 ALLOCATION TO GAS AND OIL PRODUCTION IS MADE ON THE BASIS OF 499 1971 DATA FOR THE PRODUCTION OF MINERAL ENERGY (0004,20), UN- 599 PROCESSED NATURAL GAS 2.487E16 BTU, CRUDE PETROLEUM 1.956EI6 699 BTU. ON THIS BASIS THE ALLOCATION FRACTION FOR OIL IS 0.44. 799 THE ALLOCATION TO 1.OE12 BTU/YR IS MADE ON THE BASIS OF THE 899 1971 OIL PRODUCTION GIVEN ABOVE. ON THIS BASIS, THE ALLOCA- 999 TION FRACTION IS 5.11E-05. ALLOCATION TO ONSHORE AND OFFSHORE1099 IS MADE ON THE BASIS OF 1963 PRODUCTION OF CRUDE OIL AT 2.75 1199 E9 BBL INCLUDING 1.75E8 BBL FROM OFFSHORE FACILITIES (0010, 1299 53). ON THIS BASIS THE ALLOCATION FRACTIONS ARE 0.065 OFFSHORE1399 AND 0.935 ONSHORE. 1499 2034 199 BASED ON.1971 DATA FOR TRANSPORT OF CRUDE OIL BY PIPELINE, 83 299 DISABLING WORK INJURIES, 2517 MAN-DAYS LOST, 1 DEATH (0035, 399 4). TOTAL CRUDE OIL TRANSPORTED BY PIPELINE IN 1970 IS 5.2�8 499 E09 BBL (0011,561) THE ALLOCATION TO 1.OE12 BTU/YR IS 3.36 599 E-05. 699 2035 199 THE OIL EMITTED TO WATERBODIES FROM OFFSHORE PRODUCTION IS THAT 299 OIL RELEASED BY THE INCOMPLETE SEPARATION OF BRINE AND OIL AT 399 THE WELL AND IS BASED ON A BRINE PRODUCTION OF 2.7 BBL PER 499 BBL CRUDE OIL AND 50 PPM OIL CONTENT IN THE 3RINE (2003,102). 599 THE BRINE ITSELF IS NOT CONSIDERED A POLLUTANT TO THE RECEIV- 699 ING WATERBODY. 799 2036 199 AIR EMISSIONS FROM CRUDE OIL STORAGE TANKS ARE BASED ON EMISSION 299 FACTORS FROM(0002,4-4) . IT IS ASSUMED THAT ALL TANKS ARE OF 399 FIXED ROOF DESIGN. IT IS ALSC ASSUMED THAT CRUDE STORAGE 499 WOULD HAVE 30 DAYS CAPACITY OR 1620C BBL. YEARLY THRUPUT IS 599 178000 BBL (EQUIVALENT TO 1 OE12 BTU) . WATER EMISSIONS BASED ON 699 (2009, TABLE 5). 799 2037 199 AIR EMISSIONS FOR PRODUCT STORAGE TANKS ARE BASED ON EMISSION 299 FACTORS FROM(0002,4-4). IT IS ASSUMED THAT ALL TANKS ARE OF 399 FIXED RCOF DESIGN. IT IS ALSO ASSUMED THAT _DBODUCT TANKS 499 WOULD HOLD 30 DAYS PRODUCTION OR 16636 BBL. YEARLY THRUPUT IS 599 183000 BBL,BASED ON AVERAGE HEAT CONTENT OF PETROLEUM 699 PRODUCTS (0005, 38) WATER E.MISSIONS BASED ON (2009 TABLE 5) 799 IV-21 FTN. 2038-2047 2038 199 AIR EMISSIONS RESULTING FROM FILLING LOSSES FROM LOADING UNDER- 299 GROUND STORAGE TANKS AT SERVICE STATIONS ONLY ARE CONSIDERED 34 HERE. BASED ON(0005,38) THE BBL/YR OF GASOLINE EQUIVALENT To 499 1.0E12 BTU/YR IS 190500. AIR-EMISSION FACTORS FROM(0002,04-5) 599 ASSUMING 50P SPLASH FILL AND 50P SUBMERGED FILL. 699 2039 199 AIR EMISSIONS RESULTING FROM SPILLAGE AND FILLING LOSSES IN FIL- 299 LING AUTOMOBILE GAS TANKS AT SERVICE STATIONS ONLY ARE CONSID- 399 FEED HERE. BASED ON (0005,38) THE BBL/YR OF GASOLINE EQUIVA- 499 LENT TO 1.OE12 BTU/YR IS 190500. AIR EMISSION FACTORS FROM 599 (0002, 4 -5) 699 199 2040 BASED ON(2012,56/57), A-100000 BPSD REFINERY WILL HAVE A LAND 294 REQUIREMENT OF 1900 ACRES WITH 220 ACRES OCCUPIED BY PROCESS 399 EQUIPMENT AND 390 ACRES AS A BUFFER ZCNE. 178000 BBL/YR 499 (EQUIVALENT TO 1.0E12 BTU/YR) IS EQUAL To 540 BPSD. IMPACT 599 GIVEN IS A RESULT OF A STRAIGHT RATIO. 699 2041 199 TOTAL CRUDE 0IL SUPPLIED TO REFINERIES IN 1971 WAS 4.08EO9 BBL, 299 BASED ON(0005,14). ALLOCATION FACTOR FOR 1.OE12 BTU/YR IS 399 4.35E-05, USING 178000 BBL/YR EQUIVALENT TO 1.OE12 BTU/YR. 499 FOR 1971 THERE WERE 831 DISABLING INJURIES AND 10 DEATHS IN 599 THE REFINING INDUSTRY (0035,4) . TOTAL MANDAYS LOST WERE 47170. 699 2042 199 TOTAL PRODUCTS MOVED BY PIPELINE IN 1971 WAS 4.58EO9 BBL(0005,29) 299 ALLOCATICN FACTOR FOR 1.OE12 BTU/YR,EQUIVALENT TO 1830CO BBL/ 399 YR,BASED ON AVERAGE HEAT CONTENT OF PETROLEUM PRODUCTS (0005, 499 38) IS 6.9E-05. FOR 1971 THERE WERE 62 DISABLING WORK INJURIES 599 AND ONE DEATH IN THE PRODUCTS PIPELINE INDUSTRY (0035,5). 649 TOTAL MAN DAYS LOST WERE 1455. 799 2043 199 BASED ON(2004,49) THE CAPITAL COST OF A 100000 BPSD ELECTROSTATIC 299 DESASTER IS 741000 DOLLARS AND ITS OPERATING COST IS 0.595 39.9 CENTS/BBL. BASED ON(2004,32,40,44) THE CAP*ITAl COST OF A l.OE5 499 BPSD ATMOSPHERIC AND 2-STAGE VACUUM FRACTIONATION UNIT IS 599 15.97EO6 DOLIARS AND ITS OPERATING COST IS 24.95 CENTS/BBL. 699 FIXED CHARGE RATE IS 10P.1972 DOLLARS.BPSD EQUIVALENT TO 1.0 799 E 12 BTU/YR IS 540. 899 2044 199 BASED ON(2004,94) THE CAPITAL COST OF A 50000 BPSD DISTILLATE 299 HYDROTREATER IS 3.2EO6 DOLLARS AND ITS OPERATING COST IS 24.3 399 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS.. BPSD EQUIV- 499 ALNT To 1.OE12 BTU/YR IS 521. 599 2045 199 BASED ON(2004,84)THE CAPITAL COST OF A 50000 BPSD CATALYTIC 299 CRACKING UNIT IS 11.75EO6 DOLLARS AND ITS OPERATING COST IS 399 40.8 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSD 499 EQUIVALENT TO 1.OE12 BTU/YR IS 534. 599 '20 4 6 199 BASED ON (2004, 71) THE CAPITAL COST OF A 23000 BPSD CATALYTIC RE- 299 FORMR IS 8.05EO6 DOLLARS AND ITS OPERATING COST IS 68.7 CENTS 399 PER -BL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSD EQUIVA- 499 LENT TO 1.OE12 BTU/YR IS 576. 599 2047 199 BASED ON(2004,65) THE CAPITAL COST OF A 10000 BPSD DELAYED COKER 499 IS 8.0OE06 DOLLARS AND ITS OPERATING COST IS 53.5 CENTS/BBL. 399 FIXED CHARGE RATE 10P. 1972 DOLLARS. BPSD EQUIVALENT TO 1.0 499 E12 BTU/YR IS 482. 599 IV-22 FTN. 2048-2059 2048 199 BASED ON(2004,190) THE CAPITAL COST OF A 14000 BPSD DISTILLATE 299 HYDROCRACKER IS 7.21EO6 DOLLARS AND ITS OPERATING COST IS 399. 125.2 CENTS/BBL. FIXED CHARG--' RATE IS 10P. 1972 DOLLARS. BPSD 499 EQUIVALENT TO 1.OE12 BTU/YR IS 521. 599 2049 199 BASED ON(2006,126) THE CAPITAL COST OF A 1000 BPSD ISOMERATION 299 UNIT IS 0.585EG6 DOLLARS AND ITS OPERATING COST IS 62.1 CElfTS/ 399 BEL. FIXED CHARGE RATE IS 10P. 1972 COLLARS. 'BPSD EQUIVALENT 499 TO 1.OE12 BTU/YR IS 655. 599 2050 199 BASED ON(2004,89) THE CAPITAL COST OF A 6000 BPSD H2SO4 ALKYLATION 299 UNIT IS 1.65EO6 DOLLARS AND ITS OPERATING COST IS 125.3 CENTS/ 399 BEL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSD EQUIVALENT 499 TO 1.OE12 BTU/YR IS 718. 599 2051 199 BASED ON(2004,91) THE CAPITAL COST OF A 3000 BPSD PROPANE DEAS- 299 PHALTING PLANT IS 1.05EO6 DOLLARS AND ITS OPERATING COST IS 399 34.7 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS..BPSD 499, EQUIVALENT TO 1.OE12 BTU/YR IS 482. 599 .2052 199 BASED ON (2010, 176/182) THE CAPITAL COST CF A 100MBSCFD HYDROGEN 299 PLANT IS 13.3EO6 DOLLARS AND ITS OPERATING COST IS 18.25 CENTS 399 PER MSCF H2. FIXED CHARGE .RAT IS 10P. 1972 DOLLARS. SCFD 499 ..H2 RESULIING FROM 1.OE12 BT@/@*`YR NATURAL GAS FEED Is 5.55EO6. 599 2053 199 BASED CN(2004,122) THE CAPITAL COST.OF A 3500 BPSD FURFURAL REFIN- 299 ING UNIT IS 3.OE06 DOLLARS AND ITS OPERATING COST IS 59.6 399 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSP EQUI- 499 VALENT TO 1.OE12 BTU/YR IS 500. 599 2054 199 BASED ON(2004,132) THE CAPITAL COST OF A 4000 BPSD SOLVENT DEWAX- 299 ING UNIT IS 7.68EO6 DOLLARS AND ITS OPERATING-COST IS 96.6 399 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972DOLLARS. BPSD EQUI- 499 VALENT TO 1.OE12 BTU/YR IS 500. 599 2055 199 BASED ON(2004,115) THE CAPITAL COST OF A 42000 BPSD GASOLINE 299 TREATING UNIT IS 2.97EO6 DOLLARS AND ITS OPERATING COST IS 399 4.25 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSD 499 EQUIVALENT TO 1.OE12 BTU/YR IS 606. 599 2056 199. BASED ON(3000,2-52) THE CAPITAL COST OF A 3000 BPSD SOUR GAS 299 TREATING UNIT IS 0.403EO6 DOLLARS AND ITS OPERATING COST IS 399 99760 DOLLARS/YR. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSD 499 EQUIVALENT TO 1.OE12 BTU/YR (BASED ON LPG).IS 755. .599 2057 199 BASED ON(2006,153,156,164,165,167,168,169,180) THE CAPITAL COSTr OF 299 A 4000 BPSD IUBE HYDROTREATER IS 0.94EO6 DOLLARS. BASED ON 399 (2004,152) THE OPERAT .ING COST IS 29.4 CENTS/BBL. FIXED CHARGE 499 RATE IS 10P. 1972 DOLLARS. BPSD EQUIVALENT TO 1.0E12 BTU/YR IS 599 500. 699 2058 199 BASED ON(2004,199) THE CAPITAL COST 07 A 2500 BPSD AROMATICS EX- 299 TFACTION UNIT IS 12.4EO6 DOLLARS AND ITS OPERATING COST IS 399 163.1 CENTS/BBL. FIXED CHARGE RATE IS 10P. 1972 DOLLARS. BPSD 499 EQUIVALENT TO 1.OE12 BTU/YR IS 606. 599 2059 199 BASED ON(2006,206) THE CAPITAL COST OF A .500 BPSD WAX DEOILING 299 UNIT IS 0.615EO6 DOLLARS. BASED ON (20,04,157) THE OPERATING 399 COST IS 110.5 CENTS/BBL. FIXED CHARGE RATE IS ICP. 1972 DOL- .499 LARS. BPSD EQUIVALENT TO 1.OE12 BTU/YR IS 550. .''.599 IV-23 FTN. 2060-2066 2060 199 LAND IMPACT FOR PIPELINE TRANSPORT OF REFINED PRODUCTS IS BASED ON 299 1971 TOTAL PRODUCT LINE MILEAGE OF 72406(2001,2) AND TOTAL 399 PRODUCTS TRANSPORTED BY PIPELINE IN 1971 OF 2.658EO9 BBL(0005, 499 29) ASSUMING AN AV PIPELINE RIGHT-OF-WAY OF 62. 5 FT (20,02, 14) 599 ABOUT 37.9 ACRES ARE AFFECTED. 699 20,61 199 -BASED ON 40.5 ONSHORE OR 2.36 OFFSHORE OIL WELLS FOR PRODUCTION 07 299 OIL EQUIVALENT TO l.0E12 BTU/YR (SEE FOOTNOTE 2001) IN 1970 A 399 TOTAL OF 12547 OIL WELL WERE BROUGHT INTO PRODUCTION AT A COST 499 OF' 1 .088EO9 DOLLARS INCLUDING .533 OFFSHORE WELLS AT A COST -OF 599 2.82-E08 DOLLARS(0004,45). ON THIS BASIS THE AVERAGE COST/WELL 699 IS 6.73E04 DOLLARS FOR ONSHORE AND 5.30EO5 FOR OFFSHORE. 799 IF OIL PRODUCTION FROM WELLS PRODUCING BOTH OIl, AND GAS,THEN 899 THE COST/WELL ATTRIBUTABLE TO OIL is 5.21E4 DOLLARS ONSHORE 999 AND 4.1EO5 DOLLARS OFFSHORE, BASED ON ALLOCATION FACTORS FROM 1099 FOOTNOTE 2001. FIXED CHARGE RATE IS 10 P. 1199 2062 199 BASED ON 183000 BBL/YR PRODUCT(0005,38) AND FOOTNOTE 2003. 299 2063 199 BASED ON 183000 BBL/YR PRODUCT(0005,38) AND FOOTNOTE 2026. 299 2064 199 BASED OF 183000 BBL/YR PRODUCT(0005,38) AND FOOTNOTE 2027. 299 26q065 199 INCLUDES ONLY HYDROCARBON EMISSIONS. NO OTHER EMISSION DATA AVAIL- 299 ABLE. 399 2066 199 NATIONAL AVERAGE REFINERY POLLUTANTS 299 WATER EMISSIONS 399 BASED ON(2013,VII-7), AVERAGE STANDARD RAW WASTE LOAD FOR 499 REFINERY EFFLUENTS AFTER THE API SEPARATOR A-BE 599 BOD 265000 LB/DAY 699 COD 773000 LB/DAY 799 ORGANICS INCLUDING 899 OIL 21600 LB/DAY 999 PHENOL 14000 LB/DAY 1099 TOTAL SUSPENDED 'SOLIDS 852000 LB/DAY 1199 OTHER DISSOLVED SOLIDS INCLUDING 1299 SULFIDES 17000 LB/DAY 1399 AMMONIA 38000 LB/DAY 1499 TOTAL CHRO.MIUM 400 LB/DAY 1599 THE LOADS ABOVE ARE BASED ON REFINERY TH OUGHTPUT OF 3.41EO6 1699 BPSD. TO OBTAIN LOADINGS FOR A REFINERY PROCESSING 1.OE12 1799 BTU/YR(EQUIVALENT TO 178000 BBL/YR) MULTIPLY THE LOADINGS 1895 GIVEN ABOVE 'BY 2.61E-05. THE. RESULTIS IN TONS/YR. 1991 THERMAL PPOLLUTION(TDS FOUND IN SIMILAR MANNER) 2095 TO OBTAIN THE TOTAL NATIONAL AVERAGE REFINERY THERMAL POLL- 2199 'HE THERMAL POLLUTION PROCESS 'IS MULTIPLIED 2299 UTION., T FOR EACH BY THE RATIO OF BBL OF CRUDE/YR EQUIVALENT TO 1.OE12 BTU/YR 2395 DIVIDED BY BBL OF FEED/YR TO THE PROCESS EQUIVALENT TO 1.OE 2499 12 BTU/YR AS GIVEN IN FOOTNOTES 2005 THROUGH 2023. THIS 2599 RESULT IS THEN MULTIPLIED BY THE RATIO OF THE PROCESS CAPA- 299 CITY DIVIDED BY THE REFINERY CRUDE INPUT FOR THE TYPICAL BE- 2799 TINERY IN (2009,FIG.3). THESE RESULTS ARE SUMMED TO OBTAIN 2899 THE THERMAL POLLUTION ON THE REFINERY LEVEL. 2999 AIR EMISSIONS 3099 AIR POLLUTANTS RESULT FROM THE COMBUSTION OF FUELS IN THE 81196qS REFINERY, FROM THE CATALYTIC CONVERSI0N OF CRUDE OIL TO GASO- 32292q9 LINES, FROM STORAGE TANKS AND MANY OTHER SOURCES. 3399 FR0m (0005,21) THE FOLLOWING FUELS WERE CONSUMED IN U.S. RE- 4346145 FINERIES IN 1971,BASED ON 4.088E2O9 BBLS OF CRUDE PROCESSED 3459 IV-24 FTN. 2066 (Cont) (1) FUEL OIL 3.81EO7 BBLS 3699 (2) NATURAL GAS 1.063EI2 SCF 3799 (3) REFINERY GAS 1.013E12 S-F 3899 (4) PETROLEUM COKE 1.044EO7 SHORT TONS 3999. (5) LPG 6. 85EO6 @FBLS 4099 (6) COAL 4.05EO5 SHORT TONS 4199 EMISSIONS ARE BASED ONLY ON THE FIRST FOUR FUELS AS THEY 4299 COMPRISE 98.7P OF THE TOTAL FUELS ENERGY INPUT TO THE HEFIN- 4399 EFIES. 4499 HYDROCARBON EMISSIONS FROM STORAGE TANKS-ASSUMING THE USE OF 4599 FIXED ROOF TANKS ONLY AND 30 DAYS STORAGE OF CRUDE AND PRO- 4699 DUCTS, THE TOTAL HC EMISSION ATTRIBUTABLE TO THE REFINERY 4799 IS 160.5 TONS/YR,FROM FOOTNOTES 2036 AND 2037. 4899 HYDROCARBON EMISSIONS FROM PROCESS DRAINS- TOTAL WASTEWATER 4999 FLOW FOR A REFINERY PROCESSING 178000 BBL/YR IS 9.078EO6 GAL 5099 PER YEAR(2009,2011). AIR POLLUTANT EMISSION FACTOR FROM(0002,5199 9-4). TOTAL HC EMISSION ATTRIBUTABLE TO THE REFINERY IS 22.7 5299 TONS/YR. 5399 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS-BASED ON AIR 5499 POLLUTA@T EMISSION FACTOR PROM(0002,9-3) AND REFINERY CAPA- 5599 CITY OF 178000 BBLS/YR. TOTAL HC EMISSION ATTRIBUTABLE TO 5699 THE REFINERY IS 26.7 TONS/YR 5799 HYDROCARBON EMISSIONS FROM MISCELLANEOUS SOURCES-MISCELLANEOUS5899 SOURCES INCLUDE PIPELINE VALVES AND FLANGES,VESSEL RELIEF 5999 VALVES, PUMP AND COMPRESM'@ SEALS,AIR BLOWING,SAMPLING,ETC. 6099 AI'R POLLUTANT EMISSION FACTORS FROK(0002,9-4) AND REFINERY 6199 CAPACITY OF 178000 BBLS/YR. TOTAL HC EMISSION ATTRIBUTABLE 6299 TO THE REFINERY IS 6.32 TONS/YR 6399 HYDROCARBON EMISSIONS FROM VACUUM JETS-APPROXIMATELY 40P OF 6499 THE FEED TO THE ATMOSPHERIC/VACUUM DISTILLATION PROCESS IS 6599 SUBJECTED TO VACUUM DISTILLATION. FOR A REFINERY PROCESSING 6699 178000 BBL/YR, THIS AMOUNTS To 71200 BBL/YR. AIR POLLUTANT 6799 EMISSION FACTORS FROM(0002.9-4). TOTAL HC EMISSION ATTRIBUT- 6899 ABLE TO THE REFINERY IS 4.63 TONS/Yb 6999 AIR EMISSIONS FROM CATALYTIC CRACKER AND CATALYST REGENERATOR 7099 THE EMISSIONS FOR THE CAT CRACKING OPERATION ARE GIVEN IN 7199 FOOTNOTE 2007 FOR A FEED OF 176000 BBLS/YR (EQUIVALENT TO 1.07299 E12 BTU/YR). TO OBTAIN THE AIR EMISSIONS ATTRIBUTABLE TO A 7399 PEFINERY PROCESSING 178000 BBLS/YR, MULTIPLY THE PROCESS 7499 EMISSIONS BY 0.505. THESE ZMISSIONS.ARE PARTICULATES AT 2.71 7599 TPY,SOX AT 13.3 TPY, CO AT 611.0 TPY, HC AT 9.78 TPY, NOX AT 7699 2.80 TPY, ALDEHYDES AND OTHERS AT 3.245 TPY. 7799 AIR EMISSIONS FROM FUELS COMBUSTION7THE FOLLCLIING QUANTITIES 7899 OF FUELS ARE REQUIRED FOR A 178000 BBL/YR REFINERY BASED ON 7999 THE 1971 DISTRIBUTION- FUEL OIL AT 1.5P SULFUR-1660 BBLS, 8099 NATURAL GAS-4.64EO7 SCF, REFINERY GAS-4.41EO7 SCF AND PETRO- 8199 LEUM COKE AT 1.8P SULFUR AND 1.4P ASH -4.55EO2 SH.TONS. AIR 8299 POLLUTANT EMISSION FACTORS FROM(0002,1-3,1-7,1-9). PETROLEUK 8399 COKE ASSUMED TO BE SIMILAR TO BITUMINOUS COAL. REFINERY GAS 8499 ASSUMED TO BE SIMILAR TO N ATURAL GAS EXCEPT ?OR SULFUR. THE 8599 REFINERY GAS IS ASSUMED TO CONTAIN 48.8P OF !HE TOTAL SULFUR 8699 IN THE CRUDE LISTED AS UNACCOUNTED FOR, RECOVERED IN AND 8799 EMITTED BY CLAUS PLANTS(2024,2025).TH,E UNCONTROLLED REFINERY 8899 DOES NOT CONTAIN A CLAUS PLANT. AVERAGE SULFUR CONTENT OF 8999 CRUDE FROM FOOTNOTE 2000. 9099 ,IV-25. FTN. 2067-2071 FUEL NATURAL REFINERY PETROLEUM 9199 COMPONENT OIL GAS GAS COKE 9299 PARTICULATES 8.01E-0l 4.17E-01 3.97E-01 4.77E+00 9399 sox 8.30E+00 1.39E-02 2.03E+02 1.56E+01 9499 CO 7.OOE-03 9.36E-03 8.93E03 2.21E-01 9599 HC 1.05E-01 9.26E-01 8.82E-01 6.84E02 9699 NOX 2.77E+00 5.32E+00 5.07E+00 6.82E+00 9799 ALDEHYDFS,ETC. 3.45E-02 2.31E-01 2.21E-01 1.14E03 9899 EMISSIONS GIVEN ABOVE ARE IN TONS/YEAR 9999 2067 199 TRUCK TRANSPORT OF CRUDE OIL 299 BASED ON THE, 1968 VOLUME OF INTERCITY HIGHWAY FREIGHT TRAFFIC 399 'a OF 3.963Ell TMI(0O10,267) AND THE 1968 SHIPMENT OF CRUDE OIL 49 BY TRUCK OF 4.09EO7 TONS(0010,272). DISTANCE FOR LADEN TRIP IS 599 ASSUMED TO BE 250 MILES, GIVING 1.02E10 TMI OF CRUDE OR 2.6P 699 OF THE TOTAL 1968 VOLUME. THE UNIT OF 1.OE12 BTU/YR IS 0.065P 799 OF 'CRUDE OIL SHIPMENTS. THE PRODUCT OF THESE TWO FRACTIONS AND 899 THE HIGHWAY RIGHT-OF-WAY AREA IN THE 48 STATES, 2.1E07 AC(SEE 199 FOOTNOTE 7026) GIVES 352 AC-YR/1.OE12 BTU. 1099 2068 199 TRUCK TRANSPORT OF PETROLEUM PRODUCTS 299 BASED ON THE 1968 VOLUME OF INTERCITY HIGHWAY FREIGHT TRAFFIC 399 OF 3.963E11 TMI(0010,267) AND THE 1968 SHIPMENT OF PETROLEUM 499 PRODUCTS BY TRUCK OF 4.088EO8 TONS(0010,272). DISTANCE FOR 599 LADEN TRIP-IS ASSUMED TO BE 250 MILES. GIVING 1.022E11 TMI OF 699 PRODUCT OR 25.8P OF THE TOTAL 1968 VOLUME. THE UNIT OF 1.OE12 799 BTU/(R IS 0.0067P OF THE PRODUCT SHIPMENTS. THE PRODUCT OF 899 THE TWO FRACTIONS AND THE HIGHWAY RIGHT-OF-WAY AREA IN'THE 48 999 STATES, 2.1E07 AC(SEE FOOTNOTE 7026) GIVES 363 AC-YR/1.OE12 1099 BTU. 1199 2069 199 RAILROAD TRANSPORT OF PETROLEUM PRODUCTS 299 BASED ON THE 1968 VOLUME OF INTERCITY RAILROAD FREIGHT TRAFFIC 399 PRODUCTS BY RAILROAD OF 2.518EO7 TONS(0010,272). DISTANCE FOB 599 OF 7.568E11 TMI(0010,267) AND THE 1968 SHIPMENT OF PETROLEUM 499 LADEN TRIP IS ASSUMED TO BE 250 MILES, GIVING 6.295EO9 TMI OF 699 PRODUCT OR 0.832P OF THE TOTAL 1966 VOLUME. THE UNIT OF 1.OE12 799 BTU/YR IS 0.108P OF THE PRODUCT SHIPMENTS. BASED ON 365000 MI 899 OF TRACK(0011,556) AND A RIGHT-OF-WAY OF 50 FT.(2014,19-6),THE 999 RAIIROAD RIGHT-OF-WAY AREA IS 2.21E06 AC. THE PRODUCT OF THE 1099 TWO FRACTIONS AND THE RIGHT-OF-WAY GIVES 19.9 AC-YR/1.OE12 BTU1 199 2070 RAILROAD TRANSPORT OF CRUDE OIL 299 199 BASED ON THE 1968 VOLUME OF INTERCITY RAILROAD FREIGHT TRAFFIC 399 OF 1.568Ell TMI AND THE 1968 SHIPMENT 0F CRUDE OIL BY RAILROAD 499 OF 1.066BE06 TONS.. DISTANCE FOR LADEN TRIPS ASSUMED TO BE 599 250 MI, GIVING 2.667E08 TMI CRUDE OIL OR 0.0352p OF THE TOTAL 699 196E VOLUME. THE UNIT OF 1.OE12 BTU/YR IS 2.56P OF CRUDE OIL 799 SHIPMENTS. THE PRODUCT OF THESE TWO FRACTIONS AND THE RAILROAD 6 99 RIGHT-OF-WAY AREA OF 2.21EO6 AC(SEE FOOTNOTE 2069) GIVES 19'.8 999 AC-YR/1.OE12 BTU. 1099 2071 199 THE LAND AREA REQUIRED FOR A STORAGE TERMINAL HANDLING 2.2EO9 299 BBL/YR IS 2.000 AC. (2042) CRUDE OIL EQUIVALENT TO I.OE12 BTU/ 399 YR IS 178000 BBL/YR. PRODUCT OIL EQUIVAENT TO 1.00E12 BTU/YR - 499 IS 183000 BBL/YR. DOCKING FACILITIES AREA IS CONSIDERED NEGLI- 599 GIBLE IN COMPARISON TO THE TANK FARM. 699 IV-26 FTN. 2072-2083 2072 199 BASED ON OPERATING REVENUES OF $6.7EO8 AND 5.3E09 BBLS CRUDE OIL 299 TRANSPORTED. 178000 BBL/YR EQUIVALENT TO 1.OE12 BTU/YR 399 2073 199 BASED PM OPERATING REVENUES OF $5.8E08 AND 2.9609 BBI PRODUCT 299 OILS TRANSPORTED. 183000 BBL/YR EQUIVALENT TO 1.OE12 BTU/YR 399 2074 199 BASED ON (2007,11-13) ESCALATED TO 1972 AND A LADEN TRIP OF 1500 299 MI (SEE FOOTNOTE 2028). CRUDE OIL TONNAGE IS 26600 AND PRODUCT 399 TONNAGE IS 27300. 499 2075 199 BASED ON AN AVERAGE RATE OF 0.8 CENTS/GAL (2016,134/135). RATE IN- 299 CLUDES FIXED AND OPERATING COST. 399 2076 199 BASED ON (0021,31/32)THE AVERAGE FREIGHT RATE FOR 1970 IS 1.45 299 CENTS/TON-MI. LADEN TRILP MILEAGE IS 250 (SEE FOOTNOTE 2030). 399 2077 199 BASED ON (2017,46,47), THE NEW 1972 BASE RATE FROM RAS TANURA TO 299 U.S. EAST COAST IS $1.37/BBL LADEN VOYAGE VOYAGE IS 10,000 MILES (SEE 399 FOOTNOTE 2024). 499 2078 199 PRIMARY EFFICIENCY IS DEFINED AS 1 MINUS THE FRACTION OF THE PRI- 299 MARY FUEL INPUT ATTRIBUTABLE TO PHYSICAL LOSSES MINUS THE 399 FRACTION OF THE PRIMARY FUEL INPUT USED IN THE PROCESS AS FUEL 499 AND/OR STEAM. BY EQUATION, THE PRIMARY EFFICIENCY 599 EQUALS (1-(Y/1.OE12)-(Z/1.OE12) X 100P, WHERE Z IS THE 699 BTU OF PHYSICAL LOSSES AND Y IS THE BTU OF INPUT FEED USED 799 AS FUEL AND/OR STEAM. IT WAS ASSUMED IN FOOTNOTES 899 2005 THROUGH 2023 THAT ALL OF THE REFINERY PROCESSES 999 WOULD USE NATURAL GAS AS THE PRIMARY FUEL THUS Y EQUALS O AND 1099 THE PRIMARY EFFICIENCY APPROACHES 1 EXCEPT FOR PHYSICAL LOSSES 1199 SUCH AS THOSE DUE TO EVAPORATION AND WASTEWATER CONTAMINANTS. 1299 THIS PROCEDURE RESULTS IN A HIGH ANCILLARY FUEL REQUIREMENT. 1399 IT CAN BE SHOWN THAT THE OVERALL PROCESS EFFICIENCY WILL BE 1499 THE SAME AS THAT IF Y WERE LARGE AND THE ANCILLARY DEMAND LOW. 1599 ALL EFFICIENCES ARE ON A BTU BASIS. IT WAS FURTHER ASSUMED 1699 THAT OIL LOST TO WASTEWATER WOULD HAVE THE SAME HEAT CONTENT 1799 AS CRUDE OIL AND THAT HYDROCARBON LOSSES TO THE ATMOSPHERE WOULD HAVE A HEATING VALVE OF 200 BTU/LB. 2079 199 BASED ON FEED AND FUEL REQUIREMENTS FROM FOOTNOTE 2023. 299 2080 199 BASED ON DATA FROM (0040,TABLES 0-1/0-6) 299 2081 199 BASED ON (0012,71) 0.006P VOL. IS LOST IN LEAKAGE. THUS PRIMARY 299 EFFICIENCY IS 99.994P. 399 FROM FOOTNOTE 2031, PIPELINE ENERGY IS 450 BTU/TON-MI, AVERAGE 499 PIPELINE MOVEMENT IS 300 MILES. TON/YR OF CRUDE AND PRODUCT 599 ARE 26600 AND 27300 (FROM FOOTNOTE 2074). 699 2082 199 BASED ON (0020,1/8) TANKERS LOSE APPROXIMATELY 0.11P OF THEIR 299 CARGOES IN DISCHARGES, LEAKS AND SPILLS. THUS, PE IS 99.89P 399 FROM (7012,13) TANKER ENERGY IS 930 TMI/GAL, AVERAGE LADEN TRIP 499 IS 10,000 MI 599 2083 199 BASED ON (0020,1/8) BARGES LOSE 0.028P OF THEIR CARGOES IN LEAKS 299 AND SPILLS. THUS, PE. 99.972P FROM (7012,13) BARGE ENERGY 399 IS 220 TMI/GAL, AVERAGE LADEN TRIP IS 1500 MI. 499 IV-27 FTN. 2084-2093 2084 199 BASED ON CAPITAL COST OF THE INDIVIDUAL PROCESSES AND THEIR ALLO- 299 CATION FACTORS. ALSO INCLUDES 43P ADDITIONAL COST FOR OFFSITE 399 FACITITIES (2004,121) FIXED CHARGE RATE IS 10P . 1972 DOLLARS, 499 BPSD EQUIVALENT TO 1.CE12 BTU/YR IS 540. 59.0 TOTAL CAPITAL COST FOP A 100000 BPSD REFINERY IS 1.423E'08 699 LOLLARS 799 OPERATING COST FOUND IN SIMILAR MANNER. 899 2085 199 BASED ON GASOLINE STORAGE IN UNDERGROUND TANKS. BBL/YR GASOLINE. 299 EQUIVALINT TO 1.OE12 BTU/YR IS 190500. BASED ON FOOTNOTE 2071, 399 2001) ACRES ARE REQUIRED FOR A TANK FARM HANDLING 2.2EO9 BBL/ 499 YR. 599 2086 199 POLLUTION FRCM OFFSHORE OIL DEVELOPMENT AND PRODUCTION OPERATIONS 29 CAN RESULT FROM BLOWOUTS DURING DRILLING, FROM RUPTURE OF THE 399 WELL CASING DUE TO STORM OR SHIP COLLISION, FROM SPILLAGE OF, 499 OIL IN STORAGE AT THE SURFACE AND FROM PIPELINE LEAKS. 599 THE PRINCIPAL DIFFERENCE BETWEEN OFFSHORE AND LAND OPERATIONS 699 IS TAB POSSIBILITY OF CATASTROPHIC FAILURE OF THE OFFSHORE 79 WELL DUE TO DAMAGE OR DESTRUCTION BY SHIPPING OR STORMS. THE 899 POTENTIAL FOR A MAJOR CATASTROPHE IS GREATER THAN ON LAND 999 BECAUSE OF THE GROUPING OF WELLS ON PLATFORMS FOR MANY REASONS l99 AND THE GREATER LOGISTICS PROBLEMS IN CONTROLLING, A FIRE OR 1199 WILL OPT OF CONTROL (2003,CHAPTER 4). 1299 2,087 6 THE MAJOR CAUSE OF ALL PIPELINE ACCIDENTS IN 1970 WAS EXTERNAL 4 CORROSION AT 43P, EARTH-MOVING EQUIPMENT ACCOUNTED FOR 20P, 39 PERSONNEL ERRORS 4P. NATURAL CATASTRCPHES SUCH AS LAND SLIDES, 499 EARTHQUAKES AND FLOODS WERE OF MINOR MAGNITUDE IN THEIR 599 EFFECTS ON PIPELINES. DRAGGING OF ANCHOR LINES CAN RUPTURE AN 699 OFFSHORE. PIPELINE (2003,CHAPTER 6). 799 2088 199 LARGE SCALE DISASTER CAN RESULT FROM COLLISIONS WITH OTHER VESSELS 299 O--STRUCTURES, GROUNDINGS AND RAMMINGS WITH FIRES AND/OR 399 EXPLOSIONS CAUSING DAMAGE TO VESSEL(S) AND/OR CREW(S) 499 2089 199 COLLISION OF TANK TRUCK OR TRAIN WITH OTHER MOVING OR STATIONARY 299 OBJECT, RESULTING IN FIRE AND/OR EXPLOSION, AFFECTING PERSONS 399 AND PROPERTY IN THE VICINITY. 49 9 2090 199 FIRE AND/OR EXPLOSION DUE TO SPARKS OR OPEN FLAMES. POSSIBLE DAm- 299 AGE TO SERVICE STATION FACILITIES, SURROUNDING PROPERTIES 39 5 PEOPLE. 2091 199 FIRE AND/OR EXPLOSIONS CAUSED BY GAS LEAKS, OIL LEAKS, ACTS, OF 299 GOD, OR HUMAN ERROR. POSSIBLE DAMAGE TO REFINERY, PERSONNEL, 399 ADJACENT PROPERTIES. 499 2092. 199 FIRE AND/OR EXPLOSION CAUSED BY SPARKS AND IMPROPER VENTING. MOST 299 REFINERY FIRES AND EXPLOSIONS ARE IN THE. TANK FARM. 399 2093 199 BASED ON(0005,21) THE PRIMARY FUELS (THOSE THAT ARE DERIVED FROM THE CRUDE OIL FEED) CONSUMED IN REFINERIES PROCESSING 4.088EO9 399 BBLS OF CRUDE ARE FUEL OIL 3.81EO7 BBLS EQUIVALENT To 2.39E14 U99 I BTU,REFINERY GAS 1.013E12 SCF EQUIVALENT' TO 1.2O2OE15 4BTU,PETRO- 591 LEU0M COKE 1.044E6O7 SHORT TONS EQUIVALENT' TO 3.146E14 BTU. l 9 TOTAL PRIMARY FUELS USAGE IS 1.557E15 BTU. TO OBTAIN THE PRI-_ 07961 MART FUELS USAGE IN A REFINERY, PROCESSING 178000 BBL/YR(EQUIV- 899 IV-28 -2099 FTN. 2094 ALENT TO 1.OE12 BTU/YR) MULTIPLY BY 178000 DIVIDED BY 4.088EO9 999 PRIMARY FUELS USAGE IN NATIONAL AVERAGE REFINERY IS 6.78E10. 1099 PRIMARY EFFICIENCY IS DEFINED AS THE FRACTION OF THE PRIMARY 1199 FUEL FORM ENTERING AN INDIV-DUAL PROCESS THAT IS ULTIMATELY 1299 DELIVERED BY THAT PROCESS. EXPRESSING THE PRIMARY FUEL AS 1399 A FRACTICN OF THE FUEL INPUT(1.OE12 BTU/YR) WE GET 6.78EI0 1499 DIVIDED BY 1.OE12 OR 6.78E-02. THUS PRIMARY EFFICIENCY IS 1 1599 MINUS 6.78E-02 OR 9.322E-01. 1699 2094 199 BASED ON(0005,21) THE ANCILLARY FUELS CONSUMED IN REFINERIES 299 PROCESSING 4.088EO9 BBLS CRUDE ARE LEG 6.85EO6 BBLS EQUIVALENT 399 TO 2.75E13 BTU, NATURAL GAS 1.063E12 SCF EQUIVALENT TO 1.096 499 E15 ETU,COAL 4.05EO5 SHORT TONS EQUIVALENT TO 1.00BE13 BTU, 599 PURCHASED ELECTRICITY 2.07E10 XWH EQUIVALENT TO 2.12E14 BTU 699 (CONVERTFD AT 10239 BTU/KWH), PURCHASED STEAM 2.39E10 LBS 799 EQUIVALENT TO 2.87E13 BTU. TOTAL ANCILLARY ENERGY IS THEREFORE 899 1.374E15 BTU. TO OBTAIN THE ANCILLARY DEMAND FOR THE NATIONAL 999 AVERAGE REFINERY PROCESSING 178000 BEL/YR(EQUIVALENT TO 1.0E 1099 12 BTU/YR) MULTIPLY BY 178000 DIVIDED BY 4.08BE09. 1199 2095 199 FROM (2027,13) THE API SEPARATOR PRODUCES 200 MG/L OF SUSPENDED 299 SOLIDS. THUS A 100,000 BPSD REFINERY (WHICH,FROM FOOTNOTE 399 2C66, PRODUCES 5.1 MGD OF WASTEWATER) PRODUCES 4.25 TONS/DAY 499 OF SLUDGE. FOR A REFINERY PROCESSING 1.OE12 BTU/YR (EQUIVALENT 599 TO 178000 BBL/YR), THE SLUDGE AMOUNTS TO 7.57 TONS/YR. NO 699 ADDITIONAL INFORMATION IS AVAILABLE ON SOLID WASTES GENERATED 799 IN REFINERIES. 899 2096 199 COST FOR TRANSPORTING OIL VIA SUPERTANKER IS ESTIMATED AT 0.83 299 DOLLARS/BBL(2028,Al6). 399 2097 199 FROM FOOTNOTE 2036, THE CRUDE STORAGE AMOUNTS TO 16200 BBLS CAPA- 299, CITY. FROM(2040,138) THE COST OF A 16200 BBL CARBON STEEL VER- 399 TICAL STORAGE TANK WITH A CONICAL ROOF IS 1.045EO5 DOLLARS 499 (1972). FIXED CHARGE RATE IS 10P. OPERATING COST IS ESTIMATED 599 AT 7P OF THE CAPITAL COST/YR(2041,162/168). 699 2098 199 FROM FOOTNOTE 2037, THE PRODUCT STORAGE AMOUNTS TO 16636 BBLS, 299 CAPACITY. FROM(2040,138) THE COST OF A 16636 BBL CARBON STEEL 399 VERTICAL STORAGE TANK WITH A CONICAL ROOF IS 1.05SE05 DOLLARS 499 (1972) . FIXED CHARGE RATE IS 10P. OPERATING COST IS ESTIMATED 599 AT 7P OF THE CAPITAL COST/YR(2041,162/168). 699 2099 199 FROM (0010,584) THE TOTAL INSURABLE VALUE OF 650145 GASOLINE SER- 299 VICE STATIONS WAS .1.724EO9 DOLLARS IN 1969. THIS AMOUNT IS FOR 399 STRUCTURES, EQUIPMENT AND CONTENTS OTHER THAN OIL STOCKS. 499 ASSUMING THAT THE INSURED VALUE IS 75P OF THE ACTUAL CASH 599 VALUE, THEN THE AVERAGE ACTUAL CASH VALUE PER STATION IS 35400 699 DCLLARS. FFOM(0010,322) AVERAGE GALLONS OF GISOLINE SOLD PER 799 PASSANGER CAR WAS 687.9. PROM(OO-10,305) THERE IS AN AVERAGE OF 899 372 AUTOMOBILES PER SERVICE STATION. THUS,THR AVERAGE SERVICE 999 STATION DISPENSES 2.56EO5 GALLONS OF GASOLINE,, EQUIVALENT TO 1099 3.19BE10 BTU (0005,38) . THEREFORE, IN ORDER TO, DISPENSE THE 1199 EQUIVALENT OF 1.OE12 BTU/YR GASOLINE, APPROXIAATELY 31.27 1299 SERVICE STATIONS ARE REQUIRED AT A TCTAL CAPITAL INVESTMENT OF1399 1. lOE06 DOLLARS. FIXED CHARGE RATE 1S .10P. NO INFORMATION 1499 AVAILABLE ON OPERATING COSTS.' 1599 IV-29 s 7 zo 1. 2s .1 FUCL E.- -ER POL-TANTS (TONS/lo- 9W. F, 00L 12. .1. I-T- 011--1 -.-L -T- 11-1 ACT-Y P-CESS s.- SOLIDS sus.- -TE. Tli. B.- -e. C -1" -T ACIOS A.E. I.. T.. 11-1- ,..T. -TL 0 --------- 3 7 A T.- 14 . . . . . . .7 17 24 21 17 29 33 14 43 45 4. % Gat: GIL TABLE ENTRIES ARE BASED 04 jQ12 BTU OF REM"" I IITS KAM PROCESS OR.A(TIVITT. Sr I FOOTNOTE 2000 FOR MEASURE EQUIMERTS OF joj2 ITU. INGLE 14. ENVIRONMENTAL IMPACTS. ""ClEtET AND COST FOR CONTROLLED NATIONAL GIL SIRPT'LY C- s", IV-31 Preceding page blank FTN. 2100-2101 FOOTNOTES FOR TABLE 14 2100 199 BASED ON EFFIUENT LIMITATIONS IN (2013,11-10) FOR API REFINERY 299 CATEGORY D AND CRUDE THROUGHPUT EQUIVALENT TO 1.OE12 BTU/YR 399 BOD 7.8LB/10005BL 499 CCD 47 .6LB/1000BBT 599 ORGANICS 699 OIL 3.9LB/100OBBL 799 PHENOLS .039LB/1000BBL 899 TOTAL SUSPENDED SOLIDS 7.BLB/100OBBL 999 OTHER DISSOLVED SOLIDS 1099 SULFIDE .066LE/100OBBL 1199 AMMONIA 3.9LB/100OBBL 1299 TOTAL CHROMIUM .098LB/100OBBL 1399 TOTAL DISSOLVED SOLIDS ARE REDUCED BY CONTROL OF OTHER 1499 DISSOLVED SOLIDS GIVEN ABOVE. 1599 2101 199 THE AIR POLLUTANTS FOR A 1.OE12 BTU/YR CONTROLLED REFINERY ARE 299 POLLUTANT FUEL CAT 399 (TON/YR) COMBUSTION CRACKER STORAGE OTHER 499 PARTICULATES 2.13E+00 6.03E-01 - 599 NOX 1.69E+01 2.80E+00 - 699 sox 7.46E+00 1.33E+01 - 2.OOE-01 799 HC 1.77E+CO 4.90E-01 1.28E+01 8.53E+00 899 Co 2.80E-02 1.38E-01 - 999 ALDEHYDES 4.60E-01 3.25E+00 - 1099 FUEL COMBUSTION EMISSIONS 1199 CONTROL- LIMIT THE S CONTENT OF THE FUELS 1299 THE FOLLOWING QUANTITIES OF FUELS ARE REQUIRED FOR A 1780001399 BBL/YR REFINERY BASED ON THE 1971 FUEL DISTRIBUTION GIVEN 1499 IN (0005,21) AND THE REPLACEMENT OF 1.8P COKE (IN THE 1599 UNCONTROLLED REFINERY) WITH .7P S RESIDUAL FUEL OIL- 3840 1699 BBL .7P S RESID, 46.4EO6 NATURAL GAS, AND 44.1E06 SCF 1799 REFINERY GAS. EMISSIONS IN TABLE ABOVE ARE BASED ON THESE 1899 FUEL CCNSUMPTIONS AND EMISSION FACTORS GIVEN IN (0002,1-7, 1999 1-9) WITH THE TWO FOLLOWING MODIFICATIONS- 1)FOOTNOTE 2125 2099 LISTS A FUEL SAVINGS OF 1.69E10 BTU/YR FROM THE HEAT 2199 RECOVERED IN THE CO WASTE HEAT BOILER. WITH THE ASSUMPTION 2299 THAT ALL THE REFINERY GAS IS STILL USED IN THE REFINERY, 2399 FUEL OIL AND NATURAL GAS USAGE IN THE REFINERY ARE REDUCED 2499 PFOPORTIONALLY BY 910 BBL AND 10.9EO6 SCF RESPECTIVELY. 2599 THE POLLUTANTS ASSOCIATED WITH THIS FUEL SAVINGS ARE THUS 2699 SUBTRACTED FROM THE ORIGINAL FUEL COMBUSTION EMISSICNS 2799 EXCEPT FOR THE NOX EMISSION. SINCE A CO WASTE HEAT BOILER 2899 PRODUCES NOX EMISSIONS, IT WAS ASSUMED THESE NOX EMISSIONS 2999 WOULD CANCEL THOSE NOX EMISSIONS ATTRIBUTABLE TO THE FUEL 3099 SAVINGS. 2) RESIDUAL FUEL OIL WAS LIMITED TO .7P S AS NOTED3199 ABOVE TO CCMPLY WITH STATE REGULATIONS FOR THE ACHIEVEMENT 3299 OF AMBIENT AIR QUALITY STANDARDS. REFINER GAS IS ASSUMED 3399 TO HAVE EMISSIONS SIMILAR TO THE COMBUSTION OF NATURAL GAS 3499 EXCEPT POF THE H2S CONTENT. (2025) INDICATES THAT THE NEW 3599 SOURCE PERFORMANCE STANDARDS FOR REFINERIES LIMIT THE H2S 3699 IN PROCESS GAS COMBUSTED TO .1 GRAIN H2S/DSCF.THUS THE SO23 799 EMISSION FROM THE-COMBUSTION OF REFINERY AS IN A 3899 CONTROLLED 1.4OE12 BTU/YR REFINERY IS 5.941-01 TON S02/YR. 3999 CAT CRACKER EMISSIONS 4099 CONTROL-ESP FOE PARTICULATES AND (70 B0ILER FOR CC 4199 THE EMISSIONS FOR THE CAT CRACKER ARE GIVEN IN FOOTNOTE 4299 2107 FOR A FEED OF 176000 BBL/YR 4(1.8OE12 5TU/YR). TO OBTAITN 4399 IV-33 Preceding page blank FTN. 2102 THE AIR EMISSIONS ATTRIBUTABLE TO A REFINERY PROCESSING 4499 17800O BBL/YR, MULTIPLY THE PROCESS EMISSIONS BY .505 4599 STORAGE EMISSIONS 4699 CONTROL FLOATING ROOF TANKS FOR HC 4799 WITH THE USE OF FLOATING ROOF TANKS AND ASSUMING 30 DAYS 4899 STORAGE OF CRUDE AND PRODUCTS, THE HC EMISSIONS ARE 5.48 4999 TON HC/YR FOR CRUDE STORAGE AND 7.30 TON HC/YR PRODUCT 5099 STORAGE AS GIVEN IN FOOTNOTES 2123 AND 124. 5199 OTHER EMISSICNS 5299 CCNTROL-CLAUS PLANT AND TAIL-GAS UNIT FOR H2S 5399 (2024) INDICATES 48.8P OF THE TOTAL S IN THE CRUDE ENDS UP 5499 IF THE PPOCESS GAS. FOR 79P S CRUDE(FOOTNOTE 2000)AND 5599 178000 BBL/YR REFINERY THIS AMOUNTS TO 101.4 TON S/YR. 5699 HOWEVER .3 TON S/YF. (.594 TON S02/YR) IS EMITTED WITH THE 5799 COMBUSTED REFINERY GASES SO THAT 101.1 TON S/YR IS ACTUALLY 5899 SENT TO THE CLAUS PLANT FOR RECOVERY. WE ASSUME THE USE OF 5999 A 3 STAGE REACTOR PLANT WITH 95P RECOVERY USING A TAIL GAS 6099 CLEAN-UP UNIT TO GIVE AN OVERALL 99.9P S RECOVERY.THUS 6199 .20 TCN S02/YR IS EMITTED IN THE CLAUS PLANT TAIL GASES. 6q099 HC EMISSIONS FOR A CONTROLLED REFINERY COME FROM BLOWDOWN 6399 SYSTEMS(.445 TON HC/YR), PROCESS DRAINS(.865 TON HC/YR), 6499 MISCELLANEOUS LOSSES(6.32 TON HC/YR), AND COOLING TOWERS 6599 (.90 TON HC/YR) AND HAVE BEEN COMPUTED FOR A 178000 BBL/YR 6699 REFINERY (1.OE12 BTU/YR) FROM (0002,9-3/9-4). A 1.OE12 BTU/679 YR REFINERY REQUIRES 3.02EO6 GAL/YR OF COOLING WATER(FROM 6849 FOOTNOTE 2103)AND PRODUCES 9.078EO6 GAL/YR WASTE WATER(FROM6999 FOOTNOTE 2066) 7099 2102 199 THE COSTS ASSOCIATED WITH CONTROLS ON A 1.OE12BTU/YR REFINERY ARE 299 GIVEN HERE. 399 S02 CONTROL 499 A 100000 BPSD REFINERY PROCESSING .79P S CRULE (FOOTNOTE 599 2000) WITH 48.BP OF THE S IN THE PROCESS GAS (FOOTNOTE 699 2101) PRODUCES 56.9 TON S/D IN THE REFINERY GASES. HOWEVER 799 HE COMBUSTED PROCESS GASES SO 899 .16 TON S/D IS EMITTED IN T THAT 56.7 TON OR 50.6 LONG TON S/D ARE SENT TO THE ClAUS A US 999 PLANT FOR RECOVERY. (2021,75) INDICATES A CLAUS PLANT WITH 1099 3 CONVERTORS AND TAIL-GAS-CLEANUP FACILITIES FOR 50 LT S/D 1199 REQUIRES 1.9E06$ INVESTMENT. FENCE A 540 BPSD REFINERY 1299 REQUIRES 1026 $/YR AT 10P FCR. OPERATING COSTS FOR THE 1399 CLAUS PLANT ONLY ARE FROM (2025) AND HAVE BEEN SCALED FROM 1499 15 To 50 LT S/D USING A .6 EXPONENT TO GIVE 95500 $/YR THE1599 OPERATING COST FOR THE TAIL-GAS-CLEANUP UNIT IS FROM (2022,1699 15) FCR RECOVERY OF 99.9P OF THE S TO THE CLAUS PLANT AND 1799 IS GIVEN AS 27500 $/YR. THUS THE TOTAL OPERATING COST IS 199 123000 $/YR FOR A 50.6 LT S/D CLAUS PLANT (SERVICING A 1999 100000 BPSD REFINERY) OR 665 $/YR FOR A 1.OE12 BTU/YR 2099 FEFINERY. NO CREDIT IS TAKEN FOR S RECOVERED,. 2199 CONTROL CF WATER POLLUTANTS 2299 COSTS FOR A 2 MGD BIOLOGICAL TREATMENT PLANT LISTED BELOW 239 ARE FROM (2013,VII-5) 2499 CAPITAL 0PERATING 2599 PROCESS CCIST-$ COST-$/qYR 2699 SAND OR DUAL MEDIA FILTER 1.90EC5 3.4OE04 2799 2 STAGE SOUR WATER STRIPPER 8.50E04 2899 CHROMATE REMOVAL SYSTEM 6.50E2O4 2.00E04 2999 EQUALIZATION 1 .00E05 9. 0 O8OE3 30 9 9 DISSOLVED AIR FLOTATION 8.50E04 9.00OE03 34q198q4 ACTIVATED SLUDGE 1. 25E2O6 1 . 12 ED 5 3299 SECONDARY CLARIFICATION 7.00EO4 1. 70 EO4 4 3399 TOTAL 1.85E06 2.01EO5 3499 IV-34 FTN. 2102 (Cont) THESE COSTS WERE THEN SCALED BY A .6 EXPONENT TO GET THE 3599 COSTS FOR TREATING 5.1 MGD (100000 BPSD REFINERY REQUIRES 3699 '"HEN MULTIPLIED BY 5.4E-03 37-99 5.1 MGD FROM FOOTNOTE 20661 AND To GET 1747 $/YR CAPITAL LOST (AT 10P FCR) ANL 1904 $/YR 3899 OPERATING COST FOR A 1.OE12 BTU/YP REFINERY. 3999 CCNTROL OF PARTICULATES FROM CAT CRACKER 4099 FOOTNOTE 2107 GIVES THE COSTS FOR AN ESP SERVICING A CAT 4199 CFACKEP WITH 1.OE12 BTU/YR INPUT. TO OBTAIN THE COSTS FOR 4299 A 1.OE12 BTU/YR REFINERY MULTIPLY BY .505 TO GET 482 $/YR 4399 FIXED COST (AT 10P FCR).AND 220 $/YR OPERATING COST. 4499 CONTROL OF CO FROM CAT CRACKER 4599 FOOTNOTE 2107 GIVES THE COSTS FOR A CO WASTE HEAT BOILER 4699 SERVICING A CAT CRACKER WITH 1.OE12 BTU/YR INPUT. TO OBTAIN4799 THE COSTS FOR A 1.CE12 BTU/YR REFINERY KULTIPLY BY .505 TO 4899 GET 1218 $/YR FIXED COST AND 1655 $/YR OPERATING COST. 4999 STEAM-FUEL CREDIT FROM CO BOILER 5099 (2026) INDICATES THAT A CO BOILER SERVICING A 70500 BPSD 5199 CAT CFACKER WILL PRODUCE"450000 LB STEAM/HR. ASSUMING A 5299 FUEL COST OF 45C/1.GE06 BTU AND STEAM AT 60C/1000 LB 5399 GIVES A 2.24EO6 $/YR CREDIT. FOR 1.OE12BTU/YR INPUT TO THE 5499 CAT CRACKER THIS SAVINGS IS 17126 $/YR AND FOR A 1.OE12 BTU5599 /YR REFINERY (MULTIPLYING BY .50@) THE CREDIT IS 8660 $/YR.5699 CCNTROL OF HC FROM CRUDE, STORAGE TANKS 5799 FOOTNOTE 2123 INDICATES-J, 2000 $/YR INCREMENTAL FIXED COST 5899 FOR FLOATING ROOF STOft@E AND NO INCREMENTAL OPERATING COST5999 CREDIT FOR CRUDE SAVED BY FLOATING RCOF STORAGE 6099 HC EMISSIONS FROM FIXED ROOF TANKS ARE 67.2 T/YR FROM 6199 FOOTNOTE 2036.AND 5.5 T/YR WITH FLOATING ROOF STORAGE FROM 6299 FCOTNOTE 2123. ASSUMING 7.3 C/GAL CRUDE GIVES A 1261 S/YR 6399 CREDIT FOR HC EMISSION REDUCTION. 6499 CCNTFOL OF HC FROM PRODUCT STORAGE TANKS 6599 FOOTNOTE 2124 INDICATES A 2000 $/YR INCREMENTAL FIXED COST 6699 FOR FLOATING ROOF STORAGE AND NO INCREMENTAL OPERATING COST6799 CREDIT FOR PRODUCTS SAVED BY FLOATING ROOF STORAGE 6899 FOOTNOTE 2037 GIVES 93.3 TON HC/YR EMITTED FROM FIXED ROOF 6999 TANKS AND FOOTNOTE 2124 LISTS 7.3 TON HC/YR FROM FLOATING 7099 ROOF TANKS. ASSUMING 12.5C/GAL OF GASOLINE AND MOST OF THE 7199 PRODUCT STORAGE AS GASOLINE GIVES A 3486 SIYR CREDIT. 7299 CCNTROL OF THERMAL POLLUTION 7399 FROM FOOTNOTES 2103 AND 2125 WITH .125 KILL-IONS OF TOWER 7499 UNITS AND AN ASSUMED COST/TOWER UNIT OF 4.75 $ GIVES 6.OE057599 $ CAPITAL COST FOR A MECHANICAL DRAFT WET COOLING TOWER 7699 SERVICING A 100000 BPSD REFINERY. ASSUMING POWER COSTS ARE 7799 THE PRIMARY OPERATING COSTS AT I C/KWH GIVES AN OPERATING 7899, COST CF 2.17E05 i/YP. FOR A 1.OE12 BTU/YR -EFINERY FIXED 7999 COSTS ARE 324 $/YR(AT 10P FCR)AND OPERATING COSTS 1172 $/YR8099 SOLID WASTE DISPOSAL COSTS 8199 (2033,38) INDICATES AN ANNUAL DISPOSAL COST OF 34.4 $/TON 8299 FOR CLAY COOLING AND STORAGE,PRIMARY AND SFCONDARY HANDLING8399 FILTER PEESS DEWATERING,TRANSPORTING,SOIL rIODEGRADATION. 8499 FOOTNOTE 21C4 GIVES 36.1 TON SOLID WASTES @;ENERATED BY 8599 CONTRCLS IN A 1-0E12 BTU/YR REFINERY GIVIN:s 1242 $/YR COST.8699 POLLUTANT-CONTROL TECHNOLOGY CAPITAL OPERATING TOTAL8799 S02-cLAus PLANT AND TAIL GAS CLEANING 1026 665 1691 8899 WATER POLLUTANTS-BIOLOGICAL OXIDATION 1747 1904 36,51 6999 PARTICULATES-ESP ON CAT CRACKER 482 220 702 9099 CO-CC BOILER ON CAT CRACKER 1218 1655 2873 9199 CREDIT FCR FUEL SAVED IN CO 'BOILER -8660 -8660 9299 HC-FLOATING ROOF ON CRUDE STORAGE 20C0 0 2000 9399 CREDIT CEUDE SAVED BY FLOATING ROOF -1281 -1281 9499 HC-FLOATING ROOF ON PRODUCT STORAGE 2000 0 2000 9599 I V - 3 5 FTN. 2103-2107 CREDIT PRODUCT SAVED BY FLOATING ROOF -3486 -3486 969 THERMAL-MECHANICAL DRAFT WET TOWER 324 1172 1496 979.9 SOLIDS-DISPOSAL BY BIODEGRADATION 1242 1242 9899 TOTAL REFINERY INCREMENTAL COSTS-$/YR 8797 -6569- 2220 9999 21D3 19 A 1.OE12 BTU/YR REFINERY USES 3 02EOB GAL WATER/YR FOR COOLING 299 PURPOSES AND PRODUCES 7.06E1O BTU/YR THERMAL DISCHARGE (FROM; 399 FOOTNOTE 2066). THE THERMAL DISCHARGE CAN BE COMPLETELY 499 ELIMINATED BY THE USE OF A MECHANICAL DRAFT WET COOLING' TOWER. 599 2104 199 SOLID WASTES ARE GENERATED BY THE ESP USED TO CONTROL PARTICULATES 299 FROM THE CAT CRACKER AND BY THE WATER POLLUTION CONTROL SYSTEM 399 FOOTNOTE 2107 GIVES 4.17 TON/YR SOLID WASTEF OR 1.OE12 BTU/YR 499 INPUT TO THE CAT CRACKER. TO CONVERT THIS FOR A 1.OE12 BTU/YR 599 REFINERY,MULTIPLY BY .505 TO GET 2.11 TON/YR FROM THE CAT 699 CRACKER. (2034,75/78) INDICATES THAT A 6.0 MGD WASTEWATER 799 TREATMENT SYSTEM PRODUCES 5500O LB/D SOLID WASTES. FOR A 5.1 899 MGD SYSTEM(100000 BPSD REFINERY) THIS BECOMES 46750 LB/L TOTAL 999 TREATMENT SYSTEM WASTES. (2027,13) NOTES THAT THE API 1099 SEPARATOR CAN PRODUCE 8320 LB/D IN TREATING 5.0- MGD WASTE 1199 WATER OR 8500 LB/D FOR 5.1 MGD. THE UNCONTROLLED REFINERY HAS, 1299 AND API SEPARATOR SO THAT ONLY 38250 LB SOLID WASTE/D ARE 1399 ATTRIBUTED TO THE,CONTROLLED REFINERY WATER POLLUTION- CONTROL. 1499 SYSTEM. FOP A 1.OE12 BTU/YR REFINERY THIS'BECOMES 34.0 TON-/YR 1599 FOR WATER POLLUTION CONTROL. THE SUM TOTAL INCREMENTAL SOLID 1699 W A STE GENERATED IN A CONTROLLED 1.OE12 BTU/YR REFINERY IS 17�9 THUS 36. 1 TON/YR. 1899 2105 199 LAND REQUIREMENTS FOR PRINCIPAL SUL-FUR RECOVERY PROCESS EQUIPMENT, 29:9 STORAGE,INCINERATOR,AND STACK FROM (2023,107) IS .0699 ACRES 399 FOR A 50.7 LT S/D, CLAUS PLANT (100OO BPSD REFINERY) . FOR' A 499 l.CE12 BTU/YP REFINERY THIS IS 3.77E-04 ACRES. (2035,81) 599 INDICATES THAT A 25OO0,GPM COOLING SYSTEM EMPLOYING TWO 699 MECHANICAL DRAFT WET COOLING TOWERS REQUIRES 1.5 ACRES LAND. 799 USING .75 ACRES/1250O GPM AND NOTING THAT A 100000 BPSD 899 REFINERY REQUIRES 117500 GPM (FOOTNOTE 2066) GIVES 4.05E03 999 ACRES FOR A 1.GE12 BTU/YR REFINERY. (2036,62) INDICATES, AN, 1099 EXTENDED-AEPATION ACTIVATED SLUDGE PLANT TO TREAT 5 MGD 1199 REQUIRED- A 2.17 ACRE SITE. ASSUMING ABOUT AN ADDITI0NAL ACRE 1299 FOR THE EQUALIZATION BASIN, D ISSO LVED AIR FLOTATION,ACRE FINAL 1399 FILTRATION UNITS GIVES A TOTAL OF 3 ACRES FOR A 5 MGD 1499 WASTEWATER TREATMENT SYSTEM(100000 BPSD REFINERY). FOR 1.OE 1599 12 BTU/YR THIS BECOMES 1.62E-02 ACRES. THUS THE TOTAL 1699 INCREMENTAL LAND REQUIREMENT FOR CONTROLS ON A 1.OE12 BTU/YR 1799 REFINERY IS 2.06E02 ACRES. THIS IS PROVIDED FOR IN THE, 1899 REFINERY FIGURE GIVEN IN FOOTNOTE 2040. 1999 2106 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 29 9 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 39 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 1491) SAME AS GIVEN IN FOOTNOTE 2006. EMISSIONS BELOW ARE IN' TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BO'ILERS SOURCES HC 2.64E-01 4.65E02 2.68E+00 8991 2 81087 WATER POLLUTANTS AND THERMAL DISCHARGE ARE THE SAME AS GIVEN IN 2 9 9 FOOTNOTE 2007. AIR POLLUTANT SOURCES INCLUDE STEAM BOILERS, AND 439 PROCESS HEATERS ,BLOWDOWN SYSTEMS,PIPELINE VALVES AND FLANGES, 8q499 VESSEL RELIEF VALVES,PUMP AND COMPRESSOR SEALS.PROCESS DRAINS, 409 AND CATALYST REGENERATION OPERATICN..AIR POLLUTANT EMISSION 06911) FACTORS FROM (0002,1-9,9-3/9-4) EXCEPT AS NOTED BELOW' TABLE., 4791 IV-36 FTN. 2107 (Cont) POLLUTANT CATALYST PROCESS STEAK OTHER 899 (TON/YR) CONVERSION HEATERS BOILERS SOURCES 999 PARTICULATES 1.20E+00 2.42E-01 6.50E-02 - 1099 NOX 5.54E*00 2.78E+00 7.48E-01 - 1199, sox 2.63E+01 7.25E-03 1.95E-03 - 1299 HC 9.68E-01 3.63E-01 9.75B-02 2.43E+00 1399 Co 2.72E-01 4.83E-03 1.30E-03 - 1499 NH3 4.75E+00 O.OOE+00 O.OOE+00 - 1599 OTHER ORGANICS 1.67E+00 1.21E-01 3.23E-02 - 1699 BBL FEED EQUIVALENT TO 1.OE12 BTU/YR IS 176000(0005,38) AND 1799 FCOTNOTE 2000. 1899 CONVERSION S02 EMISSIONS 1999 3.2P GF TOTAL SULFUR IN CRUDE IS ATTRIBUTED TO REFINERY CAT2.099 CRACKER REGENERATION OPERATIONS BASED ON AN EPA SULFUR 2199 BALANCE FCR REFINERIES (2024).THUS FOR .79PS CRUDE AND A 2299 1.OE12 BTU/YR REFINERY (178000 BBL CRUDE/YR)13.3 TON S02/YR2399 ARE DISCHARGED FROM CAT CRACKER OPERATIONS. THESE REFINERY 2499 CAT CRACKER CONVERSION S02 EMISSIONS ARE OBTAINED FOR 1.OE 2599 12 BTU INPUT TO CAT CRACKER BY MULTIPLYING BY RATIO OF BBL 2699 OF FEED EQUIVALENT TO 1.OE12 BTU TO BBL OF CRUDE EQUIVALENT2799 TO 1.OE12 BTU AND THEN MULTIPLIED BY RATIO OF BBL OF CRUDE 2899 PPOCESSED/DAY IN THE REFINERY TO BBL OF FEED/DAY TO CAT 2999 CRACKER FROM(2009,FIG.3). NO CONTROL OF THESE CONVERSION 3099 S02 EMISSIONS IS ANTICIPATED. 3199 CONVERSION PARTICULATE EMISSIONS 3299 (2029) INDICATES THAT THE NEW SOURCE PERFORMANCE STANDARDS 3399 FOR FLUID CAT CRACKERS WILL LIMIT PARTICULATE DISCHARGES T03499 .022 GRAINS/DSCF. (2029) ALSO NOTES THAT A 50000BPSD CAT 3599 CRACKER HAS A REGENERATOR GAS FLOW RATE OF 15000ODSCFM AND 3699 WOULD THUS EMIT .339 TON PARTICULATES/D OR 6.78E-06 TON/BBL3799 FRESH FEED IN COMPLIANCE WITH THE STANDARD. 3899 CONVERSION CO EMISSIONS 3999 (2029) INDICATES THAT THE NEW SOURCE 'PERFORMANCE STANDARDS 4099 FOR FLUID CAT CRACKERS WILL LIMIT CO EMISSIONS TO NO MORE@ 4199 THAN .050P VOLUME OF REGENERATOR OFFGAS. USE OF A CO WASTE 4299 HEAT BOILER IS ASSUMED FOR COMPLIANCE WITH THE STANDARD. 4399 (2029) NOTES THAT CO EMISSION FROM CO BOILERS IS ABOUT 10 4499 PPM WHICH,FOR A 50000 BPSD CAT CRACKER(150000 DSCFM),GIVES 4599 .0772 TON CO/D OR 1.54E-06 TON CO/BBL FEED. 4699 CONVERSION HC EMISSIONS 4799 THE CC WASTE HEAT BOILER CAN REDUCE HC EMISSIONS FROM THE 4899 ]REGENERATOR OFFGAS BY,95P.. 4999 OTHER SOURCE HC EMISSIONS 5099 TOTAL REFINERY OTHER SOURCE HC EMISSIONS ARE ALLOCATED To 5199 THE CAT CRACKING. PROCESS BASED ON THE RATIO OF CAT CRACKER 5299 CAPACITY TO TOTAL REFINERY CAPACITY FROM(2009,FIG.3),THAT 5399 IS,0.16303(SEE FOOTNOTE-2007). THESE-EMISSIONS REFLECT 5499 CONTROLS ON BLOWDOWN SYSTEMS,PROCESS DRAINS,AND VACUUM 5599 JETS. .5699 SOLID WASTES FROM CONTROLS 5799 SOLID WASTES ARE GENERATED BY THE ELECTROSTATIC 5899 PRECIFITATOR USED TO CONTROL PARTICULATE EMISSIONS.ITHXS 5999 SOLID WASTE IS EQUAL TO THE DIFFERENCE IN PARTICULATE 6099 EMISSIONS FROM THE UNCONTROLLED CAT-CRACKER REGEN ERATOR(SEF6199 FOOTNOTE 2007)AND THE CONTROLLED REGENERAT-'Ei GIVEN ABOVE. 6299 ENERGY REQUIREMENIS FOR CONTROLS 6399 POWER CONSUMPTION FOR ESP TAKEN FROM (2031,393) ASSUMING 6499 PERFORMANCE SIMILAR TO THAT ON A PULVERIZED FUEL FIRED 6599 BOILER AND USING 15000ODSCFM AND .9 LOAD FACTOR FOR ESP 6699 SERVICING A 50000 BPSD CAT CRACKER. ELECTRICITY CONVERTED 6799 AT 10200 BTU/KWH. ENERGY REQUIRED IS 2.90EO7 BTU/YB FOR 6399 IV-37 FTN. 2108-2111 10E12 BTU/YR INPUT TO CAT CRACKR. 6959 (2026) INDICATES A POWER REQUIREMENT OF 7.45EO6 KWH/YR AND 7099 AN AUXIL IARY FUEL REQUIREMENT OF 5.27E11 BTU/YR FOR A Co 7199 WASTE HEAT BOILER SERVICING A 70500 BPSD CAT CRACKER. FOR 1.0112 BTU/YR CAT CRACKER WE HAVE 5.81E08 BTU/YR POWER 7399 REQUIREMENT(ELECTRICITY CONVERTED AT 10200 BTU/KW4)AND 7499 4.03E09 BTU/YR AUXILIARY FUEL REQUIREMENT. THUS THE TOTAL 7599 ,ENERGY REQUIREMENT FOR CONTROLS 02 1.OE12 BTU/YR CAT- 7699 CRACKER IS 4.4EO9 BTU/YR. 7799 CONTROL COSTS 7899 FROM (2029) THE CAPITAL COST OF AN ESP SERVICING A 65000 7999 ElPSD CAT CRACKER IS 1.15EO6$. FOR A 539 BPSD UNIT (1.OE12 8099 BTU/YR) THE COST WOULD BE 954$/YR AT 10P FIXED CHARGES.. 8199 (2029) ALSO GIVES 52500S/YR. FOR OPERATING COSTS OF THE ESP 8299 'WHICH TRANSLATES To 435$/YR FOR AN ESP ON A 539BPSD UNIT. 8399 (2026) LISTS THE CAPITAL,COST OF A CO WASTE HEAT BOILER 8499 SERVICING A 70500 BPSD CAT CRACKER AT 3.15EO6$. FOR A539 8599 ElPSD UNIT THE COST IS 2408 $/YR AT 10P FIXED CHARGE RATE. 8699 2026) GIVES THE OPERATING AND MAINTAINENCE COSTS FOR THE ESP 879 AT 4.28EC5$/YR WHICH BECOMES 3272$/YR ON A 539 8899 CO BOILER BPSD UNIT. THUS THE INCREMENTAL CCSTS FOR CONTROL ON A 8999 1.0E12 BTU/YR CAT CRACKER ARE 3362 $/YR FIXED, 3707,$/YR 9099 OPERATING, AND 7069 $/YR TOTAL ANNUAL. NO ACCOUNT HAS BEEN TAKEN AT THE PROCESS LEVEL FOR STEAM- 9299 9199 GENERATED IN THE CO BOILER OR FOR AIR POLLUTANTS ASSOCIATED 9399 WITH COMBUSTION OF AUXILIARY FUEL IN THIS BOILER (HOWEVER SEE 9499 FOOTNOTE 2101). AIR POLLUTANTS FROM PROCESS HEATERS AND STEAM 999 BOILERS BASED ON A NATURAL GAS FEED. 2.416EO7 SCF FUEL IS USED9699 TO PROCESS l.OE12 BTU FEED FROM (2006,1-71/8) AND (0005,38). 9799 SCF FUEL FOR STEAM IS, 6.50EO6 BASED ON(20O6,131/8)1031 BTU/SCF 9899 AND 85P FUEL EFFICIENCY.ELECTRIC AT I.O4 KWH/BBL(20O6,131/138)9999 2108 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS.,PROCESS DRAINS AND 299 VACUUM JETS' CAN BE CONTROLLED TO THE, LEVEL, GIVEN IN (0002,9-3/-399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2006. EMISSIONS BELOW ARE-IN TON/YR. 59 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 4.98E-01 2.46E+00 899 2109 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAIN'S AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2009. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 4.87E-O2 6.53E-03 2.26E+0O 899 199 2110 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS PROCESS DRAINS AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 39 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2010. EMISSIONS BELOW ARE IN`TON/YR. 599 PROCESS STEAM, OTHER 699 HEATERS BOILERS SOURCES 799 2111 199 HC 6.14E-01 1.67E-01 1.99E+00 899 299 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS PROCESS DRAINS AND - VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN 4(0002,9-3/ -390q9 4499 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE I SAME AS GIVEN IN FOOTNOTE 2009. EMISSIONS BELOW ARE IN TON/YR. 54 PROCESS STEAM OTHER 699 IV-38 FTN. 2112-2119 HEATERS BOILERS SOURCES 799 HC 4.08E-01 2.21E+00 899 2112 199 HYDROCARBON EMISSIONS FROM BLCWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2012. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699' HEATERS BOILERS SOURCES 799 HC 1.61E-01 1.31E-01 2.68E+00 899 2113 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTE3S,PROGESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN, IN (0002,9-3/ 399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2013. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 1.24E+00 4.29E+00 899 2114 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (COC2,9-3/ 399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2014. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM. OTHER 699 HEAZERS BOILERS SOURCES 799 HC 2.64E+00 899 2115 .199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PR(jCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ j99 9-4). PROCESS 111EATER AND STEAM BOILER HC EMISSIONS-ARE THE 499 SAME AS GIVER*IN FOOTNOTE 2015. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATEAS BOILERS SOURCES 799 HC 6.98E-01. 1.15E-01 2.17E+00 899 2116 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4), PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2016. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 7.10E-01 1.15E-01 2.36E+00 .899 2117 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIO-NS ARE THE 499 SAME.,AS GIVEN IN FOOTNOTE 2017. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 fic 5.OOE-.01 l.ClE+C.O 1.97E+00 899 2118 199 t HYDROCARBON EMISSIONS FROM BLCWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2018. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 1.20E-02 4.03E+00 899 2119 199 HYDFOCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 IV-39 FTN. 2120-2125 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME IS GIVEN 'IN FOOTNOTE 2019. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 2.47E+00 899 2120 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 3-99 9-4). PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 499 SAME AS GIVEN IN FOOTNOTE 2020. EMISSIONS BELOW ARE IN, TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 3.75E-01 1.68E- 01 2.17+00 899 2121 199 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS.PROCESS DRAINS,AND 299 VACUUM JETS CAN.BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4)- PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE SAME AS GIVEN IN FOOTNOTE 2021. EMISSIONS BELOW ARE IN TON/YR. 599 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 2.03E+00 899 2122 19 HYDROCARBON EMISSIONS FROM BLOWDOWN SYSTEMS,PROCESS DRAINS,AND 299 VACUUM JETS CAN BE CONTROLLED TO THE LEVEL GIVEN IN (0002,9-3/ 399 9-4),. PROCESS HEATER AND STEAM BOILER HC EMISSIONS ARE THE 49 SAME AS GIVEN IN FOOTN0TE 2022. EMISSIONS BELOW ARE IN TON/YR. 59 PROCESS STEAM OTHER 699 HEATERS BOILERS SOURCES 799 HC 7.91E-01 1.93E-01 2.24E+00 899 2123 199 WE ASSUME THE USE OF A 50 FT DIAMETER 50 FT HIGH FLOATING HOOF 299 STORAGE TANK TO STORE OUR 16200 BBL (30 DAY STORAGE) CRUDE 399 (SEE FOOTNOTE 2036). EMISSION FACTORS FROM (0002,4-4). (2026) 499 AND 59 , (2030) INDICATE NO INCREMENTAL OPERATING COSTS AND A $20000 INCREMENTAL CAPITAL COST FOR 2OOO BBL FLOATING ROOF 699 TANK. BASING THE HEATING VALUE OF HC EMISSIONS ON THE VALUE 799 OF THE CRUDE STORED GIVES A 99.979P PRIMARY EFFICIENCY FOR 899 THE FLOATING ROOF DESIGN. FOOTNOTE 2102 GIVES A CREDIT OF 1281 999 $/YR FOR HC NOT EMITTED DUE TO USE OF FLOATING ROOF TANK 1099 AND,THIS HAS BEEN CREDITED TO OPERATING COSTS. 1199 2124 199 WE ASSUME THE USE OF A 50 FT DIAMETER 50 FT HIGH FLOATING ROOF 299 STORAGE TANK TO STORE OUR 16636 BBL (30 DAY STORAGE) OF 399 PETROLEUM PRODUCTS (SEE FOOTNOTE 2037). EMISSION FACTORS, FROM 499 (0002,4-4). (2026) AND (2030) INDICATE NO INCREMENTAL 599 OPERATING COSTS AND A $20000 INCREMENTAL CAPITAL COST FOR 699 20000 BBL FLOATING ROOF TANK. BASING THE HEATING VALUE OF HC 799 EMISSIONS ON THE VALUE OF GASOLINE GIVES A 99.97P PRIMARY 899 EFFICIENCY FOR THE FLOATING ROOF DESIGN. FOOTNOTE 2102 GIVES A 999 CREDIT OF 3486 $/YR WITH THE USE OF FLOATING ROOF TANK 1099 AND THIS HAS BEEN CREDITED TO OPERATING COSTS. 1199 2125 199 ENERGY REQUIREMENTS FOR CONTROLS ON A 1.0E12 BTU/YR REFINERY ARE 29.9 PRESENTED HERE. 3 99 S02 CONTROL 499 FOR THE CLAUS 599 ENERGY REQUIREMENTS I S PLANT AND TAIL-GAS CLEANUP UNIT ARE ASSUMED TO BE 15P OF THE OPERATING,COSTS. 699 ASSUMING A FUEL COST OF 45C/1.OE06 BTU GIVES A FUEL 799 REQUIREMENT OF 2.22E08 BTU/YR 89 PARTICULATE CONTROL ON CAT CRACKER 999 FOOTNOTE 2107 GIVES THE ENERGY REQUIREMENT FOR 1.OE12 BTU/ 1099 YR INFUT TO THE CAT CRACKER. FOR A 1.OE12 BTU/YR REFINERY 1199 MULTIPLY THIS BY .505 TO GET 1.47EO7 BTU/YR. 1299 IV-40 FTN.; 2126 CC CCNTROL ON CAT CRACKER 1399 FCOTNCTE 2107 GIVFS A POWER REQUIREMENT OF 5.81E08 BTU/YR 1499 AND AN AUXILLARY FUEL REQU-REMENT OF 4.03EO9 BTU/YR FOR 1.01599 E12 BTU YR INPUT TO THE CAT CRACKER. FOR A I.OE12 BTU/YR 1699 REFINERY MULTIPLY THESE NUMBERS BY .505. 1799 STEAM-FUEL CREDIT FOR CO BOILER 1899 FOOTNOTE 2102 INDICATES A FUEL SAVINGS OF.8660 $/YR FOR A 1999 CC BOILER IN A 1.OE12 BTU/YR REFINERY. BASED ON 45C/1.0'EO6 2099 BTU THIS REPRESENTS A FUEL SAVINGS OF 1.92EiO BTU/YR. 2199 THERMAL POTLUTION CONTROL 2299 ENERGY REQUIREMENTS FOR A .125EO6 GPM MECHANICAL DRAFT WET 2399 COOLING TOWER ARE FROM (2032). ASSUMING A 70 DEGREE F WET. 2499 BULB AND A 15 DEGREE F APPROACH AND WITH A 28 DEGREE F 2599 TEMPERATURE RISE (FROM FOOTNOTE 2103),(2032,N-10/N-12)GIVES2699 A FAN POWER REQUIREMENT OF 1.05 MW AND A PUMPING POWER 2799 REQUIFEMENT OF 1.7 MW FOR A TOTAL POWER REQUIREMENT OF 2899 2.75 MW. THIS HAS BEEN CCNVERTED TO BTU/YR BASED ON A .9 2999 LOAD FACTOR AND 10200 BTU/KWH, ANE SIZED FOR A 540 BPSD 3099 (1.OE12 BTU/YR)REFINERY TO GIVE AN ENERGY REQUIREMENT OF 3199 1.19EC9 BTU/YR. 3299 WATER POLLUTION CONTROL 3399 POWER REQUIREMENTS FOR AN EXTENDED-AERATION ACTIVATED 3499 SLUDGE-PLANT TREATING 5.0 MGD WASTEWATER ARE 4.44EO6 KWH/ 3599 YR FRCM (2036,65) P04ER.@EQUIPEMENTS FOR A DISSOLVED AIR 3699 FLOTATION UNIT TR;ATINa*r.44 MGD WASTEWATER ARE 1.96EO5 3799 KWH/YF FROM (2037,53) OR 6.95EO5 KWH/YR FOP A 5.1 MGD 3899 SYSTEV. FOOTNOTE 2102 GIVES AN OPERATING COST OF 80000 $/ 3999 YR FOR THE WASTEWAIER TREATMENT OPERATIONS EXCLUSIVE OF 4099 THE ACTIVATED SLUDGE AND DISSOLVED AIR FLOTATION UNITS. 4199 SCALING THIS To 5.1 MGD WITH A .6 EXPONENT AND ASSUMING 15P4299 OF THIS OPERATING EXPENSE IS FOR POWER COST AT 1C/KWH 4399 GIVES AN ENERGY REQUIPEMFNT OF 2.1E06 KWH/YR. THE TOTAL 4499, KWH REQUIREMENT FOE A 5.1 MGD WASTEWATER TEEATMENT SYSTEM 4599 IS THUS 7.24EO6 KWH/YR (FOR A 100000 BPSD,REFINERY). 4699 MULTIPLYING THIS BY 5.40E-03 AND CONVERTING BY 10200 BTU/ 4799 KWH GIVES AN ENERGY REQUIREMENT OF 3.985EO8 BTU/YR FOR A 4899 1.OE12 BTU/YR REFINERY. 4999 TOTAL ENERGY REQUIREMENTS FOR A 1.OE12 BTU/YRREFINERY 5099 THERE IS A 169.4ECS BTQ/YR FUEL SAVINGS FOR THE REFINERY 5199 BASED CN 192.OE08 FUEL CREDIT FROM THE CO WASTE HEAT BOILER5299 @AND,22.62EO8 FUEL EEQUIRED FOR S02 CONTROL AND AUXILIARY 5399 FUEL IN THE CO BOILER. THIS FUEL SAVED WAS ALLOCATED AS 5499 57.1EC8 BTU/YR FUEL OIL AND 112.3E08 BTU/YR NATURAL GAS AS 5599 NCTED IN FOOTNOTE 2101. THUS THE PRIMARY ENERGY REQUIRED 5699 IN A 1.OE12 BTU/YR REFINERY IS 6.773E10 BTU/YR (FOOTNOTE 099 2093) LESS .571E10 BTU/YR FOR A NEW PRIMARY EFFICIENCY OF 5899 93.8P. THE ANCILLARY ENERGY REQUIREMENTS BECOME 5.98E10 5999 BTU/YF (FOOTNOTE 2C94) LESS 1.12E10 BTU/YR (NATURAL GAS 6099 SAVED) PLUS .19E10 BTU/YR OF ELECTRICITY REQUIRED (THE SUN 6199 OF ELECTRICITY REQUIRED FOR THE ESP, CO BOILER, THERMAL 6299 CCNTROL, AND WATER POLLUTION CONTROL) FOR AN ANCILLARY 6399 ENERGY REQUIREMENT OF 5.O5ElC BTU/YR. 6499 2126 199 WE ASSUME THE USE OF DOUBLE bOTTOM CONSTRUCTION ON TANKERS AND 299 SUPERTANKERS WHICH 1) PROVIDES CLEAN BALLAST SIORA 399 GE AND 2) REPRESENTS A FACTOR OF SAFETY IN THE EVENT OF GROUNDING. 499 (0020,4) NOTES THAT 967000'METRIC TONS OF OIL/@YR ARE - 599 DISCHARGED TO THE OCEAN WITH THE TANKER BALLAST AND WOULD BE 699 COMPLETELY ELIMINATED WITH THE PROVISION FOR CTIEAN BALLAST 799 STORAGE. IN ADDITION 250000 METRIC TONS OF CIL/YR ARE LOST TO 899 THE OCEAN THROUGH VESSEL CASUALTIES--@26P OF WHICH IS ATTRIBUTED.999 IV-41 FTN.2127-2129 TO GROUNEINGS. (0020,26) NOTES THAT 70P OF THE POLLUTION 109 RESULTING FROM GROUNDINGS COULD BE ELIMINATED BY DOUBLE BOTTOM 1199 CONSTRUCTION. THE TOTAL EFFECT OF DOUBLE BOTTOM CONSTRUCTION 129 THEN WOULD BE TO ELIMINATE 1012500 OF THE 1367000 METRIC TONS 1399 OF OIL/YR DISCHARGED TO THE OCEAN FROM TANKER OPERATIONS. 1499 374500 METRIC TONS OF OIL/YR WOULD STILL BE DISCHARGED FROM 1599 BILGE PUMPS,LEAKS,VESSEL CASUALTIES,AND TERMINAL OPERATIONS. 1699 THIS FIGURE IS FOR 1300E06 METRIC TONS OIL/YR TRANSPORTED SO 1799 THAT OIL DISCHARGED IS BASED ON .0288P OF THE TONNAGE SHIPPED.1899. FROM THIS THE PRIMARY EFFICIENCY IS SEEN TO BE 99-971P 1999 THE,INCPEMENTAL CAPITAL COST FOR DOUBLE BOTTOM CONSTRUCTION 2099 ON A 4OO00 DWT TANKER IS 1.76E06 $ AND ON A 200000 DWT TANKER 2199 4.75EO6 $ FROM (0020,26). A 40000 DWT TANKER CAN CARRY 352000 2299 BEL CRUDE SO THAT 178/352 1.765EO6 $ IS (2007,10-7) TIMES 2399 ATTRIBUTED TO THE TANKER TRANSPORT OF 1.OE12 BTU/YR. A 200000 2499 DWT TANKER CAN CARRY 1.65EO6 BBL CRUDE (2007,10-7) SO THAT 2599 1.7,8E05/1.65EO6 TIMES 4.75EO6 $ IS ATTRIBUTED TO SUPERTANKER 2699 TRANSPORT OF 1.OE12 BTU/YR. NO INFORMATION AVAILABLE ON 2799 INCREMENTAL OPERATING COSTS. THE CREDIT FOR OIL NOT DISCRARGED2899 BASED Oil 7.3 C/GAL CRUDE AMOUNTS TO ONLY 465 $/YR,. 2999 2127 199 BASED ON FOOTNOTE 2126 .0288P OF THE OIL TRANSPORTED IS LOST 29 THROUGH LEAKS,SPILLS,ETC. FOR 183000 BBL/YR OF PETROLEUM 399 PRODUCTS (1.OE12 BTU/YR) THIS AMOUNTS TO 8.07 TON OIL/YR. THE 499 PRIMARY EFFICIENCY IS 99.9712P BASED ON THE ABOVE. 599 THE INCREMENTAL CAPITAL COST OF A DOUBLE BOTTOM CONSTRUCTION 69 FOR A 40000 DVT TANKER GIVEN IN FOOTNOTE 2126 SHOULD BE 79 MULTIPLIED BY 183/352 AND ANNUALIZED AT 10P TO GET THE 899 INCREMENTAL COST FOR TANKER TRANSPORT OF 1.OE12 BTU/YR OF 999 PETROLEUM PRODUCTS. SIMILARLY THE INCREMENTAL CAPITAL COST FOR10 99 A 200000 DWT SUPERTANKER GIVEN IN FOOTNOTE 2126 SHOULD BE 1199 MULTIPLIED BY 1.83E05/1..65E06 AND ANNUALIZED AT 10P TO GET THE1299 INCREMENTAL COST FOR SUPERTANKER TRANSPORT OF 1.OE12 BTU/YR OF1399 PETROLEUM PRODUCTS. THE CREDIT FOR PRO DUCT NOT DISCHARGED 1499 BASED ON 9.5 C/GAL(RESID) AMOUNTS TO ONLY 545 $/YR. 1599 2128 199 1.0E12 BTU/YR OF GASOLINE IS EQUIVALENT TO 8E06 GAL GASOLINE/YR. 29 (0002,4-5) INDICATES AN UNCONTROLLED EMISSION RATE OF 9.5 LB 399 HC/1000 GAL AND (2038,11) INDICATES A 95P REDUCTION IN 499 EMISSIONS WITH THE USE OF A COMPRESSION-LIQUEFACTION VAPOR 599 RECOVERY SYSIEM. THIS REDUCES THE EMISSIONS TO 1.89 TON HC/YR. 699 BASING THE HC EMISSION HEATING VALUE ON THATOF GASOLINE GIVES 799 A 99.99P PRIMARY EFFICIENCY FOR THIS SYSTEM. THE COST FOR THIS 89 SYSTEM IS GIVEN IN FOOTNOTE 2129 AND INCLUDES THE COST FOR 999 CONTROLING HC EMISSIONS FROM BOTH SERVICE STATION TANKS AND 1099 THE FILLING OF AUTCMOBILE GAS TANKS. 1199 2129 199 (0002,4-5) INDICATES AN UNCONTROLLED HC EMISSION RATE OF 12.0 LB 2991 HC/1000 GAL FOR FILLING AUTO TANKS. (2033,4) NOTES THAT .7 LB 3991 HC/1000 GAL IS DUE TO SPILLAGE AT THE VEHICLE. ASSUMING THAT 42 THE SPILLAGE IS NOT CONTROLLED AND THAT A 95P EFFICIENT 599 CCMPRESSION-LIQUEFACTION VAPOR RECOVERY SYSTEM IS IN USE, 699 1.265 LB BC/1000 GAL WOULD BE EMITTED IN THE CONTROLLED 799- FILLING CF AUTOMOB ILE GA S TA NKS. BA SED 01 190500 BBL GASOLINE 899 /YR (EQUIVALENT TO 1.OE12 BTU/YR,FROM (0005,38)) THIS RESULTS IN 5.0,6 TON HC/YR EMITTED. BASED ON THIS EMISSION AND A 1099 HEATING VALUE FOR THIS EMISSION SIMILAR TO THAT FOR GASOLINE, 1199 THE PRIMARY EFFICIENCY FOR THIS CONTROLLED PROCESS IS 99.97P. 129 (2039) INDICATES THAT FOR A LARGE SERVICE STATION PUMPING 1399 960000 GAL GASOLINE/YR, THE C0ST OF A COMPRESSION 1499 LIQUEFACTION VAPOR RECOVERY SYSTEM IS $8000 CAPITAL COST (FOR 1599 IV-42 FTN. 2129 (CONT) EQUIPMENT AND INSTALLATION COSTS) AND 800 $/YR IN OPERATINGQ 1699 AND MAINTENANCE COSTS. FOR 1.OE12 BTU/YR (8EO GAL/YR) THESE 1799 COSTS ARE 6.66EO3 $/YR CAPITAL (AT 10P FCR) AND 6.66EO3 $/YR 1899 OPERATING FOR A TOTAL ANNUAL COST OF 1.33EO4 $/YR. HOWEVER 1999 BASED ON THE DIFFERENCE IN HO EMISSIONS FOR THE UNCONTROLLED 2099 AND CONTROLLED CASES FOR THE FILLING OF BOTH SERVICE STATION 2199 AND AUTOMOBILE TANKS, 79.05 TON HC/YR ARE NOT EMITTED WITH THE 2299 USE OF THE CONTROL SYSTEM. CONSIDERING THIS SAVINGS TO BE 2399 EQUIVALENT TO GASOLINE AND VALUED AT 12.5 C/GAL YIELDS A 2499 CREDIT OF 3204 $/YR. THUS THE TOTAL INCREMENTAL ANNUAL COST 2599 FOR THIS CONTROL SYSTEM IS 1.01EOR $/YR. 2699 IV-43 0) 2 3 4 5 6 7 a H) 13 1. 15 1. .1 a 19 to 21 22 0 24 25 t. V. WATER POLLUTANTS (TONS ljo't BTU, EX. COL 12) MR POLLUTANTS ITOWRISON M) CCUPAT-M. NE.ITH 'vFt.TT&L 013-111 SOLIDS WSPENDED TOTAL INERISM. PANT- WON- ALD "TTNEB SOL- R LE "a""T R ACT-11 PROCESS so. con .0. C. 'E TOTA __O.. RASTER ONSAMCS C e I Ft. L - OSCA NOR ACtOS BASIS PO. No- OTHER T.TAL(DI) SOLIDS 6.7. ILATEI CARENNRR an M T4 4 .4 _S' cl- a _1 .4 7 -- -------- m2;I - ----- - J- 4. U,j -ul 22 A -7 "@n UP. 27 a URA I L.- 4 1 SRI NNA 40 Rm 42 'iz 43 43 Wa 45 77 < 14 NOTE: ALL TABLE ENTRIES ARE SASE4 OR 1012 BTU OF at @ISJEE INTO EACH PROCESS OR ACYIVIT'. TABU 15. ENVIRONMENTAL IMPACTS AND EFFECUMCT HM TRE SEE FOOTNOTE 2000 FOR REA54RE EQUIVALENTS OF 1012 STU. UNCONTROLLED DOMESTIC ON-SEIDIM OF OIL SUPPLY a a .21 I L_ .21 N-I Precediflg page "Ut FOOTNOTES FOR TABLE 15 FTN. 2200-2201 2200 199 BASED ON(2018,59), DOMESTIC ONSHORE OIL HAS AN AVERAGE SULFUR CON- 299 TENT OF 0.81PC.USING THE NATIONAL AVERAGE OF 0.79PC(FRCM FOOT- 399 NOTE 2000) AS A STANDARD, THE ONSHORE PRODUCED OIL CONTAINS 499 2.5.P MORE SULFUR. FUEL OIL FROM THIS CRUDE WOULD CONTAIN'ABOUT 599 1.54PC S & PETROLEUM COKE WOULD CONTAIN ABOUT 1.85PC S.THE SOX 699 EMISSIONS FROM THE CATALYTIC CRACKING OPERATION, AND PROM THE 799 BURNING CF FUEL OIL, PETROLEUM COKE AND REFINERY GASES WILL 899 INCREASE BY 2.5PC'. THESE INCREASES ARE 999 CAT. CRACKER SOX 3.33E-01 TONS/YR 1099 FUEL OIL COMBUSTION 2.08E-01 1199 REFINERY GAS COMBUSTION 5.08E+00 1299 PETROLEUM COKE COMBUSTION 3.90E-01 1399 2201 199 SOX EMISSIONS WILL INCREASE BY 2.5P ABOVE THOSE FROM FOOTNOTE 299 2007(SEE FOOTNOTE 2200). THIS ADDITIONAL SOX E14ISSION AMOUNTS 399 TC .6.58E-01 TONS/YR. 499 Preceding page blank IV-47 I It .3 1. 15 1. 1 IN 1. 2. 21 22 0 94 25 INA JET FUEL REGION RATER POLLUTANTS (TONS/10- STU, EX. COL 121 AIR POLLUTANTS IT00I M) OCCUPATIONAL NEALTN POTENTIAL. I TO `NE..w`L NNDRO_ ALGE"ll SOLIDS LAND 1= Z@ `4' ACTIARTI PRBC@W SOL'.. SUSPENDED TAL 00 coo I CO ETC TOTAIL TONS I m i VmEma@ PD, NO. lawd-m I-Al" CARSAIDN'S "ILASTER DENIER TOTAL( SI ONCMICS _S yal um ACIDS BASES SOLID. 0 1 1 . ..... P, NN, 492@" 4 7 -Jo P., - 7 1 7 AN, s-U . L . . . . A 0 i -10 @ev AN, ARN 1 1) No I 1 -1 I i POW 2w z 236i ij@ i i 2w I.- I 2, !-,- , .. -- -1- -.1- 15 P" n -- TU* - 1- X_ . IF 2, ANA IN ZE` NX *0 BE BE t4 ANN P'. 1 1- -1. i- I AR Be ANA ANN ...... -T L_ , NNA - as .-A. _1@ AN, . . . . . . . . - ANN -ANPI NSA 13 im AN - AX ANA INS! .1m lx2L.CAAR AN - AS NX A. - L-U . m mm@. 37 NNA w si jCI,, INS RE ANN NNA ARM ANN NNA ANN 42 40 40 NOR: At TABLE ERITES ME EASED ON 1012 BTU OF RESOURCE J.RI EACH PROCESS ORICTIVITY. TABLE 10. ENMORMENTAL DVACTS AND EPYWIENIC-3 3%HC THE SEE FOOTNOTE 200 FOR KEASIRK EQUIVALENTS OF 1012 jn@ CONTROLLED DOMMC ON-SHCRE w OIL SUPPLY IV-49 Precedinz pap. 4Rot FOOTNOTES FOR TABLE 16 FTN.2300-2301 2300 199 BASED ON (2018,59), DOMESTIC ONSHORE OIL HAS AN AVERAGE SULFER 299 CONTENT OF 0.81 PC. BASED ON 3.2 PC OF THE S IN THE CRUDE 399 BEING DISCHARGED FROM THE CAT CRACKER REGENERATOR (FOOTNOTE 499 2107), THE CAT CRACKING S02 EMISSION FOR A 178000 BBL/YR 599 REFINDERY (1.OE12 BTU/YR) IS 13.65 TON S04/YR. BASED ON 48.8 699 PC OF THE S IN THE CRUDE AS H2S IN THE REFINERY PROCESS GAS 799 (FOOTNOTE 2066), WITH .3 TON S EMITTED IN THE COBUSTION OF 899 THIS PROCESS GAS (FOOTNOTE 2101), AND WITH A 99.9 PC RECOVERY 999 OF THE S IN THE PROCESS GAS SENT TO THE CLAUS PLANT AND TAIL- 1099 GAS UNIT (FOOTNOTE 2101), .21 TON OF S02 ARE DISCHARGED YEARLY 1199 FROM THE CLAUS UNIT. FUEL COMBUSTION S02 EMISSIONS ARE THE 1299 SAME AS GIVEN IN FOOTNOTE 2101 AND ARE LIMITED BY REULATIONS 1399 2301 199 FROM FOOTNOTE 2300, THE CAT CRACKER SO2 EMISSION FOR A 1.OE12 BTU/ 299 YR REFINERY IS 13.65 TON SO2/YR. FOR 1.OE12 BTU/YR INPUT TO 399 THE CAT CRACKER MULTIPLY THIS BY 1.98 (FOOTNOTE 2107). 499 Preceding page blank IV-51 1 2 3 A A 6 1 6 a 13 1. to If 11 IN 1. zo 12 Is A. 25 1. 2' WATER POLLUTAWTS (TONS/,o" on. EX, COL .2) - A:R oAL.,_1s (Yox@,,dl m) occ PATRWAL HEALTH POTAWT- AWCR.LARY ANNE. -61--11mVEO SOLIDS AUSIA[w. TOY. ALAW-DAY-5 LA:.!-l A, o. so. O@L "' I "" - AC A It".41 1- COVS .1.=.. TAN o TOTAL T- CRE , ...RIEs -m OEATH5 ACTIVITY PROCESS AC.D. BASES Po. WO. OTHIE TOTALMS), URA CAFJACNS 10 on LM"C" BTU DISASTER 3"U'd Im P.- 4 5 I- I 1 11 01 1 14 I Ti -1-1 id I I Io. 'o HI 12 12 .3 -MM 13 -TJ -A IH. I i: 1 1 1 -10 12- 17 IS Is WAY -1 AAW M 22 AW I HIT, AIJ -1 1 H. 23 VIA. I 24 _L4 t-- I A. HW 25 Be 26 27 H. -h- 27 AA I A ------ 1- ------- @ta- _-1 I WAY I WAY, SO 3, ";,Y 321 HIM 331 Ell! ga I- LffiU _L4 WAY I- "A.- WAY 35 AN ------ - --Y. . 2i WAY -1 AN ARY I WAY so A. A, @il_ V--W-- AWA AW AWA_ AWA- 43 43@ 4511 4' AN NOTE: ALL TABLE EITILES ARE BASED 01 ID12 $TO Of RESOURCE INTO EACH PROCESS OR ACTIvITT. TABLE 17. ENWRONMENTAL IMPACTS AND EFFXIE@@f FOR THE SEE FOOTNOTE 2ACO FOR REASURIE EQUItALIENTS Of WE BTU. UNCONTROLLEU DOMESTX OFF-SM&E BEGM OF OIL SUPPLY I ESl [email protected] @PRO IV-53 Preceding page blank FOOTNOTES FOR TABLE 17 FTN. 2202-2203 2202 199 BASED ON (2018,59), DOMESTIC OFFSHORE OIL HAS AN AVERAGE SULFER 299 CONTENT OF 0.61P. USING THE NATIONAL AVERAGE OF 0.79P (FROM 399 FOOTNOTE 2000) AS A STANDARD, THE OFFSHORE PRODUCED OIL CON- 499 TAINS 24.7 LESS SULFER. FUEL OIL FROM THIS CRUDE WOULD CON- 599 TAIN ABOUT 1.16PC S AND PETROLEUM COKE WOULD CONTAIN ABOUT 1.39P 699 SULFER. THE SOX EMISSIONS FROM THE CATALYTIC CRACKING OPERAT- 799 TION, AND FROM THE BURNING OF FUEL OIL, PETROLEUM COKE AND RE- 899 FINERY GASES WILL DECREASE BY 24.7PC. THESE DECREASE ARE 999 CAT. CRACKER SOX 3.29E+OO 1099 FUEL OIL COMBUSTION 2.05+00 1199 REFINERY GAS COMBUSTION 5.01E+01 1299 PETROLEUM COKE COMBUSTION 3.85E+00 1388 2203 199 SOX EMISSIONS WILL DECREASE BY 24.7P BELOW THOSE FROM FOOTNOTE 299 2007 (SEE FOOTNOTE 2202). THIS DECREASE AMOUNTS TO 6.50E+00 399 TONS/YR. 499 Preceding page blank IV-55 IV-55 On M11 - A 's 20 2. 22 a 2. go To r, WATER POLLUTANTS (TONS/10' BTU, EX, COIL. tR J MR POLLUTANTS ITOR$11e M) ... ,"T"", """T" AN,HL,WD, r SCAL rE`@ DIRSOL@D SOLIDS SUIPEar. TOTAL sN CARROND 10 CfAPN2 LURE I wom: A(IIHITI PROCESS TOIALt.W "s 6.T.8 BOB COD ISASTE. RKIN. ACID3 BASES PC,. ROLM, DRUNKS NO @11 CAI_ m -T 4 I.N ----------- -- --------- .1. IPP I--- Wei s,, l- 15 IlT. -111r- -7 WP4 PA nal Wll RO 22 En --m- t4 l :-7. l I--- I I WN I---- P_ OR PP. _mL --ma I--- l NO I WWI -m ma AN PUl1= .a @ - im- All, -'- , -1. _. , - 1-' - !:-., - :- . l 30 1 AW "N- CUP 3 PAN 1. 1--- 1 WU AND ------- EBI PRE NNA 24 So - . - f .- . AN w .-PAN I "I I PAN AW mum- AN AWA Z.. I I - -1 1 - - ANA AN - - ARN Now AM - L..' I - - PAN, _d -1 -1 ANN A_ Poll JUL- '12 44 4? IND NOTE: ALL TABLE EkT21ES ARE USED ON 1012 BTU OF RESOURCE IRTo EACH PROCESS OR ACTIVITT. SEE FOD"Ort IM FOR KEASURE EQUIVALENTS OF ID12 BTU@ TABLE 18. ENVIRONMENTAL IMPACTS AM EPKCIEUL 1M CON77UNAM DOMESTIC OFF-SRORR Do OF OIL StIPPLY IV-57 Preceding page bla!A FOOTNOTES FOR TABLE 18 FTN 2302-2305 2302 199 BASED ON (2018,59) , DOMESTIC OFFSHORE OIL HAS AN AVERAGE SULFUR 299 CONTENT OF 0.61 PC. bASED ON 3.2 PC CF THE S IN THE CRUDE 399 BEING DISCHARGED FROM THE CAT CRACKER REGENERATOR (FOOTNOTE 499 2107), THE CAT CRACKING S02 EMISSION FOR A 178000 BBL/YR 599 REFINERY (1.OE12 BTU/YR) IS 10.25 TON S02/YR. BASED ON 48.8 699 PC OF THE S IN THE CRUDE AS H2S IN THE REFINERY PROCESS GAS 799 (FOOTNOTE 2066) , WITH . 3 TONS EMITTED IN THE COMBUSTION OF 899 THIS PROCESS GAS (FOOTNOTE 2101), AND WITH A 99.9 PC RECOVERY 999 Of THE S IN THE PROCESS GAS SENT TO THE CLAUS PLANT AND TAIL- 1099 GAS UNIT (FOOTNOTE 210l) , .16 TON OF S02 IS DISCHARGED YEARLY 1199 FROM THE CLAUS UNIT. FUEL COMBUSTION S02 EMISSIONS ARE THE 1299 SAME AS GIVEN IN FOOTNOTE 2101 AND APE LIMITED BY REGULATIONS.1399 2303 199 LAND REQUIREMENTS FOR PRINCIPAL SULFUR RECOVERY PROCESS EQUIPMENT, 299 STOPAGE, INCINERATOR AND STACK,CHANGES TO 2.91E-C4 ACRES(FROM 399 FOOTNOTE 2105) AND RESULTS IN A TOTAL INCREMENTAL LAND 499 REQUIREMENT FOR CONTROLS ON A 1.OF12 BTU/YR REFINERY OF 2.05E 599 --2 ACRES. THIS IS PROVIDED FOP IN THE REFINERY FIGURE GIVEN 699 IN FOOTNOTE 2040. 799 2304 199 BASED ON FOOTNOTE 2125 ANL 0.61 PC S IN THE CRUDE, THE ENERGY 299 REQUIREMENT FOR OPERATION OF THE CLAUS PLANT AND TAIL-GAS 399 UNIT IS 1.71E)8 BTU/YR.FROM FOOTNOTE 2125 THE ANCILLARY 499 ENERGY REQUIREMENT FOR A 1.OE12 BTU/YR REFINERY CHANGSES To 599 5.04E10 BTU/YR. 699 2305 199 FROM FOOTNOTE 23C2,THE CAT CRACKER S02 EMISSION FOR A 1.OE12 BTU/ 299 YR REFINERY IS 10.25 TON S02/YR. FOR 1.OE12 BTU/YR INPUT TO 399 THE CAT CRACKER MULTIPLY THIS EY 1.98 (FOOTNOTE 2107). 499 Preceding page blank IV-59 1 2 1 .4 5 A ? A, 9 1. IS ;4 15 1. 11 .8 1. 29 1. 22 24 2. 1 1.11 REGION RATER POLLUTANTS (TONS/10" BTU. El Cft 12) AIR POLLUTANTS (TMlIOP BTU) OCCUPAT-AL T- [jM-AByT5, D,LAR-EN ACTIVITY PROCESS DISSOLVED SOLIDS SUSPENDED TOT L coo PAHTIC- So. NYmo - Co ALOR.- 1TIM"SI-S -DERT., N@RIEIS _@D SCALE ACA)s BASES RCR.IDS C So. -le'ST ETC, TOM OTHER TOTAL(DS) PE6 No. CH-C. A ;W@';7U SASTE T"ll, 2 4 NA, 1, It. 1.1 -1 1: 7 6 a-A AN, IIN 10, r- 1 11-1 12 13 A -1 1; 1 1 1 1 - - --------- I- I U- I z MA NN I- - I I UP S, AN !m I 1 -1 1- 1.-, 1 R- to U. I- INY N. A. 1. -1 1 ms N. AN, A- 1 71- 1 1 I2i I AW IRA AN, .m i,- A.I 3. AN IIP I I.- AIR -I, -- ANA A, IATY L.- AN, SON A, S31 PRA I A. -I ANNI-IIANA SIR UP ANA SIR 3. SIR All -,, 4-nif AIR NOTE: A L L ;,ABLE EXTRIES ARE "SED 0. IDI@ BTU OF. RESOURCE INTO EACH "OCES Sr OR ACT11ITY. TA13LE 19, ENVIRONMENTAL WACTS AND EFFIcTmicy THE SE THOn 2003 FOR REASURE EQUIMENTS, of TO IZ BTU.. UNCONTROLLED VAPORTED CANAD11N REGION OF OIL SUMY Preceding PF Mgt --iEti-9o FOOTNOTES FOR TABLE 19 FTN..2204-2205 2204 199 BASED ON(2019,1/13), CANADIAN CRUDE OIL HAS AN AVERAGE SULFUR CON- 299 TENT OF 0.59P. USING THE NATIONAL AVERAGE OF 0.79P (FROM FOOT- 399 NOTE 2000) AS A STANDARD, THE CANADIAN OIL CONTAINS 25.3P LESS 499 SULFUR. FUEL OIL FROM THIS CRUDE WOULD CONTAIN 1.12P S & PET- 599 RCLEUM COKE WOULD CONTAIN 1.34P S.THE SOX EMISSIONS FROM THE 699 CATALYTIC CRACKING OPERATION, AND FROM THE BURNI.NG OF FUEL 799 OIL, PETPOLEUM COKE AND REFINERY GASES WILL DECREASE BY 25.3P. 899 THESE DECREASES ARE 999 CAT. CRACKER SOX 3.37E+00 TONS/YR 1099 FUEL OIL COMBUSTION 2.10E+CO 1199. FEFINERY GAS COMBUSTION 5.13E+01 1299 PETROLEUM COKE COMBUSTION 3.94E+00 1399 2205 199 SOX EMISSIONS WILL DECREASE BY 25.3P BELOW THOSE FROM FOOTNOTE. .299 2007(SEE FOOTNOTE 22C4). THIS DECREASE AMOUNTS TO 6.65E+00 399 TONS/YR. 499 Precedini PaRe blank IV-63 1 2 3 5 a I AN TA NO 11 .3 14 1. ED 9. 22 25 2. to SIR 2" FUEL WATER POLLUTAWS (TORSI,.'- ST., IN, COL.M) AIR POLLUTARTS I-Ile BTU) OCCLARITIONAA. HEALTH RML Dill YEN EBYUU IN@AHFNIIES ACTIVITY PROCESS ols@@ SOD RAAV.C- .0. C. -n TOTAL, to NERL -.?A ULA 99 ASEL ACIDS BASES PON Ro. To,- CARICIRS T, It ANA 4441 L. -1- -L. _- -1 1- 1 3 A AAW I I RAN 1. 1 1 1 11. *- 1 1. A A I 1 -1 . . .... .... AN, A---, . WN, t_ 4 5 1 -1 1 1 LL.-L. _W, ANA 6-1 ANA ANN RN, P., ANN AN ------ Z_ _--- .1 s Mb z AAW L,@ ,ANA _L1 ILAN a RA, -_ M, 1 - HN, r?- . v-sw! PAR ANA .8 9 PAN, - PAR, .,2o, ARN @o- v 1---, ANN ANN - ANA - ANN AWN NN, 1 1 AWN @1_ NNA -Lo ,1- 1-- AWN 1- 1 1- i I I AHN I I- I- - PAR - - - ANI, l- . AR AN. .1 1 IN. IN. ANN - - am mm -11 1 - NNNI ANA 3 ANN I I ANN HNN I-. I I I EL NA, ANN, IS ANA RAN iita2ii@t - - - i WAN Is Is ANN ANN ANA 1-1. l- l.- 1-1 -- WH Us 17 AW RAN WAN __m ___@ ------ L!=j__ EY 10 WA -1 RAN AN. I L_ aL -AW ANN WAR ANN WAN ARN AWN l. ANN ANN AWN AW I -I.- I --ci TED 4 ANA, ARN -1 PAN A. ARN ANN NNAN ANN WIN ANN -1 ANN ANA ANN WAN ANN ANN A ANA ANA m m - ------ mi m a- ANN 1- 1 1 - I .. im@ 3 ANN ANN AWN vvs NNA - - - - - - I I.- 1 .1 1.11 1- 1 ------ m - AWN SEES SEEIE - ANN - - - m L,-, , t -, - , AT, t I PAR ANA ANNA AN. 25 ME - m wm 1-3 l.-I -1 PAR ANAN Al. ES PANa ANN ANN AN, ANA ------ -- 1- AWN I JOEL NN'll- !_._4 ANN ANN 9t. ANN ANA -1 --b- A- I-N, AWN RAN ANN SUN NNANA - S NNAN I- .- I I- I-- WN1 ANN ANAN so AAAJ RAN RAN ANN WAR m ANN RAN z - I-- AWN L-- AWN ANN, AAA_._ TIED 3, WAR ANN, ANN ANA -1 ANA ANN . 1- 1 l. I'm 11- 1 - I .."I ANA RAN ANN PART P- . - Z A- AWN I ANN m AWN - ANT ANN, 3,12, ZEMM SA ANA AIR AWN PAR PAR ANN ANN RAN alA* A ANN ANN - WAN RAN as As AAW -1 ANA ANN -1 ANA NAR, AWN ANN, L- ANNA ANN ANN RAN ANN ANN, - ARN -_ SIT vi NIS 47 NUTT: ALL TABLE ENTRIES ARE SED 04 1012 BTU OF RESOURCE INTO EACH PROCESS OR ACTIVITY. TABLE 20. ENVERONAIENTAL DeACTS AND EFFICIRMC-Z KE THE SEE FOOTNOTE 2000 FOR MASBIIE IQUIMEMTS Of 1012 gjU, CONTROLLED 11MMORTED CANADVIAF REGION OF OIL SUPPLY Preceding pop UFA IV-65 Ow FOOTNOTES FOR TABLE 20 FTN. 2306-2309 2306 199 BA SE D ON (20 19, 1/13) CAN ADI AN CRUDE OIL HAS AN AV ERAGE SU LFUR 299 CONTENT OF 0,59 PC. BASED ON 3.2 PC OF THE S IN THE CRUDE 399 BEING DISCHARGED FROM THE CAT CRACKER REGENERATOR (FOOTNOTE 499 2107),THE CAT CRACNER S02 EMISSION FOR A 178000 BBL/YR 599 REFINERY (1.OE12 BTU/YR) IS 9.94 TON S02/YR. BASED-ON 48.8 699 PC OF THE S IN THE CRUDE AS H2S IN THE REFINERY PROCESS GAS 799 (FOOTNOTE 2066),WITH .3 TON S EMITTED IN THE COMBUSTION OF 899 THIS PROCESS GAS (FOOTNOTE 2101)., AND WITH A 99.9 PC RECOVERY 999 OF THE S IN THE PROCESS GAS SENT TO THE CLAUS PLANT AND TAIL- 1099 GAS UNIT (F 'OOTNOTE 2101), .15 TON OF S02 ARE DISCHARGED YEARLY1199 FROM THE CLAUS UNIT. FUEL COMBUSTION S02 EMISSIONS ARE THE 1299 SAME AS GIVEN IN FOOTNOTE 2101 AND ARE LIMITED BY REGULATIONS.1399 2307 199 LAND REQUIREMENTS FOR PRINCIPAL SULFUR RECOVERY PROCESS EQUIPMENT, 299 STORAGE, INCINERATOR AND STACK,CHANGES TO 2.82E-C4 ACRES(FROM 399 FOOTNOTE 2105) AND RESULTS IN A TOTAL INCREMENTAL LAND 499 REQUIREMENT FOR CONTROLS ON A 1.OE12 BTU/YR REFINERY OF 2.05E 599 -02 ACRES. THIS IS PROVIDED FOR IN-THE REFINERY FIGURE GIVEN 699 IN FCOTNOTE 2040. 799 2308 199 BASED CN FOOTNOTE 2125 AND 0.59 PC S IN THE CRUDE, THE ENERGY 299 REQUIREMENT FOR OPERATION OF THE CLAUS PLANT AND TAIL-GAS 399 UNIT IS 1.66EO8 BTU/YR. FROM FOOTNOTE 2125 THE ANCILLARY 499 ENERGY REQUIREMENT FOR A 1.OE12 BTU/YR REFINERY CHANGESTO 599 5.04E10 ETU/YR. 699 2309 199 FROM FOOTNOTE 2306,THE CAT CRACKER S02 EMISSION FOR A I.OE12 BTU/ 299 YR REFINERY IS 9.94 TON S02/YR. FOR 1.OE12 BTU/YR INPUT TO 399 THE CAT CRACKER MULTIPLY THIS BY 1.98 (FOOTNOTE 2107). 499 'Preceding page blank IV-67 A .4 1 6 7 0 10 11 IS 6 17 1. @o 2. 24 25 17 FUEL I OCCUPATIONAL HEALTH JPDFENTIAL I ACTIVITY PROCESS Ds SU TNTED AL C. JR@IZ P [ DEATHS Boo D C - I iNjURIES No OTHER TOTAL WSI SOLIDS -.,cs c- Es o. D WATER POLLUTANTS (T- I I. BYI,, E., COL 121 AIR POLLUTARTY15 (To,is'Foll ST.) Z ACIA -E DISSOLVED 50LI TOTAL A.D. BASES pot. No, --o- 7 4 -5- T- I -S o I AW 1; is .-A ---------- 77- IIIH -1 HT, , HII IS 2-1 22 4@m 14 2 41 I's 2T AW. I, I, ANY -T I A 1 -1 1 So ..L I A., @IVHII-v 301 jT . . . ..... A- I ARI 32 131 m- -...DLE- ?I.W AW. _em_- WIN MW Sal 381 7 PAY -j AW ASIA 1 -1 L- 4f All 7 tT 44 7 47 11111 All ;.IlllollTIIEI A, lAllD DR loll U OF EXCi! PRDCES$ DR ACTIV:TY. TABLE 2 1. ENVIRONMENTAL IMPACTS AND EFFMCSfENCY FOR THE ,R E ..D FO R @ADR E EQUIVALEATS OF 101 U- UNCONTROLLED IMPORTED MMMZ EAST CRDDE REGION OF OIL SUPPLY IV-69 Preceding page Hank w FOOTNOTES FOR TABLE 21 FTN. 2206-2207 2206 199 BASED ON(2019,1/13), MIDDLE EAST CRUDE OIL HAS AN AVERAGE.SULFUR 299 CCNTENT CF 1.92P. USING THE NATIONAL AVERAGE OF 0.79P(PROM 399 FOOTNOTE 2000) AS A STANDARD, THE MIDDLE EAST OIL CONTAINS 499 143P MORE SULFUR. FUEL OIL FROM THIS CRUDE WOULD COMIN 3.65P 599 SULFUR AND PETROLEUM COKE WOULD CONTAIN 4.37P S. THE SOX 699 'EMISSIONS FROM THE CATALYTIC CRACKING OPERATION, AND FROM THE 799 BURNING OF FUEL OIL, PETROLEUM COKE AND REFINERY GASES WILL 899 lNCREASE BY 143P. THESE INCREASES ARE 999 CAT. CRACKING SOX 1.91E+01 TON/YR 1099 FUEL OIL COMBUSTION 1.19E+01 1199 REFINERY GAS COMBUSTION 2.91E+02 1299 FETROLEUS COKE COMBUSTION 2.23E+01 1399 2207 199 SOX EMISSICNS WILL INCREASE BY 143P ABOVE THOSE FROM FOOTNOTE 299 2007(SEE FOOTNOTE 2206). THIS INCREASE AMOUNTS To 3.76E+01 399 TONS/YR. 499 Preceding page blan@ IV-71 I IT 3 4 5 7 a 9 10 11 13 14 15 16 .1 .9 20 21 92 0 24 25 WATER POLLUTANTS (TO.Sl..--.TL.EX.C0LA2) AIR POLLUTART5j7OW3@H)" BTU) OCCUPIVI'lONAL HEALTH "OlIENTUIL ..... DISSOLVED SOLIDS I SUSPEAE)jDF I TOTAL I I tlIERAAAA@ NURTR' SOLIDS L. Im,A a MOANAll ._ EITU, IS ST. (mmn) @OSFTAOMIS AC.DY, 5 pc@ NO. :BTLUV.`m ULAT NVOIN TONS I "No BASE OTHER TOTALRITI) 1 - I I I i A- i. I 7 .o C.- AHN AN lo AW 12 .3 ANN WIN z x= a- A nm 14 IS - - - --------- 17 IS is -Ul W UNN I. 2, z2 -a " --- --= ------ nU 4- A 241_j ------- 9* 4 21 HAN RN, N- 27 ERM, 1- 11-1 1 .11 HN Bo ANN I I I -NNA 1 4- -2 EST, WIN @' IY" IRS 37 - ----- ANN A A ANN @a- AN, D. am 41- -6- ANN NOTE: ALL ;AZLl,ElTAr!S slE EASID o. 12 BTU OF RFSaURCE INTO rACN .ROCES5 OR ACTIVITY. TABLE 22. ENVIRONMENTAL IMPACTS AND EFFICIENE-3 FM THE E ZC@ -St RE@Ult fQIIIVAIMS 01 1012 BTu. CONTROLLED IMPORTED MIDDLE Cmrsm OOTV T REGION OF OIL SUPPLY Preceag Pago mank ME @ @E E if 'Ell ------------- FOOTNOTES FOR TABLE 22 FTN. 2310-2313 2310 199 BASED ON (2019,1/13), MIDDLE EAST CRUDE OIL HAS AN AVERAGE SULFUR 299 CONTENT OF 1.92 PC. BASED ON 3.2 PC OF THE S IN THE CRUDE 399 BEING DISCHARGED FROM THE CAT CRACKER REGENERKTOR (FOOTNOTE 499 2107),THE CAT CRACKER S02 EMISSION FOR A 178000 BBL/YR 599 REFINERY (l.CE12 BTU/YR) IS 32.3 TON S02/YB. BASED ON 48.8 699 PC OF THE S IN THE CRUDE AS H2S IN THE REFINERY PROCESS GAS 799 (FOOTNOTE 2066)#WITH .3 TON S EMITTED IN THE COMBUSTION OF 899 THIS PROCESS GAS (FOOTNOTE 2101), AND WITH A 99.9 PC RECOVERY 999 OF THE S IN THE PROCESS GAS SENT TO THE CLAUS PLANT AND TAIL- 1099 GAS UNIT (FOOTNOTE 2101), .49 TON OF S02 ARE DISCHARGED YEARLY11S9 FROM THE CLAUS UNIT. FUEL COMBUSTION S02 EMISSIONS ARE THE 1299 SAME AS GIVEN IN FOOTNOTE 2101 AND ARE LIMITED BY REGULATIONS.1399 2311 199 LAND REQUIREMENTS FOR PRINCIPAL SULFUR RECOVERY PROCESS EQUIPMENT, 299 STORAGE, INCINERATOR, AND STACK CHANGES TO 9.16E-C4 ACRES(FROM 399 FCOTNOTE 2105) AND RESULTS IN A TOTAL INCREMENTAL LAND 499 REQUIREMENT FOR CONTROLS ON A l..OE12.BTU/YR REFINERY OF 2.12E 599 C2 ACRES. THIS IS PROVIDED FOR IN THE REFINERY FIGURE GIVEN 699 IN FOOTNOTE 2040. 799 2312 199 BASED ON FOOTNOTE 2125 AND 1.92 PC S IN THE CRUDE, THE ENERGY 299 REQUIREMENT FOR OPERATION OF THE CLAUS PLANT AND TAIL-GAS 399. UNIT IS 5.40EO8 BTU/YR. FROM FOOTNOTE 2125 THE ANCILLARY 499 E.NERGY REQUIREMENT FOF A 1.OE12 BTU/YR REFINERY CHANGES TO @9� 5.07E,10 ETU/YR. 699 2313 199 FRCM FOOTNOTE 2310,THE CAT CRACKER S02 EMISSION FOR A 1.0912 BTU/ 299 YR REFINERY IS 32.3 TON S02/YR. FOR 1.OE12 BTU/YR INPUT TO 399 THE CAT CRACKER MULTIPLY THIS BY 1.98 (FOOTNOTE 2107). 499 IV-75 Preceding page blank M - -Fo P-6, 0 11 12 .1 14 1. IN, IN n @4 KFALTH POTE.TIAL -------;ATRR -PoLLuTANTs Tr-O N S 1-0 . T. I AIR POLLUTRAF75 L@/]O'- STU) OCCUPATIONAL E _A, ANCILLARY NNE O-@@ro S.LIUS 1-8 1-0 MAN-DAYS LAP ENXPQ1 I I. G - Pm Al 1IT1 PROCESS -T., AA-C- .0. SO,, C 0 TOTAL TO DEATHS 1NA)RIES SCALE Ow NO OT.ER TOTAL(05) CROA-S w. M 10STU LMTAd'Bn 0, SAS A1ON .1111 10. 1., (ipL.- TER MI -1 I-L -1- T 9 10 UI 72 i3 11 14 Is 1_7 IN Is - ----------------t- - ------------------ 2, 12 n 25 26 W So IT, 33 b4 3. r, SO .L? 41 42 44 41S A N'd I'-- I I i NOTE; ALL Tf ENTRIES "I BASED 01 1012 STU OF RESOURCE INTO EACH PROCESS OR ACTIVITIf. TABLE 23.. MVICRONMENTAL UWACTS AND EIPF@ FOR THE SEE FOOTNOTE EM FOX RZASVRE EQUIIJILEXTS OF 1012 STU. UNCONTROLLED SOUTH A%ffRTtXA 1MSWUAL REGION OF OIL SUPPLY IV-77 Preceding pne blank @-C @-*- FOOTNOTES FOR TABLE 23 FTN. 2208-2210 2208 199 THE MAJOR SUPPLIER OF SOUTH AMERICAN RESIDUAL FUEL OIL TO THE U.S. 299 IS VENEZUELA WITH 26/1.92OE8 BBLS) OF THE TOTAL RESEID IMPORT. 399 BY THE U.S. IN 1971 (2020,12). VENEZUELAN RESID WAS IMPORTED TO 499 THE U.S. WITH THE FOLLOWING SULFER DISTRIBUTION, BASED ON 599 (2020,42) 699 PERCET (WT) SULPER BBLS VOL (PC) 799 LESS THAN 0.3 6,079,000 3.2 899 0.31-0.50 9,490,000 5.0 999 0.51-1.00 45,906,000 24.0 1099 1.01-200 37,500,000 19.6 1199 GREATER THAN 2.00 92,505,000 48.2 1299 BASED ON THE ABOVE DISTRUBTION, THE AVERAGE SULFER CONTENT OF 1399 IMPORTED SOUTH AMER. RESID IS 1.50 (WT). FROM (2020,13), RESID 1499 IS GENRL. CONSUMED IN THE VICINITY OF THE PORT OF ENTRY INTO 1599 THE U.S. THE PRINCIPAL PORT OF ENTRY IS NEW YORK HARBOR WHICH 1699 RECEIVED 26P OF THE NATION'S RESID IMPORTS IN 1971 (2020,13). 1799 FROM (0005,588) RESID HAS A HTG VALUE OF 6.287EO6 BTU/BBL AND 1899 FROM (0010,588) RESIDUAL DENSITY IS 6.04 BBL/TON. THUS 1.OE12 1999 BTU/YR RESID IS EQUIV. TO 159000 BBL/YR. 2099 TRANSPORTATION OF RESID FROM VENEZ. TO NYC IS BY TANKER. THE 2199 ROUNDTRIP DISTANCE FROM VENEZUELA TO NYC IS APPROXIMATELY 4000 2299 MILES, HOWEVER ONLY THOSE AIR AND WATER POLLUTANTS ASSOCIATED 2399 WITH 100 MILES OF TRAVEL WITHIN THE U.S. COASTAL WATERS ARE 2499 ASSUMED TO HAVE ANY ENVIRONMENTAL IMPACTS. FROM FOOTNOTE 2024, 2599 THE FOLLOWING ASSUMPTIONS ARE ALSO USED IN DETERMINING THE 2699 ENVIRONMENTAL IMPACTS OF RESID TRANSPORT BY TANKER 2799 (1) TANKER SIZE IS IN THE 45000 DWT CLASS, BASED ON (2207, 2899 10-7), THE TANKER CAPACITY IS 396000 BBL, SPEED IS 16 KNOTS, 2999 UNLOADING CAPACITY IS 20000 BPH, UNLOADING TIME IS 19.8 HRS. 3099 (2) FUEL OIL FOR STEAMSHIPS CONTAIN 1.5P S, BASED ON AVERAGE 3199 SULFER CONTENT OF RESID TRANSPORTED. 3299 (3) EMISSION FACTORS FOR STEAMSHIPS UNDERWAY AND IN-BERTH 3399 FROM (0002,3-11) 3499 (4) TUGBOAT EMISSIONS BASED ON FOOTNOTE 2024 3599 (5) ACTUAL UNLOADING TIME FOR 159000 BBLS RESID IS 8 HOURS 3699 BASED ON ASSUMPTON (1). TOTAL IN-BERTH TIME IS ASSUMED TO BE 3799 24 HRS. 3899 AIR POLLUTANTS (TONS/YR) 3999 COASTAL IN-BERTH TUGBOAT 4099 COMPONENT EMISSIONS EMISSIONS EMISSIONS 4199 PARTICULATES 2.00E-02 7.50E-03 1.00E-02 4299 SOX 5.33E-01 2.30E-01 7.50E-03 4399 CO 1.00E-04 4.00E-05 6.00E-03 4499 HC 1.00E-02 4.50E-03 4.50E-03 4599 NOX 2.30E-01 1.00E-01 7.00E-03 4699 ALDEHYDES 2.00E-03 1.00E-03 3.50E-04 4799 WATER POLLUTANTS 4899 FROM (0020,L1/8) TANKERS LOSE APPROXIMATELY 0.11P OF THEIR 4999 CARGOES IN DISCHARGES, LEAKS AND SPILLS. THIS IS ASSUMED TO 5099 OCCUR WITHIN THE COASTAL WATERS OF THE U.S. 5199 2209 199 FROM FOOTNOTE 2071, FOR A STORAGE FACILITY HANDLING 2.2E09 BBLS/ 299 YR, ABOUT 2000 AC ARE REQUIRED. 1.OE12 BTU/YR EQUIVALENT OF 399 RESID IS 59000. AC FOUND BY RATIO. 499 2210 199 FROM FOOTNOTE 2208 AVERAGE LADEN TRIP IS 2000 MI. FROM FOOTNOTE 299 2082 TANKER ENERGY IS 930 TMI/GAL. 159000 BBL/YR RESID IS 399 IV-79 Preceding page blank FTN 2,211-2212 EQUIVALENT TO 2325 TONS. RESID FUEL HEAT CONTENT IS 6.287EO6 499 BTU/BBL. 599 2,211 199 FROM FOOTNOTE 2208, TANKERS LOSE ABOUT 0.11P OF THEIR CARGOES. 299 THUS PE IS 1-.0011, OR 0.9989. 399 2212. 199 BOD LOADING FOR RESlD IS. ASSUMED T0 BE STATISTICALLY SIMILAR TO 299 THAT OF CRUDEE OIL. EMISSIONS BASED ON (2009,TABLE 5) 399 IV-80 1 4 1 6 7 a 10 11 12 -3 1. 15 IS .7 @O @l .... .......... ...... .... . U El COL 121 A,R POLLUTAUTS ITONcI oCcLUNT-Al El". -AR SOLIDS AND LE o coo TI<RNAL. ITT- TOY @A- iNwRiEs 'LAR. ACTIVITY PROCtSs .-ED SOLIDS SUSPENDED TOTAL So RT,C- No' No' L TONS LOST/Doe" CA T EE ACIDS BASES PO6 .1- OTHER TOTAL(Di) SOLIDS .,mcs cws 6.7.8 TUld'.T ULATES 4 7 IT 14 IS HT 20 21 n 24 Z4 BIT N.- 27 US 31 37 T 371 381 4. 42 r 7 V -if 4? 4. NET @-- At NOTE: JU'IUl C I UACE INTO EACH PROCESS OR ACTIVITY, TABLE 24. ENVMOfW-ENTAL IMPACTS AND EFFXEMICT FM THE SEE FOO-1 a 102 BTU, CONTWLLFD SOUTH AMEIUCAN RESLY-AL FMIGION OF OIL SUPPLY 4 5 FOOTNOTES FOR TABLE 24 FTN. 2314-2315 234 199 BASED ON 159000 BBL/YR (EQUIVALENT TO 1.OE 12 BTU/YR FROM FOOTNOTE 299 2208) AND 6.04 BBL/TON, FOR RESID (FOOTNOTE 2208), AND ON A 399 CCNTROLLED DISCHARGE' LEVEL OF .0288 PC OF OIL TRANSPORTED 499 (FOOTNOTE 2126), TRERE IS 7.58 TON/YR OF RESID DISCHARGED' TO 599 WATER COURSES. 699 2315 199 BASED ON FOOTNOTE 2314 THE PRIMARY EFFICIENCY FOR DOUBLE BOTTOM 299 TRANSPORT OF RESID IS 1.0O-000288 OF .9997. 399 Preceding page blank IV-83 V. NATURAL GAS SUPPLY A. Introduction All natural gas data are contained in Table 25. The table, as it appears, presents controlled and uncontrolled natural gas supply impacts. The footnotes following Table 25 are written for the uncontrolled national case. Use of the table for.other situations is described in the following sections. 1. National--Controlled The impacts and costs for the national controlled case are the same as for the uncontrolled case, since there are no regu- lations relating to the combustion of natural gas. With regard to LPG transported by diesel trucks, the 1975 standards permit emissions a't levels above those currently indicated in the com- pilation of Air Pollutant Emission Factors (Reference 0002, page 3-7). 2. Domestic Onshore and Domestic Offshore--Controlled and Uncontrolled The 1968 offshore production of natural gas was approxi- mately four percent of the total U.S. production (Reference 0010,page 63, 108). Aside from production, the only activity for which impacts for offshore and onshore gas might differ is that of pipeline transportation. However, since most of the offshore gas is produced in the Gulf of Mexico adjacent to Texas and Louisiana, which together account for about 75 percent of the national onshore production, a local market for the offshore production is not identifiable. Because of the commingling and transport of offshore and onshore gas.from this area through much of the national pipeline system, the allocation of pipeline mileage to offshore and onshore gas, as a basis for computing impacts, is infeasible, and the national average impacts are considered to be applicable for both offshore and onshore gas. to obtain the ONSHORE region from Table 25, delete rows 2, 9, 12, 17, 18, and 19. To obtain the OFFSHORE region froir Table 25, delete rows 3, 9, 12, 17, 18, and 19. V-1 3. Imported Canadia--Controlled and Uncontrolled The 1971 imports of Canadian natural gas amounted to 9.04 (10 11) CF which was approximately four percent of the U.S. mar- keted production (Reference 0004, page 34,35). Canadian gas is used in the states of Washington, Oregon, California, Idaho,l Montana, Minnesota, and Vermont. Allocating the 1971 trans- mission and distribution pipeline mileages for these stats (Reference 0004, page 52) on the basis of the Canadian gas fraction of the total gas inflow to each state (Reference 3005, page 22) gives 39,784 miles, which is approximately 4.6 percent of the national total. Since the estimated percentages of imp ported Canadian gas and of the related pipeline usage are nearly the same, the impacts for transmission and distribution pipelines are about the same for Canadian imported natural gas and domest- tically produced natural gas. To obtain the IMPORTED CANADIAN region from Table 25, delete rows 1 through 9, 12, 13, 17, 18, and 19. (Rows applicable are 10, 11, 14, 15, and 16.) V-2 v-2 B. Impact Data Table and Footnotes v-3 R 1 4 IS 1 1. 14 1. 11 AS .1 1. a t m- RAI NATER POLLUTANTS (TONS/Io' 8TU. EX COL 12) ARI POLLUTANTS MNS/IOA RTN) OCCUPU@USNAL NEALT. dporn-AL I ACTIIITI PROCESS ol.- SOLIDS S, ."T.- 'N NT..- TOM I , I --W-., 1 1 A 3 Do S -Ioll ULA TO om BASES 'SALES AC- AD. NO, O-A AS -no I I -I IA., I N-I 1. A, ON ------ M2 J I AA NNI I 1 -1 1 1 SAN AN, I. U. 4-1 ANN xm:s ANN wm J: IS s XM .11 UNI.... 15 M - ------ ..I . . A . A. . A."- -1. IS -- - ------ !n, -1 1 1 A. A- .N.-, AS -4 ANN I I AU ll!-@ I A. 24 Ad E, AS, m rZ 34 S, 31 1 TUB V7 F t: 7r@@ @ ;Z: T -;A, - @147y- mol@: ALL TABLE EII ARE BASED on I ol"T .aOF ""C"C" INTO EACN PROCESS OR ACTIVITY@ @ABL)i ii MMWMliNTAL 199MG-M MW-n@-AXW)=W SEE FDOTBIOTE 3OGG FOR REASURE EQUIVAILIERTS OF 1012 Stu. FOR UNCONTROLLEMAMcarmuw, Preceding pe., FOOTNOTES FOR TABLE 25 FTN. 3000-3007 3000 199 ENTRIES IN THE TABLE ARE BASED ON AN ENERGY INPUT TO EACH PROCESS 299 OF I.OE12 BTU/YR..THE FOLLOWING TABLE GIVES DATA ON NATURAL 399 GAS AND LPG USED IN THE COMPUTATIONS. 499 599 FUEL NATURAL GAS LPG 699 AVERAGE CALORIC CONTENT (0005,38) 1031 BTU/SCF 95500 BTU/GAL 799 AVERAGE SPEC.WT.(3002,2-10,5-11) 4.6E-2 LB/SCF 4.5 LB/GAL 899 VOLUME EQUIVALENT TO 1.OE12 BTU 9.7E8 SCF 1.048E7 GAL 999 1099 NOTE - SCF = STANDARD CUBIC FOOT (60 DEG F, 14.73 PSIA) 1199 3001 199 BASED ON THE USE OF NATURAL GAS AS PIPELINE FUEL. THE 1970 VALUES 299 FOR GAS USED AS PIPELINE FUEL AND DELIVERED GAS WERE 7.22E11, 399 1.902E13 CF, RESPECTIVELY (0025,758) . PIPELINE FUEL IS 3.67P 499 OF THE SUM OF THESE. THIS IS ALLOCATED TO FIELD/GATHERING AND 599 TRANSMISSION PIPELINE MILEAGES, WHICH WERE 6.65E4, 2.569E5 MI, 699 RESPECTIVELY, IN 1971 (0004,51). THE USE OF GAS ENGINES TO 799 DRIVE THE COMPRESSORS IS ASSUMED, THE EMISSION FACTOR FOR NOX 899 BEING 7300 LB/MMCF (0002,1-9). ALLQCATION TO 1.OE12 BTU/YR 999 GIVES NOX VALUES OF 2.65 T/1.0E12 BTU FOR FIELD/GATHERING,AND 1099 103 T/1.OE12 BTU FOR TRANSMISSION PIFELINES. IF GAS TURBINES 1199 ARE USED THE NOX EMISSION -94CTOR IS 200 LB/MMCF (0002,1-9), 1299 AND THE FOLLOWING NOX VAI:UES SHOULD BE SUBSTITUTED - 1399 FIELD/GATHERING, 0.73 T/1.OE12 BTU, AND TRANSMISSION, 2.82 T/ 1499 1.OE12 BTU. THE DISTRIBUTION MILEAGE IS NOT.INCLUDED IN THE 1599 COMPUTATIONS BECAUSE COMPRESSORS ARE NOT NORMALLY USED ON 1699 DISTRIBU71ON MAINS. 1799 3002 199 BASED ON USE OF DIESEL TRACTOR-TRAILER WITH 9100.GAL PAYLOAL, 299 PAYLOAD AT 62P OF GROSS WEIGHT, 150 GROSS TST/GAL OF DIESEL 399 FUEL, TRIP DISTANCE OF 100 MI LOADED AND 100 MI EMPTY,AND 499 EMISSION FACTORS (0002,3-7). THE FUEL CONSUMPTION IS ESTrMATED 599 TO BE 3.76E4 GAL/1.OE12 BTU FOR THE 200 51 ROUND TRIP. 699 3003 ' 199 POLLUTION OF FRESH WATER BY BRINES RELEASED FROM NATURAL GAS 299 WELLS IS ASSUMED TO BE NEGLIGIBLE BECAUSE OF ENFORCEMENT OF 399 REGULATIONS FOR CONTROL OF POLLUTION BY STATE CONSERVATION 499 COMMISSIONS (0003,113/149). 300 599 4 199 BASED ON 1971 STATISTICS OF 24.1EI2 CF GROSS PRODUCTION, O.3E12 299 CF LOSSES AND WASTE IN FIELD AND 2.30E12 CFTOR FIELD USE 399 0004,29). 499 3005 199 BASED ON S114ULATED TYPICAL WELL PRODUCTIVITY-FOR 25 YEARS PRO- 299 DUCTION (3008,120-122), 399 3006 199 BASED ON 1971 LEASE AND PLANT FUEL CONSUMPTION OF 1.40E12 CP FOR 299 AN INPUT OF 2.114E13 CF (2.205E13 TOTAL LESS 9.06E11 PHYSICAL 399 LOSS) (0025,758) . 499 3007 199 BASED ON AN LNG TANKER WITH A CAPACITY OF 1.0E12 BTU, WHICH-TS 299 EQUIVALENT To 294,000 BBL LNG. THE TANKER IS ASSUMED TO BE A. 399 STEAMSHIP AND TO OPERATE WITHIN THE COASTAL WATERS OF THE U.S. 499 FOR A DISTANCE OF 100 N MI./ROUND TRIP. TIME IN BERTH IN A U.S. 599 PORT IS ASSUMED TO AVERAGE 2 DAYS/ROUND TiiiF. DIESEL TUGBOAT 699 USE IN U.S. FORTS IS ASSUMED TO AVERAGE 10 N ZNI/ROUND TRIP. 799 EMISSION FACTORS USED ARE. THOSE FOR STEAMSHIPS AND MOTORSHIPS 899 Preceding page blank FTN. 3008-3010 (0023-11). NO VESSEL SIZES ARE SPECIFIED FOR THESE FACTORS THE SULFUR CONTENT OF THE FUEL IS ASSUMED TO BE 0.5P, AND NO ADJUSTMENT OF FACTORS HAS BEEN MADE FOR USE OF BOIL-OFF GAS 1114171 AS PART OF THE TANKER FUEL. VALUES IN THE TABLE BELOW ARE IN 129 1 TONS/1.OE12 BTU FOR 100 MI TRAVEL IN COASTAL WATERS AND 2 DAYS1399 IN PORT. 1491 1 LNG TANKER TUGBOATS TOTALS 15991 COASTAL IN-BERTH 1699 PARTICULATES 2.OE-2 1.5E-3 l.0E-l 3.15E-2 1799 NOX 2.3E-1 2.OE-1 7.OE-3 4.37E-l 1899 sox 1.8E-1 1.52E-1 3.7E-3 3.36E-1 1999 HC 1.OE-2 9.OE-3 4.5E-3 1.54E-2 20991 co 1.OE-4 8.0E-5 6.OE-3 6.18E-3 21991 ALDFHYDES,ETC 2.OE-3 2.OE-3 3.5E-4 4.35E-3 22991 3008 1991 BASED ON ESTIMATE OF DISCHARGE OF 12 GAL OIL PER DAY DUE TO BILGE- 2991 PUMPING, LEAKS, AND BUNKERING OPERATIONS. VESSEL IS ASSUMED TO 399 BE III BERTH AND IN U.S. COASTAL WATERS A TOTAL OF 5 DAYS/TRIP. 4991 SEE FOOTNOTE 3007 FOR VESSEL DATA. SPECIFIC GRAVITY. OF OIL 5991 DISCHARGE IS ASSUMED TO BE 0.85. 699 3009 199 BASED ON 1971 FIELD AND GATHERING PIPELINE MILEAGE, 6.65E4 MI 299 (0004,51) AND 1971 NET PRODUCTION, 2.279E18 CF (0004,29). THE PIPELINE RIGHT-OF-WAY VARIES FROM 50 To 75 FT (2002,14). AN 4991 AVERAGE CF 62.5 FT IS USED. COMPRESSION STATIONS ARE ASSUMED 599 TO BE LOCATED 187 MI APART (3002,8-50) AND occupy 25 AC EACH 699 (3002,8-96). THE ALLOCATION FRACTION FOR 1.OE12 BTU/YR IS 799[ 4.26-5, GIVING 21.4 AC-YR/1.OE12 BTU FOR THE PIPELINE AND 899 0.38 AC-YR/1.OE12 BTU FOR THE COMPRESSOR STATIONS. 9991 CALCULATIONS WERE ALSO MADE USING DATA FROM A RECENT FPC 1199 1099 DOCKET FOR THE MICHIGAN-WISCONSIN PIPELINE CO. (3007). LAND 1299 REQUIREMENTS FOR COMPRESSOR STATIONS (4000 HP) ARE GIVEN AS 1399 10.ACRES WITH STATIONS AN AVERAGE OF 75 MILES APART. USING 1491 THE GATHERING AND TRANSMISSION PIPELINE MILEAGE FROM (0004, 1599 51), LAND IMPACT FOR COMPRESSOR STATIONS WAS CALCULATED. FOR 1699 GATHERING PIPELINES, THIS AMOUNTS.TO 0.38 AC-YR/1.OE12 BTU. 1791 SION PIPELINES, LAND IMPACT AMOUNTS TO 1.49 AC- 1899 YR/1.OE12 BTU. THE IMPACTS ARE IDENTICAL TO THOSE DERIVED 1999 FOR TRANSMIS USING 25 ACRE STATIONS LOCATED 187 MILES APART. 2099 3010 194 BASED N 1971 TRANSMISSION AND DISTRIBUTION PIPELINE MILEAGES, 2.569E5 AND 6.113E5 MI,RESPECTIVELY,(0004,51), AND 1971 39 0 294 MARKETED PRODUCTION, 2.249E13 CF (0004,29). THE PIPELINE RIGHT 491 OF-WAY VARIES-FROM 50 To 75 FT (2002,14). AN AVERAGE VALUE OF 59 62.5 FT IS ASSUMED FOR TRANSMISSION PIPELINES. COMPRESSOR 69 STATIONS ARE ASSUMED TO BE LOCATED 187 MI APART (3002,6-50) ON 79 TRANSMISSION PIPELINES AMD OCCUPY 25 AT EACH (3002,8-96). NO 899 COMPRESSOR STATIONS ARE REQUIRED ON DISTRIBUTION MAINS. SINCE 999 DISTRIBUTION MAINS ARE TO A LARGE EXTENT UNDER URBAN STREETS 1099 THE RIGHT-OF-WAY IMPACT IS SMALL. A LAND IMPACT-OF 25 AC/100 ll99 MI IS ASSUMED FOR DISTRIBUTION SYSTEMS FOR CONTROL EQUIPMENT. 1299 1399 THE ALLOCATION FRACTION FOR 1.OE12 BTU/YR IS 4.31E-5, GIVING 84.0 AC-YR/1.OE12 BTU FOR TRANSMISSION PIPELINES, 1.47 AC-YR/ 0.2OE412 BTU FOR COMPRESSOR STATIONS, AND 6.6 AC-YR/1.0OE12 BTU 1599 Reproduction from best available copy. IV-8 FOR DISTRIBUTION MAINS. FTN. 3011-3013 1699 CALCULATIONS WERE ALSO MADE USING DATA FROM A RECENT FPC 1799 DOCKET FOR THE MICHIGAN-WISCONSIN PIPELINE CO. (3007). LAND 1899 REQUIREMENTS FOR COMPRESSOR STITIONS (4000 HP) ARE GIVEN AS 1999 10 ACRES WITH STATIONS AN AVERAGE OF 75 MILES APART. USING 2099 THE GATHERING AND TRANSMISSION PIPELINE MILEAGE FROM (0004, 2199 51), LAND IMPACT FOR COMPRESSOR STATIONS WAS.CALCULATED. FOR 2299 GATHERING PIPELINES, THIS AMOUNTS TO 0.38 AC-YR/1.OE12 BTU; 2399 FOR TRANSMISSION PIPELINES, LAND IMPACT AMOUNTS TO 1.49 AC- 2499 YR/1.OE12 BTU. THE IMPACTS ARE IDENTICAL TO THOSE DERIVED 2599 USING 25 ACRE STATIONS LOCATED 187 MILES APART. 2699 3011 199 FROM (3010,58), COLUMBIA GAS COMPANY'S I.OE9 SCFD RECEIVING TER- 299 MINAL AT COVE POINT, MD.WILL OCCUPY A 1000 ACRE SITE INCLUDING 399 FUEL STORAGE DEPOT, DOCK AND PORT FACILITIES AND VAPORIZATION 499 SYSTEM. THIS CORRESPONDS TO 2.66 AC-YR/1.OE12 BTU. ALLOCATION599 TO STORAGE, VAPORIZATION AND PORT IS MADE ON THE ASSUMPTION 699 THAT ACREAGE IS APPROXIMATELY PROPORTIONAL TO THE INVESTMENT 799 VALUES GIVEN IN (3000,3-50). 899, 3012 199 BASED ON THE 1969 VOLUME OF INTERCITY HIGHWAY FREIGHT TRAFFIC, .299 3.963Ell TMI (0010,267), AND THE 1969-SHIPMENTS OF LPG, 399 3.33E8 BBL (0001,755) EQUIVALENT TO 3.15EO7 TONS. THE FRAC- 499 TION TRANSPORTED BY TRUCK'IS ASSUMED TO BE 16.7PC, BASED ON 599 1967 DATA (3006,39). DIST.61%@M FOR LADEN TRIP IS ASSUMED TO 699 BE 100 MI, GIVING 5.26EO8 TMI/YR OF LPG OR 0.13 PC OF TOTAL 799 VOLUME OF INTERCITY HIGHWAY FREIGHT. THE AMOUNT OF LPG 199 EQUIVALENT TO I.OE12 BTU/YR IS 2.36EO4 TONS OR 2.36EO6 TMI/YR, 999 EQUIVALENT TO 0.45PC OF LPG TRUCK SHIPMENTS AND THE HIGHWAY 1999 RIGHT-OF-WAY IN THE 48 STATES, 2.lE7 AC (SEE FOOTNOTE 7026), 1199 GIVES 122 AC-YR/1.OE12 BTU. 3013 19, BASED ON 1963 DATA, 102966 PRODUCING GAS WELLS (0010,54), IN- 299 CLUDING 387 OFFSHORE WELLS (0010,63), TOTAL PRODUCTION OF 399 1.261E13 CF (0010,108), INCLUDING 4.887E11 CF FROM OFFSHORE 499 WELLS (0010,63). ON THIS BASIS AND CONSIDERING 30 P RECOVERY 599 OF GAS-IN-PLACE, AV CAPACITIES PER WELL ARE 3.94E8 CF ONSHORE 699 AND 4.21E9 CF OFFSHORE. ASSUMING A LAND REQUIREMENT OF 1/4 AC/ 799 WELL ONSHORE AND 112 AC/WELL OFFSHORE, THE IMPACTS ARE .615 899 AC-YR/1.OE12 BTU IN ONSHORE, AND .115 AC-YR/l.C:El2 BTU OFF- 999 SHORE. IF GAS PRODUCTION FROM OIL WELLS IS UNCIER CONSIDERA-@ 1099 TION,THE LAND IMPACTS SHOULD INCLUDE 2.30 AC-Yr,,/l.OE12 BTU 1199 FOR.ONSHORE WELLS AND .278 AC-YR/1.OE12 BTU FOR OFFSHORE 1299 WELLS. THESE VALUES ARE BASED ON 1963 DATA, 5c-8777 OIL WELLS 1399 (0010,45), INCLUDING 2321 OFFSHORE OIL WELLS (1010,63), 1499 TOTAL GAS PRODUCTION FROM OIL WELLS OF 4.367E12 CF (0010,108),1599 INCLUDING 2.79E]l CF FROM OFFSHORE OIL WELLS R010, 63), 1699 TOTAL OIL PRODUCTION OF 2.753E9 BBL (0010,70) @NCLUDING 1.747 1799 E8 BBL FROM OFFSHORE OIL WELLS (0010,63). ON IIHIS BASIS,AND 1899 CONSIDERING 30P RECOVERY FOR BOTH OIL AND GAS, AV CAPACITIES 1999 PER OIL WELL ARE 2.32E7 CF GAS AND 1.47E4 BBL CF OIL FOR ON- 2099 SHORE WELLS, 4.20ES CF GAS AND 2.5OE5 BBL OIL FOR OFFSHORE 2199 WELLS. ON THIS BASIS,41.8 ONSHORE, OR 2.42 OFFSHORE OIL 2299 WELLS ARE REQUIRED FOR 1.OEI'2 BTU IN/YR OF GAS. THE ALLOCA- 2399 TION OF ACREAGE TO GAS IS BASED ON THE GAS FRACTION OF THE '2499 TOTAL CAPACITY/WELL, EXPRESSED IN BTU EQUIVALEflTS. USING 2599 5.62E6,BTU/BBL OIL (0005,38) THE GAS FRACTIONS ARE 0.22.FOR 2699 ONSHORE OIL WELLS AND 0.23 FOR OFFSHORE OIL WELLS. AT 1/4 2799 ACJWELL ONSHORE AND 112 AC/WELL OFFSHORE T:!E IMPACTS GIVEN 2899 ABOVE ARE OBTAINED. 2999 V-9 FTN. 3014-3023 3014 199 BASED ON THE 1971 NO. OF UNDERGROUND STORAGE POOLS (DEPLETED 299 FIELDS. AQUIFERS, CAVERNS), 333 (0004,58), AND THE 1971 INPUT 399 TO STORAGE, 1.85E12 SCF. ON THIS BASIS AN INPUT OF 1.OE12 BTU/ 499 YR REQUIRES 0.175 POOL. THE ACREAGE ASSOCIATED WITH EACH POOL 599 IS ASSUMED TO BE THAT REQUIRED FOR A COMPRESSOR STATION AND 699 RELATED EQUIPMENT, 10 AC PER POOL (3001,5). 799 3015 199 BASED ON- THE RATIO OF 1971 STORAGE POOL COMPRESSOR HP, 1.042E6 299 (0004,62), TO 1971 TOTAL PIPELINE COMPRESSOR HP, 1.076197 399 (0004,50), AND EMISSIONS FOR PIPELINES (SEE FOOTNOTE 3001). 499 THE SAME BASIS IS USED FOR HIGH-PRESSURE GAS HOLDERS. 599 3016 199 BASED ON, '-.HE ASSUMPTION THAT THE USE OF GAS AS FUEL FOR STORAGE 299 COMPRESSORS IS PROPORTIONAL TO THE USE OF GAS FOR PIPELINE 399 COMPRESSORS. USING THE COMPRESSOR HP RATIO (FOOTNOTE 3015), 499 AND THE PIPELINE FUEL USE (FOOTNOTE 3001), THE STORAGE FUEL 599 USE IS ESTIMATED AT 0.36P. 699 3018 199 ASSUMED EQUAL TO THE LAND REQUIREMENT FOR VAPORIZATION OF LNG (SEE 299 FOOTNOTE 3011) . 399 3019 199 BASED ON 17P OF INPUT USED AS FUEL FOR THE LIQUEFACTION PLANT 299 (3000,3-43) AND EMISSION FACTOR FOR NOX OF 4300 LB/MMCF AND 399 ZERO FOR THE OTHER POLLUTANTS (0002.1-9).A GAS ENGINE DRIVE IS 499 ASSUMED. EMISSIONS WOULD THUS BE 3.54EO2 TONS NOX/1.OE12 BTU 599 FOR A GAS TURBINE DRIVE, THE EMISSION FACTOR FOR NOX WOULD BE 699 200 L3/MMCF (0002,1-9),GIVING 16.5 TONS NOX/1.OE12 BTU. 799 3020 199 THE THEORETICAL COOLING REQUIRED TO CONVERT 1 LB OF NATURAL GAS 299 (ASSUMED TO BE 100P METHANE) AT 100 DEG F AND 100 PSIA TO A 399 LIQUID AT ATMOSPHIC PRESSURE AND -258 DEG F IS 398 BTU (3000, 499 2-172). THIS CORRESPONDS) TO A DISCHARGE TO COOLING WATER OF 599 1.80E10 BTU/1.OE12 BTU. ADDITIONALLY, PART OF THE ENERGY USED 699 TO DRIVE THE PROCESS IS ALSO DISCHARGED TO COOLING WATER. 799 ASSUMING THAT 17P OF THE INPUT GAS IS USED AS FUEL (3008, 899 424) AND THAT 50 PC OF THE ENERGY CONTENT IS DISCHARGED TO 999 COOLING WATER, A DISCHARGE OF 8.5OElO BTU/1.OE12 BTU RESULTS. 1099 IF A COOLING TOWER IS USED A VALUE OF ZERO SHOULD BE SUBSTI- 1199 TUTED. 1299 3021 199 VAPORIZATION BY COMBUSTION OF GAS IS ASSUMED. SOME DESIGNS USE 299 WATER AS A SOURCE OF BEAT. IN SUCH CASES A NEGATIVE THERMAL 399 IMPACT WOULD RESULT, THE MAGNITUDE BEING ABOUT 1.80E10 BTU/ 499 1.0E12 BTU (SEE FOOTNOTE 3020). 599 3022 199 BASED ON USE OF 2P OF LNG INPUT AS FUEL IN VAPORIZER (3000,2-252), 299 AND EMISSION FACTORS FOR NATURAL GAS COMBUSTION IN COMMERCIAL 399 HEATERS (0002,1-9). 499 3023 199 HIGH PRESSURE STORAGE TANKS ARE ASSUMED, REQUIRING 1 25 AC/MMCF 299 OF GAS STORAGE CAPACITY (3002,10-16). THE STORAGE CAPACITY IS 399 ASSUMED TO BE EQUAL TO IOP OF DAILY PIPELINE FLOW. THE FLOW 499 FOR 1.OE12 BTU/YR IS 2.64 MMCFD. THUS, THE LAND REQUIREMENT 599 IS 0.33 AC-YR/1.OE12 BTU. 699 IV-10 -3030 FTN. 3024 3024 199 BASED ON THE ACUEOUS AMINE PROCESS- WHICH IS THE MOST COMMONLY 299 USED PROCESS FOR H2s REMOVAL (3002,4-86). THE VALUE FOR 1.OE12 399 BTU/YR IS BASED ON DATA FOR TREATMENT OF 60 MMCFD WITH 100 499 GRAINS H2S PER 100 CF OF GAS (3002,4-88). THE FLOW THROUGH THE 599 HEAT EXCHANGER IS 80 GPM OF 20P MONOETHANOLAMINE SOLUTION AND 699 THE TEMPERATURE CHANGE IS 55 DEG F. THE SPECIFIC GRAVITY OF. 799 MFA IS 1.022 (0028,3-22). THE SPECIFIC HEAT OF THE 20P MEA 899 SOLUTION IS ESTIMATED TO BE 0.95 BTU/LB-DEG F. IF A COOLING .9.99 TOWEF IS USED A VALUE OF ZE130 SHOULD BE SUBSTITUTED. 1099 3025 199 THE H2S REMOVED FROM THE NATURAL GAS IS ASSUMED TO BE CONVERTED TO 299 ELEMENTAL SULFUR, USING, FOR EXAMPLE, THE CLAUS-CHANCE PROCESS 399 AS MODIFIED BY MATHIESON CHEMICAL CO. THE EXIT GASES FROM THE 499 PROCESS, VENTED TO THE ATMOSPHERE, ARE PRIMARILY NITROGEN, 599 CAFBON DIOXID'E, AND WATER VAPOR (3000,2-71). THE FUEL FOR THE 699 PROCESS IS THE ACID WASTE GAS FROM THE AMINE PROCESS (SEE 799 FOOTNOTE 3024). TH5POLLUTANT VALUES FOR 1.OE12 BTU/YR ASSUME 899 NATURAL GAS AS FUEL TO GENERATE STEAM FOR THE AKINE PROCESS. 999, ON THE BASIS OF 8250 LB/HR OF 40 PSIA STEAM FOR A 60 MMCFD 1099 PLANT (3.3 LBS STEAM/MCF) (3000,2-50).AND 75P COMBUSTION 1199 EFFICIENCY,THE FUEL REQUIRED IS 0.29 MMCFD. THE EMISSION 1299 FACTORS ARE FOR INDUSTRIAL PROCESS BOILERS (0002,1-9). IF EX- 1399 HAUST STEAM FROM A POWER PLAWF IS USED, THE AIR POLLUTANT 1499 VALUES FOR THE PROCESS ARE'ZERO. 1599 3026 199 BASED ON AN ASSUMED VALUE OF 5 AC FOR A 100 MMCFD PLANT 299 302; 199 BASED ON 3.1P OF GAS PROCESSED USED AS PLANT FUEL AND 0.1P FLARED 299 (0025,759). THE EMISSION FACTORS ARE THOSE FOR INDUSTRIAL. 399 PFOCESS BOILERS (OC02, 1-9) 499 3028 199 BASED ON AN ASSUMED THERMAL. DISCHARGE EQUAL TO 25P OF THE ENERGY 299 CONTENT OF THE GAS USED AS PLANT FUEL (SEE FOOTNOTE 3027). IF 399 A COOLING TOWER IS USED.A VALUE OF ZERO SHOULD BE SUBSTITUTED. 499 3029 199 BASfD ON 1971 DATA FOR GAS PIPELINES (0035,5), 346 DISABLING WORK 299- INJURIES, 8086 MAN-DAYS LOST, 1 DEATH. AN APPROXIMATE 399 ALLOCATION IS MADE TO 1.OE12 BTU/YR ON THE BASIS OF THE 1971 499 MARKETED PRODUCTION, 2.249E13 CF (0004,56). ON THIS BASIS, 599 THE ALLOCATION FRACTION IS 4.31E-5. ALLOCATION TO FIELD/ 699 GATHERING AND TRANSMISSION/DISTRIBUTION PIPELINES IS BASED ON 799 MILEAGES (FOOTNOTES 3009,3010). 899 3030 199 BASED ON 1971 DATA FOR NATURAL GAS PROCESSING (0035,4), 89 299 DISABLING WORK INJURIES, 2366 MAN-DAYS LOST, I DEATH.. AN 399 APPROXIMATE ALLOCATION TO 1.OE12 BTU/YR IS MADE ON THE 499 OF THE 1971 MARKETED,PRODUCTION, 2.24E13 CF (0004,56). ON 599. THIS BASIS,THE ALLOCATION FRACTION IS 4.31E-5. A FURTHER 699 ALLOCATION OF 95P TO NGL SEPARATION AND 5P TO H2S SEPARATION! 799 IS ASSUMED. 899 V-11 FTN. 3031-3039 3031 199 BASED ON 1971 DATA FOR PRODUCTION OF OIL AND GAS (0035,4), 595 299 DISABLING WORK INJURIES 20235 MAN-DAYS LOST, 13 DEATHS. 399 ALLOCATION TO-GAS AND OIL PRODUCTION IS MADE ON THE BASIS! OF 49 1971 DATA FOR PRODUCTION OF MINERAL ENERGY (0004,20), UNPRO- 599 CESSED NATURAL GAS 2.487E16 BTU, CRUDE PETROLEUM 1.956E16 699 BTU. ON THIS BASIS THE ALLOCATION FRACTION FOR GAS IS 0.56. 799 THE ALLOCATION TO 1.OE12 BTU/YR IS MADE ON THE BASIS OF THE 899 1971 GAS PRODUCTION GIVEN ABOVE. ON THIS BASIS,THE ALLOCA- 999 TION FRACTION IS 4.02E-5. ALLOCATION TO ONSHORE AND OFFSHORE 1099 IS MADE ON THE BASIS OF 1966 PRODUCTION OF UNPROCESSED 1199 DUCTION IN GULF OF MEXICO 1.355E12 CF (2000,29), 1967 OFF- 1299 NATURAL GAS, 1.898E16 BTU (0004,20), 1966 OFFSHORE, GAS PRO- 1399 SHORE GAS PRODUCTION FOR ALASKA AND CALIFORNIA 1.OEll CF 1491 (2000,47). ON THIS BASIS,THE ALLOCATION FRACTIONS ARE 0.079 1599 OFFSHORE, 0.921 ONSHORE. A 30P RECOVERY FACTOR IS APPLIED IN 1699 ORDER TO SHOW TABLE ENTRIES IN TERMS OF BTU EQUIVALENT IN. 1799 3032 199 FIRE, EXPLOSION, EARTHQUAKE, HURRICANE, LARGE VESSEL COLLIDING 29 FIRE, EXPLOSION, EARTHQUAKE, HURRICANE, LARGE VESSEL COLLIDING 299 WITH OFFSHORE PLATFORM, OR SOME COMBINATION OF THESE, AFFECT- 399 ING PERSNNEL, PLATFORM AND ADJACENT VESSELS. 49- WITH OFFSHORE PLATFORM, OR SOME COMBINATICN OF THESE AFFECT- 39 3033 19 FIRE, EXPLOSION, EARTHQUAKE, TORNADO, OR COMBINATIONS OF THESE, 29 AFFECTING PRODUCTION PERS0NNEL AND EQUIPMENT. 3034 39 19 DAMAGE TO PIPELINE CAUSED BY EXCAVATION EQUIPMENT OR EARTHQUAKE, 29 RESULTING IN FIRE AND/OR EXPLOSION AFFECTING PERSONS AND' 39 PROPERTY -IN VICINITY. 49 3035 19 FIRE, EXPLOSION, EARTHQUAKE, TORNADO, OR COMBINATION OF THESE, 29 AFFECTING PLANT PERSONNEL AND EQUIPMENT. 39 3036 19 COLLISION OF TANKER WITH OTHER VESSEL OR STRUCTURL, RESULTING IN 29 FIRE AND/OR EXPLOSION, AFFECTING CREWS AND VESSEL(S). 39 3037 19 COLLISION OF LPG TRUCK W7TH OTHER VEHICLE OR STATIONARY OBJECT, 29 RESULTING IN FIRE AND/OR EXPLOSION, AFFECTING PERSONS AND 39 PROPERTY IN VICINITY. 49 3038 19 REMOTE POSSIBILITY OF FIRE DUE TO RELEASE OF GAS BY EARTHQUAKE. 29 3039 19 BASED ON.8.9 ONSHORE OR 0.77 OFFSHORE GAS WELL FOR PRODUCTION OF 29 GAS EQUIVALENT TO 1.OE12 BTU/YR (SEE FOOTNOTE 30 13). IN 1970 A 39 TOTAL OF 3844 GAS WELLS WAS BROUGHT INTO PRODUCTION AT A TOTAL 4 COST CF $6.176E8, INCLUDING 193 OFFSHORE WELLS AT A COST OF 599 $1.389E8 (0004,45).ESCALATING TO 1972 DOLLARS USING CONSTRUCT- 699 ION COST RATIO OF 1807/1380, AND USING 10P FIXED CHARGE RATE 799 .GIVES THE FIXED COSTS. IF GAS PRODUCTION FROM OIL WELLS IS 899 UNDER CONSIDERATION 142 ONSHORE OR 8.1 OFFSHORE OIL WELLS ARE 999 J REQUIRED FOP PRODUCTION OF GAS EQUIVALENT 10 1.OE12 BTU/YR 1099 (SEE-FOOTNOTE 3013). IN 1970 A TOTAL OF 12547 OIL WELLS 1199 WAS BFOUGHT INTO PRODUCTION AT A TOTAL COST OF $1.088E9, 1288 INCLUDING 533 OFFSHORE WELLS AT A COST OF $2.82E8 (0004,45). 1399 (ON THIS BASIS THE AV COST PER OIL WELL IS 6.730E4 FOR ONSHORE 1499 Reproduced from best available copy. V-12 FTN. 3040-3044 AND $5.3OtE5 FOR OFFSHORE. ESCALATING AS ABOVE, USING IOP 1@99 FCR, AND USING ALLOCATIONS TO GAS PRODUCTION OF 0.22 FOR 1699 ONSHORE AND 0.23 FOR OFFSHORE (SEET FOOTNOTE 3013) THE FIXED 1799 lf COSTS FOR PRODUCTION OF THE GAS EQUIVALENT OF I.OE12 BTU/YR 1899 FROM OIL WELLS ARE $2.75E5 FOR ONSHORE AND $1.30E5 FOR OFF-' 1999 SHORE. A 30P RECOVERY FACTOR IS APPLIED IN ORDER TO SHOW 2099 TABLE ENTRIES IN TERMS OF BTU EQUIVALENT IN. 2199 3040 199 BASED ON THE 1971 AV WELLHEAD PRICE, $0.182/MCF (0004,26). ES- 299 CALATED TO 1972 DOLLARS BY A FACTOR OF 1.064 (0004,26), GIVING 399 $1.87E5/1.OE12 BTU. TAKING 90P OF THIS TO ALLOW FOR AN 499 ASSUMED IOP PROFIT GIVES $1.68E5/1.OE12 BTU. THE OPERATING 599 COST IF OBTAINED BY SUBTRACTING FIXED COST (FOOTNOTE 3039). A 699 30P RECOVERY FACTOR IS APPLIED IN ORDER TO-SHOW TABLE ENTRIES 799 IN TERMS OF BTU EQUIVALENT IN. 899 3041 199 BASED ON SUM OF TOTAL OPERATION AND MAINTENANCE EXPENSES FOR 299 TRANSMISSION, $5.49E8, AND DISTRIBUTION, $8.12E8, FOR 1971, 399 (0004,134). ALLOCATION TO 1.OE12 BTU ON BASIS OF 1971 MARKETED 499 PRODUCTION, 2.249E13 CF (0004,56), GIVES $5.87E4. ASSUMING AN 599 ESCALATIGN FACTOR OF 1.06'GI,@@S $6..22E4 IN 1972 DOLLARS. 699 3042 199 THE OPERATING AND MAINTENANCE EXPENSE FOR FIELD AND GATHERING 299 LINES ARE ASSUMED TO BE PROPORTICNAL TO THOSE FOR TRANSMISSION 399 LINES ON A MILEAGE BASIS. THE 1971 RATIO OF FIELD AND GATHER- @499 ING MILEAGE TO TRANSMISSION MILEAGE IS 6.65E4/2.569E5 -_ 0.258 599 (0004,51). THE TRANSMISSION OPERATING AND MAINTENANCE EXPENSES 699 FOR 1971 ARE $5.49E8 (0004,134). USING THE MILEAGE RATIO AND 799 ALLOCATING TO 1.OE12 BTU ON THE BASIS OF 1971 NET PRODUCTION, 899 2.279E13 CF (0004,29), GIVES $6.05E3. ASSUMING AN ESCALATION 999 FACTOR OF 1.06 GIVES $6.41E3 IN 1972 DOLLARS. 1099 3043 199 BASED ON THE SUM OF THE TRANSMISSION AND DISTRIBUTION COMPONENTS 299 OF GAS UlILITY INDUSTRY PLANT FOR 1971, $1.82SE10 AND $1.576 399 (OC04,150).,ESCALATING TO 1972 DOLLARS USING 499 'CONSTRUCTION COST INDEX RATIO OF 1807/1570, AND USING IOP FIX- 599 ED CHARGE RATE GIVES A FIXED COST OF $ 3.92E9/YR. ALLOCATING 699 THIS TO 1.OE12 BTU/YR ON THE BASIS OF 1971 MARKETED PRODUCTION 799 2.249E13 CF (0004,56) GIVES $1.69E5/1.0.E12 BTU. 899 3044 199 @HE CAPITAL COST FOR FIELD AND GATHERING LIKES IS ASSUMED TO BE 299 PBOPORTIONAL TO THAT FOR TRANSMISSION ON A MILEAGE BASIS. THE 399 1971 RATIO OF FIELD AND GATHERING MILEAGE TO TRANSMISSION 499 MILEAGE IS 6.65E4/2.569E5 = 0.258 (0004,51). THE TRANSMISSION 599 COMPONENT OF GAS UTTLIY INDUSTRY FOR 1971 IS $1.828E10. ESCAL- 699 ATING TO 1972 DOLLARS USING CONSTRUCTION COST RATIO OF 1807/ 799 1570, USING 10P FIXED CHARGE RATE, AND MULTIPLYING BY 0.258 899 GIVES A FIXED COST OF $5.42EB/YR. ALLOCATING TO 1.OE12 BTU/YR 999 ON THE BASIS OF 1971 NET PRODUCTION, 2.279E13 CF (0004,29) 1099 GIVES S2.30E4/1.0E12 BTU 1199 V-13 FTN. 3045-3049 3045 199 BASED ON THE UNDERGROUND STORAGE COMPONENT OF GAS UTILITY INDUSTRY 299 PLANT FOR 1971, $1.883E9 (0004,150). ESCALATING TO 1972 DOLL- 394 ARS USING CONSTRUCTION COST INDEX RATIO OF 1807/1570, AND US- 499 ING 10? FIXED CHARGE RATE GIVES A FIXED COST OF $2.17E8/YR. 599 ALLOCATING THIS TO 1.OE12 BTU/YR ON THE BASIS OF 1971 MARKETED 699 PRODUCTION, 2.249E13 CF (0004,56) GIVES $9.35E3/1.OE12 BTU. 799 3046 199 BASED ON THE 1971 OPERATING AND MAINTENANCE COST FOR STORAGE IN 299 TOTAL INDUSTRY, $1.34E8 (0004,134qJ.. THIS IS ALLOCATeD TO 1.OE 399 12 BTU ON THE BASIS OF 1971 MARKETED PRODUCTION 2.249E13 CF 499 (0004,56). ASSUMING AN ESCALATION FACTOR OF 1.06 GIVES $5.3E3 599 IN 1972 DOLLARS. 599 3047 199 HIGH PRESSURE STORAGE TANKS ARE ASSUMED, WITH STORAGE CAPACITY 299 EQUAL TO 1OPC OF DAILY PIPELINE FLOW. ON THIS BASIS,A CAPACITY 399 OF 2.66EO5 CF IS REQUIRED FOR 1.OE12 BTU/YR. THE COST FOR A 499 CYLINERICAL TANK OF THIS CAPACITY WAS $6.OEO4 IN 1955 (3002,10- 599 15). ESCALATING TO 1972 DOLLARS BY USING CONSTRUCTION COST 699 FIXED COST OF $1.64EO4/1.OE12 BTU. THE 1955 OPERATING AND 699 INDEX RATIO 1807/660, AND USING 10P FIXED CHARGE RATE GIVES 799 MAINTENANCE COST WAS $172/YR (3002,10-15). ESCALATING THIS 999 1972 DOLLARS, USING THE NELSON LABOR INDEX RATIO 546/191, 1099 GIVES $492/1.OE12 BTU. 11991 3048 199 A MODIFIED CASCADE CYCLE IS ASSUMED. THE 1970 GULF COAST BASIS 299 CAPITAL COST FOR A.500 MMSCFD (OUTPUT) LIQUEFACTION PLANT IS 399 ESTIMATED AT $1.6EO8 (3008,371). ESCALATING TO 1972 DOLLARS 499 USING THE CONSTRUCTION COST INDEX 1807/1380, AND USING A 1OPC 599 FIXED CHARGE RATE GIVES A FIXED COST OF $2.09EO7. WITH SOURCE 699 GAS AT PIPELINE QUALITY AND 750 PSIA, 17PC OF THE INLET GAS 799 QUANTITY IS ASSUMED FOR PRETREATMENT AND LNG PROCESSING (3008, 899 424). THUS INPUT IS TAKEN AS 1.2 TIMES OUTPUT. THE COST OF 999 MARINE FACILITIES DEVELOPMENT IS GIVEN AS $20 x 106 BASED ON 10991 CONSTRUCTION IN 1976-1977 (3008,427). THOUGH THE COST WILL BE ALLOCATED TO 1.OE12 BTU/YR HERE, IT SHOULD BE NOTED THAT 1299 MARINE FACILITIES ARE NOT NEEDED IN MULTIPLES AS PLANT SIZE 1399 INCREASES (3008,371). ALLOCATION OF FIXED COST TO AN INPUT 14991 OF 1.OE12 BTU/YR IS $9.6EO4/1.OE12 BTU. ALLOCATION OF 1599 MARIME FACILITIES COST TO 1.OE12 BTU/YR IS $8.96EO3 AT A 1OPC 1699 FIXED CHARGE RATE. THUS TOTAL CAPITAL COST IS $1.03EO5/1.OE 1799 12 BTU. FROM (3008,372), THE ANNUAL 1970 GULF COAST BASIS 1899 OPERATING COST FOR A 500 MMSCFD OUTPUT LIQUEFACTION PLANT IS 1999 $6.5 17 06 EXCLUDING FUELS AND LOSSES. ESCALATING COSTS AT 5PC/ 2099 YR TO 1972 COSTS GIVES AN ANNUAL COST OF $7.17EO6. THE GAS 2199 IS ASSUMED TO COST $0.15/MCF AT A FOREIGN SITE. ON THIS 2299 BASIS, THE GAS COST FOR A 1.OE12/YR PLANT IS $2.47EO4. 2399 ALLOCATION OF ANNUAL OPERATING COSTS TO 1.OE12 BTU/YR GIVES 2499 6.38E04. ADDING THIS TO GAS COSTS GIVES A TOTAL ANNUAL 2599 OPERATING COST OF $8.85EO4/1.OE12 BTU. 2699 3049 191 VAPORIZATION BY COMBUSTION OF GAS IS ASSUMED. FROM (3008,408), 2799 THE 1970 EAST COAST BASIS CAPITAL COST FOR CONSTRUCTING AN LNG 2899 MARINE RECEIVING TERMINAL,INCLUDING A VAPORIZATION PLANT WITH 2999 A GROSS CAPACITY OF 1.OE9 SCFD, IS $58E06,EXCLUSIVE OF LAND IV-14 FTN.3050-3051 AND FUEL COSTS. FROM (3000,3-50),THE COST OF A 1.5E09 SCFD 699 VAPORIZATION PLANT IS APPROXIMATELY 5PC OF THE TOTAL-CAPITAL 799 COST OF THE MARINE FACILITY,EXCLUSIVE OF LAND COSTS.. ON 899 ''THIS BASIS, THE 1970 CAPITAL COST OF A 1.OEO9 SCFD VAPORIZA- 9919 TION PLANT WOULD BE $2.9EO6. ESCALATING TO 1972 COSTS USING @1099 THE CONSTRUCTION COST INDEX 1807/1380, ADDING 7PC OF COST FOR 1199 INTEREST DURING CONSTRUCTION AND USING A IOPC FIXED CHARGE 1299 RATE GIVES A FIXED COST OF $4.06EO5 FOR THE VAPORIZATION 1399 PLANT. TO ALLOW FOR CONSUMPTION OF GAS AS FUEL, INPUT IS 1499 TAKEN AS 1.02 TIMES OUTPUT (3009,63). THE ALLOCATION OF 1599 CONSTRUCTION COSTS TO AN INPUT OF 1.OE12 BTU IS THUS $1.08E03/ 1699 1.OE12 BTU. FROM (3000,2-29), THE ANNUAL OPERATING COST OF 1799 A VAPORIZATION PLANT IS TAKEN AS 6PC OF THE INVESTMENT PLUS 1899 THE COST OF GAS USED AS FUEL PLUS THE COST OF ELECTRIC POWER. 1999 THE INVESTMENT ALLOCATED TO 1.OE12 BTU IS $1.08EO4. THE GAS 2099 USED AS FUEL IS ASSUMED TO COST $0.75/MCF FOR A TOTAL OF 2199 $1.46EO4/1.OE12 BTU. POWER, AT 5 MILLS/KWH, FOR A 6.OE4 MMCF/ 2299 YR OUTPUT VAPORIZATION PLANT AMOUNTS TO.$2.19EO4 (3000,2-259). 2399 THE PORTION. ALLOCATED TO I.OE12 BTU WOULD BE $347. THE TOTAL 2499 OPERATING COST IS THUS $1.55-et)4/1.OE12 BTU/YR. 2599 3050 199 BASED ON AN LNG TANKER CAPACITY OF 120,000 m3 (EQUIVALENT TO 299 2.62EO9 CF OF 1034 BTU/CF GAS) (3008,391,423). FROM TABLE 9 399 (3008,3891, THE QUOTED 1972 PRICE FOR U.S. CONSTRUCTION OF A 499 120,000 MJ TANKER IS $72EO6. INTEREST DURING CONSTRUCTION 599 AT 7PC AND A 1OPC FIXED CHARGE RATE GIVES A TOTAL CAPITAL COST 699 OF $7.70EO6. ALLOCATION TO I.OE12 BTU/YR IS MADE ON THE BASIS 799 OF 25 ROUND TRIPS (7000 MI/ROUND TRIP) TO GIVE $1.14EO5/1.OE12 899 BTU/YR. FROM (3008,399), SHIP OPERATING COST/flCF DELIVERED AT 999 20 KNOTS IS $0.047/MCF ESCALATED AT 5PC/YR TO GIVE A.1972 1099 COST OF $0.052/MCF OR $3.@4EO6 FOR A 120,000 m3 TANKER MAKING 1199 25 ROUND TRIPS/YR. OPERATING COSTS INCLUDE FIXED ANNUAL COSTS 1299 SUCH AS CREW, MAINTENANCE, TONNAGE DUES AND INSURANCE, AND 1399 VOYAGE RELATED EXPENSES SUCH AS PORT CHARGES, PILOT FEES LINE 1499 HANDLERS, LIQUID NITROGEN EXPENSE AND COST OF BUNKER FUE@ USED 1599 IN PORT. ALLOCATION TO I.OE12 BTU./YR GIVES A TOTAL OPERATING 1699 COST OF $5.04EO4/1.OE12 BTU. 1799 3051 199 1A BOVE GROUND METAL TANKS ARE ASSUMED. THE ESTIMATED 1972 COST OF 299 CONSTRUCTION, INCLUDING INTEREST DURING CONST6CTION, IS 399 $1.4.37/BBL OF CAPACITY (3000,2-201). A TANK CAPACITY OF 1.5 x 499 106 BBL IS ASSUMED, TWICE THE CAPACITY OF THE 7ANKER SUPPLYING 599 THE FACILITY (3010,58). THIS GIVES A .1972 COST, OF $21.54EO6 699 FOR CONSTRUCTION COST OF THE TANKS INCLUDING PIPING AND SITE 799 PREPARATION. TO PROVIDE THE I.OE09 CFD REQUIR-D BY THE 899 VAPORIZATION FACILi'ry, THE TANKS MUST BE FILLED AND EMPTIED 999 74 TIMES/YR. THUS, THE ENERGY RATE IS 376.29E12 BTU,/YR. 1099 USING A FIXED CHARGE RATE OF IOPC,AND ALLOCATI!iG TO I.OE12 1199 BTU/YR,GIVES A FIXED COST OF $5.72EO3/1.OE12 B7U. SUBTRACTING 1299 THE ESTIMATED CAPITAL COSTS OF THE TANK AND V A?ORIZATION 1399 FACILITIES (SEE FOOTNOTE 3049) FROM THE CAPITA@ COST OF THE 1499 ENTIRE FACILITY ($58EO6 FOOTNOTE 3049) GIVES THE APPROXI- 1599 V 15 FTN. 3052-3057 MATE CAPITAL COST OF THE MARINE AND SENDOUT FACILITIES OF 1699 THE TERMINAL. THIS AMOUNT TO $33.56OE6. FROM (3000,3-50, 1799 THE COST OF LAND IS 10 PC ADDITIONAL OR $3.36EO6. USING A 1899 10PC FIXED CHARGE RATE, THE ADDITIONAL COST IS THEN $3.63EO6. 1999 THE FIXED COST/1.OE12 BTU/YR IS THUS $9.81EO3. ADDED TO THE 2099 COST OF THE TANK FACILITY, TOTAL FIXED COST IS $1.55EO4/1.OE 2199 12BTU. THE 1970 EAST COAST OPERATING COST OF A 1.OE09 SCFD 2299 TERMINAL EXCLUDING FUEL AND CAPITAL CHARGES IS $3.6E06/YR 2399 (3008,409). THIS AMOUNT TO $9.81EO3/1.OE12 BTU. THIS 2499 INCLUDES THE OPERATING COST AND COST OF ELECTRICAL POWER, BUT 2599 NOT FUEL FOR GAS-FIRED VAPORZATION. FROM FOOTNOTE 3049, THE 2699 COST OF ELECTRIC POWER FOR VAPORIZATION IS $348/1.OE12 BUT, 2799 AND OTHER OPERATING COSTS ARE $648/1.OE12 BTU. SUBTRACTING 2899 THESE FROM OPERATING COSTS ARE $648./1.OE12 BTU. SUBTRACTING 2999 1.OE12 BTU/YR AS THE OPERATING COST OF THE TANK, MARINE AND 3099 SENDOUT FACILITIES. 3199 3052 199 BASED ON THE AQUEOUS AMINE PROCESS, THE 1968 COST FOR A PLANT WITH299 AN INPUT OF 90 MMCFD IS ESTIMATED AS $4.15E6 (3000,2-50). ES- 399 CALATING TO 1972 DOLLARS USING CONTRUCTION COST INDEX RATIO 499 1807/1154, AND USING 10P FIXED CHARGE RATE GIVES $6.49E5/YR. 599 ALLOCATING TO 1.OE12 BTU/YR ON THE BASIS OF 330 STREAM-DAYS/ 699 YR GIVES $2.12E4/1.OE12 BTU FIXED COST. OPERATING COST FOR 799 STEAM, ELECTRIC ENERGY, AND CHEMICALS TOTAL $3.5E-3/MCF (3000, 899 2-50), WHICH CORRESPONDS TO $3400/1.OE12 BTU. ADDING A LABOR 999 COST, ESTIMATED AT $2.OE-3/MCF, WHICH CORRESPONDS TO $1940/1.0 1099 3053 199 BASED ON A 1972 INVESTMENT OF $3.34E8 REPORTED FOR 12 PLANTS WITH 299 A TOTAL CAPACITY OF 1759 MMCFD (3003). ASSUMING 330 STREAM- 399 DAYS/YR, A 10P FIXED CHARGE RATE, AND ALLOCATION TO 1.OE12 BTU/ 499 YR GIVES $5.58ER/1.OE12 BTU. THE TOTAL COST IS ESTIMATED FROM 599 THE AMOUNT OF NATURAL GAS PROCESSED IN 1971, 1.025E13 CF, AND 699 THE 1971 VALUE OF THE PRODUCTS RECOVERED, $1.39E0, (0004, 37). 799 DEDUCTING AN ASSUMED 10P PROFIT AND ALLOCATING TO 1.OE12 BTU 899 TREATED GAS GIVES A TOTAL COST OF $6.28E4/1.OE12 BTU. SUB- 999 TRACTING THE FIXED COST GIVES AN OPERATING COST OF $7000/E12 1099 BTU. 1199 3054 199 BASED ON AN AVERAGE VALUE OF 1.34 CENTS/GAL-100 MI TRUCKING RATE 299 FOR LPG IN 1962 (2007-15-18). DEDUCTING AN ASSUMED 1OP PROFIT 399 AND ESCALATING TO 1972, USING AN ESTIMATED FACTOR OF 1.3, GIVES 499 1.57 CENTS/GAL-100 MI. ALLOCATION TO 1.OE12 BTU/YR GIVES 599 $1.64/1.OE12 BTU-100MI. 699 3055 199 BASED ON ESTIMATED CONSUMPTION OF 0.34P OF INPUT GAS USED TO GEN- 299 ERATE STEAM (SEE FOOTNOE 3025). 399 3056 199 BASED ON 17PC OF INLET GAS USED A FUEL (3003, 371). 299 3057 199 BASED ON A DAILY BOILOFF RATE OF 0.25 OF CARGO CAPACITY (3008, 299 392), AND A ROUND-TRIP DURATION OF 14.- DAYS (INCLUDING AN 399 AVERAGE DELAY TIME OF 2 DAYS/ROUND TRIP) (SOME LNG IS CARRIED 499 Reproduced from best available copy. V-16 FTN. 3058-3061, ON THE RETURN VOYAGE TO KEEP THE TANKS COLD). THE BOIL-OFF 599 GAS IS USED AS PROPULSION FUEL, EXCEPT UNDER CONDITIONS OF 699 LOW POWER DEMAND. ASSUMING THAT THE USAGE ASJUEL IS ABOUT 799 60PC OF THE TOTAL REQUIREMENT (3004,3). THE ADDITIONAL BTU 899 INPUT FROM FUEL OIL IS 2.43EI0 BTU/I.OE12 BTU. 999 3058 199 PHYSICAL LOSS OF LPG AND USE OF LPG AS TRUCK FUEL ARE ASSUMED TO 299 BE NEGLIGIBLE. USING SAME BASIS AS FOOTNOTE 3002, THE AMOUNT 399 OF DIESEL FUEL REQUIRED FOR A 200MI ROUND TRIP IS ESTIMATED 499 TO BE 3.76E4 GAL/1.OE12 BTU. USING A CALORIC CONTENT OF 1.39 599 E5 BTU/GAL THE ENERGY INPUT.IS 5.21E9 BTU/1.OE12 BTU FOR A. 699 200 MI ROUND TRIP. 799 3059 199 !EFFICIENCY IS BASED ON USE OF 2P OF LNG INPUT AS FUEL IN VAPORIZER -299 (3000,2-252). THE ENERGY INPUT IS BASED ON AN ELECTRICAL 399 POWER REQUIREMENT OF 69,400 KW-HR/I.OE12 BTU (FOOTNOTE 3049). 499 USING A CONVERSION RATIO OF 3X3413 BTU/KWH GIVES AN ENERGY 599 INPUT OF 7.11E8 BTU/I.OE12 BTU. 699 3060 199 ILOSS OF GAS FROM THE TANK IS ASSUMED TO BE'NEGLIGIBLE. THE BOIL- 299 OFF GAS IS ASSUMED TO BE FUEL OR SENDOUT GAS (3000,2-202). 399 3061 199 IFROM FOOTNOTE 3049, THE ELECTRIC POWER REQUIRED TO VAPORIZE 1.OE12 299 BTU IS 69,400 KWH. FROM (301.0,60), THE POWER REQUIREMENTS FOR 399 A 1.OE9 SCFD MARINE RECEIVING TERMINAL WITH 1 .5 X 106 BBLS 499 STORAGE CAPACITY, FILLED AND EMPTIED 74 TIMES/YR, ARE 17,000 599 KW 20PC OF THE TIME AND 14,000 KW BOPC OF THE TIME. THUS,THE 699 'TOTAL ANNUAL THROUGHPUT OF THE TERMINAL IS 365EO9 SCF AT AN 799 AVERAGE OF 1.28EO8 KWH/YR. THIS AMOUNTS TO 3.49EO5 KWH/I.OE12 899 BTU. SUBTRACTING THE POWER REQUIREMENT FOR THE VAPORIZATION 999' FACILITY LEAVES 2.74EO5 KWH/I.OE12 BTU. CONVERTING TO BTU-S 1099 AND MULTIPLYING BY 3 FOR THE EFFICIENCY OF ENERGY PRODUCTION 1199 GIVES A TOTAL OF 2.81EO9 BTU/1.OE12 BTU AS THE ENERGY INPUT 1299 REQUIRED BY STORAGE, MARINE AND SENDOUT FACILITIES. 1399 V-17 VI. POWER PLANT CONVERSION ACTIVITY OF FUEL SUPPLY A. Introduction Conversion to electric power is an activity which is part of the fossil and nuclear fuel supply chain. In this report, the environmental impacts of the power plant activity have all been compiled onto one table which.should be considered as an addition to the supply impacts provided by Tables 1 through 25. Table 26, the electric power conversion activity contains two processes for each-of the three fossil fuels; coal, oil, and natural gas, and three for the nuclear system.. Since the environ- mental impacts of the supply portion of the nuclear power Plant trajectory are small, they have been aggregated and reported as one process in this table. The source of much of the information on Table 26 is a recent report prepared by the Council on Environ- mental Quality.* Whereas the CEQ report expressed all impacts on the basis of the output from a 1000 megawatt power plant, Table 26 is based on a 1012 Btu fuel input to each process. Note that the power plant data are independent of one.another and are for the national case only. A single national average fossil fuel power plant canbe constructed from the data by com- bining the three different fueled plants in the appropr Iiate ratio of electrical production by coal, oil, and gas. Regional variations are not included in Table'26. The pri- mary regional differences in power plant activity impacts will be because of the different sulfur and ash content of the regional coals and the different sulfur content of the-regional oils. No significant regional differences will occur for natural gas fueled or nuclear plants. Council on Environmental Quality, Energy and the Environment Electric Power (Washington. U.S. Government Printing Office, 1973). VI-1 B. Impact Data.Table and Footnotes VI-2 A 1 7 lo 13 1. 15 .1 .1 A. 30 WATER POLLUTANTS (TONSl,DW.TU.E9-L- POLLUTANT3 (TOW3110-RTUI cm --e m) 7 T-1 NOW LAI" H.L .771. No. Co IRTU CAR-I APNWTU LOSENG"ITU DISISTER A. -E A-TI TOTAL -4- ... --GEN TOTAL Tz'L".. IE "T -AT RE. OTHER Go M.. TG 10, IT 62- @2 4 6 -6 A .... . .... . .... 17 18 71- 1. 16 21 ... 14. -27 27- -At IS - 3711 00K -1 o 4' 41 14 45 AW 47 4. 4 40TE: ALL TABLE ENTRIES ARE BASED ON Iol2 BTU OF RFSOU17E INTG EACH PROCESS OR ACTIIIII. TABLE 26. INVIRONNERIAL IIPACII, A" :CST FOR THE ELECTRIC POIE@ OF SEE 101T@,IICIBIG F-1 A GIII.@ITIGN OF THE POWER PLANT -55-MATED UNCONTROLLED AND C3ATA=rD .ITH T@ETFGitR ACTIVITY- OIL, NATURAL GAS. AND @-.S ;--f [22'l V1-3 FOOT.NOTES FOR TABLE 26 FTN. 1900-1905 1900 199 ENTRIES IN THE TABLE ARE BASED ON AN ENERGY INPUT TO EACH PROCESS 299 OF 1.OE12 BTU. FOR THE TRANSMISSION PROCESS, THE BTU'S ARE 399 THE EQUIVALENT OF 2.93E8 KWH INPUT. POWER PLANT CONVERSION 499 OF FOSSIL FUEL TO ELECTRICITY, INCLUDING TRANSMISSION, IS AN 599 ACTIVITY WHICH SHOULD BE CONSIDERED PART OF EACH FOSSIL FUEL 699 SUPPLY MATRIX. 799 1901 199 ALTHOUGH RELIABLE DATA ARE NOT AVAILABLE, THE FOLLOWING ESTIMATES 299 WERE DERIVED FROM (1921,110,115,122,129,132,216) AND (1922, 399 20,22). SOURCES OF WATER POLLUTANTS INCLUDE DEMINERALIZER 499 REGENERATIONS , ASH SLUICING, BOILER BLOW- 599 DOWNS, CLARIFICATION WASTES, COAL PILE RUNOFF, AND MISCELL- 699 ANEOUS.CLEANING AND DRAIN WASTES. ONLY THE ACIDITY FROM THE 799 COAL PILE RUNOFF. IS SHOWN BELOW. 899 WATER POLLUTANTS-TONS/1012 BTU 999 ACIDITY 25.7 1099 TOTAL DISSOLVED SOLIDS 58.1 1199 SUSPENDED SOLIDS 6.84 1299. ORGANICS 2.71 1399 1902 199 BASED ON A POWER PLANT EFFICIENCY OF 38P, 62P OF THE BTU IN-PUT 299 IS REJECTED HEAT. OF THIS, ONE-SIXTH IS REJECTED WITH THE 399 STACK GASES. FROM (1901,11/13). 499 1903 199 EMISSION FACTORS ARE FROM (0002,1-3). THEY APPLY TO A 'GENERAL' 299 PULVERIZED-FEED FURNACE OF OVER I.OE8 BTU/HO iUR WITH PARTICU- 399 LATES CONTROLLED TO 98%. FROM (1903) ASH CONTENT IS 12.53 PC 499 AND SULFUR CONTENT IS 2.59 PC. THERE ARE 41,000 TON COAL/ 599 1.OE12 BTU (FOOTNOTE 1000). 699 AIR EMISSIONS FROM POWER PLANT - TONS/1.0,EI2 BTU 799 PARTICULATES 82.2 899 SULFUR OXIDES 2017.0 999 CARBON M014OXIDE 20.5 1099 HYDROCARBONS 6.15 1199 NITROGEN OXIDES 369.0 1299 ALDEHYDES 0.103 1399 1499 NOTE- AN INSIGNIFICANT AMOUNT (EQUIVALENT TO APPROXIMATELY @1599 2.2 CURIES) OF RADIOACTIVITY IS EMITTED ANNUALLY FROM A 1699 1000 MWE COAL-FIRED PLANT. THIS FIGURE WAS DERIVED FROM 1799 (1904,27). 1899 1904 199 IN FOOTNOTE 1903 IT WAS STATED THAT 12.53 PC OF THE COAL BURNED 299 BECOMES ASH. OF THIS 5137 TONS, 82.2T/1.OE12 3TU ARE EMITTED 399 TO THE AIR AS FLYASH AND THE REMAINDER, 5055T/,..OE12 BTU IS 499 SOLID WASTE. 599 1905 199 TYPICAL PLANT SIZE FOR 3000 MWE PLANTS WITH FLY ASH CONTROLS IS 299 1200 ACRES, INCLUDING 350 FOR ASH STORAGE.AND 40 FOA COAL. 399 STORAGE. SOURCE-.(1905, :11,14). 499 Preceding page blank VI-5 FTN. 1906-1911 1906 SOURCE- (1906,46) 0.166 MEN PER 14WE IS THE BASIS FOR THE CAL- 199 CULATION. INJURY DATA ARE FROM (1907,35). HALF THE COMBINED DEATHS AND PERMANENT INJURIES ARE ASSUMED TO BE FATAL INJURIES.49 PERMANENT TOTAL DISABILITIES ARE CONSIDERED TO REPRESENT 6000 DAYS LOST WHILE OTHER DISABILITIES ARE ESTIMATED AS 100 DAYS 69 LOST. MAN-DAYS LOST ARE FOR INJURIES ONLY. 799 1907 199 BASED ON ESTIMATED LAND RIGHT-OF-WAY OF 4 MILLION ACRES. SOURCE 299 (1908,111). MULTIPLIED BY .00430, THE SHARE OF TOTAL 1970 -ELECTRICITY PRODUCTION REPRESENTED BY A 1000 MWE U.S. P LA N T 499 (6.57E9 KWH)_SOURCE (1909,11). 1.OE12 BTU IS EQUIVALENT TO 599 2.93E8 KWH (SEE FOOTNOTE 1900). 1908 699 199 THE BASIS FOR WATER POLLUTANT CALCULATIONS IS THE PROPOSED 299 EFFLUENT LIMITATIONS GUIDELINES AND NEW SOURCE PERFORMANCE 399 STANDARDS FOR THE STEAM ELECTRIC POWER GENERATING POINT 499 SOURCE CATEGORY GIVEN IN (1921). FOR NEW PLANTS, BEST AVAIL- 599 ABLE DEMONSTRATED CONTROL TECHNOLOGY (BADOT) REQUIRES EFFLUENT 699 PH C0NTROL IN THE RANGE OF 6-9. HENCE ACIDS AND BASES DIS- 799 CHARGE WILL BE NEGLIGIBLE. BADCT ALSO SPECIFIES TOTAL SUSPENDED899 SOLIDS LEVELS NO GREATER THAN 15 MG/L FOR ALL INTERMEDIATE 999 AND LOW VOLUME WASTE EFFLUENTS. AT THIS LEVEL OF CONTROL 1099 THERE WILL GENERALLY BE NO NET INCREASE IN SUSPENDED SOLIDS 1199 IN WATER PASSING THROUGH THE POWER PLANT SYSTEM. ORGANICS 1299 (OIL AND GREASE) MUST BE CONTROLLED TO 10 MG/L TO MEET BADOT 1399 STANDARDS. HENCE FROM (1921,232) THESE EMISSIONS WILL AMOUNT 1499 TO .0736 TON ORGANICS/106 TON COAL OR 3.02-03 TON/1012 BTU. 1599 INFORMATION ON THE INCREASE IN TOTAL DISSOLVED SOLIDS OF 1699 WATER USED IN POWER PLANTS IS NOT READILY AVAILABLE AND WAS 1799' SYNTHESIZED FROM (1922,10,12,20,22). BASED ON THIS DATA THE 1891 NET INCREASE IN TOTAL DISSOLVED SOLIDS FOR WATER USED BY THE 1999 IS 18.2 TON/1012 BTU. POWER PLANT 2099 1909 199 ASSUMES WET LIME SCRUBBER SYSTEM FOR BOTH SOX AND PARTICULATE 2991 CONTROL WITH REMOVAL EFFICIENCIES TAKEN AT 90 P FOR SOX AND 3992 AN OVERALL OF 99.5P FOR PARTICULATES FRON (1923,31). 499 1910 1991 BASED ON 33 CF/TON FLY ASH AND 26 CF/TION WET LIME SLUDGE FROM 299 (1925,57), THE INCREMENTAL SOLID WASTE (FOOTNOTE 1911) HAS A 39 VOLUME OF 2.49E5 FT3/1.OE12 BTU. ASSUMING ONSITE DISPOSAL TO 49 A DEPTH OF 30 FT,.191 AC/1.OE12 BTU IS AFFECTED. TIME AVER- 599 AGING OVER 30 YR OF PLANT LIFE THIS BECOMES 2.87 AC-YR/1.OE12 690 BTU. FROM (1926,45) COOLING TOWERS ARE ESTIMATED TO OCCUPY 7 94q9 10 ACRES FOR A 1000 WE PLANT OR .130 AC-YR/1.OE12 BTU. THESE 894- LAND REQUIREMENTS ARE IN ADDITION TO THE LAND IMPACT OF FOOT- 994 NOTE 1905, 8.49 AC-YR/1.OE12 BTU. 1911 191 BASED ON (1924,25) AND,50P SOLIDS IN THE SLURRY, .232 TON SLUDGE 29l I.S PRODUCED/TON COAL OR 9512 TON SLUDGE/10 12 BTU. FROM FOOT- 394qq NOTES 1904 and 1909 THE INCREMENTAL FLY ASH COLLECTED AS 491 SOLID WASTE AMOUNTS TO 61 TON/1012 BTU.-HENCE THE SUM TOTAL 591 INCREMENTAL SOLID WASTE PRODUCED IS 9573 TON/10 12 BTU. THIS 699 IS IN ADDITION TO THE SOLID WASTE-FROM FOOTNOTE 1904-5055 TON/ 799 10 12 BTU. 894q1 VI-6 FTN. 1912-1917 1912 199 A LARGE NEW POWER PLANT IS ASSUMED TO HAVE A HEAT RATE OF 8960 299 BTU/KWH, EQUIVALENT TO 38P CiNVERSION EFFICIENCY. THE BEST 399 PLANTS HAVE ACHIEVED AROUND 8530-8900, WHEREAS THE NATIONAL 499 AVERAGE IS AROUND 10,500 (1913,1-5-6/1-5-7). 599 1913 199 POWER SOLD DIVIDED BY POWER PRODUCED, 1969 (1919,11,13). 299 1914 199 COSTS OF COAL FIRED POWER PLANTS ESTIMATED AT $180/KW (1914) AND 299 (1915). OPERATION AND MAINTENANCE COSTS EXCLUSIVE OF FUEL 399 COSTS ESTIMATED AT 0.71 MILLS/KWH (1918,45). A 60P LOAD 499 FACTOR IS ASSUMED AND THE FCR FOR CAPITAL IS IOP. 599 1915 199 CAPITAL AND OPERATING COSTS FOR CONTROLS ARE ESTIMATED AS 299 FOLLOWS: 399 CONTROL SYSTEM CAPITAL COST- OPERATING COST 499 $/KW REF MILLS/KWH REF 599 699 WATER POLL-CHEMICAL 1 (1921,233) .05 (1921,234) 799 WATER POLL-THERMAL 10 (1915) .05 (1920,111-3). 899 AIR POLL-SOX 40 (1923,60,61) 1.07 (1923,18/28) 999 REMOVAL & (1911,4/18) 1099 z .1 TOTAL 51 1.17 1199 BASED ON THE ABOVE, A 60P L&AD FACTOR AND A NET PLANT HEAT 1299 RATE OF 9224 BTU/KWH (37P.-PRIMARY EFFICIENCY FROM FOOTNOTE 1399 1919) THE INCREMENTAL CAPITAL COST IS 1.05+05 $/I.OE12 BTU .1499 AND THE INCREMENTAL OPERATING COST IS 1.27+05 $/I.OE12 BTU. 1599 THESE ARE IN ADDITION TO THE CO.STS GIVEN IN FOOTNOTE 1914. 1699 1916 .199 ALTHOUGH RELIABLE DATA ARE NOT AVAILABLE, THE FOLLOWING ESTI- 299 MATES WERE DERIVED FROM (1921,110,115,122,129,132,216) AND (1922,20,22). SOURCES OF WATER POLLUTANTS INC-LUDE DFMINERAL- 499 IZER REGENERATIONS, BOILER. BLOWDOWNS, 599 CLARIFICATION WASTES, AND MISCELLANEOUS CLEANING AND DRAIN 699 WASTES. 799 WATER POLLUTANTS-TONS/1012 BTU 899 TOTAL DISSOLVED SOLIDS 7.44 999 SUSPENDED SOLIDS 0.709' 1099 ORGANICS 0.0155 1199 1917 199 THE BASIS FOR WATER POLLUTANT CALCULATIONS IS THE PROPOSED EFF- 299 LUENT LIMITATIONS GUIDELINES AND NEW SOURCE PEiRFOWNCE 399 STANDARDS FOR THE STEAM ELECTRIC POWER GENERATING POINT 499 SOURCE CATEGORY GIVEN IN (1921). FOR NEW PLANTS, BEST AVAIL- 599 ABLE DEMONSTRATED CONTROL TECHNOLOGY (BADCT) REQUIRES EFFLUENT 699 PH CONTROL IN THE RANGE OF 6-9. HENCE ACIDS ANC BASES DIS- 799 CHARGE WILL BE NEGLIGIBLE. BADCT ALSO SPECIFIES' TOTAL SUSPENDED 899 SOLIDS LEVELS NO GREATER THAN 15 MG/L FOR A 999 LL :NTERMEDIATE AND LOW VOLUME WASTE EFFLUEN TS. AT THIS LEVEL OF C'0NTROL THFRE WILL1099 GENERALLY BE NO NET INCREASE IN SUSPENDED SOLILS IN WATER 1199 PASSING THROUGH THE POWER PLANT,SYSTEM. ORGANICS (OIL AND 1299 GREASE) MUST.BE CONTROLLED TO 10 MG/L TO,MEET SADCT STAND- 1399 ARDS. HENCE, FROM (1921,232) THESE EMISSIONS WILL AMOUNT TO 1499 3.02-03 TON/1012 BTU. INFORMATION ON THE INCREASE IN TOTAL 1599 DISSOLVED SOLIDS OF WATER USED IN POWER PLANTS 7S NOT READILY 1699 AVAILABLE AND WAS SYNTHESIZED FROM (1922,10,12,20,22). BASED 1799 ON THIS DATA THE NET INCREASE.IN TOTAL DISSOLVED SOLIDS,FOR 1899 WATER USED BY THE POWER PLANT IS 3.40 TON/!012 BTU. 1999 VI-7 FTN. 1918-2907 1918 199 THERMAL DISCHARGES ARE ASSUMED TO BE COMPLETELY ELIMINATED BY THE 299 USE OF MECHANICAL DRAFT WET COOLING TOWERS. 399 1919 199 ENERGY REQUIREMENTS FOR CONTROLS ON A 500 MWE PLANT ARE ESTIMATED 299 AS FOLLOWS: 399 CONTROL SYSTEM ENERGY REQUIRED-KW REFERENCE 499 WATER POLL-CHEMICA 22.4 (1921,234) 599 WATER POLL-THERMAL 5000.0 (1921,446) 699 AIR -POLL-SOX REMOVEL 9230.0 (1911,25,26)799 TOTAL 14252.4 899 THIS AMOUNT TO 2.85P OF THE POWER PLANT OUTPUT OR 14.25 MWE. 999 BASED ON THIS THE POWER PLANT OUTPUT IS DERATED TO 485.75 MWE 1099 AND THE PRIMARY EFFICIENCY IS REQUIRED FROM .38 TO .37 (SEE 1199 FOOTNOTE 1912). 1299 2901 199 AIR EMISSIONS, CONSIDERING 1.5P SULFER IN THE FUEL(ESTIMATED 299 WEIGHTED AVERAGE FROM (2020,42)), ARE CALCULATD FROM (0002, 399 1-7). 499 599 AIR EMISSIONS - POWER PLANT 699 (TONS/1.OE12 BTU) 799 899 PARTICULATES SOX CO HC NOX ALDEHYDES 999 1099 27.2 801 0.138 6.81 357 3.40 1199 2902 199 THE LAND REQUIRED FOR A 3000 MWE PLANT, IS GIVEN AS 350 ACRES IN 299 (1905,11). 399 2903 199 SEE FOOTNOTE 1906, USING 0.094 MEN PER MWE. 299 2904 199 BASED ON THE USE OF 0.6P SULFER RESIDUAL FUEL FROM DATA IN (1906).299 SEE ALSO FOOTNOTE 2901. 399 2905 199 .130 AC-YR/1.OE12 BTU ARE ADDED FOR COOLING TOWERS (SEE FOOTNOTE 299 1910). 399 2906 199 COSTS OF OIL FIRED POWER PLANTS ESTIMATED AT $150/KW (1914) AND 299 (1915). OPERATION AND MAINTENANCE COSTS EXCLUSIVE OF FUEL 399 COSTS ESTIMATED AT 0.43 MILLS/KWH (1918,45). A 6OP LOAD 499 FACTOR IS ASSUMED AND THE FCR FOR CAPITAL IS 10P. 599 2907 199 CAPITAL AND OPERATING COSTS FOR CONTROLS ARE ESTIMATED AS FOLLOWS:299 CONTROL SYSTEM CAPITAL COST- OPERATING COST- 399 $/KW REF MILLS/KW-HR REF 499 WATER POLL-CHEMICAL 1 (1921,233) .05 (1021,234) 599 WATER POLL-THERMAL 10 (1915) .05 (1020,III-3)699 TOTAL 11 .10 799 899 BASED ON THE ABOVE, A 60P LOAD FACTOR AND A NET PLANT HEAT 999 RATE OF 9053 BTU/KWH (37.7P PRIMARY EFFICIENCY FROM FOOTNOTE 1099 2908) THE INCREMENTAL CAPITAL COST IS 2.31+04 $/1.OE12 BTU 1199 AND THE INCREMENTAL OPERATING COST IS 1.10+04 $/1.OE12 BTU. 1299 THESE ARE IN ADDITION TO THE COSTS GIVEN IN FOOTNOTES 2906 1399 AND 3905. NOTE THAT INCREMENTAL FUEL COSTS ASSOCIATED WITH 1499 PURCHASING A .6P SULFER RESIDUAL OIL (FOR OIL FIRED POWER 1599 PLANTS) ARE NOT INCLUDED IN THE ABOVE ANALYSIS. ALTHOUGH 1699 PROPERLY ATTRIBUTED TO AIR POLLUTION CONTROL COSTS, THE COST 1799 OF FUEL IS NOT CONSIDERED IN THE OPERATING AND MAINTENANCE 1899 VI-8 FTN. 2908-9605 COSTS OF THE UNCONTROLLED CASE AND HENCE AN INCREMENTAL FUEL 1999 COST IS NOT GIVEN FOR THE CON-ROLLED CASE. 2099 2908 199 ENERGY REQUIREMENTS FOR CONTROLS ON A 500 MWE PLANT ARE ESTIMATED 299 AS FOLLOWS: 399 CONTROL SYSTEM ENERGY REQUIRED-KW REFERENCE 499 WATER POLL-CHEMICAL 22.4 (1921,234) 599 WATER POLL-THERMAL 5000.0 (1921,446) 699 TOTAL 5022.4 799 899 THIS AMOUNTS TO IP OF THE POWER PLANT OUTPUT OR 5 MWE. BASED 999 ON THIS THE POWER PLANT OUTPUT IS DERATED TO 495 MWE AND THE 1099 PRIMARY EFFICIENCY IS REDUCED FROM .38 TO .377 (SEE FOOTNOTE 1199 1912). 1299 3901 199 AIR EMISSIONS COMPONENTS (TONS/1.OE12 BTU) 299 FROM (0002,1-9) 399 PARTICULATES sox CO HC NOX ALDEHYDES, ETC. 499 599 7.34 .293 .190 19..6 191 3.43 699 3902 199 THE AVERAGE GAS FUELED POWER PLANT SITE FOR A 3000 MWE UNIT IS ESTIMATED AT 200 ACRES (1905,11). 399 3903 199 SEE FOOTNOTE 1906, USING 0.089 MEN PER MWE. 299 3904 199 NOTE THAT THE ONLY CONTROLS UTILIZED ARE COOLING TOWERS TO PREVENT 299 THERMAL DISCHARGE TO WATER. TEN ACRES ARE NEEDED FOR THE 399 COOLING TOWERS WITH A 1000 MWE PLANT. LAND USE FOR A 499 1.OE12 BTU PL,ANT (INPUT) IS .130 AC-YR (SEE FOOTNOTE 1910). 599 THIS IS IN-ADDITION TO THE LAND FROM FOOTNOTE 3902. 699 3905 199 COST OF GAS FIRED POWER PLANT AT* $100/KW (1914) AND (1915). .299 OPERATING AND MAINTENANCE COST EXCLUSIVE OF FUEL COST AT 399 0.51 MILLS/KWH (1906,45). A 60P LOAD FACTOR IS ASSUMED 499 AND THE FCR FOR CAPITAL IS 10P. 599 9600 199 FROM (9600,55) FOR THE ACTIVITIES OF EXTRACTION, PROCESSING, 299 AND TRANSPORTATION. 399 9601 199 FROM (9600955) FOR THE CONVERSION ACTIVITY. 299 9602 199 POWER SOLD DIVIDED BY POWER PRODUCED IN 1969 (1919,11,13). 299 9603 199 FROM (9601,S-14) LESS THOSE EMISSIONS DUE TO ELECTRICITY GENERA- 299 TION (9601,S-13,D-17) AND BASED ON 1.235 TON U-235/ANNUAL FUEL 399 REQUIREMENT (9601,S.-5). SEE AL.SO.FqOTNOT.E 9600 AND (9600,,56). 499 FROM (9601,S-15) 2.05+03 CURIES/ 1101 BTU IN ARE.RELEASED TO THE599 THE ATMOSPHERE. 699 9604 199 FROM (9601,S-14) AND BASED ON 1.235 TON U-235/ANNUAL FUEL REQUIRE- 299 MENT (9601,S-5). SEE ALSO FOOTNOTE 9600 AND (9600,56). FROM 399 (9601,5-15) 14 CURIES/joI2 BTU IN ARE RZLEASED TO WATER BODIES 499 AND 3.36 CURIES/1012 BTU IN TO LAND. 599 9605 199 ROM (9600,57) FOR THE ACTIVITIES OF EXTRACTION, PROCESSING, AND 299 TRANSPORTATION. BASED ALSO ON FOOTNOTE 960C AND (9600,55). 399 VI-9 FTN. 9606-9618 9606 199 FROM (9600,55) FOR THE CONVERSION ACTIVITY. BASED ALSO ON FOOl- 299 NOTE 9600 AND (9600,55). 399 9607 199 FROM (9601,S-13) AN,D BASED ON 1.235 TON U-235/ANNUAL FUEL REQUIRE- 299 MENT (9601,S-5). SEE ALSO FOOTNOTE 9600 AND. (9600,56). 399 9608 199 FROM (9600 571 AIR EMISSIONS ARE NEGLIGIBLE. HOWEVER 1.94+03 299 JES 10 2 BTU IN ARE RELEASED TO THE ATMOSPHERE. 39,9 CUR 9609 199 CONSIDERED AS PART OF WASTE MANAGEMENT IN THE EXTRACTION ACTIVITY. 299 4.36+02 CURIES/1012 BTU ARE BURIED IN THEGROUND (9600,5,7)., 399 9610 199 BASED ON (9600:,57) FOR THE CONVERSION ACTIVITY. 299 9611 199 BASED ON $300/KW FROM (9600,58), A 0.75 LOAD FACTOR, 31P PLANT 299 EFFICIENCY AN'D ANNUALIZED AT 1OP/YR. OPERATION, MAINTENANCE, 399 AND INSURARCE COSTS' ESTIMATED AT 0.99 MILLS/KWH FROM (9600, 499 58). 599 9612 199 SEE FOOTNOTE 1916 FOR CHEM,ICAL WATER POLLUTANTS. FROM (9600,57) 299 4.59 C-URIES/1012 BTU IN ARE RELEASED TO WATER BODIES. 399 9613 199 BASED ON @ 31P EFFI'C'IENT PLANT AND ONCE THROUGH COOLING (SEE 299 FOOTNOTE 9601). 399 9614 199 REDUCING POWER PLANT RADIATION EMISSIONS BY 99P IS ESTIMATED TO 299 COST $416 FOR A. ICOO MWE PLANT (9600,58). THUS AT A 10P,FIXED 399 CHARGE RATE FOR CAPITAL COST THIS AMOUNTS TO.5.53+03 $11012 499 1012 BTU (SEE FOOTNOTE 9608). 69,9' BTU IN. THE RADIOACTIVE EMISSIONS THEN BECOME 1.94+01 CURIES/ 599 9615 199 THERMAL DISCHARGES ARE.ASSUMED TO BE COMPLETELY ELIMINATED BY THE 299 9600,58). AN'D OPERATING COST IS TAKEN AS 0.05 MILLS/KWH 'USE OF COOL,I.NG TOWERS. CAPITAL COST IS ESTIMATED AT $14/KW 399 11920,111-3). A.75P LOAD FACTOR IS ASSUMED AND THE CAPITAL 599 COST IS ANNUALIZED A IOP (SEE ALSO FOOTNOTE 9616). 699 9616 199 ENERGY REQUIREMENTS FOR CONTROLS ON A 500 MWE PLANT ARE-ESTIMATED 29@9; AS FOLLOWS: 3991 CONTROL SYSTEM ENERGY REQUIRED-KW REFERENCE 499i WATER POLL-THERMAL 5000.0 (1921,446) 6991 WATER POLL-CHEMICAL 22.4 (1921,234) 5991 TOTAL 5022.4 790! THIS AMOUNTS TO 1P OF THE POWER PLANT OUTPUT OR 5 MWE. BASED 899 ,ON THIS THE POWER PLANT OUTPUT IS DERATED TO 495 MEW AND THE 9991 PRIMARY EFFICIENCY IS REDUCED FROM 0.31 TO 0.307 (SEE FOOTNOTE10991 9601). 11991 9617 1991 BASED ON 14 ACRES.FOR COOLING TOWERS FOR A 1000 MWE PLANT IN 299@ (9600,58). SEE ALSO FOOTNOTE 9610. 399:' 9618 199. SEE FOOTNOTE 1916 FOR CHEMICAL WATER POLLUTANTS AND FOOTNOTE 9612 29@, FOR RADIOACTIVE DISCHARGES. 399, VI-10 FTN. 9619 9619 199 CAPITAL AND OPERATING COSTS FOR CONTROLS ARE ESTIMATED AS FOLLOWS: 299 CONTROL SYSTEM CAPITAL COST- OPERATING COST- 399 $/KW REF MILLS/KWH REF 499 WATER POLL-CHEMICAL 1 (1921,233) 0.05 (1921,234) 599 WATER POLL-THERMAL 14 (9600,58) 0.05 (1920, 699 111-3) 799 AIR POLL-RADIOACTIVE 4 (9600,58) 899 TOTAL T9 0.10 999 BASED ON'THE ABOVE, A 75P LOAD FACTOR AND A PLANT HEAT RATE OF 1099 11,121 BTU/KWH (30.7P PRIMARY EFFICIENCY FROM FOOTNOTE 9616) 1195 THE INCREMENTAL CAPITAL COST IS 2.60+04 $11012 BTU IN (FCR IS 1299 1OP/YR) AND THE INCREMENTAL OPERATING COST IS 8.99+03 $/1012 1399 BTU IN. THESE ARE IN ADDITION TO THE COSTS GIVEN IN FOOTNOTE 1499 9611. .1599 VI-11 VII. RESIDENTIAL END USE A. Introduction Table 27 represents the end use rates and environmental impacts in the residential end use sector. The measures "dwelling-year," and "unit-year," the latter referring to a single item in average use, were selected primarily for conven- ience in the updating of data. Most multipliers are from the 1970 Census of Housing, with some for minor a G ppliancescoming from the 1969 Starch market profile, scaled up to,1970 by the rate of dwelling unit population growth. Since the 1970 Census multipliers are very "hard," 1970 was chosen as the base year for this section. Independent estimates of total 1970 residential energy for each "fuel," including electricity, are in each case within 10 percent of the amounts calculated by multiplying out the table and summing over activi- ties for each fuel. Conceptually, the activities.and fuels iden- tified in the table cover over 95 percent of all residential., energy use. While the principal end use rates (those for direct heat, etc.) are well established statistics from the American Gas Association, the Edison Electric Institute, or calculated from Bureau of Mines petroleum data in conjunction with Census figures, some use rates are subject to assumptions stated clearly in the footnotes. In particular, the use rates for room and central air onditioning are dependent upon the assumed average rated capacities of the various units. c All air emission factors are derived from FPA's compilation (Ref. 0002). Those for space heat and water heat are judged to be very accurate, while those.obtained through correction factors (from the San Francisco Bay Area Air Pollution Control District) are only rough approximations. The orders of magnitude of these factors (for gas dryers, ranges, etc.) are believed correctf and their contribution to total residential air emissions is small. Only an Sox factor is included for gas lamps (yard lights) be- ..Cause relevant emissions are not presently available. In this sector no significant environmental effects other than air pollution are energy-related. multipliers in this section may be escalated to 1971, 1972, or 1973 without serious error by application of the 1.3 percent yearly population gain figure for 1969-1971, from the 1972 Statistical Abstract. VII-1 B. Impact Data.Table and.Fcotnotes VII-2 13 Eo .1 E .1 20 E. 1. SE sEcm. -lCR POLLITANTS (TONSI-Uft. EX. COL 12) IR F-U-St-311E. . . ol- -j@X ARI KE-RE 1- -T-- -1111E C.D W-s T.- _L: _L: Ff t@* ACIOS BASES P., E Em R ... cm I.-E. -Tt .0. D-TER --t:`@ T -- -- ----- 2--- 13 -2!!L 2. 171 -2- 41 .4 7 El@CTRICAL E@ERGY [email protected] 14 6TU'5 15 DERIVED E-," '11,1"AL,,EIT 11 ILI,[email protected],11L I tl 3 7 TABLE 27. ENVIRONMENTAL IMPACTS AND FICIENCY OF 'A T @l L! 111, -T RESIDENTIAL ENERGY FE H.F V11-3 FOOTNOTES FOR TABLE 27 FTN. 5001-5015 5001 199 BTU/DWELLING-YR FROM (5010,55) WHICH ASSUMES 5000 ANNUAL DEGREE 299 HEATING DAYS. NUMBER OF OCCUPIED DWELLINGS WITH NATURAL GAS, 399 LEG HEAT FROM (5102). USE RATE IS STATISTICALLY DERIVED, AND 499 REPRESENTS AN AVERAGE SIZE DWELLING WITH AVERAGE INSULATION, 599 USE PATTERNS ETC. FOR CONTEXT, A 1700 SF TWO STORY WOOD FRAME 699 HOUSE, SYNTHESIZED TO REPRESENT THE BALTIMORE-WASHINGTON AREA, 799 USED ABOUT 1.36+08 BTU/YEAR FOR GAS FORCED AIR HEAT, FROM 899 (5106,II-42). 999 5002 199 BASED ON 2.51E+15 BTU DISTILLATE PLUS KEROSENE INTO RESIDENTIAL 299 SECTOR, FROM (0007,38/40). WE SUBTRACT 2.15E+14 BTU TOTAL 399 COMPUTED FOR WATER HEAT TO GET AMOUNT FOR SPACE HEAT, THE ONLY 499 OTHER IMPORTANT USE NUMBER OCCUPIED UNITS USING DISTILLATE 599 (0R KEROSENE - A SMALL NUMBER) FROM (5102). 699 5003 199 FROM (5112). MULTIPLIER IS FROM (5102) 299 5004 199 FROM (5101,55). MULTIPLIER IS FROM (5102) ASSUMES NAT. GAS AND 299 LPG HAVE SAME EFFICIENCY AND USE PATTERNS. 399 5005 199 BASED ON RATE FOR GAS WATER HEAT. ASSUMES FACTORS OTHER THAN 299 TECHNICAL EFFICIENCY SAME FOR OIL, GAS WATER HEAT ARE 399 50P, 64P, RESPECTIVELY (0007,18). MULTIPLIER IS FROM (5102) 499 5006 199 FROM (5102). ASSUMES HALF OF ALL UNITS ARE QUICK RECOVERY 299 TYPE (5103). 399 5007 199 FROM (5101, 55). MULTIPLIER IS FROM (5102). 299 5008 199 FROM (5104). MULTIPLIER IS FROM (5102). 299 5009 199 BASED ON 31E+06 BTU/YR PER12000 BTUH CAP UNIT (5105,55). 299 ASSUMES AVERAGE UNIT IS 24000 BTUH CAP; SEE FOOTNOTE 5010 399 MULTIPLIER ASSUMES 8PL TOTAL ARE GAS UNITS (0007). TOTAL UNITS 499 --CM(5102) 599 699 5010 199 FROM (5104). AVERAGE CENTRAL UNIT 3350 WATT RATING CORRESPONDS TO 299 24O00 BTUH CAP, FROM (5114). MULTIPLIER IS FROM (5102) 399 5011 199 FROM (5103); AVERAGE ROOM UNIT DRAWS 1500 WATTS, EQUIVALENT TO 299 10000 BTUH CAP, FROM (5113). MULTIPLIER IS FROM (5102) 399 5012 199 FROM (5103). MULTIPLIER IS FROM (5102). 299 5013 199 BASED ON 40000 BTU/CYCLE (5105). ASSUMES 12 CYCLES/YR. NO 299 ADJUSTMENTS FOR SUPERIOR INSULATION (5101,55). NO MULTIPLIER 399 AVAILABLE BUT IS ASSUMED SMALL RELATIVE TO TOTAL NUMBER RANGES 499 5014 199 BASED ON 10000 (DIRECT KWH EQUIVALENT) BTU/CYCLE (5106) NO 299 ADJUSTMENTS FOR SUPERIOR INSULATION. NO MULTIPLIER 399 AVAILABLE BUT ASSUMED SMALL AT PRESENT. NORMAL USE RATE FROM 499 599 5015 199 FROM (5103). MULTIPLIER IS P OF HOUSEHOLDS (5107). TOTAL 299 HOUSEHOLDS, (5102). VII-5 ] Preceding page blank FTN. 5016-5031 5016 199 QUICK WARM-UP TUBE SETS DRAW 30 WATTS WHEN OF. ASSUMES DUTY 299 CYCLE COMPLEMENTARY TO ACTUAL USE CYCLE (5108). SOLID STATE 399 SETS ARE MAKING THIS FEATURE OBSELETE. NO MULTIPLIER AVAIL- 499 ABLE AT PRESENT. 599 5017 199 FROM (5103). DISTRIBUTION OF DIFFERENT TYPES OF REFRIGERATION 299 UNITS FROM (0007.50). TOTAL HOUSEHOLDS FROM (5102). P WITH 399 REFRIGERATOR. (5107). 499 5018 199 FROM (5103). ASSUMES 50PC ARE NO FROST UNITS. TOTAL NUMBER 299 FROM (5102). 399 5019 199 FROM (5101, 55). REF. (5117) GIVES ESTIMATE FOR NO. GAS POST 299 LIGHTS AT END OF 1972). 399 5020 199 BASED ON 950 KWH OF INCANDESCENT LIGHTING/DWELLING-YR (5104) 299 THE BTU MEASURE FOR FLUORESCENT LIGHTING ASSUMES 55 KWH/ 399 DWELLING-YR FOR ONE 30 WATT LAMP USED 5 HR/DAY. MULTIPLIER 499 IS TOTAL OCCUPIED UNITS (5102). 599 5021 199 FROM (5103). MULTIPLIER P IN 1969 FROM (0007). TOTAL HOUSEHOLDS 299 1969, 1970 FROM (0018). 399 5022 199 FROM (5103). MULTIPLIER ASSUMES 5P OF SINGLE FAMILY HOMES HAVE 299 ATTIC FAN, NUMBER HOMES FROM (5102). 399 5023 199 FROM (5103). MULTIPLIER ASSUMES 90P OF ALL OCCUPIED UNITS WITH WARM 299 AIR HEAT USE A FAN. NUMBER SUCH UNITS FROM (5102,1-288) 399 5024 199 FROM (5103). MULTIPLIER ASSUMES 50P OF HOMES WITH NO A/C USE 299 A ROLL-ABOUT FAN. NUMBER A/C AND TOTAL UNITS FROM (5102,1-235) 399 5024 199 FROM (5103). MULTIPLIER ASSUMES 90P OF ALL RURAL HOMES USE A WATER 299 PUMP. NUMBER RURAL HOMES FROM (5102, 1-286) 399 5026 199 FROM (5103). MULTIPLIER ASSUMES 20P OF ALL PHONES ARE RADIO-PHONO 299 COMBINATION. PERCENT HOMES WITH PHONES FROM (5107). TOTAL 399 HOUSEHOLDS FROM (5102). 499 5027 199 FROM (0002). BTU/BBL CONVERTED FROM (0005). 299 5028 199 FROM (0002). BTU/BBL CONVERTED FROM(0005). 0.218 P TAKEN AS 299 SULFER CONTENT OF NUMBER 2 FUEL OIL. BASED ON WEIGHTED AVER-L 399 AGE OF SULFER CONTENT IN FIVE REGIONS OF U.S. DERIVED FROM 499 (5109.7) AND (5118,38). 599 5029 199 FROM (0002). 1031 BTU/OF CONVERSION FROM (0005). 299 5030 199 FROM (0002). 4.011 BTU/BBL CONVERTED FROM (0005). ASSUMES AVERAGE 299 SULFER CONTENT OF 12 GRAINS/100 CF LPG. 15 GRAINS/100 CF IS 399 REGULATION BY (5110). ASTM ALSO SETS 10 GRAINS/100 OF MAXIMUM 499 FOR HD-5, A HIGH QUALITY PROPANE, INDICATING THAT 599 ORDINARY LPG IS SOMEWHERE BETWEEN 10 AND 15 GRAINS/100 CF. SEE 699 (5111). 799 5031 199 1001 BTU/CF CONVERTED FROM (0005). ASSUMES SAME EMISSION FACTORS 299 AS FOR SPACE HEAT, EXCEPT FOR A 10P INCREASE IN NOX RATE, FROM 399 (0008,A-1) 4.011 BTU/BBL CONVERTED FOR LPG ALSO FROM (0005). 499 SPACE HEAT FACTORS FROM (0002) 599 VII-6 FTN. 5032-5035 5032 199 FROM (0002). BTU/BBL CONVERTED FROM (0005).OIL WATER HEAT AND 299 SPACE HEAT ARE FROM SAME FURNACE. THE SULFUR CONTENT OF FUEL 399 OIL IS TAKEN AS 0.218 PC BASED ON A WEIGHTED AVERAGE OF 499 SULFUR CONTENTS IN THE 5 U.S. REGIONS, DERIVED FROM (5109,7) 599 AND (5118,38). 699 5033 199 EMISSION FACTORS FOR SPACEHEAT FROM (0002) THE FOLLOWING 299 CORRECTICN FACTORS FOP OTHER RESIDENTIAL USES ARE INFERRED 399 FPOM (O008,A-1) 499 PART NOX sox HC CO ALDEHYDES 599 RANGE 1.0 0.6 1.0 1.0 1.0 1.0 699 DRYER A1.5 1.0 1.0 1.0 1.0 799 WATER HEATING 1.0 1.1 1.0 1.10 1.0 1.0 899 999 UNIT CONVERSIONS FOR NATURAL GAS, LPG FROM (0005). SULFUR 1099 CONTENT FOR LPG FROM ASTM STANDARDS (5110), AND (5111). 1199 GAS CENTRAL A/C USES ABSORPTION CYCLE, WITH NO MOVING PARTS 129 EXCEPT FOR A SMALL FAN. GAS IS FIRED UNDER A VESSEL TO HEAT 1399 A LIQUID..IT IS ASSUMED THAT GAS A/C EMISSIONS ARE SAME AS 1499 FOR WATER HEAT. 1599 1699 5034 199 ASSUMES SOX EMISSIONS SAMS AS SPACE HEAT FACTOR FROM (0002). NO 299 FACTORS AVAILABLE FOR OTHER POLLUTANTS. 399 5035 199 EMISSION FACTORS, ESTIMATED DUTY CYCLE (50 HR/YEAR) FROM 299 (5115,15FF). BTU PEP UNIT-YR CALCULATED FROM 0.043P SULFUR IN 399 GASOLINE PRODUCING 26 GR/UNIT-YR S02, IN 4-STROKE ENGINES. 499 ASSUME THIS FIGURE (CORRESPONDING TO 12 GALLONS GAS/YEAR) 599 REPRESENTS ALL MOWERS, SINCE 2-STROKE ENGINES ARE ONLY 7P OF 699 TOTAL. EMISSION RATES GIVEN IN (5115,15FF) FOR 4-STROKE AND 799 2-STROKE ENGINES WERE WElGHTED BY NUMBER EACH TYPE IN USE TO 899 GET AVERAGE VALUES. 0.67 GR/CU CM GASOLINE FROM (5116,F3) . 999 5.248E+06 BTU/BBL GASOLINE FROM (0005) . TOTAL NUMBER IN USE 1399 ESTIMATED AT ONE PER SINGLE FAMTILY RESIDENCE. NO. RESIDENCES, 1199 FROM (5102),WAS 42.1 MM IN 1970. 1299 NOTE- ELECTRICAL ENERGY CONSUMPTION GIVEN IN BTU IS DERIVED BY TAKING THE BTU EQUIVALENT OF KWH (3413) AND MULTIPLYINGY 3 TO REFLECT THE EFFICIENCY OF POWER PLANT ENERGY PRODUCTION. VII-7 VIII. COMMERCIAL END USE A. Introduction The environmental impacts and energy use in the uncontrolled commercial end use sector are given in Table 28. Eighteen separ- ate categories of end use have been identified. It is estimated that these categories cover more than 95 percent of all commer- cial energy use. No individual category use rates exist in'the literature and hence the measures assigned are based on the simplest practical definition of energy use. By estimating the average floor area per employee, it is ossible to compute, for instance, the total design lighting, cooling, and heating loads in the commercial sector. Detailed employment statistics ate published by the Bureau of Labor. Design lighting, cooling, heating, and total occupancy criteria for all types of commercial. buildings are available from the Electric Energy Association. Thus, the expedient measure of energy use for electric lighting is "square foot-year?" and energy (Column.28) is expressed as "Ptu/squa 're foot-year." The multiplier is then.the computed area of commercial space using electric lighting, namely all commercial area. Several assumptions must be made before the rather broad commercial sector data available can be broken apart into desirable components. For example, one assumption involves the average floor area,per erployee. Special pain has been taken in the footnotes to state clearly what these assumptions are. Some of the work in the commercial sector is new, and probably un- available from any source heretofore. @7 I I I B Impact Data Table and Footno tes VIII-2 4 ED 11 1. ED 24 El E. oG-lOHAL HEALTH @E-- END USE SECTOR A-U-T% (T-/@EASLPR) LA..E A- HE- 'o so. TOTAL D-TER COD DIS$-D 30LIDS TOTAL ULATI, -4= A.- BASES T-51 D-nes HH -T 7 6 7 A HH 2 - -------- 12 .0 ED 21 25 2-7 261 1 30 T A 31 4. AD 4. @ 44 49 4 TABLE 28. ENVIRONMENTAL UAPACTS AliL --TICIENCY OF 11111TIll 11 ITI'.16L11 Ill EDJI'[email protected] COMMERCIAL ENERGY"s-H OF @o) IITI@ EL111111AL I .... .. THE 8TO EQUI I.LE w. D o REFLECT THE FG$SIV FUEL EQUIVALERT OF ELECTRICITY. HUI, 'T I 4 4. DO VIII-3 FOOTNOTES FOR TABLE 28 FTN. 5501-5506 5501 199 FROM (5501), INSTALLED RECEPTACLES PROVIDE 2.0 WATTS/SF IN COM- 299 MERCIAL BUIDLINGS. ASSUME 10P IS USED FOR MISCELLANEOUS 399 APPLIANCES NOT INCLUDING OTHER USES CONVERED IN THIS TABLE, 499 DURING BUILDING USE. (5502) SHOWS COMMERCIAL BUILDILNGS OPEN 599 FOR BUSINESS 59.5 HR/WK, PLUS 10 HR/WK AT 1/3 LOAD, OR TOTAL 699 63 HR/WK OPERATION. FROM (5503), IN 1970 THERE WERE 46.1 MM 799 EMPLOYEES IN COMMERCIAL AREA. 350 SF/EMPLOYEE IS ASSUMED. 899 SEE FOOTNOTE 5508 FOR JUSTIFICATION OF THIS SF/EMPLOYEE 999 NUMBER. 1099 5502 199 FROM (5501), DESIGN CRITERION FOR LIGHTING IS ABOUT 4-5 WATTS/SF. 299 WE CONCERVATIVELY ASSUME 3.0 WATS/SF FOR AVERAGE COMMERCIAL 399 BUILDING. (5502) SHOWS DATA FOR MANY KINDS OF COMMERCIAL 499 BUILDINGS OPEN FOR BUSINESS 59.5 HR/KW PLUS 10 HR/WK AT 1/3 599 POWER, OR TOTAL OF 63 HR/WK PLUS 10 HRL/WK AT 1/3 699 POWER, OR TOTAL OF 63 HR/WK. FROM (5503), IN 1970 THERE WERE 799 46.1 MM COMMERCIAL EMPLOYEES. ASSUME 350 SF/EMPLOYEE. 899 5503 199 FROM (0007,77-78). THERE IS AN AVERAGE 480 KWH/CF-YR REFRIGERA- 299 TION VOLUME IN COMMERCIAL BUILDINGS. WE ASSUME 480 KWH/CF-YR 399 FOR FREEZER VOLUME, TOO, SINCE RESIDENTIAL DATA FROM (5504) 499 SHOW REFRIGERATORS, FREEZERS USE SAME KWH/CF-YR. FROM (0007) 599 IN 1970 THERE WER 158 MMCE TOTAL VOLUME REFRIGERATOR AND 699 FREEZER IN COMMERCIAL BUILDINGS. 799 5504 199 FROM (5501), DESIGN SPECIFICATION FOR COMMERCIAL FLOOR SPACE IS 299 250 SF/TON CAPACITY OR 48 BTUH/SF (5502) SAYS IN 1959 399 REFRIGERATOR AIR COOLING EQUIPMENT OPRATED ABOUT 865 499 EQUIVALENT FULL LOAD HRS/YR. (0007) SAYS 1000 HRS/YR IS 599 NOMINAL. WE ASSUME 1000 EQUIVALENT FULL LOAD HRS/YR FOR 1970. 699 (5502, 1021) SAYS A DRY CONDENSING CYCLE A/C WITH 90 DEGREE F 799 CONDENSOR AND 40 DEGREE F EVAPORATOR REQUIRES ABOUT 0.8 BHP/ 899 TON RATING. THIS INDICATES A COEFFICEINT OF PERFORMANCE OF 3.3 999 FOR REFRIG. CYCLE PART OF SYSTEM. FROM (5502, 1021), 1099 REFRIGERATION IS USUALLY LARGEST POWER USER IN 1199 COMMERCIAL A/C SYSTEMS. TO ACCOUNT FOR AUXILIARY EQUIPMENT 1299 LIKE FANS, PUMPS, WE ADD ANOTHER 90P TO ENERGY USE RATE FOR 1399 REFRIGERATION CYCLE ALONE. FROM (0007) ABOUT 70 P 1499 COMMERCIAL AREA HAD A/C IN 1970, AND 13 P OF THAT WAS GAS A/C, 1599 THE REST ELECTRIC. TOTAL FLOOR AREA ASSUMES 350 SP/EMPLOYEE 1699 46.1 MM EMPLOYEES FROM (5503). FOR GAS UNITS WE ASSUME A 1799 COEFFICIENT OF PERFORMANCE OF 1.65, AND ADD 90/2=45P TO TOTAL 1899 IN FORM OF ELECTRICITY FOR AUXILIARY EQUIPMENT. 1999 5505 199 ASSUME TOTAL NUMBER OF MEALS IN 1970 WAS 200 MM PEOPLE AT 3 MEALS/ 299 DAY OR 220 MMM MEALS (0007) ESTIMATES 17.5 OF ALL MEALS 399 WERE PREPARED COMMERCIALLY IN 1968, AND 12 P OF THOSE WITH 499 ELECTRICITY--GAS COOKING IS 1/2 AS EFFICIENT AS ELECTRIC. FROM 599 (0007) GROWTH RATES WE ESTIMATE 125E12 BTU GAS AND 8.55E12 699 EQUIVALENT BUT ELECTRICITY USED IN 1970. ASSUME RATIO LPG/LPG 799 +N.GAS IN ALL COMMERCIAL USES (10.6/246.8-4.3-) HOLDS FOR 899 COOKING. FINAL ELECTRICAL RATE CONVERTED BY (3X3413) BTU/KWH. 999 5506 199 FROM (0007) 580E09 GALLONS WATER HEATED COMMERCIALLY, 1968. FROM 299 (0007) GROWTH RATE WE GET 600E09 FOR 1970. FROM (0007) 70P 399 WATER IS HEATED BY GAS, 20P ELECTRIC, 10P COINCIDENTAL WITH 499 SPACE HEAT (WE INCLUDE THIS 10P WITH SPACE HEAT). ALSO FROM 599 (0007) ASSUME 92P EFFICIENCY FOR ELECTRICITY AND 64P 699 EFFICIENCY FOR GAS, AT 80 DEGREES F TEMPERATURE RISE AND 8.345 799 LP/GAL WATER. NEGLECT STANDING LOSSES. ASSUME OVERALL 899 VIII-5 Preceding page blank FTN. 5507-5509 COMMERCIAL RATIO LPG/LPGN.GAS (=43P) HOLDS FOR WATER HEAT. 99 5507 199 (5505,31) SAYS 11.18EO9 KWH USED FOR STREET LIGHTING, 1970. FROM 299 (506,31), MCDERATE SIZE STREET LAMP IS 4000 LUMENS AND 300 399 11HR/DAY SCHEDULE. AS A CHECK,THERE WERE 451 M WATTS. ASSUME 499 MILES CITY STREETS IN 1969 (5507,58). 9.2MM LAMPS OVER 451 M 599 MILES MEANS ABOUT 250 FT BETWEEN LAMPS WHICH IS REASONABLE. 699 ASSUME 5508 199 REMAINER OF FUEL ENERGY NOT OTHERWISE IDENTIFIED GOES INTO 299 SPACE HEAT. APPROXIMATE BURNER EFFICIENCIES DETERMINE 399 FFACTIONS OF TOTAL FLOOR -AREA HEATED BY DIFFERENT FUEL INPUTS. 499 TOTAL FLOOR AREA ESTIMATE IS 350 SF/EMPLOYEE. 46.1 MM WORKERS 599 FROM (5503). (0007,18), GIVES THERE BURNER EFFICIENCIES FOR 699 COMMERCIAL SPACE HEATING: COAL- 70P N.GAS- 71P LPG 77P 799 OIL- 76P. WE ASSUME RESIDUAL AND DISTILLATE OIL SAME 899 EFFICIENCY. TOTAL NATURAL GAS FOR COMMERCIAL AND OTHER 999 (INSTITUTION, MUNICIPAL) CATEGORIES= 2.44E+15 BTU . TOTAL 1099 RESIDUAL FUEL OIL (COMMERCIAL) =1.17E+15 BTU . TOTAL COAL 1199 4.27E+14 BTU (ASSUME ALL COMMERCIAL) LISTED UNDER RESIDENTIAL 1299, AND COMMERCIAL TOTAL LPG FOR RESIDENTIAL AND COMMERCIAL 1399 7.22OE+14 BTU DISTILLATE FUEL OIL FOR RESIDENTIAL AND 1499 COMMERCIAL = 3.06E+15 BTU, FROM (C025.,23/28). AMOUNTS IN 1599 MISCELLANEOUS CATEGORIES SMALL, EXCEPT FOR NATURAL GAS,. 1699 LPG= 6.17E+14 BTU, FROM TABLE 27 TOTAL DISTILLATE FOR 1899 ASSUMED TO BE FOR MUNICIPAL USE (INCLUDED). TOTAL RESIDENTIAL 1799 RESIDENTIAL USE = 2.49E+15 BTU. SUBTRACTING ENERGY FOR OTHER COMM' RCIAL USES LEAVES THESE AMOUNTS FOR SPACE HEAT NATURAL 2099 GAS- 1.86E+15 BTU; LPG- 8.3E+13 BTU; COAL- 4.27E+14 BTU, 2199 DISTILLATE- 5.70E+14 BTU, RESIDUAL- 1.17E+15 BTU. SOLVING,WE 2299 GET THE AREAS HEATED bY EACH FUEL, AND FINALLY THE BTU/SF-YR 2399 FOR EACH FUEL. AS A CHECK, (5501) GIVES NOMINAL DESIGN CRI- 2499 T FULL LOAD HEATING HRS PER YEAR AND 45P SYSTEM EFFICIENCY, 2699 TERION OF 3.6 BTUH/OF VOLUME COMMERCIAL AREA. ASSUMING 2000 2599 COMPARISCN WITH 2.52E+05 BTU/SF-YR USE RATE FOR GAS INDICATES 2799 THAT THE AVERAGE CEILING HEIGHT MUST BE ABOUT 15.7 FEET, A 2899 REASONABIE NUMBER. 2999 5509 199 SPACE HEAT FACTORS TAKEN FROM (0002). 1031 BTU/CF (DRY) NATURAL 299 GAS.4.01E+06 BTU/BBL LPG, 5.83E+06 BTU/BBL DISTILLATE OIL, 399 it 6.29E+06 BTU/BBL RESIDUAL OIL, 2.54E+07 BTU/TON ANTHRACITE, 499 AND 2.42E+06 BTU/TON. BITUMINOUS COAL FROM (0005,38). 599 12 GRAINS SULFUR/100 CF LPG FROM (5511) AND (5512). 0.218 PC 699 SULFUR IN NUMBER 2 FUEL OIL FROM (5513) AND (5518,38) BY 799 AVERAGING FIVE REGIONAL VALUES; 1.73P SULFUR IN NO. 5 FUEL 899 OIL FROM SAME REFERENCE. ANTHRACITE IS 27P OF COMMERCIAL 999 COAL, REST BITUMINOUS, FROM (0025). FROM (5510), ANTHRACITE 1099 IS 12P ASH, 0.6P SULFUR; BITUMINOUS IS 10P ASH, 2.OP SULFUR. 1199 SOLID WASTE/MEASURE IS DERIVED FROM THE ASH CONTENTS OF THE 1299; COALS AND SPACE HEAT FACTORS IN (0002). PARTICULATE EMISSIONSI 1399 ARE SUBTRACTED. FOLLOWING CORRECTION FACTORS APPLIED TO 1499 SPACE HEAT FACTORS (0002) GIVE EMISSIONS FOR OTHER USES, 1599 FROM (0008 A-1 1699 (GAS) PART SOX CO HC NOX ALDEHYDES 1799 WATER HT 1.0 1.0 1.0 1.0 1 . 1 1.0 1899 COOKING 1.0 1.0 1.0 1.0 0.6 1.0 1999 AIR CONDITIONING 1.0 1.0 1.0 1.0 1.1 1 .0 2099 WE-ASSUME AIR CONDITIONING EMISSIONS SIMILAR TO WATER HEAT. 2199 VIII-6 FTN. 5510 5510 199 BTU/BBL ASPHALT AND ROAD OIL FROM @0005,38). TOTAL NUMBER BTU 299 FROM (0025,28). 399- NOTE- ELECTRICAL ENERGY CONSUMPTIO.N IN BTU'S IS DERIVED BY TWING THE BTU EQUIVALENT OF KWH (3413) AND MULTIPLYING BY13 TO REFLECT THE EFFICIENCY OF POWER PLANT ELECTRICITY PRODUCTION. VIII-7 IX. INDUSTRTAL END USE 'A. Introduction The industrial sector has been approached on an industry 47 basis, staying within the general definition of the industry that is consistent with its SIC (Standard Industrial. Classifica- tion) code number.. The industrial data are contained in Table 29 with six industries presented in the following order: SIC 26 Paper and Allied Products' SIC 37 Transportation Equipment. SIC 32 Stone Clay, Glass and Concrete SIC 28 Chemicals SIC 20 Food and Kindred Products SIC 33 Primary Metals A seventh large indlistry, SIC 29 - Petroleum Refineries and Related Products, is contained implicitly within theoil tables.. In descending order of energy consumption among all industries, the six industries evaluated are.as follows: 1 SIC 33 2 SIC 28 3 SIC 32 4 SIC 26 5 SIC 20 6 SIC 37 Each of the industries has been broken down into subparts which, in effect, correspond to a specific end use. For example, Pulp and Paper Mills under SIC 26 is the first such industrial end use. A further breakdown of the end use is by the fuels con- sumed. I-Tote however, that contrary to other end use tables, en- vironmental impacts are not allocated to each fuel. The avail- able data on industrial environmental impacts did not justify any attempt at disaggregating the level of data presented. The en- vironmental usefulness of the industrial table is limited, therefore, since environmental impacts cannot be allocated to specific fuels except in a Very approximate fashion.. The 1967 Census of Manufactures - Fuels and Electric Energy Consumed -, was used to determine the energy efficiencies of many of the industrial end uses. Certain assumptions are inherent in that use and should be noted. IX-1 0 There are certain omissions in the data from this reference where consumption of certain fuels is with- held to avoid divulging individual company data. It is assumed that the omissions for any SIC category are small in comparison with the consumption of fuel types given. 0 For industries, in which the fuel efficiency is based on the- 1967 data, the assumption is made.that fuel mixes and efficiencies remain constant between 1967 and the specified multiplier year. Q Use of 1967, data fixes the production processes and fuel mixes of the industries involved to that year. General Reference 0007 - Patterns of Energy Consump- tion in the U.S., Stanford Research Institute, 1972 can be used for information about,trends in production processes that could affect fuel efficiencies and fuel mixes. As a general caution the reader is urged to read the foot- notes before using the industrial end-use data. The footnote will point out exactly which environmental impacts have been presented (energy-related, process-related or both). Difficulties in dis- tinguishing the impac-ts together with the limited data available prec-1'uded. rigorous separation of the industrial end-use environ- ment al impacts., Figure 13 summarizesithe emission data which appe.ar in the tables. IX-2 Industry Classification Process Related Emissions Included With Energy Use-Related Emissions Water Emissions Air Emissions Pulp and Paper Mills Yes Yes* Paper Products Mfr. Yes No Motor Vehicles No No Motor Vehicle Parts No No Glass Products Yes Yes* Clay Products No Yes* Cement and Related Yes Yes,* Stone and Related Yes Yes* Chemicals, Inorganic" Yes Yes* Chemicals, Organic Yes Yes* Meat and Dairy Products Yes No Bakery Sugar Confectionary Yes No Beverage, Can, Cured & Frozen" Yes Yes*. Grain Mill & Misc. Food & Kindred Yes Yes* Iron & Steel Making No No Iron & Steel Castings No No Primary Aluminum No No Primary Copper No No Primary Zinc No No Table entry includes both energy and process related emissions, however, these emissions are disaggregated. in the related footnote. Solid waste table entry includes process related impact. Figure 13. Basis for Industrial End-Use Emission Data IX-3 B. Impact Data Tables and Footnotes ix-4 END USE -T.G. A A a @3 R 1. 1. 20 1, @2 I. E. 30 WATER 101LUTANTS AIR POLLUTAITSUON31-9) KIIALTH E.. -E ..-EO VEL- ... coD 30. C. TOTAL E.- LA- ..E.. RE`--- --W ACIOS BA O-R TOTAL- -D8 OREARIC, ".1 'A, LcsTWE. 3 A 5 7 21- -L-A ,0 4@- 12 _13 T 21 El. RE .7 33 _34 17 - ----------- AD AT T3 43 -1 48 -;7. NOTE: ELECTRICAL ENERGY CaNSUKPTION IN BTU-5 IS 'E TOE ITI El" IIALEIT 11 IN" '1111, AN@ R,LTI;LTl!NGE",Ty3TATll G TABLE 29. ENVIRONMENTAL WACTS AND EFTICIENCY OF RE 'LICT 'HE F.,IIL FUEL rQIIIVALEXT OF EIECiRl CIFT. INDUSTRAAL MRGY USE (PART I OF 3) IX-5 1 6 1 A 14 IT 1. 1. 1. B, 24 R. 1ATER P01-T-S (TONSIMEMURE. EX CM CR) --A- (,o .... R.- I -- -ol wo- -I I -No '*T' -A- L.CTE .'E. RNA, -T-AV C11-R V.. Co. No. @EZYM C... ANN. C_ C__, _.C, BTU-] 6 T "o - ------------------ 14 No 20 14 21 Cl 2. IN 31 3S L4 34 p 39 IN, 45 V7 R produi d from ec best a@ailable copy. ITE: ELECTRICAL ENERGY C0KSUAPTj0N IN BTU-S IS DERIVED BY TAKING -EENCY OF THE BTU "U 1111.11T 11 W 1@11) M QLTIlLlI.. 11 1. TABLE 29. ENVIRONMENTAL IMPACTS AND n"t- REFLECT THE .$,I L .. L EQUIVALENT DF ELECTRICITY. DMUSTREAL ENERGY USE, (PAR7 4r)F 3) IX- 7 blaA ru R I 0VT I A 3 4 o I a I. I 1, 1. 11 A I I S I @II @4 11, 2. .1 1. 1@ END usc mECT-�R -;ATER -POLLUTANTS (TONS111ASIR IT, @COL. 12 1 AIR -LUTANT1 (T1NSJ1EAS,,Rf) - -- E.- ..--A C BASES Mo. TOTAL A, I.T-E-I ETC ..S S. 1OS- 'T A EID ISE SOLI.S A-S A LF 10 13 16 IS 2S 23 -2A -T- SO it A, IS -3-2 AM 4 ---ZO 41 A MOTE: ILF@T 'T", DER !,I-i ENERGY @QMSU4PTIOk TK E . . . "Ll' ol "I I'll 3) A" MuLT,"! RE"Ec, TYE 1E.: @IEL EW@IALEI,T OF ELECTqiMr@'. TABLE 29. ENVIRONMENTAL IMPACTS -@LNM E@!,CZEN@-Y OF INDUSTRIAL ENERGY USE IX-9 preceding page blank M, FOOTNOTES P09 TABLE 29 FTN. 6100-6105 6100 199 INCLUDED UNDER ORGANIC CHEMICALS ARE ALL CHEMICALS REPORTED IN 299 (6100) AND (0025,255/266). THESE CHEMICALS MAKE UP SIC 2815, 399 SIC 2818, SIC 282, SIC 283, SIC 289, SIC 2879, SIC 2851, SIC 499 AND MOST OF SIC 284. THE PERCENTAGE BREAKDOWN OF SELECTED 599 CRGANIC CHEMICALS AS USED IS AS FOLLOWS- ACETIC ACID = 1.45, 699 ACETONE = 0.68, ACRYLATES = 0.01, ADIPIC ACID = 0.44, CARBON 799 BLACK = 1.24, DETERGENT = 1.15, ETHYL BENZENE AND STYRENE = 899 3.7, EXPLOSIVES = 0.90, BUTANOL = 0.20, BUTADIENE = 1.32, LD 999 POLYFTHYLENE = .1.8, PHTHALIC ANHYDRIDE = 0.73, PLASTICS 6.651099 PAINT = 1.02, PAINT AND VARNISH = 3.31, PRINTING INK 1.02 1199 PCLYSTYPENE = 2.00, PHENOL = 0.77, PHENOLIC RESINS = 0.50, 1299 NYLON = 0.30., SYNTHETIC FIBERS = 0.60, SYNTHETIC RUBBER = 1.861399 TEREPHIHATIC ACID = 0.55, UREA = 2.65, UREA & MELAMINE. 1499 RESINS = 0.321. 1599 6101 199 INCLUDED UNDER INORGANIC CHEMICALS ARE THOSE CHEMICALS REPORTED IN .299 (6101), (6102) AND SELECTED MATERIAL FROM (0025). THESE 399 CHEMICALS MANE UP SIC,2812, SIC 2813, SIC 2816, SIC 2871, SIC 499 2872 AND PARTS OF SIC 284. WHERE VALUE OF TOTAL PRODUCTION 599 ONLY IS GIVEN, THE AVERAGE VALUE OF SEP09TED TONNAGE IS USED. 699 THE PC BFEAKDOWN OF PRODUCTION OF SELECTED CHEMICAL IS AS 799 FOLLOWS- AMMONIA = 8.10, AL SULFATE = ' 0.74, CA CARBIDE = 0.46, 899 CHLORINE = 8.30, FRIT =.0.58,'HYDROCHLORIC ACID =1.18, 999 HYDROFLOUPIC ACID = 0.14, NITRIC ACID = 3.91, PHOSPHORIC ACID 1099 3.30, PHOSPHOROUS = 0.35, PHOSPHATE FERT. = 2.86., NITRATE 1199 FEET 1.03, SODA ASH = 4.13, NA CHLORATE = 0.12, NA DICHROM- 1299 ATE 0.09, NA METASILICATE =0.13, NA ORTHOSILICATE = 0.02, NA1399 TRIPHOSPHATE = 0.71, SULFURIC ACID = 17.26 1499 6102 199 ACID EFFLUENT FOR SELECTED INORGANIC CHEMICALS IS GIVEN BELOW. 299 (6103,A). (WASHING AND RINSING EFFLUENT NOT INCLUDED) LB/TON 399 CHLORINE (DIAPHRAM AND MERCURY CELL) 42.07 499 PHOSEHORIC ACID (WET AND DRY PROCESS) 0.50 599 AL SULFATE (BAUXITE FEED AND CLAY FEED) 12.25 699 SODIUM METASILICATE 0.61 799 HYDROFLOURIC ACID 537.00 899 ACID EFFLUENT PER TON PRODUCT IS THE SUN FROM EACH SOURCE 999 WEIGHTED BY PC OF PRODUCTION. SEE FOCTNOTE 6101 1099 6103 199 EFFLUENT OF 2ASES FOR, SELECTED INORGANIC CHEMICALS ARE GIVEN BELOW 199 (6103,A) (EFFLUENT FOR WASHING AND SCRUBBING OPERATIONS ARE 399 NOT INCLUDED) L13/TON 499 CHLOFINE (DIAPHRAM AND MERCURY CELL) 43.50 599 SODIUM METASILICATE 10.00 699 SODA ASH 196.00 799 SODIUM CHLORATE 40.00 899 EFFLUENT OF BASES PER TON OF PRODUCT IS THE SUM OF EACH 999 SOURCE WEIGHTED BY PC OF PRODUCTION. SEE FOOTNOTE 6101 1099 6104 159 1PHOSPHATE EFFLUENTS OCCUR IN MAKING PHOSPHORIC AC D PHOSPHOROUS 299 A@D SODIUM TFIrHOSPHATE. THE EFFLUENT !S'AS FOLLOWS- (6103,A) 399 PHOSPHORIC ACID 22 50 LBjTON 499 :50 LB/TON 599 PHOSFHOROUS 10 SODIUM TRIPOLY PHOSPHATE 11.00 LB/TON 699 TOTAL PHOSPHATE EFFLUENT IS THE SUM FROM EACE SOURCE WEIGHTED 799 BY PERCENTAGE OF EACH SOURCE. SEE FOCTNOTE 6101. 899 6105 199 Preceding page blank FTN. 6106-6108 CLASSIFIED UNDER OTHER DISSOLVED SOLIDS IS A HOST OF DISSOLVED. 299 SOLIDS FFOM EACH SOURCE. THE EFFLUENT FROM EACH SOURCE IS AS 399 FOLLOWS (6103,A)- LB/TON 499 CHLOIINE 520.50 599 PHOSPHOROUS 13.60 699 ALUMINUM SULFATE 454.50 799 SODA ASH 3314.40 899 SODIUM METASILICATE 6.10 999 HYDROFLOURIC ACID 7100.00 1099 SODIUM CHLORATE 507.50 1199 SODIUM DICHROMATE 200.00 1299 TOTAL OTHER DISSOLVED SOLIDS IS THE SUM OF THE INDIVIDUAL 1399 SOURCES WEIGETED BY THE PERCENTAGE OF PRODUCTION OF EACH 1499 SOURCE. SEE FOOTNOTE 6101 1599 .6106 199 EFFLUENT OF SUSPENDED SOLIDS IS AS FOLLOWS FOR VARIOUS INORGANIC 299 CHEMICALS (6103,A) LB/TCN 399 CHLORINE 48.78 499 PHOSPHORIC ACID 4257.00 5991 PHOSPHOROUS 137.Cl 699 SODA ASH 17.70 799 SODIUM-METASILICATE 12.00 899 SODIUM ORTHOSILIATE 79.10 999 HYDROFLOURIC ACID 155.00 1099 TOTAL SUSPENDED SOLIDS PER 'PON PRODUCT IS THE SUM OF EACH 1199 SOURCE WEIGHTED BY THE PC OF PRODUCTION OF EACH SOURCE. SEE 1299 FOOTNOTE 6101 1399 1 6107 199 ORGANICS HAVE BEEN REPORTED FOR CHLORINE AND SOUA 299 ASH (6103,A) LB/TON 399 CHLORINE (CHLORINATED HYDROCARBON) 0.650 499 SODA ASH 0.003 599 ORGANICS PER TON OF PRODUCT IS THE SUM FROM 699 EACH SOURCE WEIGHTED BY PC OF PRODUCTION OF EACH SOURCE. SEE 799 FOOTNOTE 6101 899 6108 1991 BOD PER MGD MAY BE ESTIMATED FROM TOTAL BOD (0016,E99), BOD AND 2991 FLOW FOR UNTREATED WATER (0016,103) AND TOTAL WASTEWATER FLOW 399 (CO16,98) FOR-ALKALIES/CHLORINE, INDUSTRIAL INORGANICS AND 499 FERTILIZERS AS FOLLOWS 599 TOTAL BOD (CO16,99) COMP. BOD (LBS) 699 ALKALIES/CHLORINE 6 9237.0 799 INDUSTRIAL ORGANICS 10 53e55.0 899 FERTILIZER 3 3918.0 999 UNTPEATED (0016, 103) COMP. (MGD) BOD (LBS) 999 ALKALIES/CHLORINE 5 31.3 7697.0 1099 INDUSTRIAL INOFGANIC 6 189.3 32555.0 1199 FERTILIZER 2 1.9 362.0 1299 TOTAL FLOW (0016,98) COMP. (MGD) COMP. (MG D) 1399 ALKALIES/CHLORINE 6 18.6 9 39.8 149 INDUSTRIAL INORGANIC 10 28.4 13, 201.8 159 ck FERTILIZER 3* 17.5 8 69.1 1690q% TOTAL FLOW, MAY BE FOUND BY ASSUMING THE DIFFERENCE IN THE 179 COMP. FROM TOTAL BOD AND THE COMP. FROM INTREATED CAN BE 1899 ATTRIBUTED TO COMP. WITH TREATED WASTEWATER AND MULTIPLYING BY 1999 AVERAGE WASTEWATER FLOW. IN TURN THE BOD CAN BE ALLOCATED 2099 RESPECTIVELY. UNTREATED TREATED 2199 COMP. (MGD) BOD C0MP. (MGD) BOD 2299 A L K/CH L 5 31.3 7697 0 1 3.10 1540.0 2 3 99 IND. INOR. 6 189.3 32555.0 4 11.36 21300.0 2499 FERT. 2 1.9 3612.0 1 5.83 306.0 2599 IX- 12 FTN. 6109-6113 AVERAGE BD/MGD WEIGHTED BY NUMBER OF PLANTS = 742.78, LBS/GD 2699 AVERAGE WASTEWATER FLOW PER TON PRODUCT = 16.73 GAL/DAY (6104 2799 ,IW35) 2899 BCD/TON PRODUCT = 16.73 GPD/TON X -06MGD/GAL X 742.78 LBS/MGD 2999 = 1.24-02 LB/TON OR 6.21-06 TON BOD 3099 6109 199 COD MAY BE ESTIMATED FROM TOTAL COD (0016,E100), COD AND FLOW FOR 299 UNTREATED WASTEWATER (0016,.104) AND TOTAL WASTEWATER (0016,98) 399 FOR ALKALIES/CHLORINE, INDUSTRIAL INORGANICS AND FERTILIZERS. 499 USING THE PROCEDURE OF FOOTNOTE 6108, THE RESULTS ARE AS 599 FOLLOWS: UNTREATED TREATED 699 CCMP. (MGD) COD COMP. (MGD) COD 799 ALK/CHL 5 25.6 94950.0 0 0.0 0.0 899 IND. INOR. 4 181.3 228000.0 4 11.36 42500.0 999 FERT. 2 1.9 4625.0 0 0.0 0.0 1099 AVERAGE COD/MGD WEIGHTED BY NUMBER OF PLANTS = 2896.3 LBS/MGD 1199 AVERAGE WASTEWATER FLOW PER T0N PRODUCT = 16.73 GAL/DAY (6104,1299 IW35) 1399 CCD/TON PRODUCT = 16.73 GPD/TON X -06 MGD/GAL X 2896.3 LBS/MG l499 = 4.85-02 LB/TON OR 2.42-05 TON 1599 6110 199 ENERGY EFFICIENCY IS CALCULATED BY DIVIDING ENERGY OF FUEL TYPE 299 USED IN 1967 (0041,SR4-18/SR4-19) BY PRODUCTION IN 1967 (6111 399 10) AND (0011,699). CONVERSION FACTORS FOR FUELS (0005,38). 499 INCLUDED IN THE FUEL EFFICIENCY IS FEEDSTOCK CONSISTING OF 599 1.63+05 BTU COKE, 3.90+04 BTU COAL AND 1.65+06 BTU NATURAL GAS 699 PER TON PRODUCT. 799 6111 199 THE GENERATICN OF STEAM IS A MAJOR SOURCE OF-FUEL C0NSUMPTION AND 399 AIR EMISSION. THE AMOUNT OF EMISSION DEPENDS UPON THE TYPE OF 499 AND AMOUNT OF FUEL USED (0002,1-3/1-9). EMISSION FACTORS ARE 599 GIVEN BY (0*002,1-3/1-9), (A =14.4; S = 3.32 (6112,16) FOR COAL 699 S =1.0 FOR RESIDUAL (6118) S =0.224 FOR DISTILLATE (6113, 799 7))THE AMOUNT OF FUELS USED FOR STEAM GENERATION CAN BE 899 CONSIDERED EQUAL TO THE AMOUNT OF FUEL FOR HEAT AND POWER, 999 (6114) AND (0007,119). BASED ON THIS, TOTAL FUEL USED IS 1099 AS FOLLOWS (0041,SR4-18/SR4-19)- COAL = 5.62+06 TON, 1199 DISTILLATE = 1.75+06 BARREL, RESIDUAL = 4.01+06 BARREL, 1299 NATURAL GAS 4.49+05 MMCF. THE EMISSION PROM STEAM PRODUCTION1399 FOR ONE TON OF PRODUCT (ALSO SEE FOOTNOTE 6110) IN TONS- 1499 PART sox Co HYDCARB NOX ALDHY ORG 1599 COAL 3.68-03 2.48-03 3.93-05 1.97-05 2.95-04 9.83-08 0.0 1699 DIST 9.16-08 6.35-06 1.22-09 1.83-08 3.66-37 1.22-08 0.0 1799 RESID 3.22-07 2.23-06 2.80-09 4.21-08 8.41-07 1.40-08 0.0 1899 NA. GAS 2.82-05 9.41-07 6.27-07 6.27-05 1.96-04 4.71-06-1.1-051999 TOTAL 3.71-03 2.49-03 3.99-05 8.25-05 4.92-04 4.63-06 1.1-052099 TOTAL PARTICULATE EMISSION IS THE SUM OF EMISSION FROM STEAM 2199 GENERATION AND EMISSION FROM PROCESSES. PARTICULATE EMISSION 2299 FROM PROCESSES IS AS FOLLOWS- 2399 HYDROFLUORIC ACID (0002,5-9) 20.00 LB/TON 2499 PHOSPHORIC ACID (6105,3) 0.36 LB/TON 2599 NITRATE FERTILIZER (CO02,6-9) 10.00 LB/TON 2699 PHOSPHATE FERTILIZER (0002,6-10) 91.00 LB/TON 2799 FPIT MANUFACTURING (0002,8-13) 16.00 LB/TON 2899 CALCIUM CARBIDE (OC02,8-5) 66.00 LB/TON 2999 TOTAL PROCESS EMISSION IS THE SUM OF EACH SOURCE WEIGHTED BY 3099 THE PERCENTAGE OF PRODUCTION OF EACH SOURCE SEE FOOTNOTE 6101 3199 6113 199 -OX EMISSION FROM PROCESSES IS AS FOLLOWS- 299 NITRIC ACID (0002,5-10) 6.67 LB/TON (90% CONTROLED) 399 SULFURIC ACID (6107,13-4) 0.17 LB/TON 499 IX-13 FTN6114-6120 NITRATE FERTILIZER (0002,6-9) 3.90 LB/TON 599 TOTAL PROCESS EMISSION IS THE SUM FROM EACH SOURCE WEIGHTED BY 699 PERCENTAGE OF PRODUCTION OF EACH SOURCE (FOOTNOTE 6101). TOTAL 799 EMISSION IS THE SUM OF PROCESS EMISSION AND EMISSION FROM 699 STEAM GENERATION (SEE FOOTNOTE 6111) 999 6114 199 MAJOR PROCESS EMISSIONS OF SOX ARE AS FOLLOWS 299 SULFURIC ACID (6107,7) 40-00 LB/TON 399 PHOSPHORIC ACID (6105,29) 0.13 LB/TON 499 CALCIUM CARBIDE (0002,8-5) 6.00 LB/TON 599 TOTAL PROCESS EMISSION IS THE SUM OF THE ABOVE SOURCES 699 WEIGHTED BY THEIR RESPECTIVE PERCENTAGE OF PRODUCTION (FOOT- 799 NOTE 6106). TOTAL EMISSION IS THE SUM OF THE PROCESS EMISSION B99 6115 199 AND THE EMISSION FROM STEAM GENERATION (SEE FOOTNOTE 6111) 999 HYDROCAREON EMISSION FROM PROCESSES IS REPORTED FOR AMMONIA PRODUC 299 TION, 90.00 LB/TON (0002,5-3), AND FOR CALCIUM CARBIDE MAN- 399 THE SUM OF THE ABOVE WEIGHTED BY THEIR RESPECTIVE PERCENTAGE 599 UFACTURING, 18.02/TON (0002,8-5). TOTAL PROCESS EMISSION IS 499 OF PRODUCTION (FOOTENOTE 6101). TOTAL EMISSION IS THE SUM OF 699 THE PROCESS EMISSION AND EMISSION FROM STEAM GENERATION (SEE 799 FOOTNOTE 6111) 899 6116 199 CO EMISSION FROM PROCESSES IS REPORTED FOR NITRIC ACID, 16.6 LB/ 299 TCN (6108,10), AND AMMONIA PRODUCTION, 100.0 LB/TON (ASSUMING 399 EACH 599 THE ABOVE 5OPC CONTROL) (0002,5-3). TOTAL PROCESS EMISSION IS THE SUM OF 499 WEIGHTED BY THE PERCENTAGE OF PRODUCTION OF SOURCE.(FOOTNOTE 6101). TOTAL EMISSION IS THE SUM OF THE 699 PROCESS, AND THE STEAM GENERATION EMISSION. 799 6117 199 OF EMISSION INCLUDE A VARIETY OF COMPOUNDS AND 299 OTHER SOURCES CHEMICALS. THE REPORTED PROCESSES ARE AS FOLLOWS- 399 AMMONIA (0002,5-3) 10.000 LB AMMONIA/TON 499 CHLO-ALFALI (0002,5-6) 80.000 LB CHLORINE/TON 599 HYDROFLUORIC ACID (0002,5-9) 0.200 LB FLUORIDE/TON 699 NITRIC ACID (6108,10) 0.077 LB HCN/TON 799 FHOSIHORIC ACID (6105,19) 1.100LB FLUORIDE/TON 899 NITRATE FERTILIZER (0002,6-9) 1.900 LB AMMONIA/TON 1099 SODA ASH (0002,5-17) 7.OCO LB AMMONIA/TON 999 PHOSPHATE FERTILIZER (0002,6-10) 0.320 LB FLUORIDE/TON 1199 FRIT (0002,8-13) 5.000 LB FLUORIDE/TON 1299 HYDROCHLORIC ACID (0002,5-9) 0.200 LB HCL/TON 1399 TOTAL PROCESS EMISSION IS THE SUM OF THE ABOVE WEIGHTED BY 1499 EACH SOURCES PERCENTAGE OF PRODUCTION (FOOTNOTE 6101). TOTAL 1599 EMISSION IS THE SUM OF PROCESS EMISSION AND ALDEHYDE AND 1699 NOTE 6111) 1899 ORGANIC EMISSION FROM FUELS USED IN STEAM GENERATION. (FOOT- 1799 6118 199 THE ONLY SOLID WASTE REPORTED IS FOR THE PRODUCTION OF CHLORINE, 299 23.15 LB/TON (6111,A). CHLORINE MAKES UP APPROXIMATELY 8.2 PC OF TAE TOTAL INORGANIC CHEMICAL PRODUCTION (FOOTNOTE 6101). 499 399 6119 199 ENERGY EFFICIENCY IS CALCULATED BY DIVIDING ENERGY OF FUEL TYPE 299 USED IN 1967 (0041,SR4-18/SR4-19).BY PRODUCTION IN 1967,-92.1 399 MILLION TON (6100) AND (0025,255). CONVERSION FACTORS FOR FUEL 499 ARE FOUND IN (0005,38). INCLUDED IN FUEL EFFICIENCY-IS 2.42+05 590qQ BTU COAL, 1.70+04 BTU COKE, 4.23+06 BTU NATURAL GAS AND 699 799 7.21+05 BTU FUEL OIL (ASSUMED TO BE RESIDUAL) (0039,30) AND SEE FOOTNOTE 6110 899 6120 196q4 ESSENTIALLY ALL THE FUEL INPUT FOR HEAT AND POWER INTO THE ORGANIC 299 IX-14 FTN. 6121-6125 CHEMICAL INDUSTRY IS USED TO PRODUCE STEAM OR FOR DIRECT FIRE, 399 (6114) AND (0007,11.9). EITHER USE IS DIRECT COMBUSTION OF FUEL 499 , THEREFORE THE EMISSION FACTORS ARE ASSURED THE SA-ME, (0002, 599 1-3/1-9). THE FUEL INPUT FOR V7,AT AND POWER IS AS FOLLOWS, 699 (0041,SR4-18/SB4-19) 1.55*06 TON COAL, 6.36+06 BARREL 799 DISTILLATE, 8.45+06 BARREL RESIDUAL AND 7.56+05 MMCF NATURAL 899 GAS. THE EMISSION FROM FUELS USED FOR ONE T ON OF PRODUCT (ALSO 999 SEE FOOTNOTE 6119) IN TONS IS AS FOLLOWS- 1099 PART sox co - HYDCARB NOX ALDHY ORG 1199 COAL 1.57-03 1.06-03 1.68-05 8.41-06 1.26-04 4.20-08 DIST 5.18-07 1.11-06 6.90-09 1.04-07 2.07-06 6.90-08 - 1399 RESID 1.05-06 7.29-06 9.17-09 1.38-07 2.75-06 4.59-08 - 1499 NA GAS 7.38-05 2.46-06 1.64-06 1.64-04 5.13-04 1.23-05 2.87-051599 TOTAL 1.65-03 1.07-03 1.85-05 1.73-04 6.44-04 1.25-05 2.87-051699 PARTICULATE EMISSION FROM PROCESSES ARE GIVEN BELOW, LB/TON- 1799 CARBON BLACK (0002,5-4) 60.0 (96.1PC PRODUCTION (0025,255) 1899 2300.0 (3.9PC PRODUCTION (0025f255) 1999 EXPLOSIVES (0002,5-8) 36.4 2099. PLASTICS (0002,5-14) 10.5 2199 PRINTING INK (0002,5-15) 2.0 2299 DETERGENT (0002,5-16) 14.0 (CYCLONE, 85.OPC CONTROL) 2399 PAINT (0002,5-11) 2.0 (PEIR TON PIGMENT) 2499 TOTAL PROCESS EMISSION IS THE SUM OF EACH SOURCE WEIGHTED BY 2599 THE SOURCES PERCENTAGE OF PRODUCTION, SEE FOOTNOTE 6100. TOTAL2699 PARTICULATE EMISSION IS THE-SUM OF THE PROCESS AND FUEL USE 2799 EMISSION. 2899 6122 199 NOX EMISSION FROM PRCCESSES ARE AS FOLLOWS, IN LB/TON- 299 ADIPIC ACID 12.0 399 EXPLOSIVES 17.0 (WITH BUBBLE CAP ABSORPTION) 499 TEREPHTHALIC ACID 13.0 599 TOTAL PRCCESS EMISSION IS THE SUM OF EACH SOURCE WEIGHTED BY 699 THE PC OF PRODUCTION OF EACH SOURCE (FCOTNOTE 6100). TOTAL NOX 799 EMISSION IS THE SUM OF PROCESS AND FUEL USE (FOOTNOTE 6120) 899 EMISSION. 999 6123 199 PROCESS EMISSION OF SOX IS REPORTED FOR EXPLOSIVES ONLY, 96.0 LB/ 299 TCN (0002,5-8). EXPLOSIVES MAXE UP APPROXIMATELY .90 P 399 OF TOTAL PRODUCTION. TOTAL PROCESS EMISSION = 4.80-.02 TON 499 TOTAL SOX EMISSION IS THE SUM OF THE PROCESS AND FUEL USE 599 (FOOTNOTE 6120) EMISSION. 699 6124 199 HYDRCCARBON EMISSION FROM PROCESSES IS AS FOLLOWS, LB/TON- 299 CARBON BLACK (0002,5--;4) 11500.0 (3.9PC OF PRODUCTION) 399 1800.0 (12.5PC PRODUCTION, GAS) 499 400.0 (83.6PC PRODUCTION, OIL) 599 PAINT & VARNISH-(000.2,5-11) 4.0 (AFTERBURNERS) 699 SYNTHETIC FIBERS (0002,5-20) 7.0 (NYLON) 799 SYNTHETIC PUBBEP (0002,5-21) 83.0 ' (399 TOTAL PROCESS EMISSION IS THE SUM FROM EACH SOURCE WEIGHTED BY 999 THE PERCENTAGE OF PRODUCTION OF EACH SOURCE (FOOTNOTE 6100). 1099 TOTAL HYDROCARBON EMISSION IS THE SUM OF THE PROCESS AND FUEL 1199 USE EMISSION (FOOTNOTE 6120) 1299 6125 199 ICO EMISSION FPOM PROCESSES IS REPORTED FOR CARBON BLACK ONLY- 299 3.35+04 LB/TON CHANNEL PROCESS (3.9PC PRODUCTION (0025,263)) 399 5.30+03LB/TON GAS FURNACE.(12.5PC PRODUCTION (0025,263)) AND 499 4.5r+03LB/TON OIL FURNACE (83.6PC PRODUCTION '0025,263)). 599 TOTAL CO EMISSION IS THE SUM' OF THE CARBON BLACK EMISSION 699 AND EMISSION FROM FUEL USE (FOOTNOTE 6120).CAt?BON BLACK 799 REPRESENTS 1.24 PC OF TOTAL PRODUCTION (SEE FOOTNOTE 6100) 899 IX-15 FTN. 6126-6132 6126 199 OTHER EMISSIONS CONSIST PRIMARILY OF ORGANICS WITH AMOUNTS OF 299 OTHER COMPOUNDS, LB/TON 399 CARBON BLACK (0002,5-4) 8.51 (H2S) 499 PHTHALIC ANHYDRIDE (OC02,5-13) 11 . 00' (ORGANIC) 599 PLASTICS (OCQ2,5-14) 17.70 (GASES) 699 PRINTING INK (0002,15) 235.00 (ORGANIC,50PC SETTLING) 799 SYNTHETIC FIBERS (0002,5-20) 83.00 (CS2,H2S,OIL VAPOR) 899 TOTAL PRCCESS EMISSION IS THE SUM FROM EACH SOURCE WEIGHTED BY 999 THEIR RESPECTIVE PERCENTAGES OF PRODUCTION (FOOTNOTE 6100). 1099 TOTAL EMISSION IS THE SUM OF THE PROCESS EMISSION AND THE FUEL1199 USE EMISSION (FOOTNOTE 6120) 1299 6127 199 ACID EFFLUENT IS REPORTED FOR ACETIC ACID AND ANHYDRIDE (6115, 299 C126) AS .02 TON PER TON OF PRODUCT. ACETIC ACID AND ANHYDRIDE 399 MAKES UP APPROXIMATELY 1.45PC OF TOTAL PRODUCTION, FOOTNOTE 499 6100. 599 6128 199 F04 EFFLUENT IS REPORTED FOR POLYSTYRENE (6115,Cl6l) AS 5.08-03 299 TON,PER TON PRODUCT. POLYSTYRENE PRODUCTION AMOUNTS TO 2.OPC 399 OF TOTAL PRODUCTION (FOOTNOTE 6100) 499 6129 199 AN ESTIMATE OF SUSPENDED SOLIDS CAN BE OBTAINED FROM (0016,E98, 299 E101,E105) USING THE PROCEDURE DEVELOPED IN FOOTNOTE 6108. 399 SUSPENDED SOLIDS AND WASTEWATER FLOW FOR THE PLANTS REPORTING 499 ARE AS FCLLOWS- UNTREATED TREATED. 599 COMP MGD SS COMP MGD 699 699 COAL TAR PRODUCTS - - - 3 71.10 3615.0 799 ORGANIC CHEMICALS 16 91.1 403673.0 13 884.00 60179.0 899 PLASTICS/RESINS 745.6 15320.0 6 8.22 3572.0 999 SYNTHETIC RUBBER 358.8 60760 0 3114.00 21400.0109917 75.0 CELLULOSIC MAN-MADE FIBERS 430.1 42740:0 6 19.56 6066.01199 ORGANIC FIBEFS, NONCELLU. 2 0.7 4 23.80 22244.01299 PHARMACEUTICALS - - - 1 1.00 8220.013991 DETERGENS 510.3 8115.0 1 1.70 5519.01499 GUMI AND WOOD CHEMICALS 1 0.0 425.0 - - - 15991 AGRICULTURAL PESTICIDES 1 0.3 876.0 2 0.40 6 2. 0 16931 EXPLOSIVES 475.0 20605.0 2 2.06 14004.01799 CARBON BLACK 1 0.6 1000.0 3 0.15 143.0189 AVERAGE SS/MGD, WEGHTED BY NUMBER OF PLANTS 1795.12 LB/MGD l FROM (6104,IW/34) WASTEWATER AMOUNTS TO 13.3 GPD/TON PRODUCT. 209) TOTAL SS = 1795.12 LB/MGD X -06 MGD/GAL X 13. 3 GPD/TON 21991 = 2.39-02 LB/TON OR 1.94-05 TON SS 2299 6130 199 USING THE PROCEDURE OF FOOTNOTE 6129, BCD CAN.-BE ESTIMATED FROM 299 (0016,E98,E99OE103). AVERAGE BOD/MGD WEIGHTED BY NUMBER OF 399 PLANTS = 2950.24 LB/MGD. FROM (6104, IW/34) WASTEWATER AMOUNTS 499 TO 13.3 GPD/TON PRODUCT. TOTAL BOD = 2960.24 LB/MGD X -06 MGD/ 599 3.92-02 6131 199 6 X3.3 GPD/TON LB/TON OR 5.10-05 TON 6131 199 COD CAN BE ESTIMATED FROM (0016,E98,E100,El04) USING THE TECHNIQUE 299 OF FOOTNOTE 6129. AVERAGE COD/MGD WEIGHTED BY NUMBER OF PLANTS 399 766,7.52 LB/MGD. FROM (6104,TW34) WASTEWATER AMOUNTS TO 13.3 499 GPD/TON PRODUCT. TOTAL COD = 7667.52 LB./MGD X -06 MGD/GAL X 599 13.3 GPD/TCN = 1.02-01 LB/TON OR-5.10-05 TON 69 6132 199 ORGANIC. EFFLUENT IS REPORTED FOR THE FOLLOWING: 299 ACETIC ACID AND ANHYDRIDE (6115,C126) 2.00-02 TON/T0N 39 ACETONE (6115,C127) 8.00-02 TON/TON 499 ACRYLATES (6115,Cl3l) 6.50-03 TON/TON 599 PHENOL (6115,C157) 1.40-04 TON/TON 699 IX-16 FTN. 6133-6303 BUTADrENE (6115,C137) 4.00-06 TONITON 799 BUTANOL (6115,C13B) 1.00-01 TON/TON 899 ETHYL BENZENE AND STYFENE (6115,C147) 5.00-02 TON/TON 999 LD POLYETHYLENE (6115,C160) 6.00-06 TON/TON 1.099 UREA (6115,C166) 4.00-04 TON/TON 1199 POLYSTYRENE (6115,Cl6l) 3.43-03 TON/TON 1299 PHENOLIC RESINS (6116,77) 4&30-02 TON/TON 1399 UPEA & MELAMINE RESINS (6116,68) 1.10-01 TONITON. 1499 TOTAL ORGANICS IS THE SUM OF THE ABOVE SOURCES 1599 WEIGHTED BY THE PERCENTAGE OF PRODUCTION OF-EACH SOURCE, SEE 1699 FCOTNOTE 6100. 1799 6133 199 SOLID WASTE IS REPORTED FOR THERMOPLASTICS (6117). AVERAGE SOLID 299 WASTE GENERATED IS 1.1PC OF PRODUCTION OF THERMOPLASTICS FOR 399 1969 (6117,32). ASSUMING NO MAJOR CHANGE IN PROCESSES, TOTAL 499 SOLID WASTE FROM THERMOPLASTICS IS 22.00 LB/TON PRODUCT. 599 THERMOPLASTICS MAKE UP APPROXIMATELY 6.60PC OF TOTAL ORGANIC 699 CHEMICAL PRODUCTION (FOOTNOTE 6100) 799 6134 199 EQUAL TO THE SUM OF THE LISTED QUANTITIES 299 6300 199 INCLUDED UNDER THIS CLASSIFICh.TION ARE FLAT GLASS, FIBROUS GLASS, 299 GLASS CONTAINERS AND SCI*ENTIFIC, TECHNICAL AND INDUSTRIAL . 399 GLASSWARE. SOURCES OF DATA AND CONVERSIONS USED IF NEEDED ARE 499 AS FOLLOWS- FLAT GLASS (6305), 15B.22 LB/FT3 (6309,43) 599 FIBROUS GLASS (6307) 699 GLASS CONTAINERS (6306), 0.53 LB/UNIT 799 899 (6311 , MC67 (2) -32A) SCIENTIFIC, TECHNICAL ANE INDUSTRIAL GLASSWARE 999 (6308) , 0.80 LB/U NIT (631 1,MC67 (2) -32A) 1099 199 6301 THE ENERGY CONSUMED- SHEET GLASS = 7.51 KWH/LB,(6311,MC(67(2)-32A) 299 PLATE GLASS = 3.25 KWH/LB (6312,14), GLASS CONTAINERS = 4.00 399 KWH/LB (6312,15), MISCELLANIOUS GLASS = 4.0 KWH/LB (6312,15) 499 THE ENERGY BREAKDOWN BY PERCENTAGE OF FUEL TYPE USED IS AS 599 FOLLOWS, +06 BTU/TON- COAL RESID DIST NAT GAS ELEC 699 SHEET GLASS 3.56 36.29 11.44 799 PLATE AND FLOAT 1.54 15.70 4.95 899 CONTAINER GLASS 1.89@ 1.42 0.30 19.04 4.65 999 MISCELLANIOUS 0.41 0.94 0.30 19.74 5.91 1099 INCLUDED FOR SHEET AND PLATE GLASS IS 3.56+06 BTU/TON AND 1199 1.54+06 BTU/TON RESPECTIVELY UNDIFFERETIATED FUEL, WHICH IS 1299 ASSUMED TO BE RESIDUAL. THE WEIGHTED AVERAGE BTUITON PRODUCT 1399 FOR EACH FUEL TYPE IS, COAL = 1.55+06 BTU, RESIDUAL = 1.63+06 1499 BTU, DISTILLATE = 2.97+05 BTU, NATURAL GAS = 2.23+07 BTU, 1599 ELEC 5.93+06 BTU (WEIGHTING IS BY PC OF TOI'AL PRODUCTION- 1699 SHEET .06, PLATE = .04, CONTAINER = .70 KISCELANIOUS = .20)1799 6302 199 INCLUDED UNDER THIS CLASSIFICATION ARE CLAY CONSTRUCTION PRODUCTS, 299 CLAY REFRACTORIES AND POTTERY AND RELATED PRODUCTS. SOURCES OF 399 DATA AND CONVERSIONS AS NEEDED*ARE AS FOLLOWS- 499 CLAY CONSTRUCTION PRODUCTS (6303), 6.50 LB/B:TCK (0002,A7) 599 TILE 130.00 LB/FT3 (6405,, 699 433) 799 CLAY REFRACTOR'IES (6304),'2.25 - 6.50 LB/91NCH BRICK (0023, 899 6@209) 999 POTTERY AND RELATED, 500 DOLLARS PER TON (63@0,64) 1099 6303 199 IX-17 FTN 6304-6311 FUEL EFFICIENCY IS CACULATED By DIVIDING AMOUNT OF FUEL AND 299 ELECTRICITY USED BY TONNAGE OF PRODUCTION (631,MC67(2)-328/ 399 MC,67(2)-32C)IN 1967. 499 6304 199 WITH CYCLONE SCRUBBER, PARTICULATE EMISSION FOR BRICK AND RELATED 299 PRODUCTS IS 18.00 LB/TON IN THE DRYING PROCESS AND 19.00 LB/ 399 TON IN THE GRIN-DING PROCESS, (0002,8-4,8-8). FOR CURING AND 499 FIRING USING COAL FIRING, PARTICULATE EMISSION IS REPORTED AS 599 7.5A LB/TON.COAL (A=14.4 (6302,16)), (0002;8-4). SINCE THE 699 PROCESSES ARE ESSENTIALLY THE SAME FOR POTTERY AND RELATED 799 PRODUCTS,THE EMISSIONS CAN BE CONSIDERED THE SAME. TOTAL 899 PARTICULATE EMISSION, WITH 11PC *OF PRODUCTION FROM COAL FIRED 999 FURNACES USING .03 TON OF COAL PEP TCN OF PRODUCT (SEE 1099 FOOTNOTE 6303) = 18.00 LB/TON + 19.00 LB/TON + (7.5 X 14.4 1199 X.,03) LB/TON X.11 = 37.36 LB/TON OR 1.86-03 TON/TON PRORUCT. 1299 6305 199 N0X EMISSION IS: DEPENDENT UPON TYPE OF FUEL USED FOR CURING AND 299 FIRING (OO02,8-4)- GAS FIRED 0.60 LB NOX/TON PRODUCT 399 OIL FIRED 1.30 LB NOX/TON PRODUCT 499 COAL FIRED 1.50 LB NOX/TON PRODUCT 599 ALLOCATING EMISSION BY PERCENTAGE OF FUEL TYPE USED (SEE 699 FOOTNOTE 6303, TOTAL, NOX EMISSION = 0.60 LB/TON X 0.85 + 799 1.30 LB/TON X.04, + 1.50 X 0.11 = 0.727 LB/TON OR 3.00+04 TON 899 PR TON BRICK 999 6306 199 FLUORIDE EMISSION HA.S BEEN ESTIMATED AT 0.80 LB/TON. (0002,64) OR 299 4.00-04 TON PER TON BRICK. 399 6307 199 ABOVE A FIRING TEMPERATURE OF 2500F, SOX MAY EXIST DEPENDING UPON 299 SULFUR CONTENT OF MATERIAL BEING FIRED (0002,8-3). SINCE MOST 399 KILNS, USED FOR MANUFACTURE OF CLAY PRODUCTS ARE FIRED LESS 499 THAN 2500F (6300,,69/73) SOX CAN BE CONSIDERED NEGLIGABLE. 599 6308 199 PARTICULATE EMISSION FROM GLASS MANUFACTURING IS STATED AS 2.00 LB 99 MANUFACTURING 58..50 LB/TON OR 0.029 TON/TON. TOTAL EMISSION 499 /TON, (0002,8-13). PARTICULATE EMISSION FROM FIBER GLASS 399 EQUALS THE AVERAGE EMISSION FROM THESE TWO SOURCES WEIGHTED BY 599 THEIR RESPECTIVE PC OF PRODUCTION (SEE FOOTNOTE 6300). TOTAL 699 EMISSION =0.001- TON X 0.930 + 0-.029 X 0.07 = 0.00113 TON. 799 (GLASS MANUFACTURING INCLUDES FLAT,.CONTAINER AND SCIENTIFIC) 899 6309 199 CLASSIFIED UNDER CEMENT AND RELATED ARE SIC 3241,HYDRAULIC CEMENT. 299 AND SIC 327 CONCRETE, GYPSUM, AND PLASTER PRODUCTS. SOURCES OF 399 DATA AND CONVERSIONS WHERE NECESSARY ARE AS FOLLOWS- 499 CEMENT(00 11,660) , GYPSUM PRODUCTS (0025,561) , LIME C0NCRETE BLOCK AND BRICK (6314,81), CONCRETE PRODUCTS, NEc- 699 AVERAGE VALUE OF $45.00 PER TON (63,10,11C67 (2)-32C) AND 7991 (0009, 366) 899 6310 199 FUEL EFFICIENCY OBTAINED FROM (0025,287) FOR CEMENT AND BY FUELS 299 AND ELECTRICITY USED DIVIDED BY PRODUCTION (6310,MC67(2)-32C) 399 FOR THE, OTHER, PRODUCTS . CONVERSIONS FOR FUELS (0005, 38) 499 6311 199 PARTICULATE EMISSION FOR CEMENT AND, RELATED IS AS FOLLOWS: 299 PORTLAND CEMENT 12.80 LB/BBL OR 0.034 TON/TON DRY PROCESS 399; AND 8.80 LB/BBL OR 0.023 TON/TON WET PROCESS 499 9 (0002,8-7). 80PC CONTROL 599 CONCRETE BATCHING 0 . 11 L B / Y D 3 0 R C . 0 5 5 TO N/T 0 N (2q0 0 0 2, 8 - 11 699 50PC OF PLANTS CONTROLD. DIRECT ENERGY USE 799 FOR PROCESS IS SMALL. CONCRETE PRODUCTS EMISSION, INCLUDES CONCRETE BATCHING, 0.055 IX-18 FTN. 6312-6317 TON AND FROM CURING STEAM GENERATION, 1099 3.00+06 TON (0002,8-11). AND (SEE FOOTHUTE 1199 6310) 1299 GYPSUM PRODUCTS EMISSION Ft J CALCINING GYPSUM, WITH FABRIC 1399 FILTER CONTROL IS 0.302 LB/TON OR 0.0002TON1499 /TON (0002,8-14) 1599 LIKE MANUFACTUPE EMISSION, WITH CYCLONE AND 5OPCOP PRODUCTION1699 FROM EACH KILN TYPE IS 41.10 LB/TON OR 0.0211799 TON (0002,8-15) 1899 TOTAL EMISSION IS WEIGHTED BYPC OF TCTAL PRODUCTION OF EACH 1999 SOURCE. (PORTLAND CEMENT 0.14, READY MIXED CONCRETE = 0.69, 2099 CONCRETE BLOCK BRICKS 0.06, CONCRETE PRODUCTS = 0.06, 219.9 GYPSUM PRODUCTS 0.02, LIME = 0.03 OF TOTAL PRODUCTION) 2299 6312 199 BOX EMISSION FOR CEMENT AND RELATED IS DEPENDENT UPON THE TYPE OF 299 FUEL USED. AVERAGE EMISSION FOR CEMENT IS 273 PPM/TON FEED 399 (6301,16) AT 70000 SCF/TON FEED (6301,10) AND 600 LB/BBL FEED. 499 (6301,06). BY CONVERSION,NOX EMISSION = 7.00-05 TON NOXITON 599 CEMENT. EMISSION FOR CONCRETE PRODUCTS IS FROM CURING STEAM 699 GENERATION.(SEE FOOTNOTE 6311)- NOX = 1.10-05 TON. EMISSION 799 FROM GYPSUM PRODUCTS OCCURS FROM BURNING OF FUELS FOR EXTERNAL 899 FIRING. NOX EMISSION FOR GYPSUM, PRODUCTS WEIGHTED BY PC OF 999 FUEL USED:= 1.98-04 TON.(0002,1-3/1-9). DATok FOR NOX EMISSION1099 FROM LIME MANUFACTURING IS UN&VALABLE. EMISSION FROM READY 1199 MIXED CONCRETE IS NEGLIGIBLE. TOTAL NOX EMISSION IS THE SUN OF1299 THE INDIVIDUAL SOURCES WEIGHTED BY'PERCENTAGrp THAT EACH 1399 PRODUCT CONTRIBUTES TO TOTAL PRODUCTION (SEE FOOTNOTE 6311) 1499 6313 199 REACTION WITH FEED MATERIAL (CARBONATE), WILL REDUCE POTE4TIAL SOX 299 EMISSION FROM A CEMENT KILN BY AN AVERAGE OF 59PC (6302,15) 399 BASED UFCN THIS AND AVERAGE SULFUR CONTENT OF FUEL USED, 499 COAL =3.32 PC PER TON (6302,16), DIST =0.224 PC/GAL (6317,7), 599 RESID =1.0 PC/GAL (6318,164), NA GAS =0.286 LB/MMCF (0002,1-9) 699 SOX EMISSION FOR'CEMENT = 1.90-03 TON. THE MANUFACTURE OF 799 LINE IS SIMILAR TO CEMENT IN FIRING AND CARBONATE FEED. THE 899 EMISSION CAN BE CONSIDERED SIMILAR AND DEPENDENT UPON FUEL 999 USED. SOX EMISSION FROM LIKE = 1.17-03 TON. SOX EMISSION FROM 1099 CONCRETE BLOCK, BRICK AND PRODUCTS OCCURS FRQN STEAM 1199 GENERATICN (SEE FOOTNOTE 6312), SOX = 1.57-06. SOX EMISSION 1299 FROM GYPSUM PRODUCTS OCCURS FROM-FUEL USED FOR INDIRECT FIRING1399 (SEE FOOTNOTE 6312), SOX = 5.49-04 TON. TOTAcL EMISSION IS 1499 THE SUN OF THESE SOURCES WEIGHTED BY THEIR PERCENTAGE OF TOTAL1599 PRODUCTION (SEE FOOTNOTE 6311) 1699 6314 199 SOURCES OF HYDROCARBONS ARE STEAM GENERATION FOR CONCRETE BLOCK, 299 BRICKS AND PRODUCTS AND FROM INDIRECT FIRING OF GYPSUM 399 PRODUCTS. HYDROCARBON EMISSION WEIGHTED BY PERCENTAGE OF FUEL 499 USED IS AS FOLLOWS (0002,1-3/1-9)- CONCRETE BLOCK, BRICKS AND 599 PRODUCTS = 3.38-06 TON, GYPSUM-PRODUCTS = 4.62-04 TON. 699 TOTAL EMISSION IS THE SUN OF THESE EMISSIONS WEIGHTED BY 799 PRODUCTION. THESE SOURCES MAKE UP 14.0 PC Of TOTAL PRODUCTION 899 SEE FOOTNOTE.6311. 999 6315 199 ,SOURCES OF CO EMISSION ARE THE SAME AS HYDROCA.RSON EMISSIONS (SEE 299 FOOTNOTE 6314) 399 6316 199 SOURCES OF ALDEHYDES AND OTHER EMISSIONS ARE T"C SAME AS HYDRO- 299 CARBON EMISSIONS. (SEE FOOTNOTE 6314) 399 .6317 199 INCLUDED UNDER STONE AND RELATED ARE SIC 3281, CUT STONE AND STONE 299 PRODUCTS AND SIC 329 MISCELLANIOUS NONMETALLIC MINERAL 399 IX-19 FTN. 6318-6324 PRODUCTS. SOURCES OF DATA AND CONVERSIONS WHERE NECESSARY ARE 499 AS FOLLOWS- CUT STONE AND STONE PRODUCTS $61.00 PER TON 599 (0025, 1048) AND (6319,21) 699 ABRASIVE PRODUCTS $895.00 PER TON (0025,154)AND 799 (6319,21) 699 ASBESTOS PRODUCTS $800.00 PER TON (0025,200) AND 999 (6319,21) 1099 GASKETS AND INSULATIONS AND NONMETALLIC-MINERAL 1199 PRODUCTS, NEC $200.00 PER TON (6311,mC67(2) - 1299 32E) AND (0011,345) 1399 MINERALS, GROUND OR TREATED 1.30+08 TON (6311, 1499 MC67(2)-32E) AND (0025) 1599 MINERAL WOOL $80.00 PER TON (6304) AND (0011,345) 1699 NONCLAY REFRACTORIES (6304) AND (0008,6-208) 1799 6318 199 FUEL EFFICIENCIES ARE OBTAINED BY DIVIDING FUEL USED BY TOTAL 299 PRODUCTION FOR 1967, (6311,MC67(2)-32D/32E) 399 6319 199 PARTICULATE EMISSICNS ARE REPORTED FOR NONCLAY REFRACTORIES 299 (0002,8-5),.CLAY MANUFACTURING (OC-02,8-82p MINERAL WOOL 3 99 MANUFACTURING (0002, 8- 16) , PERLITE MANUFACTURING (0002,8-17) , 499 PHOSPHATE ROCK PROCESSING (O002,8-18) AND ROCK PROCESSING 599 (0002,8-19) OTHER SOURCES OF EMISSIONS ARE FROM STEAM GENERA- 699 TION IN ASBESTOS PRODUCTS (6316,100/118) AND MINERAL WOOL 799 MANUFACTURING (0002,8-15), (0002,1-3/1-9). THE EMISSION FROM 899 EACH OF THE ABOVE SOURCES IS AS FOLLCWS- NONCLAY REFRACTORIES 999 (CONTROLED CASE) = 63.40 LB/TON, CLAY MANUFACTURING =7.00 1099 LB/TONS MINERAL WOOL MANUFACTURING = 50.00 LB/TON, PERLITE 1199 MANUFACTURING-21.00 LB/TON, PHOSPHATE ROCK PROCESSING=37.00 1299 LB/TON, ROCK PROCESSING = 11.30 LB/TON. FROM STEAM GENERATION 1399 THE PARTICULATE EMISSION IS 4.41-04 TON AND 3.12-04 TON 1499 RESPECTIVELY. TOTAL EMISSION IS THE SUM OF THE INDIVIDUAL 1599 SOURCES WEIGHTED BY THEIR PERCENTAGE'OF TOTAL PRODUCTION (CUT 1699 STOE = 2.6 PC, ABRASIVES = 0.6PC, ASBESTOS = 0.5 PC, GASKETS 1799 ANb INSULATION = 1.2PC MINERALS GROUND = 88.4PC, MINERAL WOOL 1899 =4.5PC, REFRACTORIES = 2.lPC). l999 6320 199 NOX EMISSION FROM STEAM GENERATICN FOR ASBESTOS PRODUCTS AND 299 399 499 MINERAL WOOL MANUFACTURING IS 3.31-04 TON AND 3.13-04 TON RESPECTIVELY (0002,1-3/1-9). TOTAL EMISSION IS THE SUM FROM 499 EACH SOURCE WEIGHTED BY PRODUCTION. SEE FOOTNOTE 6319. 599 6321 A SOX EMISSIONS ARE REPORTED FOR MINERAL WOOL MANUFACTURING AS 0.02 29 LB/TON FROM THE CUPOLA (0002,8-16). EMISSION FROM STEAM 399 GENERATION FOR ASBESTOS PRODUCTS AND MINERAL WOOL MANUFACTUR- 499 ING IS 2.76-04 TON AND 1.85-04 TON RESPECTIVELY (0002,1-3/ 599 1-9) . TOTAL EMISSION IS THE SUM FROM EACH SOURCE WEIGHTED BY 699 PERCENTAGE OF PRODUCTION. SEE FOOTNOTE 6319. 79 6322 199 HYDROCARBON EMISSIONS OCCUR FROM FUEL USED IN STEAM GENERATION FOR 299 MINERAL WOOL AND ASBESTOS PRODUCTS. THE 399 EMISSION FROM EACH SOURCE is 6.78-05 TON AND 6.97-05 TON 499 RESPECTIVELY. TOTAL EMISSION IS THE SUM WEIGHTED BY PERCENTAGE 599 OF PRODUCTION. SEE FOOTNOTE 6319 699 6323 199 CO EMISSIONS OCCUR FROM FUEL USED IN STEAM GENERATION FOR MINERAL 499 WOOL AND ASBESTOS PRODUCTS. THE EMISSION FROM EACH SOURCE IS 3.66-06 TON AND 5.07-06 TON (0002,1-3/1-9). TOTAL EMISSION Is THE SUM OF. EACH SOURCE WEIGHTED B Y PRODUCTION OF EACH SOURCE. SEE FOOTNOTE 6319. Ina 6324 IX-20 FTN. 6325-6332 INCLUDED UNDER ALDEHYDES ETC. IS FLUORIDE FROM NONCLAY REFRACTOR- 299 IES = 1.3 LB/TON (0002,8-6) AND ALDEHYDES AND ORGANIC5 FROM 399 FUEL USED IN STEAM GENERATION FOR MINERAL WOOL AND ASBESTOS 499 PPODUCTS; 4.96-06 TON ALDEHYDL, 1.16-05 TON ORGANIC AND 599 '5.09-06 TON ALDEHYDE, 1.18-05 TON ORGANIC RESPECTIVELY. TOTAL 699 IS THE SUM FROM EACH SOURCE WEIGHTED BY PERCENTAGE OF 799 PRODUCTICN. SEE FOOTNOTE 6319 . 899 6325 199 AN AVERAGE NCX EMISSION FOR GLASS MANUFACTURING OF 0.40 TON PER 299 DAY IS REPORTED (0008,B-1/B-4). ASSUMING AN AVERAGE PRODUCTION 399 RATE OF 500 TON PER DAY, NOX EMISSION 8.00-04 TON/TON PRODUCT499 6326 19.9 SOX EMISSION FROM k GLASS FURNAC.E IS GIVEN AS 65 PPM FOR A EXHAUST 299 GAS FLOW OF 6500 SCFM (6313,639). ASSUMING THIS IS THE STACK 399 EXIT FLOW, OPERATION IS 24 HOURS PER DAY AND 500 TON PER DAY 499 PFODUCTICN, TOTAL EMISSION = 4.19-05 TON.ITON PRODUCT. 599 6327 199 EMISSIONS OF FLUORIDE AND B203 ARE REPORTED FOR A GLASS FURNACE AS 299 60PPM ANE 0.025 GRAIN/SCF. USING THE ASSUMPTIONS Or FOOTNOTE 399 63261EMISSION IS 3.87-05 TON FLUORIDE AND 3.34-04 TON B203 499 6328 199 EFFLUENTS FOR SEVERAL FLAT GLASS MANUFACTURING PLANTS ARE GIVEN BY 299 (6316,40/41). AVERAGE EFFLUE'NT WEIGHTED BY FLOW OF EFFLUENT/ 399 TON IS AS FOLLOWS- SS TS BOD PHOS HEXA14E 499 (LE/TON) - 2.72 48.87 2.39 0.64 2.50 599 FLAT GLASS MAKES UP APPROXIMATELY 11 PC OF TOTAL PRODUCTION. 699 6329 199 TOTAL DISSOLVED SOLIDS IS OBTAINED BY SUBTRACT ING SS FROM TS (SEE 299 FOOTNOTE 6328) 399 6330 199 DATA ON EFFLUENT*LEVELS FOR THE CEMENT AND RELATED CLASSIFICATION 299 ARE GIVEN FOR HYDRAULIC CEMENT, CONCRETE PRODUCTS, READY MIXED 399 CONCRETE, GYPSUM PRODUCTS AND LIME MANUFACTURE (6316,47/100). 499 EFFLUENT VALUES FQR PROCESS WATER AND COOLING WATER IS INCLUD- 599 ED IF ENERGY IS CONSUMED. EFFLUENT FOR WASH AND RINSEVATER 699 IS EXCLUDED. AVERAGE LEVELS WEIGHTED BY FLOW FOR EACH EFFLUENT 799 SOURCE IS AS FOLLOWS- TON/TON PRODUCT 899 NO EFFLUENT CAN BE FOUND FROM AN ENEEGY USE FOR READY NIXED - 999 CONCRETE 1099 CEMENT CONCRETE PRODUCTS GYPSUM LIME 999 Ss 1.77-04 1.00-05 3.00-06. 8.85-05 1099 TS 8.00-04 1.95-04 1199 SC4 1.14-04 1299 CL 3.36-05 1399 K 5.37-05 1499 CA 5.67-05 NA 3.33-05 1699 BOD 5_00-06 3.50-06 1799 COD 5.10-06 1899 CAOH 4.50-04 1999 CAC03 4.50-04 2099 TOTAL EFFLUENT OF EACH TYPE IS THE SUN OF EACH SOURCE WEIGHTED2199 BY PERCENTAGE OF TOTAL PRODUCTION: SS = 2.81-05, TS = 9.87-05,2299 S04 1.53-05, CL = 4.51-06, K = 7.21-06, CA = 7.61-06, 2399 NA 4.47-06, BOD = 6.50-07, COD = 1.20-07, CAOH = 1.57-05, 2499 CAC03 = 1.57-05. SEE FOOTNOTE 6311. 2599 6331 199 ITOTAL DISSOLVED SOLIDS IS EQUAL TO TS MINUS SS. (SEE FOOTNOTE 299 6330) 399 6332 199 'EFFLUENT FOR THE STONE AND RELATED INDUSTRY IS GIV'Y_N FOR ASBESTOS 299 IX-21 FTN. 6333-6404 PRODUCTS ONLY. NO DATA WAS AVAILABLE FOR THE OTHER PRODUCTS. IN 399 THIS GROUP. THE AVERAGE EFFLUENT WEIGHTED BY FLOW IS AS 499 FOLLOWS- SS = 3.41-04 TON, TS = 5.13-02 TON, BOD = 3.62-04 599 TON, COD = 1.85-04 TON. ASBESTOS PRODUCTION MAKES UP 0.5 PC 699 OF TOTAL PRODUCTION.- SEE FOOTNOTE 6319 799 6333 199 TOTAL DISSOLVED SOLID = TS - SS (SEE FOOTNOTE 6332) 299 6400 199 INCLUrED UNDER MEAT AND DAIRY PRODUCTS ARE THE SIC CODES 20.1 AND 299 202. SOURCES OF INFORMATION ON PRODUCTION ARE (6400) AND (001 1 399 581/-622). 499 6401 199 ENERGY PER MEASURE IS COMPUTED BY DIVIDING FUEL TYPES USED IN 1967 4199 (0041) BY PRODUCTION IN 1967 (6402). CONVERSION FACTORS FOR 399 FUEL QUANTITY TO BTU (0005,38). 499 6402 199 AIR EMISSIONS FROM MEAT AND DAIRY PRODUCTS OCCUR PRIMARILY FROM 299 USE OF FUEL FOR STEAM GENERATION AND HEATING. ASSUMING THAT 399 ESSENTIALLY ALL FUELS INPUT ARE USED FOR STEAM GENERATION AND 499 HEATING, THE AMOUNTS OF EACH FUEL TYPE USED PER TON OF PRODUCT 599 ARE AS FOLLOW .(SEE FOOTNOTE 6401)- COAL 1.21-02 TON, 699 DISTILLATE 2.56-02 GALLON, RESIDUAL 2.51-02 GALLON, 799 NATURAL GAS 1.04-03 MMCF. -USING THE ABOVE AND THE EMISSION 899 FACTOR.S FROM (0002,1-3/1-9), THE TOTAL AIR EMISSIONS ARE AS 999 FOLLOWS IN TONS- 1099 PART sox co HYDCARB Nox ALDEHYD ORGANIC 1199 1.14-03 7.66-04 1.23-05 2.71-05 1.58-04 1.64-06 3.66-06 1299 6403 199 WATER EFFLUENT FOR MEAT AND DAIRY PRODUCTS ARE AS FOLLOWS TON/TON 299 MEAT PACKING 0.01530 TON COD (6403,32) 399 0.00740 TON BOD (6407,40,58) 499 POULTRY PROCESSING 6.00840 TON BOD (6404) AND (6405,IW4) 599 0.01080 TON COD (6404) 699 0.00483 TON DS (6404) 799 0.00563 TON SS (64014) AND (6405,IW4) 899 0.00225 TON GREASE (6404) AND (6405,IW4) 999 CREAMERY BUTTER 0.11900 TON BOD (6408,9-17,9-35) 1099 CHEESE 0,10500 TON BOD (6 40 8,9- 4 6, 9- 64) 1199 0.00064 TON PG4 (6406) 1299 0.00007 TON N03 (6406) 1399 0.00760 TON SS (6406) 1499 CONDENS & EVAP MILK 0.00391 TON BOD (6408,9-79,9-96) 1599 ICE CREAM & FROZEN 0.00088 TON BOD (6408,9-111,9-126) 1699 FLUID MILK 0.00010 TON BOD (6408,9- 14 1,9- 148) 1799 TOTAL EFFLUENT OF EACH TYPE IS THE SUM FROM EACH SOURCE 1899 WEIGHTED BY THE PC OF TOTAL PRODUCTION OF EACH SOURCE (MEAT 1999 PACKING = 0.23, POULTRY PROCESSING = 0.08, CREAMERY BUTTER 2099 0.006, CHEESE = 0.012, COND 6 EVAP MILK = 0.014, ICE CREAM 2199 FROZEN = 0.018, FLUID MILK = 0.63) 2299 6404 199 INCLUDED UNDER BAKERY, SUGAR & CONFEC.TIONARY AND RELATED PRODUCTS 299 ARE SIC 206 AND SIC 207. DATA FOR PRODUCTION AND CONVERSION, 399 WHERE NECESSARY, IS AS FOLLOWS- 499 BAKERY PRODUCTS AVERAGE-VALUE (6402), (6409,5) AND 599 (0009,335) 699 SUGAR PRODUCTS (6400,1114) 799 CONFECTIONARY & RELATED AVERAGE VALUE (6402), (6409,6) AND 899 (0009,335) IX-22 FTN. 6405-6411 6405 199 ENERGY PER MEASURE IS CALCULATED 2Y DIVIDING ENERGY OF FUEL TYPES 299 USED (0041) BY PRODUCTION (6402) IN 1967. CONVERSION FACTORS 399 FOR FUEL TYPES (0005,38). 49.9 6406 199 ESSENTIALLY NO AIR EMISSION FROM PROCESS USE OF ENERGY COULD BE 299 FOUND. THE ONLY EMISSION OCCURS FROM THE USE OF FUELS FOR 399 STEAM GENERATION AND INDIRECT HEATING. THE EMISSION FRCM BOTH (499 SOURCES CAN BE CONSIDERED THE SAME, THUS FBOM FOOTNOTE 6405, 599 TON OF COAL, 1.71-03 TON OF COKE, 8.48-02 BARREL OF .699 DISTILLATE, @.05-02 BARREL RESIDUAL AND 2.66-03 MMCF NATURAL 799 GAS PER TON OF PRODUCT IS'USED. FROM (0002,1-3/1-9).THE 899 EMISSIONS ARE AS FOLLOWS- 999 PART sox CO HYDCARB NOX ALDEHYD ORGANIC 1099 3.90-03 2.45-13 3.84-05 7.21-05 4.63-04 4.19-36 9.30-06 -1199 6407 199 WATER EFFLUENT IS REPORTED FOR SUGAR. SUGAR BEET P30CESSING HAS 299 THE FOLLCWING EFFLUENTS (6411.IW15/IW19) ASSUMING SETTLING 399 PONDS- BOD = 6.40 LB/TON, COD = 20.26 LB/TON, DISSOLVED SOLID 499 479.23 LB/TON, SS = 44.57 LB/TON, N03= 1.82 LB/TON AND 59q AMMONIA = 11.14 LB/TON. FRCM SUGAR CANE PROCESSING THE 699 EFFLUENT IS REPORTED AS FOLLOWS (6410,1175)- SS = 1750.00 LB 799 ITON, COE = 650 LB/TON, N03 = 12.00 LB/TON,AND P04 = 5 LB/TON. 899 TOTAL WATER EFFLUENT OF EACH TYPE IS THE SUM FROM EACH SOURCE 999 WEIGHTED BY PRODUCTION (THISO-REPRESENTS 34PC OF TOTAL- SUGAR 1099 EEET PROCESSING = 0.110 S@GAP CANE PROCESSING ='0.23) 1199 6408 199 INCLUDED UNDER THE CLASSIFICATION OF BEVERAGES AND CANNED, CURED 299 AND FROZEN FOOD ARE SIC 20B AND SIC 203.SOURCES OF INFORMATION 39q ON PRODUCTION ARE (0011), .(6400) AND WHERE NECESSARY TO TAKE 499 AVERAGE VALUE OF PRODUCT (6402) AND (6409). 599 6409 199 THE CNLY AIR EMISSIONS THAT ARE REPORTED FOR PROC ESSES ARE IN MAKE 299 ING BEVERAGES (0002,6-6)- 5.00 LB PARTICULATE / TON PRODUCT. 399 OTHER EMISSIONS OCCUR FROM USE OF FUEL FOR HEATING AND STEAM 499 GENERATICN. ESSENTIALY ALL FUEL INPUTS ARE USED FOR THIS, THUS 599 3.13-02 TON OF COAL, 4.04-02 BARREL DISTILLATE, 8.13-02 699 BBL RESIDUAL AND 1.66-03 MMCF OF NATURAL GAS IS USED PER TON 799 PRODUCT. USING THE FACTORS FROM (0002,1-3/1-9) THE,EMISSIONS 899 ARE AS FCLLOWS 999 FART sox CO HYDCARB NOX ALDEHYD ORGANIC 1099 2.94-03 1.98-03 3.16-C5 4.91-05 3.42-04 2.65-06 5.82-06 1199 TOTAL EMISSION FOR EACH TYPE IS THE SUM OF THE PROCESS AND THE1299 FUEL U*SE EMISSION 1399 6410 199 SOLID WASTE IS REPORTED FOR CANNED, DFYED 'AND FROZEN FRUITS AND 299 VEGETABLES AS FOLLOWS (6417)- TON11000 TON PROCESSED 399 VEGETABLES 1037.0 499 FRUITS 526.0 599 SPECIALTIES 93.0 699 TOTAL SOLID WASTE IS THE SUM OF THE ABOVE WEIGHTED BY THEIR 799 RESPECTIVE PC OF PRODUCTION. THESE EQUAL 29PC OF TOTAL PRODUCT 899 (VEGETABLES = 0.10, FRUITS = 0.0.6, SP ECIALTIES = 0.10) 999 6411 199 WATEP EFFLUENT FOR BEVERAGE AND CANNED, CURED AND FROZEN FOODS is 299 AS FOLLO@S- TON/TON PRODUCT 399 WINERY (6412,332)-BOD-= 8.28-05, COD = 3.78-05, SS = 2.90-05 499 BREWERY (6413) -BOD = 6.24703, COD = 8.75-03, SS = 2.07-03 599 CANNERY (6414), (6415), (6416)- BOD = 1.15-@2, COE = 1.71-02 699 P04.= 3.32-05, N04 = 1.35-04 799 SS = 1.18-04, TDS 1.77-01, 899 IX-23' FTN 6412-6502 BASES 4.5505, ALK 5.51-04 99 ORGANIC = 5.51-04 1099 FROZEN (6414)- BOD 2.11-01. COD- 1.92-01, TDS = 2.61-02 1199 TOTAL WASTE EFFFLUENT IS THE SUM OF EACH SOURCE FCR EACH TYPE 1299 q WEIGHTED BY THE RESPECTIVE PC OF PRODUCTION OF EACH SOURCE. 1399 (WINE = C,06, BREWERY = 0.19, CANNERY = 0.24, FROZEN =0.063 1499 -OF TOTAL PRODUCTION) 1599 6412 199 INCLUDED UNDER THE CLASSIFICATION OF GRAIN MILL AND MISCELLANEOUS 299 FCOD AND KINDRED PRODUCTS ARE SIC 204 AND sic 209. SOURCES OF 399 INFORMATION ON PRODUCTION ARE (6400) (0011) AND (6402). 499 6413 199 AIR EMISSION FROM PROCESSES ARE REPORTED AS FOLLOWS: 299 ALFALFALEHYDRATING (00026-1) 60.0 LB/TON PARTICULATE 399 COFFEE ROASTER (0002,6-2) 6.7 LB/TON PARTICULATE 4 99 0.1 LB/TON NOX 599 0.2 LB/TON ALDEHYDES 699 0.9 LB/TON ORGANIC ACID 799 FEED AND GRAIN MILLS 31.6 LB/TON PARTICULATE 899 STARCH MANUFACTURING 8.0 LB/TON PARTICULATE 999 OTHER EMISSION OCCUR FROM FUEL USED FOR STEAM GENERATION AND 1099 HEATING. ESSENTIALLY ALL FUELS INPUT CAN BE CONSIDERED TO BE 1199 USED, THUS FROM FOOTNOTE 641C, 1.02-02 TON OF COAL, 4.45-03 1.299 BARREL DISTILLATE, 6.89-03 BARREL RESIDUAL AND 3.27-03 MMCF1399 NATURAL GAS ARE USED FOR ONE TON OF PRODUCT. USING THE 1499 EMISSION FACTOR FROM (0002,1-3/1-9) THE EMISSIONS FROM THIS 1599 SOURCE IN TONS ARE AS FOLLOWS- 1699 PAR T sox co HYDCARB NOX ALDEHYD ORGANIC 1799 9.62-04 6.47-04 1.03-05 1.17-05 9.76-05 5.25-07 1.15-06 1899 TOTAL EMISSION IS THE SUM OF THE PROCESS EMISSIONS WEIGHTED BY1999 PC 13F TOTAL PRODUCTION OF EACH SOURCE PLUS THE THE EMISSION 2099 FROM FUEL USED FOR STEAM GENERATION AND HEATING 2199 6414 199 THE ONLY WATER EFFLUENT REPORTED IS 2.0 PC OF PROCESSED FEED 299 MATERIAL IS DISSOLVED SOLIDS FOR WET CORN MILLING (6418,322) 399 THIS IS 40.00 LB/TON GRAIN PROCESSED. WET CORN MILLING MAKES 499 UP 2.0 PC OF TOTAL PRODUCTION 599 6415 199 TOTAL DISSOLVED SOLID IS THE SUM OF THE LISTED DISSOLVED SOLIDS 6500 FUELS AND ELECTRIC ENERGY PURCHASED FOR HEAT AND POWER IN 1967 299 FROM(6110,18). INCLUDES PULP MILLS, PAPERMILLS, PAPERBOARD 3 99 MILLS, INCLUDING BUILDING PAPER. USED TOTAL MILL PRODUCT 499 TONNAGES IN 1967 & 1971 (0011,634) TO GET DIVISOR. 599 6501 199 FUELS AND ELECTRIC ENERGY PURCHASED FOR HEAT AND POWER IN 1967 299 Pam (6110,18). INCLUDES CONVERTED PRODUCTS AND PAPERB0ARD CONTAINERS, BOXES. MULTIPLIER IS THE TONNAGE OF MILL PRODUCT 499 FROM FOOTNOTE 6500 MINUS BUILDING PAPER. THIS ASSUMES ONLY 599 BUILDING PAPER IS NOT FABRICATED AFTER IT IS MADE AND CUT. 699 THIS MULTIPLIER, IS THE TONNAGE OF INPUT,RATHER THAN OUTPUT, 799 FOR CONVENIENCE. 899 6502 199 WATER POLLUTANTS FROM (0016). THOUGH DATA IS FOR 1969, COMPARISON 299 WITH 1972 GUIDELINES(6503) AND EXTRAPOLATIONS FROM (6502) 399 SHOWS THAT IT PROBABLY IS MORE ACCURATE FOR 1971. PAPER IND- 499 599 USTRY POLLUTION RATES HAVE DIMINISHED RAPIDLY IN RECENT YEARS. DATA FROM (0016) IS CLOSE TO THE -B- STANDARDS IX-24 FTN. 6503 FROM THE 1972 GUTDELINES(6503). EXTRAPOLATIONS FROM (6502), 799 AN EARLIER, DETAILED STUDY, SHOW 1971 EFFLUENTS(POLLUTION) 899 ABOUT 3 TIMES THOSE FROM (6503 AND 0016). THAT EXTRAPOL- 999 ATION WAS VALID AT THE TIME (6502) WAS DONE. IT ALLOWED FOR 1099 THE EMERGENCE OF NEW TECHNOLOGY, ETC. IT WAS USED TO PRCJECT 1199 THE CORRECT VOLUME OF TOTAL WASTEWATER IN 1972, ABOUT 35.8 1299 THOUSAND GAL PER TON PRODUCTION. (0016,27)SHOWS 2.60E+06 1399 LB BOD PER DAY FROM PLANTS PRODUCING 1.89E+09 GAL/DAY TOTAL 1499 DISCHARGE. AT 350 DAY/YEAR AND 5.42E+C7 TONS/YEAR, THAT IS 1599 1.33E+06 TONS BOD/YEAR OR 2.46E-02 TON/TON PRODUCT.(0016,29) 1699 REPORTS 2.22E+06 LB SUSPENDED SOLIDS PER DAY FROM PLANTS 1799 PRODUCING 1.77E+09 GAL/DAY WASTEWATER. THAT IS 1.22E+06 1699 TONS/YEAR, OR 2.25E-02 TON/TCN PRODUCT. (0016,28) REPORTS 1999 1.64E+C6 LB/DAY COD FROM PLANTS PRODUCING 1.77E+09 GAL/DAY 2099 WATER. ThAT IS 9.04E+05 TON/YEAR, OR 1.67E-02 TON/TON 2199 PRODUCT. DISSOLVED SOLIDS WERE OBTAINED FROM (6502) AND 2299 REDUCED EY FACTOR OF 0.4, SINCE BOD AND SUSPENDED SOLIDS 2399 DATA FROM (6502) PROJECTIONS WERE 0.45, 0.38 TIMES 2499 THAN (0016) DATA, RESPECTIVELY. THE FOLLOWING SHOWS THE USE 2599 OF (6502) IN PROJECTING 1971-72 POLLUTION RATES. NOTE THAT 2699 ONLY THE RESULT FOP. DISSOLVED SOLIDS IS USED. REFERENCE 2799 (6502) ASSUMES THE SHAPE OF PRODUCT MADE BY KRAFT, 2899 SULFITE, BLEACHED, UNBLEACHED IS SAME AS IN 1963, BUT 2999 CCNSIDERS THE OVERALL SHIFT TO NEWER TECHNOLOGY THROUGH YEARS 3099 1967-1972-1977. ASSUMES THAT POLLUTION FROM INTEGRATED PAPER 3199 MILLS REPRESENTS POLLUTANTS PAPER TON PRODUCT FOR ENTIRE MILL 3299 INDUSTRY. IT GIVES POLLUTANTS FOR OLDER,PRESENT-1967, 3399 AND NEWER TECHNOLOGY, AND ESTIMATES PERCENT OF PLANTS AT EACH 3499 LEVEL IN 1972--- 11PC-OLDER,58PC-PRESENT,31PC-NEWER. 3599 MELIAN PLANT SIZES ARE--- 3699 OLDER 260 TONS/DAY 3799 PRESENT 550 TONS/DAY 3899 NEWER 850 TONS/DAY 3999 WEIGHTING BY PLANT SIZES GIVES SHARES OF 197Z PRODUCTICN, BY 4099 TONNAGE--- OLDER-5PC, PRESENT-52PC,NEWER-43PC. 4199 FINAL TONS POLLUTANT/TONS PRODUCT WERE COMPUTED BY WEIGHTING 4299 WASTELOADS FROM FOLLOWING TABLE (6502,25) BY 1972 PRODUCTION 4399 SHARES ABOVE--- 4499 -WASTELOADS-LBS/TON PRODUCT- 4599 SUS. SOLIDS DIS. SOLIDS TOTAL SOLIDS BOD 4699 4799 OLDER 190 810 1000 200 4899 PRESENT 120 550 670 135 4999 NEWER 90 260 350 80 5099 5199 NOT SHOWN ON TABLE IS 35.75 THOUSAND GAL.TOTAL, WASTEWATER 5299 EFFLUENT PER TON PAPERMILL PRODUCTION, FOR 1972, CALCULATED 5399 IN SAME WAY. FINALLY, AFTER COMPARING WITH DATA FROM (0016) 5499 AND (6503) , THE CORRECTION ACTOR OF 0.4 WAS APPLIED. NO COD 5599 WAS INCLUDED IN (6502). 5699 6503 199 AIR POLLUTANTS COME FROM THREE MAIN SOURCES-- PULP- PROCESSING, 299 BARK BURNING, AND BURNING OTHER FUELS FOR STEAM GENER- 399 ATION. PAPERBOARD DRYING PRODUCES NEGLIGIBLY SMALL PARTIC- 499 ULATE EMISSIONS(0002,10-4). 599 PULP PROCESSING--FOR EACH TON OF WOODPULP USED IN MILLS IN 699 1971, 54.15/43.61=1.24 TON. OF PAPER AND BOARD, WERE MADE, FROM 799 (0011,633). REF.(O002,10-3) GIVES FACTORS PER TON PULP MADE. 899 WE ASSUME THE AVERAGE RECOVERY BOILER IS EQUIPPED WITH A 999 VENTURI SCRUBBER. HALF OF ALL LIME KILNS HAVE A SCRUBBER AND 1099 HALF ARE UNCONTROLLED. EMISSIONS FROM FLUIDIZED BED 1199 I X - 2 5 FTN. 6504 CALCINATORS ARE NEGLIGIBLE (FEW INSTALLATIONS). FROM (0002) 1299 WE INCLUDE FACTORS FROM BLOW TANK ACCUMULATOR, WASHERS AND 1399 SCREENS, MULTIPLE-EFFECT EVAPORATORS, RECOVERY BOILERS, 1499 SMELT DISSOLVING TANK, LIME KILNS, AND TURPENTINE CONDENSORS. 1599 WE ASSUME ALL THESE ARE USED FOR EACH TON OF PULP MADE. 1699 BARK BURNING--FROM (6501,8-12), 175 TONS OF BARK ARE BURNED 1799 PER YEAR FOR EACH TON OF PULP MADE PER DAY IN THAT YEAR. 1899 FROM (0011,633),IN 1971,43.6 MILLION TONS OF PULP WERE MADE. 1999 AT 350 DAYS/YEAR, THAT IS 124 THOUSAND TONS PULP PER DAY, AND 2099 MILL10N TONS WOOD BARK PER YEAR. (0002,1-11) GIVES 2199 EMISSIONS FOR BURNING WOOD AND BARK IN BOILERS, BY TON WEIGHT. 2299 STEAM GENERATION--ALL FOSSIL FUELS PURCHASED ARE ASSUMEED USED TO MAKE STEAM (AND ELECTRICITY). COMPUTING EMISSIONS FROM (0002,1-3/1-9) FOR EACH FUEL GIVES EMISSIONS PER TON OF MILL END PRODUCT, PAPER AND PAPERBOARD, CORRECTED FROM PULP PRODUCTION BASIS REPORTED--- 2799 2899 AIR POLLUTANTS FROM BURNING FUELS (EXCEPT WOOD) 2999 PER TON PAPER 3099 IN TONS POLLUTANT (NEGATIVE EXPONENTS FOLLOW EACH NUMBER) 3199 COAL RESID DISTIL GAS TOTAL 3299 PARTICULATES 9.09-03 2.61-04 6.32-05 6.27-05 9.48-03 3399 2.80-04 2.27-06 8.41-07 1.39-06 2. 84 -04 3499 HC 1.40-04 3.41-05 1.26-05 1.39-04 3.26-04 3599 NOX 2.10-03 6.61704 2.53-04 6.08-04 3.64-03 3699 ALDEHYDES- 6.98-07 1.14-05 8.42-06 3.48-05 5.52-05 3899 sox 1.06-02 3.13-03 1.36-04 2.09-06 1.39-02 3799 (AND OTHER) 3999 TO GET THESE NUMBERS, WE ASSUME 50 PERCENT COLLECTION EFFIC- 4099 LENT FLY-ASK (PARTICULATE) CONTROLS ON COAL BOILERS. 4199 ASSUME COAL IS 10 PERCENT ASH, 2 PERCENT SULFUR, FROM (5510) . 4299 ASSUME RESIDUAL FUEL OIL IS 1.73 PERCENT SULFUR (NO.5 GRADE), 4399 AND DISTILLATE FUEL OIL IS 0.224 PERCENT SULFUR (NO.2 GRADE) , 4499 FROM (5109). BTU CONVERSIONS FROM (0005). 4599 TOTAL POLLUTANTS-- IN USING FACTORS FROM (0002), WE 4699 ASSUME THAT THE KRAFT PROCESS (OF PULPING) REPRESENTS THE 4799 INDUSTRY. ABCUT 80-85 PERCENT OF PULP IS KRAFT PROCESSED. 4899 THE TOTALS SHOWN ON THE TABLE ARE BROKEN DOWN BELOW--- 4999 5099 AIR POLLUTANTS FROM ALL MILL SOURCES 5199 IN TONS POLLUTANT PER TON PAPER 5299 (NEGATIVE EXPONENTS FOLLOW EACH NUMBER) 5399 5499 PULP PROCESS BARK OTHER FUEL TOTAL 5599 PARTICULATES 2.98-02 6.00-03 9.48-03 4.53-02 5699 2.82-02 4.00-04 2.84-04 2.89-02 5799 HC 4.00-04 3.26-04 7.26-04 5899 cc NOX 2.00-03 3.64-03 5.64-03 5999 Sol 2.02-03 6.00-04 1.39-02 1.65-02 6099 OTHER* 7.78-03 1.00-04 5.52-05 7.94-03 6199 6299 6504 199 299 ASSUME ALL PURCHASED FUELS USED FOR HEATING DESIGNATED LARGE COMMERCIAL. IN (0002) . BTU CONVERSIONS FROM (0005) . NOMINAL 399 10 PERCENT ASH, 2 PERCENT SULFUR COAL, FROM (5510). ASSUME 4 9 9 OIL IS 1.873 PERCENT SULFUR AND DISTILLATE IS 599 RESIDUAL FUEL 0.224 PERCENT SULFUR, FROM (5109) . A LISTING BY FUEL FOLLOWS-- 699 AIR POLLUTANTS FROM PAPER PRODUCTS 799 MANUFACTURING 899 IN TONS POLLUTANT PER TOM PAPER INPUT 999 (NEGATIVE EXPONENTS FOLLOW EACH NUMBER) 1099 IX-26 FTN 6505-6601 1199 COAL RESID DISTIL GAS TOTAL 1299 PARTIC 1.32-04 1.63-05 8.89 06 5.69-06 1.63-04 1399 CO 4.07-06 1.43-07 1.19-07 5.99-06 1.03-05 1499 HC 2.03-06 2.12-06 1.77-06 2.40-06 8.32-06 1599 NOX 3.04-05 4.26-05 3.56-05 2.99-05 1.39-04 1699 sox 1.54-04 1.95-06 1.92-05 1.80-07, 1.75-04 1799 OTHER 1.01-08 7.08-07 1.19-06 3.30-06 5.21-06 1899 6505 199 SHOWS 1.644E+06 LB/DAY COD FROM 1.77E+09 GAL/DAY WATER 299 DISCHARGED IN 1969. FOOTNOTE 6502 GIVES 3.575E+04 GAL WATER 399 PER TON MILL PRODUCTION (5.42E+07 TONS IN 1971). MULTIPLYING 499 GIVES 0.904E+06 TOYS COD IN 1971. BUT BOD AND SUSPENDED SOLIDS 599 DATA DERIVED FROM MORE DETAILED REF. (6502) ARE 2.2 &2.6 TIMES 699 SURVEY DATA FROM (0016), RESPECTIVELY. WE MULTIPLY BY 2.5 TO 799 GET 2.26E+06 TONS COD, 1971,'FROM ALL MILLS. 899 6506 199 (0016,30) GIVES A RANGE OF PH VALUES 2p DISCHARGED WASTEWATERS 299 FROM 3.4 TO 10.0. (6502,37) GIVES A RANGE OF 3.5 TO 11 OR12 39 FOR MAIN MILL WASTEWATERS. (6503,4) LIMITS PH BY REGULATION, 499 TC BETWEEN 6.0 AND 85. 599 6600 199 ENERGY USED IN IRON & STEEL MAKING IS BASED ON DATA REPORTED BY 299 AISI FOR 1972 (6600,53,54,59) . ALL VALUES OF ENERGY USE ARE 399 BTU/T0N RAW STEEL PRODUCED. THE AGGREGATE ENERGY FOR MAKING 499 STEEL INCLUDES IRON VIA THE BLAST FURNACE BUT DOES NOT INCLUDE 599 IRON ORE AND LIMESTCNE MINING AND SHIPMENT. THIS IS CONSIS- 699 TENT WITH THE DEFINITION OF INDUSTRIES UNDER SIC 33. 799 A BREAKDOWN OF FUELS USED FOR IRON AND STEEL IS AS FOLLOWS-- 899 999 COAL(OTHER THAN FOR COKE) 4.36EO6 TONS 1099 COKE(CONSUMED) 54.8E06 TONS 1199 FUEL OIL 1.313EO9 GAL 1299 TAR & PITCH 232.EO6 GAL 1399 IPG 14.96EO6 GAL 1499 NATURAL GAS 771.9EO9 CUBIC FT 1599 PURCHASED ELECTRICITY 39.36EO9 KWH 1699 RAW STEEL PRODUCED IN 1972 WAS 133.24EO6 TONS(6600,8) 1799 CONVERSION FROM BULK FUEL USE TO BTU USING (O005,38) AND THE 1899 FOLLOWING FACTORS-- TAR & PITCH AT 6EO6 BTU/BBL OR 0.143 1999 BTU/GAL, LPG AT 95,500 BTU/GAL 2099 FOR PURPOSES OF REPORTING, FUEL OIL* FIGURE OBTAINED FROM 2199 AISI HAS BEEN PROPORTIONED INTO DISTILLATE AND RESID USING 2299 DATA IN (0041) FOR 1967. THIS SHOWED FUEL OIL TO BE 39PC DSTL 2399 AND 61PC RESID BY VOLUME. TAR & PITCH HAS BEEN REPORTED AS 2499 AS PART OF RESID, LPG AS PART OF NATURAL GAS AND PURCHASED 2599 ELECTRICITY AT 3 TIMES BTU EQUIVALENCE. 2699 NOTE ENERGY IS ON A COKE INPUT SINCE CONVERSION OF COAL 2799 TO COKE IS HANDLED SEPARATELY IN THE SUPPLY TABLES FOR COAL. 2899 THE AGGREGATE ENERGY USE BASED ON A COAL INPUT (TO INCLUDE 2999 COKE PRODUCTION) IS 26.3EO6 BTU/TON OF STEEL FOR 1972. COKE 3099 OVEN & BLAST FURNACE GASES ARE NOT INCLUDED IN STEEL ENERGY 3199 INPUTS SINCE THEY ARE ACCOUNTED FOR IN INPUTS TO COKE OVEN 3299 AND BLAST FURNACE PROCESSES. TOTAL ENERGY USE DERIVED FROM 3399 ROW 43 DATA IS REPRESENTATIVE,OF SIC 3312 3499 6601 199 ENERGY USE FOR IRON & STEEL CASTINGS(SIC 332) IS BASED ON ON 1967 299 DATA. THE MULTIPLIER IS FOR 1969, OBTAINED FROM(0007) BULK 399 IX-27 FTN. 6602-6604 ENERGY USE IS SHOWN BELOW. ALL VALUES EXCEPT COKE FROM 499 (004 1, 22 2 3) 599 COAL (OTHER THAN FOR COKE) 419.6EO3 TONS 699 COKE 3485. E03 TONS 799 DISTILLATE 916. E03 BBL 899 RESIDUAL 377.5EO3 BBL 999 NATURAL GAS 55.6EO9 CU FT 1099 PURCHASED ELECT 581.7EO7 KWH l199 1299 ESTIMATED COKE USE FROM (0001,413). THIS ESTIMATE DIFFERS 1399 GREATLY FROM (0041) AND IS A POTENTIAL SOURCE OF ERROR. 1499 FERROUS CASTINGS IN 1967 BREAK DOWN AS FOLLOWS (0007,103) 1599 GREY IRON 14.33EO6 TONS 1699 MALLEABLE IRON 1.04EO6 TONS 1799 STEEL 1.86EO6 TONS 1899 TOTAL 17.23EO6 TONS 1999 ENERGY VALUE FOR EACH FUEL DERIVED USING HEAT VALUES FROM 20991 (0005,38) AND THE TOTAL CASTINGS PROLUCED OF 17.23EO6 TONS/YR 2199 SHE MEASURE IS TON OF AVERAGE CASTING 2299 6602 199 ENERGY USE IN BTU/TON OF PRIMARY ALUMINUM PRODUCED IS DERIVED 299 FROM FUEl USE REPORTED IN (0041,22,23) AND ELECTRODE CARBON 399 REPORTED IN (6601) BULK FUEL USE ESTIMATED FOR 1967 499 FOLLOWS (0041) 599 COAL 565.2 E03 TONS 699 PETROLEUM COKE 1.95EO6 TONS (FOR 1968) 799 DISTILLATE 36.2 E03 BBL 899 106.7 E03 BBL 999 RESIDUAL NATURAL GAS 13.08E10 CU FT 1099 PURCHASED ELECT. 41.96EO9 KWH 119 PRIMARY ALUMINUM PRODUCED IN 1967. WAS 3.269EO6 T (0001,151) 1299 CONVERSICN OF FUEL USE TO BTU USING HEAT VALUES FROM (0005,38)1394 TONS OF PETROL. COKE/TON ALUMINUM = 0.60 USING ABOVE DATA. 1499 PETROL CCKE CONVERTED FROM VOL TO WEIGHT MEASURE USING 1599 401. LB/BBL (0010,588),GIVING 30.EO6 BTU/TON PETROL COKE 1699 AND CONTRIBUTING 10 PC OF THE TOTAL ALUM. ENERGY REQUIREMENT. 1799 OF 195.5E06 BTU/TON. FOR COMPARISON,ALCOA REPORTS AN 1899 ENERGY VALUE FOR PRIMARY ALUM OF 216.EO6 BTU/TON (6602,58). 1999 THE MULTIPLIER IS FROM (0025,167) 209 6603 ENERGY USE IN BTU/TON PRIMARY COPPER PRODUCED IS DERIVED FROM FUEL 299 USE REPORTED IN (0041,22,23) BULK FUEL USED IN 1967 PRIMARY 399 COPPER PRODUCTION IS AS FOLLOWS 49 COAL 159.7 E03 TONS 59 COKE 12.8 E03 TONS 69 DISTILLATE 120.9 E03 BBL 79 RESID 1454. E03 BBL 899 NATURAL GAS 26.31E09 CU FT 999 PURCHASED ELECT 859.8 E06 KWH 1099 PRIMARY COPPER PRODUCED IN 1967 = 1.133EO6 TONS (0001,452). 1199 ENERGY VALUES IN THE TABLE USE THE ABOVE DATA AND HEAT VALUES 1299 FROM (0005,38) THE MULTIPLIER IS PRIMARY PRODUCTIGN FOR 1399 1970 FROM (0025,468). FOR COMPARISON,SRI (0007,111) REPORTS 1499 THE ENERGY VALUE FOR PRIMARY COPPER TO BE 40EO6 BTU/TON. 6604 199 ENERGY USE.IN BTU/TON OF PRIMARY ZINC HAS BEEN OBTAINED FROM 299 CENSUS DATA (0041,22,23) BUT WITH A MODIFICATION OF COKE USE 399 TO REFLECT REDUCING REQUIREMENTS FOR DISTILLED ZINC. THE 1967 499 SLAB ZINC PRODUCTION IS AS FOLLOWS (0001,1156) 599 699 ELECTROLYTIC PRIMARY 371,267 TONS - 39.6 PC DISTILLED PRIMARY 567,563 TONS - 60.4 PC 899 IX-28 FTN. 6605-6606 TOTAL 938,830 TONS 899 ELECTRCLYTIC ZINC USES ALUMINUM ELECTRODES. DISTILLED ZINC 999 USES 0.5 TO 0.8 TONS OF COAL OR COKE PER TON ZINC OUTPUT. 1099 (6601,810).THE COAL OR COKE 1.@ A REDUCING AGENT. COKE USE HAS 1199 BEEN COMPUTED USING 0.5 TONS/TON DISTILLED ZINC (0.302 TONS 1299 /TON TOTAL PRIMARY ZINC). BULK FUEL USE IS AS FOLLOWS FOR 1399 1967----- 1499 COAL 678.6 E03 TON 1599 COKE 284. E03 TON 1699 DISTILLATE 8.3 E03 BBL 1799 NATURAL GAS 27.35EO9 CU FT 1899 PURCHASED ELECT. 1493. E06 KWH 1999 THE 1970 MULTIPLIER FOR PRIMARY ZINC TONNAGE IS FROM 2099 (0025,1175) PRIMARY ZINC CORRESPONDS TO SIC 3333 2199 66;5 199 PARTICULATE EMISSIONS ARE THE AGGREGATE CF IRON & STEEL MAKING 299 BASED ON THE OUTPUT OF A TON OF RAW STEEL. THE RATIO,TONS PIG 399 IRON/TON STEEL , IS 0.617 (0025,594). EMISSIONS DURING THE 499 SINTERING PROCESS OF IRON MAKING ARE EXPRESSED IN TERMS OF 599 TONS OF SINTER IN THE SOURCE MATL (0002) THIS IS CONVERTED 699 TO IRON CUTPUT USING 0.507 TONS SINTER/TON PIG IRON USING 799 SINTER PRODUCTION DATA FROM (0025,589). EMISSIONS FROM COKING 899 ARE INCLUDED IN COAL SUPPLY. UNCONTROLLED EMISSIONS, CURRENT 999 .LEVEL OF CONTROL AND CURRENT INDUSTRY AVERAGE EMISSIONS 1099 FOLLOW 1199 UNCCNTROL@ED CURRENT LEVEL CURRENT EMIS- 1299 PFOCESS CGNTROL(6603) -SION LB/TON 1399 1499 BLAST FUFNACE 150 99 PC 1.5/ IRON 1599 SINTERING 42 95 2.1/ SINTER. 1699 OFEN HEAFTH 1799 OXYGEN LANCE 22 90 2.2/LANCED STL1899 NO OXYGEN LANCE 12 45 6.6/UNLAN. STL1999 BOF 46 92 3.7/BOF STEEL 2099 ELECTRIC ARC 2199 OXYGEN LANCE 11 90 1.1/LANCED STL2299 NO OXYGEN LANCE 7 45 3.9/UNLAN STL 2399 SCARFING 2C 25 15. /SCARF STL 2499 NOTE THAT THE CURRENT EMISSION LEVEL DERIVES FROM AN ESTIMATED2599 LEVEL O.F PARTICULATE CONTROL THAT REPRESENTS THE AVERAGE OF 2699 THE IRON AND STEEL INDUSTRY IN 1973. THE CONTROL LEVELS ARE 2799 LESS THAN THEORETICAL EFFICIENCIES. SPECIFIC LEVELS AT ANY 2899 ONE SITE ARE HIGHLY DEPENDENT ON LOCAL AIR QUALITY LEVELS. 2999 DATA AGGREGATION FOR STEEL PRODUCTION PROCESSES USES THE 3099 FOLLOWING BREAKDOWN (0025,605) 3199 OPEN HEARTH 36.6 PC OF STEEL PRODUCED 3299 BOP 48.1 PC 3399 ELECTRIC ARC 15.3.PC 3499 OPEN HEARTH AND ELECTRIC ARC PRODUCTION ARE ASSUMED TO HAVE 3599 A 50/50 MIX BETWEEN LANCED AND NO-LAVCED STEEL 3699 6606 199 NOX EMISSIGNS FOR SEVERAL PARTS OF IRON AND STEEL MAKING ARE. 299 REPORTED IN (6604) THE VALUES AVAILABLE ARE AS FOLLOWS 399 LBS NOX 499 BLAST FURNACE 0.444 LBS/TON IRON CALC.FR'OM (6604,7-34) 599 IRON SINTERING 1.04 LBS/TON SINTE- (6604,7-36) 699 OPEN HEARTH 245. LBS/TON STEEL (6604,7-34) 799 -1.0 LBS/TON (6604,7-35) BOF 0.36 STEEL 899 999 THE EMISSIONS ARE RELATIVELY UNCONTROLLED. AGGREGATION 1099 INTO TONSITON RAW STEEL USES THE CONVERSION FACTORS AND 1199 IX-29 FTN. 6107-6630 STEEL PRODUCTION BY PROCESS MIX GIVEN IN FOOTNOTE 6605. 199 BOP EMISSION TAKEN AT 0.7 LBS NOX/TON STEEL 299 SOX IS GENERATED FOR SINTER OPERATION AT RATE OF 3 LBS S02/TON 6607 199 SOX 15 GENERATED FOR S.NTER OPERATION AT RATE OF 3 LOS S02 /TOR 299 SINTER (0002,7-9) CONVERSION TO TONS/TON OF STEEL USING 399 FOOTNOTE. 660.5 FACTORS. OTHER SOX SOURCES NOT AVAILABLE BUT 499 PROBABLY SMALL. 599 699 199 CO EMISSIONS ARE FROM-IRON SINTERING AND BOP/ELECTRIC ARC STEEL 299 FURNACES. CO, GENERATED IN, THE BLAST FURNACE IS USED AS, FUEL, 399 AND SLIPS. APE NOT CONSIDERED. TO OCCUR. EMISSION FACTORS 499 FROM (OO02,7-9) ARE AS POLLOWS- 599 699 SINTER 44LBS CO/TON SINTER = 22.3 LB/TON PIG IRON 799 BOP STEEL 1.5 LB/TON BOP STEEL = 0.7 LB/ TON ALL STEEL 899 ELECT ARC 18 LB/TON LANCED, E-A STEEL = 1.,4 LB /TON ALL STL 999 1.8 LB/TON NO LANCED' E-A STEEL =1.4 LB/TON ALL STEEL CO FROM THE BOP FURNACE IS AN AVERAGE VALUE . ELECTRIC ARC PRODUCTICN ASSUMES 50/50 MIX-BETWEEN LANCED AND NO-LANCED 1299 SINTER AND IRON STEEL EQUIVALENTS FRCM. FOOTNOTE, 6605. 13991 6609 199 THE' PRIMARY SOLID BY-PRODUCT IS THE SLAG PRODUCED IN THE BLAST 299 FURNACE PROCESS. THE SLAG IS READILY SALABLE AS A GENERAL RULE. 399 FOR BALLAST CEMENT AGGREGATE AND LAND FILL (6601,305) AND IS 499 NOT CONSIDERED A SOLID WASTE. SOLIDS GENERATED BY PARTICU- 59 9 LATE CONTROL HAVE NOT BEEN. ASSESSED. 699 6610 199 AVERAGE WATER CONSUMPTION FOR THE STEEL INDUSTRY IS 29000 GAL/TON 299 USING 1968 DATA (6605,7-20). BECAUSE OF MANY OUT FALLS FOR 399 EACH STEEL MILL, AVERAGE TEMP RISE IS NOT AVAILABLE.. 499 66 199 EFFLUENT CHARACTERISTICS VARY GREATLY FROM ONE. LOCATION TO 299 ANOTHER, ALLOWABLE DISCHARGE DEPENDS UPON THE RECEIVING 399 WATER CHARACTERISTICS. THE WATER POLLUTANTS ARE DERIVED FROM- 499 TREATMENT LEVEL B INTERIM EFFLUENT GUIDELINES ISSUED BY THE 599 EPA FOR INDUSTRY SIC 3312 (6606) PROCESSES WHICH PRODUCE 699 EFFLUENT'S ARE NOT NECESSARILY RELATED TO ENERGY USE AND HENCE 799 THE AGGREGATE EFFLUENT FROM SIC3312 HAS BEEN DERIVED FROM ONLY 899 THE-FOLLOWING OPERATIONS GIVEN IN IN(6606) IRON MANUFACTURING-SUSPENDED SOLIDS,NH3,CYANIDE,PHENOL 899 STEEL MANUFACTURING-SUSPENDED SOLIDS 999 HOT FORMING -SUSPENDED SOLIDS,OIL&GREASE 1291 EFFLUENTS FOR IRON MANUFACTURE HAVE BEEN EXPRESSED AS TONS 1399 PER ION CP STEEL USING 0.617 TONS IRCN/TON STEEL (0025,594) 1499 ALL STEEL IS ASSUMED TO BE HOT FORMED. AFTER CONVERSION TO 1599 TONS/TON RAW STEEL AND AGGREGATION, THE TOTAL EFFLUENTS ARE 1699 AS FOLLOWS--- 1799 SUSPENDED SOLIDS 1.21E-03 TONS/TON AMMONIA 6.20E-05 1999 CYANIDE 6.20E-06 2099 PHENOL 3.08E-06 2199 OIL & GREASE 4.50E-04 2261 6630 (0042 299 AIR EMISSION FROM PRIMARY ALUMINUM PRODUCTTON IS REPORTED BY ,7.1-5/7.1-6). SINCE A WIDE RANGE AND AMOUNT OF CONTROL ARE 499 USED IN THE INDUSTRY, THE MINIMUM AMOUNT OF CONTROL IS USED. 599 THE EMISSONS ARE AS FOLLOWS, IN TON/TON PRIMARY ALUMINUM 699 PART FLOURIDE PART FLOURIDE 799 BAUXITE GRINDING .SPRAY TOWER 4.07-03 Reproduced from CALCINING OF AL(0H)3 best available coPY IX-30 SPRAY TOWER 6.00-02 FTN. 6631-6634 1099 ANODE BAKING FURNACE 1199 LRY ELECTROSTATIC PREC. 5-5-04 4.65-04 0.00-00 1299 PREBAKED REDUCTION CELL (PB) 1399 MULTIPLE CYCLONE 8.95-02 1.24-02 2.24-03 1499 HORIZONTAL-STUD (HSS) 1599 SCEERBERG CELL 1699 SPRAY TOWER 1.40-02 1.06-03 2.22-03 1799 VERTICLE-SIUD (VES) 1699 SODERBERG CELL 1999 SFRAY TCWER 9.80-03 1.52-04 1.32-03 2099 TOTAL 1.26-01 2.12-02 2.12-03 2199 THE TOTAI INCLUDES THE AVERAGE CELL EMISSIONS. THE AVERAGE 2299 CELL EMISSION IS CALCULATED BY WEIGHTING BY PC OF PRODUCTION. 2399 (PB = 61.9 PC, HSS = 25.5 PC, VSS = 12.6 PC) (0042,7.1-2/3) 2499 6631 199 EMISSION OF NOX, SOX, HYDROCARBONS AND CO ARE SMALL OR NEGLIGIBLE 299 FROM THE PROCESS. THE FUELS INPUT INTO THE INDUSTRY ARE 399 ESSENTIALY ALL USED FOR ELECTRICITY PRODUCTION (0041,SR4-22/23)499 6632 199 UNCONTROLLED EMISSIONS OF PARTICULATE ANE SOX ARE REPORTED FOR 299 COPPER SMELTERS (0042,7.3-2). ELECTRCSTATIC PRECIPITATORS AND 399 CYCLONES ARE THE MOST COMMON SOURCES OF CONTROL (0042,7.3-1) 499 BASEL UPON THIS AND THE EFFICIENCY OF THE PRECIPITATOR = 99.7 599 AND CYCLCNE = 90.0,THE EMISSIONS ARE AS FOLLOWS, TON/TON OF 699 PRIMARY COPPER PART SOX 799 ROASTING 2.70-04 1.20-02 899 SMELTING ('REVEBRERATORY FURNACE) 1.20-04 6.40-02 999 CONVERTING 3.60-04 1.74-01 1099 REFINING 6.00-05 1199 TOTAL 8.10-04 2.50-01 6633 199 AIR EMISSIONS FROM ZINC SMELTING ARE GIVEN IN (0042,7.7-01) ALL 299 ZINC SMELTING PROCESSES START BY ROASTING AND SINTERING OF 399 ZINC OXIDES. AIR EMISSONS DIFFER ONLY IN THE PROCESSES USED 499 FOR THE EXTRACTION OF ZINC dETAL--HORIZONTAL RETORTS, VERTICAL 599 RETORTS, ELECTROLYTIC PROCESS. FROM (0028,1192,1193) THE PC 699 BREAKDOWN IN PROCESSES ARE 41.0 PC ELECTROLYTIC, 35.0 PC 799 VERTICAL RETORT AND 26.0 PC HORIZONTAL RETORT. FROM THE ABOVE, 899 THE EMISSIONS IN TON/TON METAL ARE AS FOLLOWS. (ASSUMING 999 ELECIRCSIATIC PRECIPITATORS USED FOR PARTICULhTE CONTROL AND 1099 50 PC CCNTFOI IN SULFUR EMISSION) 1199 PARTICULATES SULFUR OXIDES 1299 ROASTING 4.80-03 2.20-02 1399 SINTERING 3.60-03 1499 HORIZONTAL RETORT 1.66-04 1599 VERTICAL RETORT 1.40-03 1699 ELECTROLYTIC PROCESS 4.92-05 1799 TOTAL 1.00-0,2 2.20-02 1899 6634 199 AIR 'EMISSIONS FOR IRON AND STEEL CASTINGS CONSIST PRIMARILY OF 299 PARTICULATES, CO AND NOX (0042,7.10--1,7.13-2). ASSUMING THAT 399 MOST OF THE IRCN CASTING PRODUCTION IS BY CUPOLA AND PRODUCT- 499 ION OF STEEL CASTINGS IS DISTRIBUTED EVENLY BETWEEN ELECTRIC 599 ARC, OPEN-HEARTH AND ELECTRIC INDUCTION, THE -EMISSIONS ARE As 699 FOILOWS,(IN TONS)- IRON CASTING (ASSUMING WET CAP AND AFTER 799 BURNER)= 4.00-03 TON PART. AND 4.50-03 TON CO , STEEL CASTING- 899 ELECTRIC ARC = 1.08-04 TON PART AND 3.30-0% TON NOX, OPEN 999 HEARTH = 8.65-05 TON PART. AND 1.65-06 TON NOX, ELECTRIC 1099 INDUCTION = 8.25-07 TON PART. (ASSUMING ELECTROSTATIC ligg PRECIPITATOR). TOTAL EMISSONS ARE THE SUM OF THE EMISSIONS OF 1299 IX-31 FTN. 6635-6702 IRON CASTINGS AND STEEL CASTINGS WEIGHTED BY THEIR RESPECTIVE 1399 PC OF PRODUCTION (IRON CASTING = 89.2 AND STEEL CASTING 1 10. 8) 1599 6635 199 HYDROCARBON, SOX, ALDEHYDES AND METALLICS ARE EMITED BUT 299 ARE HIGHLY VARIABLE (0042,7.10-1,7.13-1). HYDROCARBONS EXIST 399 FROM THE COKE USED IN THE CHARGE TO CUPOLA IN IRON CASTINGS 499 AND FROM OIL COATINGS ON SCRAP USED IN BOTH PROCESSES. SOX AND 599 ALDEHYDES ARE DEPENDENT UPON THE COKE CHARGED AND METALLICS 699 FROM METAL CHARGED. 799 6636 199 MAXIMUM ALLOWABLE EFFLUENT LEVEL FOR PRIMARY ALUMINUM MANUFACTURE 299 IS 10.9 LB/TON FLUORIDE, 10.0 LB/TON SS AND 5.0 LB/TON OIL AND 399 GREASE (6630,B) . FROM (0016,E99) BCD FOR 4 PLANTS WAS 554.0 LB 499 /DAY, COD FOR 2 PLANTS WAS 23558. 0 LB/DAY FROM (0016 , E100) . 6q1 599 AVERAGE PRODUCTION PER PLANT IS EQUAL TO 1.54+05 TON/YR (0001, 699 151, 1134) . ASSUMING A 360 DAY OPERATING YEAR,PRODUCTION PER 799 PLANT = 428.0 TON PER DAY, THUS BOD = 3.24-01 LB/TON AND COD = 899 2.75+1)1.LB/TON OF PRIMARY ALUMINUM. 999 6637 1999 COD EFFLUENT IS REPORTED FOR ONE PRIMARY COPPER PRODUCER AS 1335.0 2 99 LB/DAY (0016, 100) AND SS IS REPORTED AS 10680. 0 LB (00 16, 10 1) 399 FROM (6631,BB) AVERAGE PRODUCTION IS 1.10+05 TON PER YEAR. 499 ASSUMING 360 PRODUCING DAYS PER YEAR, PRODUCTION PER PLANT 599 306.0 TON PER DAY, THUS COD = 2. 18-03 TON AND SS = 1.74-02 TON 699 PER TON PRIMARY COPPER 799 EFFLUENT FROM IRON FOUNDRIES CONSIST OF 1917.0 LB BOD FOR PLANTS 299 6638 199 (0016,99), 7135.0 LB COD FOR 3 PLANTS AND 9946.0 LB SS FOR 7 399 PLANTS. AVERAGE PRODUCTION PER PLANT IS 1.35+04 TON PER YEAR. 499 (6632,3-57) AND (0007,103). ASSUMING 260 PRODUCING DAYS PER 59 YEAR, PRODUCTION PER DAY PER PLANT = 52.0 TON. BASED UPON THIS 69 BOD = 3.69-03 TON, COD 2.29-02 TON, SS 1.37-02 TO N. ALL 79 IMPACTS ARE PER AVERAGE TON OF CASTINGS. 89 6701 199 USE RATES ARE BASED ON 1967 FUEL, PRODUCTION FIGURES 299 FROM (6701). INCLUDES PASS CARS,TRUCKS, TRUCK TRACTORS, CHASSIS, AND BUSES 399 AS NEW UNITS (ALL SIC 3711). INCLUDES MOTOR VEHICLE PARTS 499 AND ACCESSORIES AS PARTS (SIC 3714). TOTAL UNITS IN 1967 FROM 599 (6701,16). TONS OF PARTS BASED ON AVERAGE VALUE PER LB OF 699 35 CENTS FOR WHEELS,SHOCKS,MUFFLERS, AND ENGINES, FROM 799 (7004,IV-31) AND (6701,18) NOTE THAT MOST PARTS ARE SHIPPED TO AUTO MANUFACTURING PLANTS. CARE MUST BE TAKEN IN SEPARATING 899 IMPACTS. MULTIPLIER 999 FOUND BY MULTIPLYING 1967 PRODUCTICN BY 1971 SALES PASSENGER CARS/1967 SALES=8585/7437 1199 =1.15. SALES RECORDS FROM (0011) AND (0018).1967 PRODUCTION 1299 OF PASS CARS WAS 7.32E+06 UNITS (6701,16). 1967 VALUE OF PARTS AND ACCESSORIES WAS 1.1735E+10 DOLLARS J6701,18). TOTAL 1499 ESTIMATED WEIGHT OF PARTS IN 1967 IS THEN 3.36E+10 LBS, OR 1599 1.68E+07 TONS. 1699 6702 199 AIR POLLUTANTS ARE FROM (0002). ASSUME FOSSIL FUELS BURNED IN 299 GENERAL INDUSTRIAL BOILERS. ASSUME 50 PERCENT FLY-ASH CONTROL 399 10 PERCENT ASH-2 PERCENT SULFER BITUMINOUS COAL, 0.225 PERCENT 499 SULFUR DISTILLATE, 1.73 PERCENT SULFURE RESIDUAL OIL (5510)., 599 (5109) . NOT INCLUDED ARE ANY EXHAUSTED POLLUTANTS FROM 699 PAINTING, ETC., WHICH ARE PRESUMED SMALL AND NOT DIRECTLY 799 RESULTANT FROM ENERGY USE. 899 Reproduced from best available copy. IX-32 670 FTN. 6703-6704 3 199 POLLUTANTS FROM BODY &ND FINAL ASSEMBLY OPERATIONS. TAKEN LARGELY 299 FROM -B- SCHEDULE IN (6702,7), AND MAY BE MORE REPRESENTATIVE 399 OF 1972 THAN 1971. TOTALS FROM @6702,7/8) MULTIPLIED BY 1.16 499 TO INCLUDE TRUCKS. BUSES (WHICH ARE HEAVIER) . CORRECTION 599 FACTOR FROM (6703.6). OIL, GREASE ENTERED AS 699 ORGANICS. TOTAL CHROMIUM, PHOSPHATE (NOT ENTERED) ARE 799 CHROMIUM-.-2.81E-06 TONS/UNIT PHOSPHATE--2.81E-05 TON/UNIT 899 NO CCD FACTORS IN (6702). TOTAL UNCONTROLLED COD,BOD GIVEN 999 IN (6703,5). ALSO SAYS COD,BOD REMOVAL EFFICIENCIES 80 TO 1099 95 PERCENT. CO MPARING 1.61E-03 TON/UNIT BOD (6703,5) WITH 1199 1.10E-04 TON/UNIT FROM (6702,7/8) SHOWS A 93 PERCENT REMOVAL 1299 EFFICIENCY. USING THIS EFFICIENCY FOR COD YIELDS 3.53E-04 1399 TCN/UNIT. 6704 199 POLLUTANTS FROM PARTS, ACCESSORIES, TAKEN LARGELY FROM -B- 299 SCHEDULE IN (6702,7/8).THOUG(i MOST PARTS ARE MADE IN PARTS 399 'PLANTS, 'ABOUT 30 PERCENT OF GAS ENGINES, FOR INSTANCE, WERE 499 MADE IN PLANTS CLASSIFIED AS BODY OR FINAL ASSEMBLY, IN 1967 599, (6701,16/18). WE DO NOT ACCOUNT FOR POLLUTION DOE TO THOSE 699 PARTS MADE IN VEHICLE ASSEMBLY PLANTS. ONE COULD ASSUME THE 799 30 PERCENT FIGURE FOR ENGINES WAS APPLICABLE FOR ALL PARTS, 899 AND ADD 3C/70 = 43 PERCENT OF THESE WATER POLLUTANTS(FOR 999 PARTS) TO NEW VEHICLE POLLUTANTS BY RE-NORMALIZING TO A UNIT 1099 VEHICLE MULTIPLIER. WE INC06'Ei EMISSIONS FROM CASTING OPER 1199 ATIONS, ENGINE MANUFACTURE, ELECTROPLATING, FRAME MANUFACTURE 1299 ANDRARTS STAMPING. IN GENERAL, THE UNITS GIVEN IN (6702,7/8) 1399 WERE TRANSFORMED INTO POLLUTANTS PER TON PARTS PRODUCED BY 1499 ESTIMATING THE WEIGHT OF AN AVERAGE PRODUCT (FRAME, SQUARE 1599 FOOT OF STAMPED METAL) AND ESTIMATING THE NO. OF PARTS MADE 1699 IN 1971(I.E., ABOUT 8 MILLION ENGINES, MADE IN PARTS PLANTS). 1799 WHERE DATA ON THE ACTUAL NO. OF A MAJOR PART MADE WAS NOT 1899 FOUND, AN ESTIMATE OF 8 MILLION WAS USED (I.Ei, FOR EACH SET 1999 OF STAMPINGS). THE FOLLOWING ASSUMPTIONS WERE USED FOR UNITS 2099 TRANSFORMATIONS. 2199 THE AVERAGE ENGINE WEIGHS 550 LBS (7004,IV). 2299 THE AVERAGE VEHICLE HAS 550 LBS CAST IRON (7004,IV). 2399 ABOUT8.16 MILLION ENGINES WERE MADE IN 1971(6701,18). 2499 THE AVERAGE CAR HAS 3000 LBS STAMPED METALS(7004,IV-26). 2599 STAMPED FRAMES ARE .118 IN. STEEL(6705,50). 2699 STAMPED HOODS ARE .036 IN. STEEL(6706,30). 2799 AVERAGE STAMPING IS ABOUT .075 IN. 2899 AUTOMOTIVE STEEL IS AROUND 0.25 LB/CI (6708,87). 2999 EFFLUENTS REPORTED PER AUTO PART CAN BE SC@LED TO INCLUDE 3099 TRUCKS, BUSES BY MULTIPLYING BY 1.16 (6703,6). 3199 EACH FRAME WEIGHS 1000 IBS. ALL VEHICLES HAVE ONE. ABOUT 3299 8 MILLION WERE MADE IN PARTS PLANTS, 1971. IN 1971 3399 VEGA BUMPERS WERE .09 IN. STEEL (6707,55).ASSUME AVERAGE 3499 IS .1 IN. STEEL FOR PLATED PARTS. 3599 ASSUME 15 SF PLATED STEEL PER VEHICLE. ABOUT 8 MILLION 3699 SETS PLATED PARTS WERE MADE IN PARTS PLANTS, 1971. 3799 FOLLOWING WATER POLLUTANTS ENTERED AS OTHER IN THE TABLE. 3899 UNITS ABE TONS PCLLUTANT PER TON-1971 TOTAL PARTS PRODUCTION. 3999 COPPER 1.62E-06 CHROMIUM 2.95E-06 PHENOLS 5.23E-06 4099 NICKEL 8.32E-07 IRON 3.92E-C6 PHOSCHATES 2.64E-05 4199 CYANIDE 2.10E-08 ZINC 5.89E-Ob 4299 OILS. GREASE ENTERED AS ORGANICS. 4399 IX-33 NOTE- ELECTRICAL ENERGY C0NSUMPTION. GIVEN IN. BTU'S IS DERIVED BY TAKING THE BTU EQUIVALENT OF KWH (3413) AND MULTIPLYING BY 3 TO REFLECT THE EFFICIENCY OF POWER PLANT ELECTRICITY PRODUCTION. IX-34 X. TRANSPORTATION END USE A. introduction Environmental impacts and energ y efficiency within the trans- portation sector are shown in Table 30. As with most other end uses, air emissions are the most readily identifiable impact that are directly related to energy consumption. Transportation has been broken into four major categories; freight, passenger, feed- stock and military and government. Energy use rate and environ- mental impacts associated with each specific use under these four categorie-s are generally appropriate for the 1970 to 1973 time period. For the automobile, the emission controls are at the level for the average automobile in use during 1973. Where possible, the measure of use is ton-mile or passenger-mile. For some uses, however, the only use measure available is gallons of fuel. As an exercise in data validity and usefulness, some of the information in Table 30 has been carried a step further in order to arrive at total Btu's consumed and total air pollutants emitted. Multiplying Column 29 x Column 28 yields the total Btu con- sumed for specific use.. Summing these products yields the Btu's consumed for each category: Category Btu's of Total Freight 48.05x 1014 28.0 Passenger 115.23x1014 67.1 14 Feedstock 1.53xlO 0.9 14 Military and 7.OlxlO 4.1 Government Total 171.8xlo 14 Btu The year associated with the total of 171.8xlO 14 Btu's is somewhere between 1970 and 1971. Bureau of Mines data,, which includes mili- tary fuel, gives a total of 170.8xlO14 Btu for 1971 and 164.9x1014 Btu for 1970. The agreement between Bureau of Mines data and Table 30 aggregation is good considering that each involves a different approach to arriving at total energy use. 74@ A similar technique has been used on transportation air im- pact data to determine total tons of air pollutants in the transportation sector. (Column 19 is multiplied by Column 29.) X-1 Tons of Air Category Pollutants % of Total 5 Freight 219.0x10 20.6 5 Passenger 841.0X10 78.9 Feedstock 0 0 Military and 5 Government 5.4xlO 0.5 Total 1.07xlO8Tons This total value.can be compared with the aggregate air emissions for U.S -transportation derived from the "Nationwide Inventory of Air Pollutant Emissions, 1968" prepared by USDHEW in August 1970. Summing HEW data for CO, particulates, SOx, HC and NOx yields 0.89x108 tons (for 1.968). X-2 B. Impact Data Table and Footnotes, X-3 A 1 22 25 1. 27 IN R, so WATER POLIUT-Ts (TONSIME-RE. EX .1 R-I.T.- 1"TON-EANUNE) SOL.DS L.N I FURL WEASUR. .1 0-1-10 1 TOTALI I --- .T"S OALEL TU" INT-ANII n7@ I , 1 1. E.O LsE A.- As. 1, AQ, IOT- TO-TALMS) R-5 ...,Cs AT. so. CO -YM TOTAL. A 7 .0 IR 13 ..A 2 R4 17 31 -iN 40 AN 43 44 41 AN -;7, 47 OTE: ELECTRICAL ERERST CONSURPTIGM IN RTU'S IS Q--VED a, TA.ING T r RIO D LTIR Y 5, EFTICIENCY OF H EQUIVALENT .1 q (3413) AN AU L M TO TABLE 30. ENVIRONMENTAL EMPACTS A' 'E'LEIT TRE 'o .. L UEL EQUIVALENT Of EjECTNIC'j TRANSPORTATION ENERG-1 Preceding page blank X-5 FTN. 7001-7005 FOOTNOTES FOR TABLE 30 7001 199 DOMESTIC TRAFFIC IS COMPOSED LARGELY OF BARGES PUSHED BY DIESEL 299 POWERED TOWBOATS. ENERGY PER TON MILE IS AN.AVERAGE VALUE 399 BASED ON 5.29E11 TON-MILES CONSUMING 0.20E15 BTU FOR THE 499 YEAR 1969 (7001). 599 7002 199 THE PORTION OF TON-MILES CONSIDERED IS PROPORTIONAL TO ACTUAL 299 BUNKER REPORTS AND REFLECTS ONLY THE FUEL PURCHASED IN THE 399 U.S. BY BOTH U.S. AND FOREIGN SHIPS CARRYING U.S. FOREIGN 499 TRADE GOODS. DATA ON FOREIGN TRADE SHIPPING FROM (7001). 599 FOR 1972, RESIDUAL FUEL REQUIRED FOR FOREIGN TRADE IS .699 ESTIMATED AT 0.42E15 BTU EQUIVALENT. 799 7003 199 RECREATION BOAT DATA FROM USCG (7001), (7002). RECREATION BOATS 299 ARE ASSUMED TO AVERAGE.30 HP, 2 CYCLE WITH 3.6 PM/VEHICLE 399 MILE. TOTAL FUEL USE IS CONSIDERABLY LARGER THAN REPORTED 499 FIGURES FROM TAX REBATE RECORDS AND MARINE USE. EST. 1969 599 IONSIMPTION 11 1,1119 GAL FIR 2 3,OE9 PM* 699 7004 199 DATA ARE DERIVED USING 2.2 PASSENGER MILES/VEHICLE MILE FROM 299 REFERENCE 7003 (2.2 HOLDS FOR BOTH URBAN AND RURAL). THE 399 NATIONWIDE AVERAGE VEHICLE MILE/GALLON OF GASOLINE FOR 499 1970 IS 13.57 (7020,52). TOTAL VEHICLE MILEAGE IS DIS- 599 TRIBUTED 54.4PC URBAN/45.6PC.RURAL FOR 1970 (7020,52). 699 URBAN FUEL ECONOMY IS NOT THE SAME AS FEDERAL DRIVING 799 CYCLE FUEL ECONOMY. BASED ON AVAILABLE DATA (7004, 899 IV-18) AN ESTIMATE OF URBAN FUEL-ECONOMY IS 12 MPG. NO 999 ESTIMATES EXIST FOR AVERAGE RURAL ECONOMY BUT THE NUMBER 1099 CAN BE CALCULATED USING A TANK MILEAGE APPROACH IN CON- 1199 JUNCTION WITH AN OVERALL ECONOMY OF 13.57 MPG AND THE URBAN 1299 VALUE OF 12.0 MPG. THIS CALCULATION YIELDS 16.1 MPG FOR 1399 RURAL MILEAGE. OVERALL AUTOMOBILE BTU/PASS-MILE IS 4190 1499 USING 124,952 BTU/GAL (0005,38). THIS OVERALL NUMBER IS 1599 MORE ACCURATE THAN THE RESULTING URBAN/RURAL BREAKDOWN. 1699 MULTIPLIERS ARE DERIVED FROM 1,959,857EO6 TOTAL NATIONAL 1799 PM (0021,20) USING A .544/.456 URBAN/RURAL SPLIT. 1899 7005. 199 BTU PER PASS-MILE DERIVED FROM 1969 DATA USING (7006). TRANSIT, 299 INTERCITY, AND SCHOOL BUS DATA HAVE BEEN COMBINED TO FIT 399 CATEGORIES OF URBAN, RURAL, GASOLINE AND DISTILLATE. 499 PASSENGER MILE MULTIPLIER VALUES FOR THE FOUR CATEGORIES 599 IN 1971 ARE DERIVED USING RATIOS OF PASSENGER MILES TO. 699 VEHICLE-MILES AVAILABLE FROM 1969 DATA (7006) AND MUL- 799 jIPLYING BY 1971 VEHICLE-MILE D I ATA (7007). BTU/PM FOR 899 GASOLINE POWERED BUSES ARE LOW BECAUSE OF HIGHLY LOADED 999 SCHOOL BUSES. PASS-MILE/VEHICLE-MILE ARE AS FOLLOWS: 1099 URBAN-GASOLINE 19.0 1199 URBAN-DIESEL 15.1 1299 RVRAL-GASOLINE 24.3 1399 RURAL-DIESEL 21.0 1499 x-7 Preceding page blank FTN. 7006-7012 7006 199 AN URBAN/RURAL BREAKDOW.N IS NOT KNOWN FOR TRUCKS. GAL/MILE 299 DATA 'FROM (7006) HAVE BEEN COMBINED INTO THE TWO CATEGORIES 399 OF GASOLINE AND DISTILLATE (DIESEL). IN 1969, TON-MILES 499 FOR GASOLINE POWERED TRUCKS WAS 2.64E11 FOR DIESEL IT 599 POWERED TRUCKS=1.46, FOR DIESEL EQUALS 10.6. THE MULTIPLIER 799 WAS 2.81Ell. TON-MILES PER VEHICLE-MILE FOR GASOLINE 699 OF TOTAL TON MILES FOR 1971 OBTAINED FROM (7007) DISAG- 899 GREGATED INTO GASOLINE AND DIESEL. 999 7007 199 -ASSUMING THAT URBAN RAIL TRAFFIC IS ALL ELECTRIC. A VALUE OF 299 0.33 PURCHASED KWH/PASS-MILE IS REPRESENTATIVE OF THE NYC 399 SUBWAY 'SYSTEM (7008). THE PASSENGER-MILES OF THE NYC SYSTEM 499 COMPRISE THE MAJORITY OF TOTAL RAPID TRANSIT PASS-MILES 599 TOTAL-PASS-MILES OF 7.75E9 FOR RAPID TRANSIT IS A DERIVED 699 NUMBER FOR 1970 USING 2.56IE09 TOTAL KWH CONSUMED (7011,20) 799 DIVIDED BY 0.33 KWH/PASS-MILE. KWH CONSUMPTION FOR SUBWAYS 899 INCLUDES LIGHTING AND CONTROLS. CONVERSION OF PURCHASED KWH 999 TO BTU IS AT INPUT TO POWER PLANT USING 10239 BTU/KWH. 1099 7008 199 USING HEAT.VALUE FROM (0005,38). THE TOTAL GALLONS OF LUBRICANTS 299 AND AVIATION LUBRICANTS REPORTED FOR THE YEAR 1969 (7010). 499 TO TRANSPORTATION HAS BEEN TAKENS THE SUM OF AUTOMOTIVE 399 7009 199 (7008) REPORTS DATA FOR 3 COMMUTER RR'S WITH THE LIRR (HEAVY 299 AIR -CONDIT.) AT 0.281 KWH/PM FOR 1.03E9 PASS-MILES. THE AVG. 399 COMMUTER 'AND INTERCITY OPERATION IS ESTIMATED TO BE ABOUT 499 0.23 KWH/PM. TOTAL PM ARE DERIVED FROM A KWH VALUE OF 1.39 599 E9 IN 1970 (0021,67) ABOVE PURCHASED KWH'S CONVERTED TO 699 BTU USING 10239 BTU/KWH. 799 7010 199 THE DIESEL INTERCITY COACH TRAIN IS ESTIMATED TO HAVE AN ENERGY 299 USE OF 47.6 PM/GAL (0027,11). PASSENGER-MILES ATTRIBUTABLE 399 TO DIESEL USE OBTAINED BY SUBTRACTING ELECT. PM OF 6.07E9 499 FROM TOTAL PM OF 12.2E9 OBTAINED FROM (0009,545). (ALL DATA 599 FOR 1969 TO OBTAIN CONSISTENCY.) 699 7011 199 TOTAL DOMESTIC PM FOR 1970 (7009) ARE 109,665E6, SUMMING CERTI- 299 399 FICATED ALL SERVICES AND SUPPLEMENTAL. TOTAL FUEL FOR DO- 499 MESTIC OPERATIONS IN 1970 WAS 7.65E9 EXCLUDING AMNT FOR 599 ALL CARGO CARRIERS) GALS (0010,428). GASOLINE USE IS NEG- 699 LIGIBLE. (0012) PROVIDES A BREAKDOWN OF JET FUEL CONSUMP- 799 TION IN 1970 BY NAPTHA AND KEROSINE TYPE. THE AVERAGE 799 899 HEATING VALUE FOR JET FUEL ACCORDING TO AMOUNT USED,, IS 133,200 BTU/GAL FUEL USE FOR CIVIL AVIATION WAS 98.6P JET FUEL IN 1968. IT IS BETTER THAN 99P JET FUEL IN 1972. 7012 199 299 INTERNATIONAL PASSENGER-MILES ARE TOTAL REPORTED (0021,16) DIVIDED BY TWO TO REFLECT CONSUMPTION OF FUEL LOADED IN 399 ,THE U.S. BTU/PM IS DERIVED FROM TOTAL FUEL CONSUMED IN 499 INTERNATIONAL OPERATIONS EXCLUDING ALL-CARGO CARRIERS 599 (0010,428)2.039E09 GAL. BTU/GAL ARE SAME AS IN FOOTNOTE 7011. Reproduced from best available copy. X-8 FTN. 7013-7021 7013 199 REVENUE TON-MILES FOR 1970 ARE FOR CLASS I RAILROADS. BTU/TON- 299 MILE DERIVED FROM FUEL CONSUMPTION AND TON-MILE DATA REPORT- 399 ED IN (0021,32 and 67). 499 7014 199 FROM (0027,9). DOMESTIC TON MILE MULTIPLIER ALSO FROM (0027,9) 299 AND (0011,566). 399 7015 199 INTERNATIONAL TON-MILES ARE TOTAL REPORTED (0021,16) DIVIDED 299 BY TWO TO REFLECT CONSUMPTION OF FUEL IN U.S. BTU/TON-MILE 399 ARE ASSUMED TO BE THE SAME AS FOR DOMESTIC TRANSPORT. 499 7016 199 DERIVED FROM DATA REPORTED IN (0002,3-2) WHICH REFLECT THE 299 WHOLE 1973 POPULATION OF GASOLINE-ENGINE-POWERED VEHICLES. 399 AUTOMOBILE EMISSIONS PER PASS-MILE BASED ON 2.2 PM/VEHICLE- 499 MILE. (SEE FOOTNOTE 7004.) EVAPORATION AND CRANKCASE LOSSES 599 FROM OLDER CARS APPORTIONED 50/50 FOR URBAN/RURAL. NOX 699 ASSUMED TO BE EQUAL FOR URBAN AND RURAL. PARTICULATES, SOX, 799 ALDEHYDES, ETC. CALCULATED BY WEIGHTING URBAN/RURAL EMISSION 899 ACCORDING TO GAL/MlLE (FROM FOOTNOTE 7004). ON THIS BASIS 999 URBAN LB/PASS-MILE 1.9 TIMES RURAL LB/PASS-MILE. 1099 7017 199 THE MEASURE FOR GENERAL AVAIATION IS HOURS OF OPERATING TIME. 299 THE BREAKDOWN OF HOURS BY TYPE OF AIRCRAFT IS-SINGLE ENGINE 399 PISTON 76.4P, MULTI-ENGINE PISTON 16.1P, TURBINE FIXED WING 499 4.3P, TURBINE AND PISTON ROTOR CRAFT 3.1P (7005). JET FUEL 599 USE WAS 1.7E8 GAL, GASOLINE USE 5..29E8 GAL (7005). JET FUEL 699 CONVERSION FROM FOOTNOTE 7011. GASOLINE CONVERTED AT 124,952 799 BTU/GAL. 899 7018 199 DERIVED FROM (0002,3-2) WHERE DATA ARE FOR WHOLE 1973 POPULATION 299 OF GASOLINE-ENGINE-POWERED VEHICLES. TRUCK EMISSIONS PER 399 TON-MILE CALC. USING 1.46 TON-MILES/VEHICLE-MILE. CO BASED 499 ON 64.5 GM/MILE BY COMBINING URBAN/RURAL DATA FROM (0002). 599 HC BASED ON 7.38 GM/MILE. 699 7019 199 DIESEL DATA FROM (0002,3-7) USING CONVERSION FACTORS OF 5.1 299 MILES PER GAL (7006,11) AND 10.6 TON-MILES/VtCHICLE-MILE 399 (FOOTNOTE 7006)., 499 7020 199 DIESEL LOCOMOTIVE DATA REPORTED AS LB/1000 GAL. (0002,3-7). CON- 299 VERSION TO TONS/TON-MILE USING 0.323 LOCOMOTIVE MILES/GAL. 399 AND 598 TON-MILES/LOCOMOTIVE-MILE (CALCULATED FROM (0021) 499 NATIONAL STATISTICS). 599 7021 199 AIR EMISSIONS ARE FOR LANDING-TAKEOFF (LTO) CYCLE WHICH INCLUDES 299 TAXI AND IDLE. IT IS ASSUMED THAT FREIGHTERS ARE PREDOMIN- 399 ANTLY LONG RANGE TURBOJETS AND TURBOFANS. BASIC DATA ARE IN 499 LBS EMISSION PER LTO-ENGINE. LTO CYCLE STOPS AT 3500 FT 599 ALTITUDE. AVERAGE FREIGHTER ESTIMATEn TO USE 200 GALS JET 699 FUEL PER LTO-ENGINE. (00@2,3-9 AND 3-10). CONVERSION TO. 799 TONS/TON-MILE ASSUMING LTO'S CONSUME IOP OF TOTAL GAL. USED 899 (7021,11). TOTAL GAL/TON-MILE FROM FOOTNOTE 7014. 9�0 X_ 91 FTN. 7022-7029 7022 199 BASIC EMISSION DATA FROM (0002,302). URBAN PASS-MILES/VEH-MILE= 299 19.0, RURAL PM/VM=24.3 (SEE FOOTNOTE 7005). ON A VEHICLE-MILE 399 DISTRIBUTION OF PART., SOX, AND ALDY. ON THE BASIS OF GAL/ 499 MILE, USING URBAN EQUALS 1.6 RURAL GAL/MILE (7006). 599 7023 199 AVERAGE EMISSION DATA FROM (0002,3-7). CONVERSION TO LB/PAS- 299 MIL MADE BY DETERMINING URBAN/RURAL EMISSIONS ON BASIS OF 399 URBAN GAL/MILE = 1.55 RURAL GAL/MILE. URBAN PASS-MILE/VEH- 477 MILE = 15.1, RURAL - 21.0. (SEE FOOTNOTE 7005.) 599 7024 199 BASIC EMISSION DATA IN GM/PASS-MILE REPORTED IN (7008,4). 299 ASSUMING 0.331 MILES/GAL AND 175 PASSENGERS/LOCOMOTIVE- 399 MILE. 499 7025 199 BASED ON 1.1 PM/VM AND 75 MPG AVG. (7006,11). MULTIPLIER OF 299 1.O2E11 PLM FROM (7006,11). 399 7026 199 LAND USE IS NOT THE DIRECT RESULT OF ENERGY CONSUMPTION. LAND 299 USE ATTRIBUTABLE TO ROAD VEHICLES IS GIVEN FOR REFERENCE 399 ONLY. IT IS BASED ON LAND AREA FOR 48 STATES OF 1.90E9 499 ACRES (0009,5). TOTAL ROAD RIGHT OF WAY LAND USE IS 1.1P 599 (REF.7013) OR 21.OE6 ACRES. IF DISTRIBUTION IS TREATED ON 699 BASIS THAT CAR = TRUCK = BUS, THEN ACRES/VEHICLE-MILE = 799 1.8E-5 (USING 1970 TOTAL VEHICLE MILES = 1.13E12 FROM REF. 899 0021). 999 VEHICLE ACRES/PASS-MILE ACRES/TON/MILE 1099 1199 URBAN BUS-GASOLINE 9.32E-7 1299 RURAL BUS-DIESEL 8.45E-7 1399 URBAN AUTO-GASOLINE 8.05E-6 1499 RURAL AUTO-DIESEL 8.05-6 1599 TRUCK-GASOLINE 1.21E-5 1699 TRUCK-DIESEL 1.67E-6 1799 1899 PASS-MILE & TON MILES PER VEHICLE MILE FROM FOOTNOTES 7004, 1999 7005, 7006. 2099 7027 199 EMISSIONS DATA IN LBS/1000 LBS FUEL FROM REF. (7014, 84) BASED 299 LARGELY ON TESTS OF A GM-6-71 DIESEL ENGINE USING 0.25P 399 SULFER FUEL. CONVERSION USING 7 LBS/GAL AND 139E3 BTU/GAL. 499 7028 199 EMISSIOIN DATA IN LBS/1000 LBS FUEL FOR VESSELS OVER 1000 TONS 299 USING BUNKER C FROM REF. (7014,91). THESE ARE IN TURN DERIVED 399 FROM A 1964 BAY AREA APCD STUDY. CONVERSION USING 7 LBS/GAL 499 AND 15OE3 BTU/GAL. 599 7029 199 CONSUMPTION DATA ARE PURCHASES FOR CONTINENTAL U.S. USE ACCORD- 299 ING TO RECORDS MAINTAINED BY THE DOD DEFENSE FUEL SUPPLY 399 CENTER (7015). MULTIPLIER CORRESPONDS TO FISCAL YEAR 1972. 499 X-10 FTN. 7030-7035 7030 199 THE CURRENT POPULATION OF MOTORCYCLES IS ABOUT 62P FOUR CYCLE 299 AND 38P TWO CYCLE (7016 '21). EMISSIONS ASSUME THIS POPULATION399 SPLIT AND ARE BASED ON FACTORS FROM (7016 25) . SULFUR CON- 499 TENT IS .043P W FOR 2-STROKE AND .022P W.FOR 4-STROKE. 599 CONVERSION FROM GMS/MILE TO TONS/PASS-MILE USES 1.1 PASS- 699 MILE/VEH-MILE FROM FOOTNOTE 7025. - 799 7031 199 AIR EMISSIONS ARE FOR LANDING-TAKEOFF (LTO) CYCLE WHICH 299 INCLUDES TAXI AND IDLE. LTO CYCLE STOPS AT 3500 FT ALTITUDE. 399 THE AVERAGE DOMESTIC PASSENGER AIRCRAFT IS ASSUMED TO BE 409. A MEDIUM RANGE TURBOFAN ACCORDING TO THE CLASSIFICATION OF 599 DATA IN (0002,3-9). THE AVERAGE PASSENGER PLANE IS ASSUMED 699 TO USE 170 GALS OF JET FUEL PER ENGINE-LTO CYCLE. (0002,3- 799 10). BASIC EMISSION LBS PER ENGINE-LTO ARE DIVIDED BY GAL 899 PER ENGINE-LTO CYCLE TO GE iT L85 EMISSION PER GAL USED IN 999 LTO CYCLE. CONVERSION TO EMISSION PER PASS-MILE ASSUMES. 1099 LTO USES IOP OF TOTAL FUEL (7021,11) WITH TOTAL GALS PER 1199 PASS-MILE FROM FOOTNOTE 7011. 1299 7032 199 HC EMISSION CALCULATED AS PER FOOTNOTE 7031 EXCEPT THAT BASIC 299 EMISSION FACTOR OF 17 LBS/ENGINE-LTO IS SAME.AS FOR LONG 399 RANGE TURBOFAN. 499 7033 199 .FOR INTERNATIONAL OPERATIONS WITH ONE TERMINUS OUTSIDE THE U.S., 299 THE ACTUAL EMISSIONS IN TONS DURING THE LTO WILL BE HALVED. 399 POLLUTANTS ARE SAME AS THE ENTRIES FOR AIRPLANE DOMESTIC 499 .FREIGHT. HALVING THE EMISSIONS IS ACCOMPLISHED THROUGH THE 599 TON-MILE MULTIPLIER (SEE FOOTNOTE 7015). 699 7034 199 FOR INTERNATIONAL OPERATIONS, THE PASSENGER AIRCRAFT IS TAKEN 299 TO BE AN AVERAGE BETWEEN A JUMBO AND LONG-RANGE TURBOFAN. 399 EMISSIONS ARE CALCULATED AS OUTLINED IN FOOTNOTE 7031. 499 REDUCTION IN EMISSIONS DUE TO ONLY ONE LTO BEING IN U.S.- 599 IS ACCOUNTED FOR IN THE.PM MULTIPLIER (SEE FOOTNOTE 7012). 699 THE AVERAGE INTERNATIONAL AIRCRAFT IS ASSUMED TO USE 250 799 GALS JET FUEL PER ENGINE-LTO CYCLE (0002,3-10). CONVER- 899 SION USES BTU/PASS-MILE FROM FOOTNOTE 7012. 999 7035 199 EMISSIONS ARE BASED ON SRI DATA (7017) FOR FOUR TWO-STROKE 299 WATER-COOLED OUTBOARD MOTORS WHOSE AVERAGE RATED HORSEPOWER 399 IS 25 AND AVERAGE LOAD FACTOR IS 0.37. 499 OUTBOARDS ARE ESTIMATED TO CONSUME ABOUT 90P OF THE l.lE9 599 GALS OF FUEL USED FOR RECREATIONAL BOATS (SEE FOOTNOTE 7003).699 EMISSIONS GIVEN ARE FOR A POPULATION CONSISTING WHOLLY OF 799 OUTBOARDS AND ARE CALCULATED USING GRAM/GALLON EMISSION 899 FACTORS (7017,52) MULTIPLIED BY .046 GAL/PASS-MILEFROM 999 FOOTNOTE 7003. AIR EMISSIONS DO NOT INCLUDE EXHAUST PRODUCTS1099 ORIGINALLY RELEASED INTO THE WATER. SOX BASED ON I FUEL SULFUR1199 WEIGHT CONTENT OF X-11 FTN 7036-7041 7036 199 WATER EMISSIONS M EASU'RED ARE HC, CO, NOX, AND SOX FOR FOUR 299 OUTBOARDS AND REPORTED IN (7017,52). THE' WATER EMISSIONS 399 REPORTED ARE GASES WHICH MAY STAY" IN THE WATER OR RISE. TO 499 THE SURFACE AND BECOME AN AIR CONTAMINANT. THE TOTAL VALUE 599 REPORTED OF 1.92E-5 TONS/PASS-MILE BREAKS DOWN AS FOLLOWS: 699 799 TON/ PM 899 HC 1.52E-5 999 CID 3.90E-6 1099 NOX 2.78E-8 1199 SOX 8.15E-9 1299 7037 1991 A STUDY CONDUCTED FOR THE STATE OF MASS. (7018,3) IN 1969, AND. 299 CONFIRMED BY API I.S ASSUMED REPRESENTATIVE OF THE NATIONAL 399 PICTURE. THE STUDY INDICATED 0.8P OF USE AUTOMTIVE OILS 499 TO BE DUMPED IN SEWERS. ABOUT 23P Of DUMPED ON THE GROUND 599 AND 18P HAD AN. UNKNOWN FATE. THE REMAINDER WAS REPROCESSED 699 TO FUEL OIL (36.6PC), TAKEN OUT OF STATE (8.1PC) OR CON- 799 VERTED TO FARM USE (2.4PC). PART OF THE UNKNOWN FRACTION AND 899 PART OF THE GROUND DUMP UNDOUBTEDLY BECOME WATER POLLU- 999 TANTS. IT IS CONSERVATIVELY ASSUMED THAT 2P Of ALL LUBRI- 1099 CANTS USED IN TRANSPORTATION BECOME A POLLUTANT. CONVER- 1199 SION IS AT 7 LBS/GAL. 1299 7038 199 AIR EMISSIONS ARE FOR THE LTO CYCLE (SEE ALSO FOOTNOTE 7031.). 299 IT IS ESTIMATED THAT 10P OF THE TOTAL FUEL IS CONSUMED 399qi DURING THE LTO (7021,11). EMISSIONS PER GAL OF GASOLINE 499 USED IN THE LTO ARE CALC. USING EMISSION FACTORS IN LBS/ 599 ENGINE-LTO (0002,3-9) DIVIDED BY GALS/ENGINE USED IN THE LTO 699 (0002,3-10). CONVERSION OF EMISSIONS TO LBS/HR ASSUMES THE 799 LTO USES 10P OF TOTAL FUEL CONSUMED. 899 7039 199 EMISSIONS ARE FOR THE LTO CYCLE ASSUMING THAT 10P OF TOTAL FUEL 299 IS CONSUME DURING THE LTO (7021,11). DATA OBTAINED FROM 399 EPA/ANN ARBOR AS REPORTED IN (7019). FUEL CONSUMPTION FOR 499 THE BUSINESS AIRCRAFT DURING THE LTO IS 175 LBS/ENGINE. 599 7040 199 SOX EMISSION IS FOR THE LTO AND IS DETERMINED, FROM EPA DATA 299 (0002,3-9,3-10) FOR TURBINE ENGINES GIVING .01 LBS SOX PER 399 GAL CONSUMED IN THE LTO. CONVERSION TO LBS/HR USING THE 499 BTU/MEASURE VALUE OF 1.51E7, 133,200 BTU/GAL AND LTD FUEL 599 USE EQUAL TO 1/10 OF TOTAL FUEL USE (7021,11). 698 7041 199 PISTON AIRCRAFT EMISSIONS DETERMINED IN SAME MANNER AS FOR CIVIL 299 AIRCRAFT (FOOTNOTE 7031) AND GENERAL AVIATION (FOOTNOTE 399 7038). BASIC EPA DATA IN LBS PER LTC-ENGINE FROM (0002,3-9) 499 AND-(7021,11). THE AVERAGE MILITARY PISTON AIRCRAFT IS RE- 59 PRESENTED BY THE TRANSPORT DATA OF 7HE REFERENCE. GALS PER 698 ENGINE-LTO TAKEN AS 45. (0002-93-10). 799 Reproduced from best availale copy. X-12 FTN. 7042-7044 7042 199 MILITARY TURBINE AIRCRAFT EMISSIONS ARE CHARACTERIZED BY USING 299 THE AVERAGE TURBOJET AIRCRAFT DATA IN (0002,3-9). MILITARY 399 CRAFT RANGE FROM SINGLE ENGINE TO EIGHT ENGINE B-52'S. 499 GALLONS CONSUMED PER ENGINE-LTD -TAKEN AS ABOUT 220 (0002, 599 3-10) AND (7021,11). 699' 7043 199 EMISSIONS FOR MILITARY AND GOVERNMENT GROUND VEHICLES ARE 299 ESTIMATED BY USING EPA DATA FOR THE 1973 POPULATION OF 399 GASOLINE POWERED MOTOR VEHICLES (0002,3-2). CO EMISSION IS 499 AVERAGE OF URBAN AND RURAL.HC EMISSION IS AVERAGE OF URBAN 599 AND RURAL PLUS EVAPORATIVE AND CRANKCASE LOSSES. CONVERSION @699 FROM GRAMS/MILE USING AN AVERAGE OF 12.5 MI/GAL. 799 .7044 199 SOLID WASTE IS NOT ATTRIBUTABLE TO TRANSPORTATION ENERGY CON- 299 SUMPTION EXCEPT FOR THE SECONDARY IMPACTS OF DISCARDED 399 PROPULSION SYSTEMS. THE SOLID WASTE CAUSED BY DISCARDING 499 THE COMPLETE VEHICLE, SHIP ETC. WOULD REPRESENT AN EVEN 599 HIGHER ORDER IMPACT. INFORMATION EXISTS FOR CALCULATING 699 SECONDARY IMPACTS IF DESIRED. 799 X-13 XI. REFERENCES R produ@ (rom REF. 0001-0022 6 st avalla le CoDy. 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GAGE, SULFUR 299 OXIDE CONTROL TECHNOLOGY VISITS IN JAPAN-AUGUST 1972, U.S. 399 GOVERNMENT INTERAGENCY REPORT, MUSCLE SHOALS, ALABAMA, 499 OCT03ER 3.0, 1972. 599 1925 199 FINAL REPORT ON PROJECTED UTILIZATION OF STACK GAS CLEANING SYS- 299 TEMS BY STEAM ELECTRIC PLANTS, SULFUR OXIDE CONTROL TECHNOLOGY 399 ASSESSMENT PANEL (SOCTAP), WASHINGTON, DC. 499 1926 l99 COUNCIL ON ENVIRONMENTAL QUALITY, ENERGY AND THE ENVIRONMENT- 299 ELECTRIC POWER, U.S. GOVERNMENT PRINTING OFFICE, AUGUST 1973. 399 XI-12 REFERENCES FOR OIL SUPPLY REF. 2000-2017 2000 198 WEAVER,L.K., ET.AL., IMPACT OF PETROLEUM DEVELOPMENT IN THE GULF. 298 OF MEXICO, U.S. BUREAU OF MINES, INFORMATION CIRCULAR 8408, 398 1969 498 2001 198 CRUDE OIL AND REFINED PRODUCTS PIPELINE MILEAGE IN THE U.S.-JAN 298 1971, MINERAL INDUSTRY SURVEY, U.S. BUREAU MINES, DEC.3,1971 398 2002 198 A PRIMER OF PIPELINE CONSTRUCTION, PETROLEUM EXTENSION SERVICE AND 298 PIPELINE CONTRACTORS ASSOCIATION, AUSTIN, TEXAS, 1966 3�8 2003 198 ENVIRONMENTAL CONSERVATION-THE OIL AND GAS INDUSTRIES-VOLUME TWO, 298 NATIONAL PETROLEUM COUNCIL, FEB.1972 398 2004 198 NELSON,N.L., GUIDE TO REFINERY OPERATING COSTS, PETROLEUM PUB- 298 LISHING CO., TULSA, OKLAHOMA, JUNE 1970. 398 2005 198 1HYDROCARBON PROCESSING, VOLUME 49, NO.9, SEPT 1970, GULF PUBLISH- 298 ING CC., HCUSTON, TEXAS. 398 2006 198 HYDROCARBON PROCESSING, VOLUME,.51, NO.9. 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BRADY, TREATMENT OF 298 PEFINERY WASTEWATERS FOR REUSE, NATIONAL C01-11 FE BENCE ON COM- 398 PLETE WATER REUSE, WASHINGTON,D.C., APRIL 1973 498 2012 198 IL AND GAS JOURNAL, VOLUME 70, NO.49, DECEMBER 4,1972, PETROLEUM 298 PUBLISHING CO., TULSA,OKLAHOMA 398 2013 198 PETROLEUM REFINING GUIDELINgS AND TECHNICAL DOC!Ur@@NTATION, OFFICE 298 OF PERMIT PROGRAMS, EPA WASHINGTON,D.C., MAR,.:H 7,1973 398 2014 198 ERRITT,F.S., EDITOR, STANDARD HANDBOOK FOR CIVIL ENGINEERS, 298 MCGRAW-HILL BOOK CO., NEW YORK 1968 398 2015 198 C.C. TFANSFOPT STATISTICS IN THE UNITED STATES, FOR THE YEAR 298 ENDED DECEMBER, 1971, PART 6, PIPELINES, BURF,%U OF ACCOUNTS, 398 WASHINGTON,D.C. 498 2016 198 IYDRCCARBON PROCESSING, VOLUME 52, NO.5, MAY 1973. GULF 'PUBLISHING 298 CC., HOUSTON, TEXAS 398 2017 198 IL AND GAS JOURNAL, VOLUME 69, NO.52, DECEMBER 2-1?,1971, PETROLEUM 298 PUBLISHING CO., TULSA, OKLAHOMA 398 XI-13 Reproduced from best available copy. REF. 2018-2034 2018 198 OIL AND GAS JOURNAL, VOLUM E 70 , NO. 4 J A NU ARY 24, 1972, PETROLEUM PUBLISHING CO., TULSA, OKLAHOMA 398 2019 198 FERRERO, E.P. AND DOROTHY T. NICHOLS, ANALYSES OF 169 CRUDE OILS 298 FROM 122 FOREIGN OILFIELDS, BU.MINES INF CIRC 8542, USDI, 398 BARTLESVILLE ENERGY RESEARCH CENTER, BARTLESVILLE, OKLAHOMA, 498 1972 598 2020 198 IMPORT SUPPLEMENT TO OIL AVAILABILITY BY SULFUR LEVEL,USDI, BU 298 MINES, JUNE 1972. 398 2021 198 OIL AND GAS JOURNAL,VOLUME 71, NO.13, MARCH 26,1973, PETROLEUM 298 PUBLISHING CO., TULSA,OKLAHOMA 398 2022 198 HYDROCARBON PROCESSING, VOLUME 51, NO.4, APRIL 1972, GULF 298. PUBLISHING CO., HOUSTON, TEXAS 398 2023 198 HYDPOCARBON"PROCESSING,VOLUME 51,NO.3, MARCH 1972, GULF 298 PUBLISHING CO., HOUSTON,TEXAS 398 2024 198 BURF,RICHARD (EPA,RESEARCH TRIANGLE PARK,N.CAROLINA),PERSONAL 298 CCMMUNICAT ION, JULY 1973. 398 2025 1981 BACKGROUND INFORMATION FOR PROPOSED NEW SOURCE PERFORMANCE 2981 SIANDARDS,TECHNICAL REPORT NO.8-PETROLEUM REFINERIES,BURNING 398 OF GASEOUS FUELS, ENVIRONMENTAL PROTECTION AGENCY,RESEARCH 498 TRIANGLE PARK,N. CAROIINA,JAN. 1973. 596 2026 198 BOYS,PAUL (EPA,RESEARCH TRIANGLE PARK,N.CAROLINA),PERSONAL 298 COMMUNICATION,JULY 1973. 3981 2027 198 CROSS, FRANK L.,AND J. RONALD LAWSON, A NEW PETROLEUM REFINERY-THE 298 ENVIR0NMENTAL IMPACT, 74TH NATIONAL MEETING AMERICAN INSTITUTE 398 OF CHEMICAL ENGINEERS, NEW ORLEANS, LOUISIANA, MARCH 1973. 498 2028 198 WASHINGTCN POST, THURSDAY, APRIL 19,1973. 298 2029 198 BACKGROUND INFORMATION NEW SOURCE PERFORMANCE 298 FOP PROPOSED STANDARDS, T ECHNICA L REPORT NO.7-PETROLEUM REFINERIES, FLUID 398 CATALYTIC CRACKING-UNITS, ENVIRONMENTAL PROTECTION AGENCY, 498 2030 698 RESEARCH TRIANGLE PARY,N. CAROLINA,JAN.1973. 598 BACKGROUND INFORMATION FOR PROPOSED NEW S0URCE PERFORMANCE 298 STANDARDS,TECHNICAL REPORT NO.9-STORAGE VESSELS FOR PETROLEUM 398 LIQUIDS, ENVIRONMENTAL PROTECTION AGENCY,RESEARCH TRIANGLE 499 PARK,N. CAROL1NA,JAN.1973. 591 2031 19 STRAUSS,4., INDUSTRIAL GAS CLEANING, PERGAMON PRESS, NEW 1966 298 2032 NOMOGRAP HS FOR THERMAL POLLUTION CONTROL SYSTEMS, OFFICE OF 298 RESEARCH AND DEVELOPMENT, U.S. ENVIRONMENTAL PROTECTION 398 AGENCY, WASHINGTON', D.C., C0NTRACT NO. 68-01-0171, JULY 1973. 498 SEBESTA, EDWARD C., MANAGEMENT OF REFINERY SOLID WASTE, 74TH 298 2033 198 NATIONAL MEETING AMERICAN INSTITUTE CF CHEMICAL ENGINEERS, NFW ORLEANS, LOUISIANA, MARCH 1973. 2034 REID, GEORGE W. AND LEALE E. STREEBIN, EVALUATION OF WASTE MONITORING, U.S. ENVIRONMENTAL PROTECTION AGENCY, WASHINGT0N, XI-14 REF. 2035-2042 D.C. EPA-P2-72-001, DECEMBER 1972. 598 2035 198 OIL AND GAS JOURNAL, VOLUME 69, Ij.35, AUGUST 30,1971, PETROLEUM 298 PUBLISHING CO. , TULSA, OKLAHCMA. 398 2036 198 OIL AND GAS JOURNAI, VOLUME 70, NO.40, OCT013ER 2, 1972, PETROLEUM 298 PUBLISHING CO., TULSA, OKLAHOMA. 398 2037 198 OIL AND GAS JOURNAL, VOLUME 70, NO.47, NOVEMBER 20,1972, PETROLEUM 298 PUBLISHING CO., TULSA, OKLAHOMA. 398 2038 198 MCENTIRE, BARNARD R. AND RAY SKOFF, HYDRCCARBON VAPOR CONTROL AT 298 GASOLINE SERVICE STATIONS, 66TH ANNUAL MEETING OF THE AIR 398 POLLUTION CONTROL ASSOCIATICN, CHICAGO, ILLINOIS, JUNE 1973. 498 2039 .198 SKOFF, RAY (COUNTY OF SAN DIEGO AIR POLLUTION CONTROL DISTRICT, 298 SAN DIEGO, CALIFORNIA), PERSONAL COMMUNICATION, JULY 1973. 2040 198 COSTS OF PROCESS EQUIPMENT, CHEMICAL ENGINEERING, MARCH 16, 1964, 298 MCGPAW-HILL, NEW YORK. 398 2041 ARIES, ROBERT S. AND POBEPT D. NEWTON, CHEMICAL ENGINEERING COST 298 ESTIMATION, MCGRAW-HILL, NEW YORK, 1955. 398 2042 198 DATA FROM A.D. LITTLE INC.,.CAMBRIDGE, KASS. 298 XI-15 REF. 3000-3010 REFERENCES FOR NATURAL GAS SUPPLY 3000 198 LNG A SULFER-FREE FUEL FOR POWER GENERATION, PROJECT 8926, INST 298 GAS TECHNOLOGY, IIT CENTER, CHICAGO, ILL, MAY 1969. 398 3001 198 OPINION NO. 612, ARKANSAS LOISIANA GAS COMPANY DOCKET NO. CP70-267 298 WASHINGTON, D.C., PPC, FEC 1972. 398 3002 198 GAS ENGINEERS HANDBOOK, INDUSTRIAL PRESS INC, N.Y., 1969. 298 3003 198 NATURAL GAS PROCESSING-72, OIL AND GAS JOURNAL, JULY 10, 1972. 298 3004 198 BEAM, M.A., DESIGN CONSIDERATIONS FOR A GAS-TURBINE PROPELLED LNG 298 TANKER, LPAPER PRESENTED AT 18TH ASME GAS TURBINE CONFERENCE. 398 WASH., D.C., APRIL 1973. 498 3005 198 REGULATION OF THE NATURAL GAS PRODUCING INDUSTRY, RESOURCES FOR 298 FUTURE, INC., WASH., D.C., 1972. 398 3006 199 1967 CENSUS OF TRANSPORTATION, VOL.III, COMMODITY TRANSPORTATION 299 SURVEY, PART 3, COMMODITY GROUOPS U.S. DEPT. OF COMMERCE, 399 BUREAU OF THE CENSUS, NOVEMBER 1970. 499 3007 199 FPC DOCKET NO. CP-74-157, MICHIGAN-WISCONIN PIPELINE COMPANY, 299 1973. 399 3008 199 NATIONAL GAS SURVEY, VOL.II, SUPPLY TASK FORCE REPORT, U.S. 299 FEDERAL POWER COMMISSION, JUNE 1973. 399 3009 199 PROCES TECHNIQUES AND HARDWARE USES OUTLINED FOR LNG REGASIFICA- 299 TION, OIL AND GAS JOURNAL, MAY 13, 1974. 399 3010 199 INNOVATIONS WILL MARK LNG RECEIVING TERMINAL, OIL & GAS JOURNAL 299 AUGUST 5, 1974. 399 XI-16 REFERENCES FOR END USE- SECTORS REF. 5101-5502 5101 196 GAS PATE FUNDAMENrALS, REVISED EDITION, NEW YORK, AMERICAN GAS 298 ASSOCIATION, 1969. 398 5102 198 DETAILED HOUSING CHARACTERISTICS FOR THE UNITED STATES, REGIONS, 298 DIVISIONS, AND STATES-1970, (11970 CENSUS OF HOUSING', NUMBER 398 HC (Sl)-6), 1972. 498 5103 198 ESTIMATE'@ ANNUAL KWH CONSUMPTION OF ELECTRICAL APPLIANCES, EDISON 298 ELECTRIC INSTITUTE, NYC, NEW YORK, 1969. 398 5104 198 APPLYPNCE AVERAGE ANNUAL USE, PACIFIC GAS AND ELECTRIC COMPANY, 298 1969. 398 5105 198 RANGES WITH SELF CLEANING OVENS,' CCNSUMER REPORTS, 35:11, NOVEM- 298 SIR 1970. 398 5106 198 RESIDENTIAL ENERGY CONSUMPTION--PHASE 1 REPORT, NUMBER HUD-HAI-1, 298 HITTMAN ASSOCIATES, INCOBPORATED, 1972. 398 5107 198 PROFILE OF U.S. CONSUMER MARKET SEGMENTS, DANIEL STARK AND STAFF, 298 INCORPORATED, 1969. 398 5108 198 'BLACK AND WHITE T.V. SETS,, CONSUMER REPORTS, 36:6, JUNE 1971. 298 5109 196 BURNER FUEL CILS, 1972, (OPETROLEUM PRODUCTS SURVEY, NUMBER 76), 298 BU MINES, 1972. 398 5110 198 GASEOUS FUELS STANDAFDS, AMERICAN SOCIETY FOR TESTING AND 298 M@TERIALS,.1969. 398 5111 198 LIQUIFIED PETROLEUM GAS SPECIFICATIONS AND TEST METHODS, NUMBER 298 214), NATUPAL GAS AND PETROLEUM ASSOCIATION, 1970 ' 398 5112 198 114TH ANNUAL MARKETING ANALYSIS ON ELECTRIC HEATING,' ELECTRIC 298 HEAT AND AIR CONDITIONING, MARCH - APRIL, 1970. 398 5113 198 DIRECTORY OF CERTIFIED ROOM AIR CONDITIONERS, NUMBER 3, ASSOCIA-. 298 TlCN OF HOME APPLIANCES MANUFACTURERS, CHICAGO, ILLINOIS, 398 JUNE 15, 1971. 498 5114 198 DIRECTORY OF CEFTIFIED UNITARY AIR CONDITIONERS, AIR CONDITIONING 298 AND REFRIGERATION INSTITUTE, ARLINGTON, VIRGINIA, 1973. 398 5115 198 HARL, C.T. ANE Y.J. SPRINGER, 'SMALL ENGINE EMISSIONS AND THEIR 29H IMFACT,l AUTOMOTIVE ENGINEERING, 80-7, JULY 1972. 398 5116 198 HANDBOOK OF CHEMISTRY AND PHYSICS, THE CHEMICAL RUBBER COMPANY, 21 " CLEVELANE, OHIO, 1966. 398 5117 198 PERSONAL COMMUNICATION FROM P. KEMP, AMERICAN GAS ASSOCIATION,' 298 ARLINGTON, VA., SEPTEMBER 24, 1974. 398 5118 198 'CRUDE PETROLEUM, PETROLEUM PRODUCTS, AND NATURAL GAS LIQUIDS: 298 1972 (FINAL SUMMARY)' MINERAL INDUSTRY SURVEYS, USDOI, BU 398 MINES, 1973. 498 5501 198 ELECTRIC ENERGY ASSOCIATION, DESIGN CRITERIA, ACCESS COMPUTER 298 PROGRAM, NEW YORK, 1973. 398 5502 198 GUIDE AND DAT A BOOK, 1966-1967, ASHRAE 29E XI-17 Reproduced from best available copy. REF. 5503-6108 5503 198 EMPLOYMENT AND EARNINGS, 1909,71, DEPARTMENT OF LABOR, BU LAB 298 STAT, NUMBER 1312-8, 1971. 398 5504 198 ESTIMATED ANNUAL KWH CONSUMPTION OF ELECTRICAL APPLIANCE, EDISON 298 ELECTRIC INSTITUTE, NYC, NEW YORK, 1969. 398 5505 198 STATISTICAL YEARBOOK, EDISON ELECTRIC INSTITUTE, NYC, NEW YORK, 298 FEBRUARY, 1972. 398 5506 198 LARGE LAMP CATALOG, GENERAL ELECTRICAL, NELA PARK, CLEVELAND, OHIO298 FEBRUARY, 1970. 398 5507 198 1971 AUTOMOBILE FACTS AND FIGURES, AUTO MANUFACTURERS ASSOCIATION 298 DETROIT, MICHIGAN, 1971. 398 5508 198 NATURAL GAS PRODUCTION AND CONSUMPTION: 1971, MINERAL INDUSTRY 298 SURVEYS, USKI, BU MINES, SEPTEMBER 5, 1972. 398 5509 198 DECEMBER, 1971 US ELECTRICITY OUTPUT TOTAL 148.4E+09 KWH, PPCNEWS 298 RELEASE NUMBER 18154, MARCH 21, 1972. 398 5510 198 ANALYSIS OF TIPPLE AND DELIVERED SAMPLES OF COAL, ('REPORTS OF 298 INVESTIGATIONS', NUMBER 7712), USDI, BU MINES, 1973. 398 5511 198 GASEOUS FUELS STUDIES, AMERICAN SOCIETY FOR TESTING AND MATERIALS 298 1969. 398 5512 198 LIQUIFIED PETROLEUM GAS SPECIFICATIONS, TEST METHODS, NUMBER 2140,298 NATURAL GAS AND PETROLEUM ASSOCATIONS, 1970. 398 5513 198 BURNED FUEL OILS, 1972 (PETROLEUM PRODUCTS SURVERY, NUMBER 76) 298 USDI, BU MINES, 1972. 398 6100 198 SYNTHETIC ORGANIZ CHEMICALS, US PRODUCTION AND SALES, 1972 (TCPUB 298 479, 1970) GPO, WASH DC 398 6101 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES-M28A(71)-14, 298 INORGANIC CHEMICALS, 1971. WASH DC 1972 398 6103 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES - M28C(71)-14 298 INDUSTRIAL GASES, 1971. WASH DC 1972 398 6104 198 BRAMER, HENRY C., COST OF WATER POLLUTION CONTROL IN THE CHEMICAL 298 INDUSTRY, INDUSTRIAL WASTES, VOL 19, INO J/F 1973 P IW/33- 398 IW/35 498 6106 198 ATMOSPHERICA EMISSIONS FROM WET PROCESS PHOSPHORIC ACID MANUFACTURE298 US--EW, PHS, EHS, NAT AIR POLL CONTROL ADM. RALEIGH, NC PUB 398 NC. AP-57. APRIL 1970. 498 6107 198 CONTROL OF AIR POLLUTION FROM SULFURIC ACID PLANTS, DRAFT EPA, 298 DURHAM NC. AUG 1971. 398 6108 198 CONTROL OF AIR POLLUTION FROM NITRIC ACID PLANTS, DRAFT EPA. 298 XI-18 REF. 6109-6308 DURHAM NC. AUG 1971 398 6109 198 US BUR CENSUS, CENSUS MAN, 1967 SUMMARY REPORT - MATERIALS CONSUMED 298 MC67(1)-6, GPO WASH, DC 197 398 6110 198 US BUR CENSUS,CENSUS MAN, 1967 SPECIAL SERIES-FUELS AND ELECTRIC 298 ENERGY CONSUMED, MC 67(S)-4. GPO WASH, DC 1971 398 6111 198 INORGANIC CHEMICALS INDUSTRY PROFILE, WATER POLL CONTROL RESEARCH 298 SERIES 12020 EJI, EPA JULY 1971 398 6112 198 SULFUR REDUCTION POTENTIAL OF THE COALS OF TH US, BUR MINES 298 REPORT OF INVESTIGATIONS, RI 7633, US DEPT INT 1972 398 6113 198 BURNED FUEL OILS, 1972. ('PETROLEUM PRODUCTS SURVEY', NO. 76), BU 298 MINES 1972 398 6114 198 SHREVE, RN, CHEMICAL PROCESS INDUSTRIES. 3RD ED. NY, MCGRAW-HILL 298 BOOK CO, 1967 398 6115 198 PROJECTED WASTE WATER COST IN THE ORGANIC CHEMICALS INDUSTRY 298 CYRUS WM PICE & CO, PITTS. PA. JAN 1969 398 6116 198 THE COST OF CLEAN WATER, VOL III, IND WASTE PROFILE NO. 10, 298 PLASTICS MATERIALS AND RESINS, US DEPT INT FWPCA, OCT, 12 1967 398 6117 198 MARYNOWSKI, CHESTER W., DISPOSAL OF POLYMER SOLID WASTES BY 298 PRIMARY POLYMER PRODUCTS AND PLASTICS FABRICATORS, SRI, 398 CONTRACT NO. PH-86-68-160, EPA. 1972 6118 198 OIL AND GAS JOURNAL,'STATISTICS',VOL. 71, NO. 26 JUNE 25, 1973 298 PP 163-164 398 6300 198 IDENTIFICATION AND CLASSIFICATION OF COMBUSTION SOURCE EQUIPMENT, 298 PROCESS RESEARCH INC., JAN 26, 1972 398 6301 198 PORTLAND CEMENT, STANDARDS OF PERFORMANCE, EPA, RE TRI PK NC, JUN 298 1971 398 6302 198 SULFUR REDUCTION POTENTIAL OF THE COALS OF THE US, BU MINES REPORT 298 OF INVESTIGATIONS, RI 7633, US DEPT INT, 1972 398 6303 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES-M-2D(71)-13 298 CLAY CONSTRUCTION PRODUCTS, SUMMARY, 1971 WASH DC JUN 1972 398 6304 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES - MQ-32C(71)-5 298 REFRACTORIES, SUMMARY 1971-WASH DC SEPT 1972 398 6305 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES-MQ-32A(71)-5 298 FLAT GLASS, SUMMARY 1971. WASH DC AUG 1972 398 6306 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES-M32G(71)-13, 298 GLASS CONTAINERS , SUMMARY 1971. WASH DC JULY 19L72 398 6307 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES-M32J(71)-1, 298 FIBROUS GLASS, 1971. WASH DC JULY 1972 398 6208 198 US BUR CENSUS, CURRENT INDUSTRIAL REPORTS SERIES-MA-32E(71)-1 298 CONSUMER, SCIENTIFIC, TECHNICAL, AND INDUSTRIAL GLASSWARE, 398 XI-19 REF. 6309-6405 1971. WASH DC JULY 1972 498 6309 198 ASHRAE HANDBOOK OF FUNDAMENTALS, AM SOC HEATING, REFRIGERATING AND 293 AIF-CONDITIONING ENG INC., 1967 P 433 398 6310 198 RAMSEY, CG, AND SLEEPER, HR, ARCH GRAPHIC STANDARDS, JOHN WILEY & 298 SONS INC, 1956 398 6311 US BUF CENSUS, CENSUS MAN, 1967 INDUSTRIAL SERIES- MAJOR GROUP 32, 298 STONE, CLAY, AND GLASS PFODUCTS- GLASS PRODUCTS, MC67(2)-32A- 398 CEMENT AND STRUCTURAL CLAY PRCDUCTS, MC67(2)-32B POTTERY AND 498B RELATED PRODUCTS, MC67(2)-32C--CONCRETE, PLASTER AND CUT-STONE 596 PRODUCTS, MC67(2)-32D- ABRASIVES, ASBESTOS AND MISCELLANEOUS 698 NONMETALIIC MINERAL PRODUCTS, GPO WASH DC 1970 798 6312 198 MAKHIJANI, AE AND LICHTENBERG,IAJ, ENERGY AND WELL BEING, ENVIRON 298 VOL. 14 No 5, JUNE 1972. PG 11-18 390 6313 158 TELLEP, AARCN J. , CONTROL OF EMISSIONS FROM GLASS MANUFACTURE, CERAMIC SOC BULL VOL 51 NOe AUG 1972. PG 637-640 398 6314 198 LANGTON, TG, SCHENCK, GHK AND SUN, SC , A STUDY OF THE CONCRETE 298 BLOCK INDUSTRY- A NATIONAL AND REGIONAL APPROACH, SPECIAL RSH 398 RPT SR-91 DEPT ENVIR RESOUECES COMMWEALTH PENN, THE PENN STATE 498 UNIVI'MAY 15 1972, PG 213 598 198 298 398 6316 198 FLAT GLASS, CEMENT, LIME, GYPSUM AND ASBESTOS INDUSTRIES, IND WASTE298 STUDY REPORT. EPA WASH DC JULY 1971 398 6317 198 BURNER FUEL OILS, 1972 (PETROLEUM PRODUCTS SURVEY', NO. 76), BU 298 MINES# 1972 398 6318 198 OIL AND GAS JOURNAL,STATISTICS1 VOL. 71, NO. 26 JUNE 25, 1973, 298 FF 163-64 398 6319 198 US BUF CENSUS, ANNUAL SURVEY OF MAN. 1971- VALUE OF PRODUCT 298 SHIPA-ENTS, M71(AS)-2, WASH DC NOV.1972 398 6400 198 AGRICULTURAL STATISTICS 1972, US DEPT. AGRI. WASH DC 1972 298, 198 181 398 6402 196 US BlIF CENSUS, CENSUS MAN, 1967 INDUSTRIAL SERIES- MAJOR GROUP 20, 290 GPO WASH DC 1970 390 6403 191 ELIMINATION OF WATER POLLUTION BY PACKINGHCUSE ANIMAL PAUNCH AND 290 FLOOD, BEEFLAND INTERNATIONAL INCORP EPA NO 12060 FDS NOV 1971 391 6404 190 f WATER A0ND WASTE MANAGEMENT IN POULTRY PRCC0LSSING, CROSSWHITE, WM, 128 CAFAWAN @E,'AND MACON JA, PROCEEDINGS SECOND NATIONAL SYMPOSIUM CN FOOD PROCESSING WASTES, EPA WATEN POLLUTION CCNTFOL SERIES 12068 MARCH 1971 508 6405 408 CAGNEY,EJ, EFFLUENT WASTE WATER CLEANUP PROVIDES MARKETABLE 298 PRODUCTS, INDUSTRIAL WASTES, NOV/DEC 1971 PG IW2/IW4 XI-20 REF. 6406-6503 6406 198 BOYLD,WC AND POLNOWSKI LB, TREATMENT OF CHEESE PROCESSING WASTE- 298 WATERS IN AREAIED LA30ONS, PROCEEDINGS THIRD NATIONAL 398 SYMPOSIUM CN FOOD PROCESSING W..STES, EPA WATER POLLUTION 498 CONTROL SERIES 12068 NOV 1972 598 6407 198 THE CCST OF CLEAN WATER, VOLUME III INDUSTRIAL WASTE PROFILE NO.8- 29R MEAT PRODUCTS, US DEPT INT, FWPCA SEPT 1967 398 6408 198 THE COST OF CLEAN WATER, VOLUME III INDUSTRIAL WASTE PROFILE NO.9- 298 DAIRIES, US DEPT INT, FWPCA JUNE 1967 398 6409 198 US BUR CENSUS, ANNUAL SURVEY OF MAN. 1971- VALUE OF PRO'DUCT 298 SHIPMENTS, M71(AS)-2, US GPO WASH DC NOV 1972 6410 198 HAWAII'S SUGAR INDUSTRY FACES TOUGH PROBLEMS, ENVIRON SCI & TECH 298 VOL5 NO 12 DEC 1971 PG 1174 - 1175 398 6411 198 BRENTCN, RONALD W. TREATMENT CF SUGARBEEI WASTE BY RECYCLING, 298 INDUSTRIAL WASTES. JAN/FEB 1972 PG IW/14 - IW/19 398 6412 198 HYNES, E., STEVENS, G. AND RUSSELL, P. WINERY WASTE W ATER TREAT- 298 MENT, PROCEEDINGS THIRD NATIONAL SYMPOSIUM ON FOOD PROCESSING 398 WASTES EPA NOV 1972 498 6413 198 SCHWAFTZ, HG AND RICHARD, HJ, CHARACTERIZATION AND TREATMENT OF 298 BREWERY WASTES, PROCEEDINGS THIRD NATIONAL SYMPOSIUM ON FOOD 398 PFCCESSING WASTES, EPA NOV. 1972 498 6414 198 THE COST OF.CLEAN WATER, VOLUME III,INDUSTRIAL WASTE PROFILE NO. 6298 CANNED AND FROZEN FRUITS AND VEGETABLES, US DEPT INT, FWPCA .398 SEPT 1967 498 6415 198 DOSTAI, K.A., AERATED LAGOON TREATMENT OF FOOD PROCESSING WASTES. 298 PACIFIC NORTHWEST WATER LAB,EPA NO 12060 MARCH 1968 398 6416 198 SODERCUIST, M.F., BLANTON, G.I. AND TAYLOR, D.W., CHARACTERIZATION 298 OF FRUIT AND VEGETABLE PROCESSING WASTEWATERS, PROCEEDINGS 398 THIRD NATIONAL SYMPOSIUM ON FOOD PROCESSING WASTE, EPA 498 NOV 1972 598 6417 198 HUDSON. HENERY T, SOLID WASTE MANAGEMENT IN THE FOODS PROCESSING 298 INDUSTRY, PROCEEDING SECOND NATIONAL SYMPOSIUM ON FOOD 398 PROCESSING WASTES, EPA WATER POLL CON RES SERIES 12068, MARCH 498 1971 598 6418 198 BENSIG, H.O. AND BRCWN D.R., PROCESS DESIGN FOR TREATMENT OF WET 298 CORN MILLING WASTE, PROCEEDINGS THIRD NATIONAL SYMPOSIUM ON 398 FOOD PROCESSING WASTE, EPA NOV 1972 498 6501 198 CONTROL OF ATMOSPHERIC EMISSIONS IN THE WOOD PULPING INDUSTRY, 298 FINAL REPORT, VOL 2, CONTRACT NO. CPA 22-69-18, EPA. 398 6502 198 FEDERAL WATER POLLUTION CONTROL ADMINISTRATION,USDOI, THE COST OF 298 CLEAN WATER, VOL. 3, PAPER MILLS INDUST.RY WA-STEWATER PROFILE, 398 1967 498 6503 198 EFFLUENT LIMITATION GUIDANCE FOR THE REFUSE ACT PFRMIT PROGRAM, 298 THE PULP AND PAPER INDUSTRY, EPA, JUNE 9, 1,972. 398 XI-21 REF. 6504-7002 6504 198 SUMMARY REPORT ON THE PAPER AND ALLIED PRODUCTS INDUSTRY, THE INDUSTRIAL WASTES STUDIES PROGRAM, EPA, JAN. 27, 1972. 6600 ANNUAL STATISTICAL REPORT, AMERICAN IRON AND STEEL INSTITUE, 1972 AISI, WASH DC. MAY 1973. 6601 MINERAL FACTS AND PROBLEMS, 1970 EDITION, BU MINES, USDI, 1970 6602 COCHRAN, C.N., ALUMINUM-VILLAIN OR HERO IN ENERGY CRISIS, AUTOMOTIVE ENGINEERING, SAE, NY, NY JUNE 1973 6603 COMMUNICATIONS WITH INDUSTRIAL STUDIES BRANCH, EPA, DURHAM NC,L MAY 1973 6604 CONTROL TECHNIQUIES FOR NITROGEN OXIDE EMISSIONS FROM STATIONARY SOURCES, AP-67, USDHEW, WASH DC, MARCH 19970 6605 WATER USE IN MANUFACTURING, MC67(1)-7, 1967 CENSUS OF MANUFACTURES USDOC, APRIL 1971 6606 EPA MEMO FROM OFFICE OF PERMIT PROGRAMS TO EFFLUENT GUIDELINES DIVISION, EFFLUENT LIMITATIONS NUMBERS AND BACKUP INFORMATION FOR INTERIM GUIDELINES, OCTOBER 1972 6630 EFFLUENT LIMITATIONS GUIDENCE FOR THE REFUSE ACT PERMIT PRGRAM, THE ALUMINUM INDUSTRY, EP, OWP, OCT. 197. 6631 WHITE, LANE, THE NEWER TECHNOLOGY-WHERE IT IS USED AND WHY, SPECIAL REPORT ON COPPER, CHEM ENG. APRIL 16, 1973 6632 US BUR CENSUS, CENSUS MAN, 1967, SUMMARY SERIES - TYPE OF ORGANIZATION MC67(1)-3, GPO, WASH DC 1971 6701 US CENSUS, CENSUS OF MANUFACTURERS, 1967, INDUSTRY SERIES -- MOTOR VEHICLES AND EQUIPMENT , MC 67(2)-37A, USGPO, 1970. 6702 MOTOR VEHICLES INDUSTRY, EFFLUENT LIMITATION GUIDANCE, THE REFUSE ACT PERMIT PROGRAM, EPA, AUG. 14, 1972. 6703 THE COST OF CLEAN WATER, INDUSTRIAL WASTE PROFILE NO. 2, MOTOR VEHICLES AND PARTS, UDI, 1967 6704 SUMMARY REPORT ON THE AUTOMOBILE INDUSTRY, THE INDUSTRIAL WASTES STUDIES PROGRAM, EPA, MAR. 2, 1972 6705 AUTOMOTIVE INDUSTRIES, JAN 15, 1972 6706 AUTOMOTIVE INDUSTRIES, OCT. 14, 1972 6707 AUTOMOTIVE INDUSTRIES, SEPT. 14, 1972 6708 AUTOMOTIVE INDUSTRIES, MAY 14, 1972 7001 UNPUBLISHED USGG DATA OBTAINED FROM JOHN MILTON, USCG. 7002 USCG INTERNAL MEMO DTD 5/25/72 'TRANSPORTATION ENERGY PANEL DATA XI-22 REF. 7003-7020 INPUT. 398 7003 198 'NATIONWIDE PERSONAL TRANSPORTATION STUDY, AUTOMOBILE OCCUPANCY, 298 USDOT, FRA, APRIL 1972. 398 7004 198 $A TECHNOLOGY ASSESSMENT OF THE TRANSITICN TO ADVANCED AUTOMOTIVE 298 PROPULSION SYSTEMS' (DRAFT), HITTMAN ASSOCIATES, HIT 541, NOV 398 1972. 496 7005 AVIATION FORECAST FOR FISCAL YEAR 1972-1983, FAA OFFICE OF AVIA- 298 TICN ECCNOMICS, SEPT 1971. 398 7006 198 FRENCH,.ET Al, 'HIGHWAY TRAVEL FORECASTS'RELATED TO ENERGY RE-. 298 QUIREMENTS,l DOT, FHA, MAY 10, 1972. 398 7007 198 $HIGHWAY STATISTICS 1971,1 USDOT, FHA TABLE VM-1, OCTOBER 1972. 298 7008 198 'COMPARATIVE AIR POLLUTION ASPECTS OF PASSENGER TRAVEL,* TRI-STATE 298 REGIONAL PLANNING COMMISSION RPT 4330 2601, OCTOBER 1972. 398 7009 198 HANDBOOK OF AIRLINE STATISTICS, CIVIL AERONAUTICS BOARD, 1971. 298 198 BUREAU OF THE CENS, US, CURRENT INDUSTRIAL REPORTS, SALES OF LUBRI- 296 CATING OILS AND GREASES, JAN 1971. 398 7011 198 71-72 TRANSIT FRCT BOOK, AMERICAN TRANSIT ASSOC.,.WASHINGTON, D.C. 298 7012 198 RICE, R.A., $SYSTEM ENERGY'.AS A FACTOR IN CONSIDERING FUTURE 298 TRANSPORTATION,' ASME PAPER -70-WA/ENER-8, 1971. 398 7013 198 'PAVING OVER TH& COU NTRY RELEASE FROM DOT AND FHA. 298 7014 198 WALTER, R.A., ET AL. IUSCG POLLUTION ABATEMENT PROGRAM-A PRELIMI- 298 NARY STUEY OF VESSEL AND BOAT EXHAUST EMISSIONS,l RPT DOT-TSC- 398 USCG-72-3, NOV 1971. 498 7015 198 COMMUNICATION WITH R.E. SCHATTMAN OF THE DEFENSE SUPPLY AGENCY, 298 CAMA RON STATION, VA. 398 7016 198 HARE, CHARLES T. AND K.J. SPRINGER, #SMALL ENGINE EMISSIONS AND 298 THEIR IMPACT,' AUTOMOTIVE ENGINEERING, JULY 1972 VOL.80, NO. 7.398 7017 198 HARE, CHARLES T. AND K.J. SPRINGER 'EXHAUST EMISSIONS FROM UNCON- 298 TROLLED.VEHICLES AND RELATED EQUIPMENT USING. INTERNAL COMBUS- 398 TION ENGINES,f FINAL REPORT PART 2 OUTBOARD MOTORS, SRI RPT 498 AR-850, JANUARY 1973. 598 7018 198 IFINAL REPORT OF THE TASK FORCE ON USED OIL DISPOFAL,l API PUBLI- 298 CATICN NC. 4036, 1969. 398 7019 198 "ANALYSIS OF AIRCRAFT EXHAUST EMISSION MEASUREMENI-S,l CORNELL 298 AERO. LAB REPT NA 5007-Kl, OCT 1971. 398 7020 '1972 AUTOMOBILE FACTS. AND FIGURES.' MOTOR VEFIICLE MANUFACTURERS ASSOCIATION OF rHE U.S. INC. 1973. XI-23 REF. 7021-7022 7021 199 PILATI, DAVID A.AIRPLANE ENERGY 'USE AND CONSERVATION STRATEGIES, 298 OAK RIDGE NATIONAL LABORATORY, ORNL-NSF-EP-69, MAY 1974. 398 70.22 198 MUTCH, JAMES, J, TRANSPORTATION ENERGY USE IN THE -UNITED STATES 298 A STATISTICAL HISTORY, 1955-1971. PREPARED FOR THE NATIONAL 398 SCIENCE FOUNDATION, R-13-91-NSF, DECEMBER 1973. 498 XI-24 REF. 9600-9601 REFERENCES FOR ELECTRIC POWER ACTI'VITY OF FUEL SUPPLY 9600 198 ENERGY AND THE ENVIRONMEN.T-ELECTRIC POWER, PREPARED BY THE COUNCIL 29.8 ON ENVIRONMENTAL QUALITY, WASHINGTON, DC, GPO, AUGUST 1973. 398 9601 198 ENVIRONMENTAL SURVEY OF THE URANIUM FUEL CYCLE, WASHINGTON-1248, 298 U.S. ATOMIC ENERGY COMMISSION-, APRIL 1974. 398 X I - 2 5 APPENDIX A LIST OF ABBREVIATIONS A-1 APPENDIX A LIST OF ABBREVIATIONS A Ash AC Acre A/C Air Conditioner AMNT Amount BAAPCD San Francisco Bay Area Air AV Average Pollution Control District BADCT Best Available Demonstrated Control Technology BBL Barrel(s) BCF Billion Cubic Feet (Standard) BOD Biological Oxygen Demand BPH Barrels per Hour BPSD Barrels per Stream Day BPY Barrels per Year British Thermal Unit BTU BTUH BTU per Hour B-T-X, Benzene Toluene Xylene C Cents CO Carbon Monoxide CAP Capacity CD Calendar Day CF Cubic Feet Cubic Yard D Day DIST or DSTL Distillate ZOTI Department of Transportation DS Dissolved Solids DSCF Dry Standard Cubic Feet DSCFM Dry Standard Cubic Feet per J Minute DWT Deadweight E Equivalent ELECT Electricity EPA Environmental Protection Agency ESP Electrostatic Precipitator F Fahrenheit FCR Fixed Charge Rate FF and following pages . . . FT Foot (Feet) GAL Gallon GAS Natural Gas GASO Gasoline Gram GPD Gallons per Day A-2 GPM Gallons per Minute GR Grains HEW U.S. Department of.Health, Education and Welfare HP Horsepower 11R Hour IN Inch KWI Kilowatt KWH Kilowatt Hour-Mlectrical) L Liter LB Pound LIRR Long Island Railroad LNG Liquefied Natural Gas LPG Liquefied Petroleum Gas. LT Long Ton LTS 'Long Ton Sulfur M Thousand MCF Thousand Cubic Feet (Standard) MEA Monoethanolomine MF Moisture Free MG Milligram MGD Million Gallons per Day Mi Mile(s), MIBK Methylisobutyl Ketone MM Million MMCF Million Cubic Feet (Standard) MMCFD million Cubic Feet per Day MOL Mole MPG Miles per Gallon MW Megawatts NDO Nondegradable Organics NMI Nautical Miles NO Number ODS Other Dissolved Solids OST Office of Science and Technology P. or PC Percent PE Primary Efficiency PHS Public Health Service PM Passenger Mile PPM Parts per Million PSIA Pounds per Square Inch Absolute PSIG Pou ds per Square Inch Gage n RESID or RFO Re'sidual fuel oil ROM Run of Mine S Sulfur SCF Standard Cubic Feet SF Square Foot (Feet) SGC Stack Gas Cleaning SH Short SI Square Inch(es) A-3 SNG Synthetic Natural Gas T Ton(s) TDS Total Dissolved Solids TM or TMI Ton Mile TPD Ton per Day TPY Ton per Year TS Total Solids (Dissolved + Suspended) USDI U.S. Department of the Interior VM VEhicle Mile W or WT Weight WAL Weak Ammonia Liquor YR Year A-4 NOAA COASTAL SERVICES CTR LIBRARY 3 6668 14110836 7