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HomeMy WebLinkAboutTanana Reconnaissance Study of Energy Requirements & Alternatives 1981RECONNAISSANCE STUDY OF ENERGY REQUIREMENTS AND ALTERNATIVES FOR TANANA REPORT SUMMARY BY MARKS ENGINEERING/BROWN & ROOT, INC. ANCHORAGE, ALASKA is» ALASKA POWER AUTHORITY = } MARKS ENGINEERING/BROWN & ROOT, INC. ANCHORAGE, ALASKA July 1, 1981 Mr. Don Baxter, Project Manager Alaska Power Authority 333 West Fourth Avenue, Suite 31 Anchorage, Alaska 99501 Dear Mr. Baxter: In accordance with the terms of our agreement of September 21, 1980, we respectfully submit our report covering the Tanana Power Reconnaissance Study of Energy Requirements and Alternatives. Our study indicates that the following actions will result in near-term benefits to the residents of Tanana: 0 Serious efforts should be expended by residents and local officials of Tanana to reduce the heat losses of homes and buildings in Tanana in order to conserve fuel oi1. o Wood fuel should be utilized for space and water heating to the maximum practical extent to minimize the impact of higher fuel oi] costs in Tanana. For the long term, our study indicates that two alternatives for meeting Tanana's electrical energy requirements appear promising and merit further study. These are: o Diesel power generation with waste heat recovery o Hydroelectric power generation on Jackson Creek near Tanana We recommend that a feasibility study be undertaken to evaluate these two alternatives thoroughly. Mr. Don Baxter, Project Manager Page 2 July 1, 1981 Thank you for the opportunity to serve the Alaska Power Authority and the community of Tanana. Very truly yours, BROWN & ROOT, INC./MARKS ENGINEERING Carl L. Fick, PLE. em Ae Marks, P.E, CLF/ Ime SECTION I, II. III. IV. VI. TABLE OF CONTENTS SUMMARY AND RECOMMENDATIONS........ceceeccccaccceccecceces INTRODUCTION. ......ccccscccccescccncccccccccscceecececenecs EXISTING CONDITIONS. .........ccceccnccccccccesccccceceeccs A. Demographic and Economic Conditions. ...scscccccccenccce B. Energy Balance......... ccc cece ccccceccccccccccces C. Existing Power and Heating Facilities... ee. eeeee D. Summary of Existing CONGITIONS. ... cece eee c cece cccccecs FORECAST OF ENERGY REQUIREMENTS........cceccccceccecceccees > Economic Activity Forecast and Planned Capital PrOojeCts...cccccesccsccccscccccscccccccensescune Population Forecast.........cceccccccccsccecceccccecce. Energy End-Use Forecast........cccccccccceccccessscecce ow 1. Electrical Energy 2. Heating Energy D. Energy and Peak-Load Forecasts.....cccccccccccccccccces 1. Electrical 2. Heating E. Substitutability Between Electrical and Heating Requirements ASSESSMENT OF RESOURCES AND TECHNOLOGY..........ceceececece A. Energy Resource ASSESSMENC.... cece ec ccccccccccccccceccs B. Survey of Techno] ogy. -sserssatssccesssereeees Sewes C. Appropriate Energy Resource Technologies......seeeescee ENERGY PLANS......ecceccccsccccscccecccecsseccccescsncccees A. Introduction and APPrOdCh... ccc cccccccccccccccccccccece B. Base-Case Diesel Generation Plan......ccecececececccece 1. Plan Components 2. Timing of System Additions 3. Plan Description C. Diesel Generation with Utilization of Waste Heat....... 1. Plan Components 2. Timing of System Additions 3. Plan Description PAGE I-] II-1 IlI-1 III-1 III-] III-2 III-4 IV-1 mee <<< Sas IV-2 VI-2 SECTION VII. D. Diesel Generation With Binary Cycle.......cccceceececes VI-4 1. Plan Components 2. Timing of System Additions 3. Plan Description E. Coal-Fired Steam Generation Plan..... Setleele Srolacterecetaia eee) VI-5 1. Plan Components 2. Timing of System Additions 3. Plan Description F. Hydroelectric Generation Plan.......cccccccccccececceee VI-6 1. Plan Components 2. Timing of System Additions 3. Plan Description G. Transmission Plan...........6. VeTetire reese eerrreerees VI-6 1. Plan Components 2. Timing of System Additions 3. Plan Description H. Wood-Fired Steam Generation Plan.........eeeeeee seccees VI-7 1. Plan Components 2. Timing of System Additions 3. Plan Description I. Wood-Gas Generation Plan........ Dletole 6 6 5.0 blacede:o! exert eles b-olate VI-8 1. Plan Components 2. Timing of System Additions 3. Plan Description ENERGY PLAN EVALUATION..... biacttecotacote ares elale-s sia ee'e-o seeceeeees VII-1 A. Economic Evaluation... ..... ccc cece ccc ccccccscccccecceeee VII-1 1. Method 2. Evaluation Results B. Environmental Evaluation........ seotdtelesek iota erelels siete pieates CV dae 1. Community Preferences 2. Impact on Community Infrastructure and Employment 3. Timing in Relation to Other Planned Capital Projects 4. Air Quality 5. Water Quality 6. Impact on Fish and Wildlife SECTION VIII. APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX APPENDIX PAGE 7. Land Use and Ownership Status 8. Terrestrial Impact I C. Technical Evaluation. ...........cceecccecccecccecccseee VI[“5 1. Safety 2. Reliability 3. Availability RECOMMENDATIONS... .0ecceeccccccccccccsccccscccsscceccceesce VIII-1 A. Preferred Energy Alternatives.........cccccceccececescs VIII-1 B. Required Resource Assessments and Feasibility Studies............. cece ec ceeecceecceccceee VIII =2 APPENDICES PAGE A - Community Meetings..........ccccceccccececcececcccucece A-1 B - Data on Existing Conditions and Energy Balance......... B-1 C - Energy Forecasting Procedure and Calculations.......... C-1 D - Technology Profiles. ..... sc cece cece cc ccccecececccccccee D-1 E - Energy Plan Costs and Nonelectrical Benefits........... E-1 F - Detailed Description of the Recommended Plan(s)........ F-1 G - Coal Sources and Costs..........cccecceccecceccecceccce G-1 H - Conservation........ tence e cece ccc cece ee cece c cece cseece H-1 I - Geothermal Energy.........cceccececcccececcececcccccece I-] | =) WAN GENK ATION. oie siete a elscoel bs olale-slese b slaw plalele eblclelccatihld J-1 K - Wood Harvesting, Transportation, and Storage........... K-1 L - Environmental Elements.........sccececcececcccececeeees L-1 M - Comments by Review Agencies............. Cee evccccecccce M-1 A. I, SUMMARY AND RECOMMENDATIONS Summary 1. 2. 3. Existing Conditions As of 1980, the community of Tanana had an estimated Population of 400. The economy is supported by an FAA facility, a Public Health Service hospital, schools, fish processing plants, fishing, mining, trapping, and subsistence hunting. Community electrical power generation requirements are supplied by a central power plant with four diesel generators and a total capacity of 1950 kW. Electrical energy consumption for 1980 was about 2,000,000 kWH, with a peak demand of less than 500 kW. About half of the fuel oil entering the community is used in electrical Power generation. Heating energy requirements for the community were about 35,000 million Btu in 1980. The heating of all commercial and government buildings is accomplished with fuel oil. Residences are heated with fuel oil and wood, with the latter supplying an estimated 60% of the heat energy. There are approximately 100 residences in Tanana, of which about 86 are of log construction. Future Energy Requirements Electrical and heating energy requirements are Projected to increase 3% annually during the next 20 years. In the year 2000, the electrical energy requirement is projected to be about 3,610,000 kWH and the peak demand 850 kW. The heating energy requirement in the year. 2000 is projected to be 61,950 million Btu. Resource -and Technology Assessment Sixteen energy resources for Producing electricity and heat were examined: 4. Coal-fired steam Coal gasification Conservation Gas turbines Geothermal energy Hydroelectric energy Diesel oil Diesel oi] with binary cycle Peat conversion Solar energy Solid waste conversion Transmission Waste heat Wind Wood-fired steam o 9809 890000 GB BOB OG OG Oo oO oO oO Wood gas The sixteen possible energy resources were evaluated on the basis of (1) economics, (2) available quantity, (3) quality, (4) reliability, (5) suitability for the community, (6) community preference, (7) availability of equipment, and (8) environmental impact. The energy resources that were deemed Promising were coal steam, hydroelectric energy, diesel oil, diesel oil with binary cycle, transmission, waste heat, wood-fired steam, and wood-gas. Conservation, when applied by weatherizing the existing homes, can reduce the fuels needed for home heating, and the use of wood for home heating has definite economic advantages. Coal gasification, gas turbines, geothermal energy, peat conversion, solar energy, solid waste conversions, and wind were determined to be unsuitable for supplying electrical and heat energy for the community. Energy Plans Eight energy alternative plans were evaluated, using the energy resources that were judged to be promising: Base-case diesel generation Diesel generation with utilization of waste heat Diesel generation with binary cycle and utilization of waste heat Coal-fired steam generation with utilization of waste heat Hydroelectric generation Transmission Wood-fired steam generation with utilization of waste heat o oOo OG CO CO 8 Wood-gas generation with utilization of waste heat Of the eight generating plans evaluated, two were found to be the most advantageous and worthy of further consideration and study: o Diesel generation with utilization of waste heat o Hydroelectric generation with surplus electrical power These two alternatives were evaluated with respect to economic, environmental, technical, and community-preference factors. The total present-worth-of-plan cost minus the present-worth of non-electrical benefits for the diesel generation plan is $19,027,000, and that for the hydroelectric alternative is $13,185,000. Each of the two favorable alternatives will have surplus output beyond simply meeting the demand for electrical energy. Diesel will have waste heat, and the hydroelectric source will provide surplus electrical power. The total present worth of the usable waste heat produced by the diesel alternatives is $9,336,000. It should be noted that the large total Present worth of the waste heat utilized stems largely from the fact that the value of petroleum fuels that the waste heat is to displace has been assumed to escalate at 3.5% annually. The value of the surplus electrical energy produced by the hydroelectric alternative is $1,488,000. The hydroelectric and diesel alternatives will have only minimal environmental impact on the community. Neither of these plans are complex from a technical standpoint since both plans involve well-proven technology. Community preferences, expressed only by a limited number of residents, favor the hydroelectric alternative over the diesel. The hydroelectric alternative is based on very limited soil, topographic, and stream-flow information. ; 1-3 Conclusions Heating requirements for the houses in the community can be greatly reduced if the structures are upgraded with energy-saving improvements, and an increase in the use of wood as a fuel for home heating will decrease heating costs. In conclusion, the most advantageous alternatives for supplying electrical power and heat to the community are: o Diesel generation with utilization of waste heat o Hydroelectric generation with production of surplus electrical energy B. Recommendations Community residents should be encouraged to weatherize their homes in order to reduce space heat losses. More wood fuel should be used to heat community residences, thus reducing the use of fuel oil. A feasibility study should be undertaken to establish the most suitable source of electric power for the community. A. C. II, INTRODUCTION General The community of Tanana is being adversely influenced by excessive, constantly escalating fuel costs. The Alaska Power Authority therefore implemented a study in order to determine ways of reducing the cost of energy for the residents of Tanana. Marks Engineering and Brown & Root were engaged in a joint venture to make a reconnaissance study for supplying energy to the community. A key map is shown on Plate II-a, and a map of the Tanana area is shown on Plate II-b. Objectives The objectives of the study were to: 1. Determine the present and future electrical energy requirements of the village of Tanana .2. | Assess viable electrical power generation alternatives 3. Provide a basis for initiating specific feasibility studies, detailed data collection, and resource assessments for the more promising power generation alternatives Study Execution Execution of the study emcompassed several major items of work, which are listed below. 1. Site Reconnaissance Visits were made to Tanana to gather data and to conduct meetings with the public, village officials, and Tanana Power Company officials. The data obtained during the visits included the present Power production statistics, sources of present energy used, types and cost of available fuels, the condition of existing structures, representative costs for river and air transportation, availability and cost of local labor, information on potential for utilization of waste heat, and potential hydroelectric sites. Data on population, economic conditions, and existing power and heating facilities were also obtained. ) Energy Balance An energy balance was prepared from the data gathered at Tanana and collected from other available sources, depicting the energy types presently being utilized in Tanana. The energy types (fuel oi], coal, wood, propane, etc.), the primary use (diesel Power generation, space heating, vehicle transportation, cooking), heat values, and costs were determined, Particular emphasis was placed on potential utilization of waste heat by existing schools and public facilities. Future Energy Requirements A forecast of future energy requirements was made. This took into consideration projected economic activity, population growth, and changes in the type of energy expected to be used. Assessment of Technology and Resources An assessment was made of energy resources and technologies that warrant serious consideration as power generation alternatives for Tanana. Sixteen energy resources were assessed, including most conceivable options, along with sixteen technologies for converting those resources into electricity. Eight of the sixteen technologies were judged to be most promising and worthy of further consideration as energy plans. The following indicators were used in evaluating energy alternatives: o Economic - Present worth of plan cost - Nonelectrical benefits o Social - Community preferences - Impact on community infrastructure - Timing in relation to other capital projects o Environmental - Air quality - Water quality - Impact on fish and wildlife - Land use - Terrestrial impact o Technical - Safety - Reliability - Availability The eight plans were: Existing diesel generation (base case) Diesel generation with waste heat recovery Diesel generation with waste heat recovery - binary cycle Coal-fired steam generation Hydroelectric generation Power transmission line Wood-fired steam generation ooo ol OCOUlCODOlUlOD Wood gasification power generation 5. Assessment of Energy Plans The eight most promising alternatives were evaluated on the basis of economic, environmental, and technical factors. Those found to be most promising were diesel generation with waste heat recovery and hydroelectric generation with surplus electrical power. OD. Study Resuits The results of this study show that the most suitable alternatives for meeting Tanana's electrical power needs are diesel generation and hydroelectric power generation. It is recommended that feasibility studies for these two alternatives be undertaken. ARCTIC OCEAN Kokukum River Yukon River TANANA FAIRBANKS BERING SEA Kuskokwim River Papers Ave PANCHORAGE Jas BRISTOL BAY PACIFIC OCEAN MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. I-0 APRIL, 1961 —__— laiph M Calhoun jemorial Airport 13 AREA MAP OF TANANA Scale 1 =1 Mile ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY AREA MAP TANANA MARKS ENGINEERING / PLATE NO, BROWN & ROOT, INC. Ib APRIL, I98! III. EXISTING CONDITIONS A. Demographic: and Economic Conditions le Demographic Conditions The village of Tanana is considered a subregional center and contains an FAA facility, a White Alice site (now abandoned), a Public Health Service hospital, two large stores, a wholesale cooperative grocery distribution business, a public laundry, a safe water facility, a high school, and a sewage collection system for the school and hospital buildings. The population of Tanana was estimated to be 400 in 1980, anticipated to increase to 600 by the year 2000. Economic Conditions The economy of Tanana consists of government employment at the FAA and PHS facilities and seasonal employment by a local fish Processing firm and by the BLM firefighting center recently established in the village. Fishing, mining, winter trapping, subsistence hunting, and gathering of fuel wood are activities that also contribute to the local economy. An additional 26 HUD homes are to be constructed in Tanana, along with projected capital improvements consisting of a food processing storage facility, a multipurpose community building, and a float plane dock. The PHS hospital is scheduled to discontinue in-patient care in 1981, and the facility will be converted to an ambulatory senior citizens home and headquarters for decentralization of many health services now provided in Fairbanks. B. Energy Balance Energy is now enter ing the community in various forms. The quantities of energy for 1980 and the end use of each type of energy are shown in Table III-a. The quantities are also displayed graphically on Plate III-a. C. Large amounts of fuel oil are used in the community, as shown in Table III-a. The fuel oil is shipped into the community by river barge. Approximately 40% of the fuel oil is used by the Tanana Power Company to generate electrical energy. Wood fuel used for space heating of homes is mostly snagged from the river. Propane, gasoline, blazo, and aviation fuel also enter the community by river barge. Recoverable waste heat is produced in large quantities by the diesel generator at the Tanana Power Company plant. This recoverable waste heat, estimated to be 11,400 million Btu in 1980, represents about 42% of the energy in the fuel consumed, and the fuel-to-wire efficiency of the diesel generator units at Tanana is about 25%. Approximately 63% of the energy of the fuel oil is converted into heat that is in the exhaust and jacket water, and two-thirds of this heat is recoverable. The ability to recover waste heat from diesel exhaust and jacket water has been proven by installations throughout the world. Information sources include equipment manufacturers, and the information must be considered accurate and very reliable. (Waste heat recovery is discussed more thoroughly in Appendix D.) Not all of the recoverable waste heat can be utilized because the need for heating is low in the summer months. It is estimated that slightly less than 10,000 million Btu of waste heat could have been utilized in Tanana in 1980. Existing Power and Heating Facilities 1. Existing Power Facilities Tne existing diesel power generation consists of Caterpillar 0397, 0398, and 0399 diesel engine generators, capable of producing 350, 500, and 800 kW, respectively, and one Detroit Diesel V-1271 capable of producing 300 kW. Generation voltages of 480 and 2,400 volts are utilized, and distribution voltage is 2,400 volts. The 0399 diesel engine generator is a new unit, while the others have recently been overhauled. The existing plant building, which houses the 0399 diesel engine generator, is in poor condition. The other units are housed in their own skid-base modules. Approximately 200,000 gallons of diesel fuel oil are used annually to generate approximately 2,000,000 kilowatt hours to meet Tanana's ‘power requirements. Since Tanana Power Company does not have its own fuel oil storage facilities, fuel oil is stored in facilities owned and operated by Nenana Fuel Company. The larger diesel generator is used during the winter months, while the smaller units are used during the spring and summer. Tanana Power Company has experienced equipment Outages during the last 2 years during periods of peak demand; therefore, peak-demand data for tne past 2 years are not available. The existing diesel generation facilities do not presently fave provisions for recovery of waste heat. The location of the existing plant is well over half a mile from the nearest potential user of waste heat for space or water heating. Tentative plans have been made to relocate the plant adjacent to tne village safe water facility, a location advantageous to the utilization of waste heat for heating water and space for the safe water facility. The PHS hospital, the Federal Aviation Administration, and the school have emergency power generation facilities that are utilized when the main power source fails. There are no other private generation facilities besides Tanana Power Company. Existing Heating Facilities All commercial and government facilities are heated with fuel oil, while residences are heated with a combination of wood and fuel oil. It has been estimated that approximately 60% of the homes in Tanana are now being heated witn wood. There are approximately 100 residences in Tanana, comprising about 5 conventional frame homes, 9 trailer nomes, and 86 homes of log construction. Most residences have installed or are in the process of installing wood-burning stoves and are keeping oil-fired stoves as backup heating units. Most homes thus utilize wood heat to some extent, and it is estimated that annual wood consumption for space heating is approximately 12 cords per household. Wood logs are generally obtained during spring breakup, when many trees and drift logs come down the Yukon and Tanana Rivers. Villagers snag the logs from shore or from a boat and obtain as many logs as possible from the river. On occasion, they cut standing timber when river log supplies dwindle. Bottled propane is utilized for cooling, although some residents cook on wood-fired stoves. Most homes 5 years old or more have no floor or ceiling insulation. The ceilings are open-pole types of plywood on shiplap roofing with sheet metal covering. Floors are built over log sleepers with plywood or plank overlay. Thermopane windows were evident only on the newest buildings; older homes make use of polyethylene sheeting over windows to minimize heat losses. There are several improvements that can be effected to minimize heat loss and fuel consumption. The heating envelope could be improved by installing ceiling and floor insulation, thermopane or storm windows, enclosed storm entryways, and stack ropbers, as well as by lowering interior temperature to 70 degrees. DO. Summary of Existing Conditions The population and economic activity in Tanana are expected to increase gradually during the next 20 years. Approximately 40% of the present fuel oil requirements are for electric power generation with no waste heat recovery, while the other half is utilized for space and water heating. Wood heating is now utilized in approximately 60% of residences, and an increase in wood-fired heating is anticipated. In general, the insulation levels of most older homes are not adequate to minimize heat loss. Propane is utilized for cooking in most homes and facilities. The existing power generation facilities, with a total capacity of 1950 kW, do not presently have provisions for waste heat recovery. The large consumers of fuel oil for space heating could benefit from power generation waste heat recovery, and the existing homes could be insulated to reduce heat loss from the buildings. TABLE [II~a ANNUAL (1980) ENERGY ENTERING COMMUNITY AND RECOVERABLE WASTE HEAT ier x10 BTU x 10 Tanana Power Co. Power Generation 200,000 gal. »000 000 Road Machinery Road & Transportation 30,000 gal. i. 050 ree PHS Hospital School Housing TYPE OF FUEL a Space Heating 140,000 gal. Space Heating 4,000 gal. School AC Store Space Heating 24,000 gal. Space Heating 4,500 gal. Fuel Fuel 071 Safewater Drying-Space Heating FAA Facility 25,000 gal. Space Heating 35,000 gal. Fuel Village Homes Space Heating 50,000 gal. Total Fuel Oi] 512,500 gal. 1,200 cords 50,000 lbs. Wood Propane Village Homes Space Heating Village Homes Cooking Reg. Gasoline Blazo Vehicles, Boats Remote Camps Transportation Cooking/Lighting 80,000 gal. 1,200 gal. Aviation Fuel Aircraft Transportation 10,000 gal. 80/87 20,000 gal. 100/130 7,000 gal. Jet B Table III-a are a 5 Space Heating 85,900 Million BTU Total Annual Energy Entering Community 128,700 Million BTU Electric Power Production 27,000 Million BTU ae Recoverable Waste Heat 11,000 Million BTU Air & Ground Transportation 15,800 Million BTU ENERGY BALANCE GRAPH Showing Annual Energy Use in Community in 1980 ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY ENERGY BALANCE GRAPH MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Il-a APRIL, /98! IV. FORECAST OF ENERGY REQUIREMENTS A. Economic Activity Forecast and Planned Capital Projects The economic activity forecast for Tanana indicates that fishing, subsistence hunting, winter trapping, wood gathering, subregional fuel and food distribution, mining, fish processing, firefighting, and employment by local, Federal, and state governments will continue to increase gradually during tne next 20 years. Planned capital projects in the near future include an additional 26 HUD housing units, a food processing storage facility, a multipurpose community building, an ice skating rink, and a float plane dock. (The Probable impact of these projects on the community is discussed in Section D below.) The PHS hospital is scheduled to discontinue in-patient care in 1981, and the facility will then be converted into an ambulatory senior citizens home and headquarters for the decentralization of many health services now provided in Fairbanks. B. Population Forecast The population of Tanana is expected to increase gradually to 600 by the year 2000. C. Energy End-Use Forecast 1. Electrical Energy The end use of electrical energy will be for lighting, appliances, and electrically driven equipment throughout the next 20 years. No electric space or water heating is foreseen during the next 20 years if wood or fossil fuels are utilized for power generation. If hydroelectric generation is developed, surplus electrical energy would be produced and made available for heating. Heating Energy The end use of heating energy will be for water and space heating and clothes drying throughout the next’ 20 years. A large portion of the space heating requirements will be met by waste heat recovery if wood or fossil fuels are utilized for power generation. It is anticipated tnat the use of wood-fired space heating will increase as fuel oil prices increase. If a hydroelectric plant is developed, the surplus electrical energy could be used for heating. D0. Energy and Peak-Load Forecasts 1. Electrical Electrical energy requirements are shown on Table IV-a, along with peak loads. The 1970 census data indicated a population of 406 in Tanana. The Tanana population in 1980 was estimated at approximately 400 on the basis of discussions with local officials and residents. The population is assumed to increase at a rate of 2% per year through the year 2000 on the basis of increasing economic activity and the additional 26 housing units to be erected in Tanana in 1981. The recent and projected additions of the fish processing plant and the Bureau of Land Management firefighting: camp are expected to increase the permanent and seasonal population of Tanana. The fish processing plant contributes a seasonal peak load of 150 kilowatts during the summer. The new Bureau of Land Management firefighting camp is expected to contribute a seasonal peak load of 50 kilowatts during the summer, and a new village safe water and laundry facility contributes a year-round load of 50 kilowatts. The projected additions of energy users include the 26 new housing units, which are expected to contribute a year-round peak load of 50 kilowatts; a cold storage facility, which is expected to contribute a year-round peak load of 50 kilowatts; and a community building, which is expected to contribute a year-round peak load of 10 kilowatts. 2. The recent and projected additions of large, medium, and residential power users assume an increase in the consumption of electrical energy at an estimated rate of 3% per year and take into account the seasonal nature of the fish processing plant and firefighting camp loads. The seasonal loads during the summer months are not expected to influence the winter peak loads now experienced in Tdnana. These seasonal loads will improve the utility's load factor and will Provide for better utilization of the existing generation capacity, however. Statistics indicate that residential consumers in Tanana use approximately twice as much electricity as the average of 48 Alaska Village Electric Cooperative villages and half as much energy as an average Chugach Electric residential consumer. It is anticipated that the cost of electrical energy in Tanana will continue to increase in the near term as a result of increasing fuel oi] costs and that it will exert a restraining effect on increased use of electrical energy Per household. Appliance saturation levels are not expected to increase, in view of rising energy costs for fuel oil and electricity. Heating Heating energy requirements representing the total consumed by public buildings and homes are shown in Table IV-a. The heating energy requirements were calculated on the basis of the amount of fuels now being used. Fuel oil heaters are assumed to be 68% efficient, while wood heaters are assumed to be 50% efficient. Fuel oil heater manufacturers claim efficiency in the 85% range with modern efficient units; wood heater manufacturers claim up to 65% efficiency for their new products. The lower efficiencies assumed here are considered to be more realistic than the higher figures claimed by manufacturers. Fuel oil is assumed to have 0.135 million Btu per gallon and wood 14 million Btu per cord. The 1980 heating energy requirements were calculated on the basis of 282,500 gallons of fuel oil and 1,200 cords of wood. The 1980 heating energy requirement in millions of Btu equals 282,500 X 0.135 X 68% zs plus 1,200 X 14 X 50% = 25,900 million Btu plus 8,400 million Btu equals a total of 34,300 million Btu. The 1981 figure is projected to be 35,330 million Btu. E. Substitutability. Between Electrical and Heating Requirements Electrical energy in cost per millions of Btu is much more costly than heat supplied by other sources, such as fuel oi], wood, or propane. The likelihood that electrical energy will be low enough in price to be substitutable for space heating is very remote for Tanana. Waste heat recovery from wood-fired or fossil-fuel-fired power generation can displace a good portion of space and water heating in large heat-using facilities. TABLE IV-a PROJECTED ELECTRICAL AND HEATING REQUIREMENTS FOR TANANA ELECTRICAL PEAK LOAD ELECTRICAL ENERGY HEATING ENERGY REQUIREMENTS REQUIREMENTS REQUIREMENTS YEAR IN KILOWATTS IN KWH IN M BTU 1981 484 2,060,000 35,330 1982 4990 2,120,000 36 390 1983 514 2,180,000 37 ,480 1984 529 2,250,000 38,600 1985 545 2,320,000 Se BIE 39,760 1986 561 2,390,000 40,960 1987 578 2,460,000 42,180 1988 595 2,530,000 43,450 a 1989 613 2,610,000 44,750 1990 631 2,690,000 46,100 1991 650 2,770,000 47,480 1992 670 2,850,000 48,900 1993 690 2,940,000 50,370 1994 711 3,020,000 51,190 1995 732 3,110,000 53,440 1996 754 3,210,000 . . 55,040 ee 1997 777 3,300,000 56 ,690 Se a ee 1998 800 3,400,000 58,390 Sa ee 1999 825 3,510,000 60,150 Se 2000 850 3,610,000 61,950 Sa aa ne Re a oh 20-year Total = 55,330,000 KWH, 54-year total = 178,070,000 KWH NOTE: 1. The electrical peak loads are increased 3% per year over the 20 year period. : . 2. The annual electrical energy use is based on 2,000,000 KWH being used in 1980 with an annual increase of 3% for the 20-year period. The values are rounded off to the nearest 10,000 KWH. Heating energy requirements are also increased 3% annually. Table IV-a ve ASSESSMENT OF RESOURCES AND TECHNOLOGY EERE AND TECHNOLOGY A. Energy Resource Assessment Sixteen energy resources for furnishing electricity and heat that were _ judged to warrant a first-cut assessment are described below. In addition, a brief statement regarding the availability, quality, cost, source of data, and reliability of data is made for each resource. Information is also shown in tabular form in Table V-a. 1. Coal-Fired Steam Coal could be used to fire a steam boiler that would generate electrical power and produce abundant waste heat. The quantity of coal that could be supplied by importing it to Tanana exceeds the needs of a steam generation system. The quality of the coal should be high, and the cost for the energy derived from coal should be low to moderate. Data regarding costs and availability were generated in this report and are considered to be good. Appendix G outlines sources, transportation, and cost for coal for Tanana. Coal Gas Coal could be used to Produce Jlow-Btu gas to fuel an internal- combustion engine to drive a generator. Tne quantity, quality, cost, and source data are the same as for the coal-fired steam resource. Conservation The conservation of energy, both electricity and neat, is not an energy resource but is only a means to reduce the energy requirements of the community. Electrical and heat energy requirements can be reduced significantly by concerted efforts on the Part of building Owners and users. However, the efforts required depend largely on individual initiative and are therefore difficult to carry out. Appendix H outlines several aspects of conservation at Tanana. The source of data is observation of the circumstances at Tanana, and the reliability of the data is average. Gas Turbines Gas turbines could be used to generate electrical power at Tanana, and waste heat could be recovered. Gas turbines use a very costly fossil fuel and would therefore be a costly alternative for power generation. No nearby natural gas can be tapped to supply the required fuel, so the gas would have to be shipped in. Gas in sufficient quantity and quality could be transported to Tanana but at a high cost. The data regarding availability of the gas and the cost are considered poor. Geothermal Energy Geothermal energy would be expensive because of costs associated with geothermal development and the distance to and the quality of geothermal energy in the Tanana area. (See Appendix I for further information on the utilization of geothermal energy.) Data from available information are sketchy, and their reliability is poor. Hydroelectric Energy There are several sites for development of a hydroelectric plant in the Tanana area. The most suitable sites are on Jackson Creek, about nine miles east of the community. A large reservoir will be necessary to provide water to the turbine during those months when stream flow is small. A hydroelectric plant on Jackson Creek with a 5,000-acre- foot reservoir and a head of about 400 feet would have a capacity of 850 kW and could supply about 3,800,000 kWH of electrical energy per year. This amount would require an average flow of about 15 cfs through the turbines. The cost of generation would probably be low. The hydrological data were taken from the report now being prepared for the U.S. Corp of Engineers by OTT. The reliability of the hydrological data is considered average and adequate for this phase of the work, but topographic data are poor, and geological data needed to assess the reservoir embankment are not available. Soil conditions | at the site may greatly affect embankment construction costs. Hydroelectric generation is more thoroughly examined in Appendix D. 7. Diesel Oi] Diesel-engine-driven generators are now being employed to supply electrical power for the Tanana community. Diesel fuel in sufficient quantity and quality is now and can continue to be supplied to Tanana, and the cost for continued diesel generation is average. The source of data is the actual practice in the community, and the data are considered very reliable. Diesel generation is more thoroughly evaluated in Appendix 0. 8. Diesel Oil With Binary Cycle Tne diesel engines that will continue to drive the electric generators can be equipped with bottom cycling equipment. Fuel savings of 15% can be realized with the addition of the binary-cycle equipment, and the cost of the additional equipment is average. The source of the data is the equipment manufacturers, and the data are considered good. This alternative is more thoroughly outlined in Appendix 0. 9. Peat Conversion Peat is mot available near Tanana, and transportation costs associated with its use will be high. The quality of the peat varies, but it is being used successfully as a boiler fuel. Data are derived from knowledge of the area; the reliability of the data is poor. 10. Solar Energy Solar energy is not viable for supplying electrical power, but it can be made to supply some of the lighting and space heat needs as described in Appendix H, Conservation. Solar energy is unreliable because of the large number of cloudy days in the area. The source of li. 12. 13. 14, data is published information and knowledge of the area, and the reliability of the data is average. Solid Waste Conversion A sufficient quantity of solid waste is not produced in Tanana, and transportation of solid waste to Tanana for use as fuel would add considerably to the cost. The quality of solid waste fuel is poor. The source of data is knowledge of the area, and the reliability of the data is good. Transmission Electrical energy can be supplied by transmission from an existing grid. This transmission can best be accomplished by a regular three-wire line. A single-line ground return system can be made to transmit the power but has several disadvantages. Costs for both types of line are excessive because of the long length of line required. Source data are generated in this report and are considered relatively reliable. Transmission is more thoroughly examined in Appendix 0. Waste Heat Waste heat can be recovered from some of the electric generating Processes considered here. Waste heat recovery is an excellent low-cost energy resource, which is addressed in various sections of this report. The source of data is good. Waste heat is outlined in Appendix 0. Wind Wind of sufficient velocity and duration is not present at Tanana for consideration as an alternative energy resource. The cost of the equipment to supply even a minimal -amount of electrical energy is excessive. Wind data are based on records collected at the Tanana air strip for many years, while the cost is based on information from | equipment suppliers. Data are considered to be of good reliability. See Appendix J for additional information on wind generation. 15. Wood Steam Wood could be used to generate the steam to drive steam turbines for producing electricity. Wood of sufficient quantity can be found in the Tanana area, and the quality of this energy source is good. Cost should be low to moderate. Source data are generated in this report, and the reliability of the data is good. See Appendix K for additional information on wood fuel. 16. Wood Gas Wood can be used to produce low-Btu gas, which could be used as a fuel for a gas engine to drive generators. Sufficient quantities of wood can be obtained in the Tanana area. (See Appendix K.) The quality of the wood fuel is good, and the cost should be moderate. Source data are generated in this report and are considered good. B. Survey of Technology The technology associated with each of the sixteen energy resources listed above is described below. Information is also shown in tabular form in Table V-a. 1. Coal-Fired Steam The means for generating electrical power from coal-fired steam has long been available, for the use of coal to fire steam boilers involves an old and well-established technology. Because of concerns about air pollution and low price, however, natural gas and oil have gradually replaced coal in many installations, although recent increases in the price of oi] have renewed interest in the use of coal. Equipment for coal-fired steam generation is similar to that for other solid fuels and is commercially available. The equipment | required includes a furnace, boiler, steam turbine, and electric generator. The use of coal-fired steam is more tnoroughly reviewed in Appendix D0. Coal Gas A gasifier would be used to convert coal into a gas. Tne basic equipment would consist of three principal components: a gasifier, an internal-combustion engine for converting the gas into mechanical energy, and a generator for converting the mechanical energy into electrical energy. The use of coal gas is much like the use of wood gas, which is outlined in Appendix 0. Conservation The conservation of heat and electrical energy is simple and in many cases requires no new technology. The required technology has been well proven and includes using daylight for illumination, relamping with more efficient lamps, avoiding radiation effects of cold surfaces, reducing infiltration, increasing solar gain, and improving building insulation. More details are given in Appendix H. Gas Turbines Gas turbines have long been used to provide short-term peaking Capacity for electrical power systems. Their use to produce electrical power continuously has never been widespread because of their low efficiency when compared with gas-fired steam plants. In a gas turbine generating facility, burning gas under pressure turns a turbine, which in turn transmits power to an electric generator. Geothermal Energy Geothermal power plants and heating systems nave been in use for many years. The technology involved for electrical power Production is much like that of any steam-electric plant, except that steam is generated by geothermal heat instead of by a fire. The technology associated with space heat is the piping of heat in the form of hot water or steam from the geothermal heat source to the buildings being supplied with the heat. Hydroelectric Energy Hydroelectric technology in almost its present-day form was developed about 70 years ago. Water under head is used to drive a water turbine, which in turn drives an electric generator. More information is contained in Appendix D. Diesel Oi] The technology for diesel power generation is readily available throughout the world, and the diesel remains the most efficient of internal combustion engines. Many types and sizes of diesel-powered generators are available at favorable costs. More information is given in Appendix 0. Diesel power generation is relatively simple, requiring modest capital investments in the generating units and fuel storage facilities. Diesel engines can be overhauled to prolong their life almost indefinitely. Major overhauls can be performed at the site and result in engines that are almost the equivalent of new machines. Diesel Oil With Binary Cycle The technology for a binary cycle in association with a diesel engine has been proven and is in use to a limited extent. More information is outlined in Appendix 0. The bottoming cycle recovers energy from the exhaust heat of the diesel engine. The major components of the bottoming cycle system are the turbine, generator, vapor generator, condenser, and regenerator. The exhaust gases from the engine vaporize the working fluid of the bottoming cycle system in the vapor generator. The vaporized working 10. 1. 12. fluid then expands through a turbine, which provides power to drive an additional generator. The working fluid is then cooled in a water condenser and again enters the vapor generator, heated by the diesel exhaust. This alternative would be: provided with a compound radiator with two separate cooling systems; one would cool the existing diesel engine, and the other would cool the working fluid. Peat Conversion The technology for using peat as a fuel is very much like that for using coal or wood to fire a boiler that in turn produces steam to drive a turbine generator. Peat gasification is also a possibility. Solar Energy Solar energy is being used to produce electrical power at larger plants, where solar collectors concentrate the sun's heat at a point to produce steam for driving a turbine generator. Solar cells are also used at remote locations to produce very small amounts of electrical energy. Solid Waste Conversion The technology for using solid waste as a fuel is very much like that for using coal or wood to fire a boiler that in turn Produces steam to drive a turbine generator. Gasification of solid waste is also a possibility. Transmission Transmission of electrical energy by conventional multiwire transmission line is widespread, and the technology is well developed. The use of a single-wire ground return transmission, while theroetically feasible and a subject of discussion for many years, has not been accepted in the industry. It is therefore not a proven technology in the broad sense. The reluctance to use single-wire ground return transmission probably stems from the fact that only a 13. 14, 15. 16. small percentage in savings can be realized by going to the single-wire line. More information is presented in Appendix 0. Waste Heat The technology of waste heat recovery is simple and has been used on many installations around the world. It involves transferring heat from tne source (the exhaust and/or jacket water for tne diesel) for such uses as space heating in buildings. Wind The technology for converting the kinetic energy in wind to electrical energy is complex, since the necessary equipment is complex, mostly because of the varying direction and velocity of the wind. On the surface, the system seems simple: wind turns the blades of a windmill, which turns the shaft of a generator. A small DC windmill-driven generator with a small-capacity storage battery is not complex, but for large machines, complexity increases and is compounded by the massiveness of the blades and the need to develop the maximum energy from the unit. More information is given in Appendix J. Wood-Fired Steam The technology for using wood as a fuel is much like that for using coal to fire a boiler for Producing steam to drive a turbine generator. More information is presented in Appendix 0. Wood Gas In this technology, a gasifier is used to convert wood to a gas, which serves a dual-fuel engine that drives the generator. The engine would use a combination of 90% low-Btu gas and 10% diesel fuel. See Appendix 0 for more information. Appropriate Energy Resource Technologies A screening of the sixteen energy resource technologies examined in the first-cut assessment indicates that eight show signs of promise and should be evaluated in more detail. See Tables V-a and V-b. Table V-a tates the energy resource for each of the sixteen energy sources as outlined in paragraph A hereinbefore. In the screening, the comparison matrix in Table V-b was used to summarize all information that must be compared to reach a decision. Numerical ratings are used in the table. In the screening process, a comparison matrix in Table V-b utilizing a munerical rating system was used to evaluate certain screening criteria. The numerical ratings were summed up in the last column of the table, thus giving an overall evaluation score for each technology. Evaluation of the various screening criteria is based upon information provided in other portions of this report. The screening criteria are listed below: l. Quantity or Capability to Supply Energy The capability to supply energy was rated on a scale of 10 to 0, with 10 indicating that the alternative could be made to supply the needed energy with reasonable effort. A rating of O indicates that energy cannot be provided by this technology. 2. Quality and Reliability Quality and reliability of the technology have been rated on a scale of 4 to 0, with 4 being the highest rating. 3. Suitability The appropriateness of the technology for Tanana is based on the complexity of the system and the ease with which the system can be integrated within the community. The rating is from 4 to 1, with the highest rating indicating the greatest suitability. 4, Cost The overall cost of a technology has been given a rating of 20 to 1, with 20 indicating the lowest cost. 5. Availability of Equipment The availability of the equipment to implement the energy resource has been given a rating of from 5 to 1, with the highest figure assigned to the technologies that can be implemented most easily. The ratings in Table 5-b show that the most promising alternatives are: Coal-fired steam Hydroelectric energy Diesel oi] Diesel oi] with binary cycle Transmission Waste heat Wood steam Wood gas Waste heat is to be part of an alternative when applicable. TABLE V-a ENERGY RESOU RCE_ASSESSMENT Energy Resource Quantity of Reliability or] Overall Source Reliability Energy Source |.Quality of Cost of of Data} of Data Energy Source | Production 1 Coal-Fired Steam High High Low Good Good 1 $j 2 Coal Gas High High Average Good: Good + Th at 3 Conservation N.A. N.A. Low Poor Average | ~ | 4 Gas Turbine Good Good High Good Good 5 Geothermal Low Not Known High Poor - Poor 6 High High Hydroelectric Average Poor Poor — + _t 7 Diesel Oi] Good Good Average Good Good i [ ay 8 Diesel Oi] w/Binary Cycle| Good Good Average Good Good done 9 Peat Conversion Low Average High Poor Poor 10 Solar Good Low High Average| Average 11 Solid Waste Conversion Low Low High Good Good lV TTF 12 Transmission Good - Good High Good Good | iL a — 13 Waste Heat Good Good Low Good Good at —_| de 14 Wind Low Low High Good Good —_|— —— ——— i 15 Wood Steam Good Good Low Good Good 16 Wood Gas Good Good Average Good Good NOTE: 1. N.A. means Not Applicable Table V-a Technology 10 im 12 13 14 16 Coal-Fired Steam Coal Gas Conservation Gas Turbine Geothermal Hydroelectric Diesel Oi] Diesel Oi1 w/ Binary Cycle Peat Conversion Solar Solid Waste Conversion Transmission Waste Heat Wind Wood Steam Wood Gas *Cost includes initial and operating and maintenance costs RATINGS OF ENERGY RESOURCE TECHNOLOGIES TABLE V-b Rating Value 10 10 10 10 3 ] ating} Ratin ; Rati ability of | Total Equipment 26 23 19 18 41 28 Order 9 10 12 14 13 15 11 g VI. ENERGY PLANS A. Introduction and Approach B. The following eight energy plans incorporate those technologies and energy resources that were found to be most promising in the first-cut assessment in Section V: Base-case diesel generation Diesel generation with utilization of waste heat Diesel generation with binary cycle and utilization of waste heat Coal-fired steam generation with utilization of waste heat and diesel generation backup Hydroelectric generation with diesel generation backup Transmission line with diesel generation backup Wood-fired steam generation with utilization of waste heat and diesel generation backup . Wood gas generation with utilization of waste heat and diesel generation backup Each plan is formulated to produce the forecast electrical requirements. In addition, all plans except base-case diesel and transmission also Produce waste heat or extra electrical energy that can be used for space heating. Base-Case Diesel Generation Plan 1. Plan Components This plan projects the continued use of the existing diesel generating equipment. The existing system at Tanana consists of four diesel-powered generators. This existing system is called the base-case in this comparison of alternative energy plans. The base-case diesel power generation has a total capacity of 1,950 kW, as detailed in Section III. The 1981 peak load is projected to be 3. 484 kW. Allowing for future growth in demand by present customers, some population increase, and possible additional commercial or industrial load, peak demand is projected to reach 850 kW in the next 20 years, as outlined in Section IV. The existing equipment's capacity of 1,950 kW exceeds the projected requirement; therefore, no additional generating equipment jis projected as being required for this base-case plan. The existing plant building is in poor condition, and this energy plan anticipates the construction of a new 30' X 100! powerhouse at the present location. The new powerhouse would house all of the existing units. (The technology for diesel generation is more thoroughly outlined in Appendix D.) Timing of System Additions This plan projects the construction of the new building to house the existing equipment in 1981. It is also projected that the existing units will require major overhauls in 1985, 1990, and 9995. Pian Description The energy plan for the base-case diesel power generation alternative requires that no new diesel engine generators be added to meet the projected load growth. The existing units would continue to supply the electrical energy needs for the community. C. Diesel Generation with Utilization of Waste Heat eee tn en wt iization ot Waste heat 1. Pian Components This energy plan considers the use of the existing diesel-powered generating equipment with the addition of new waste heat recovery equipment. The existing facility consists of four diesel generators capable of producting a total of 1,950 kW. Suitable heat exchangers, a pipe transportation system to move heated steam to buildings, and related auxiliary equipment would have to be added to utilize the waste heat. The location of the existing plant is well over a half mile from the nearest large potential user of waste heat for space or water heating. Moreover, the existing plant building is in poor condition and cannot house all of the diesel generators under one roof. Tentative plans have been made for relocating the plant adjacent to the village safe water facility, a location advantageous to the utilization of waste heat for heating water and space. In addition, the Public Health Service hospital and the high school are less than 2,000 feet away and could be served by a waste heat loop from the new location adjacent to the village safe water facility. This plan projects putting all existing generating units in one new 36' X 100' building and equipping each engine with exchangers to extract heat from the jacket water and the exhaust. (The details of this plan are more throughly outlined in Appendices D and F.) Timing of System Additions This plan anticipates tnat the new powerhouse building, along with the waste heat recovery equipment, distribution system, and the necessary exchangers, will be complete by the end of 1982. Major overhauling of the existing generating units is projected for 1985, 1990, and 1995. Plan Description The existing diesel generation system in this plan is projected to continue supplying the electrical needs of Tanana, with no new generating capacity required. Waste heat from the diesel engines is to be recovered from the diesel jacket water and the exhaust, then conveyed in steam by pipeline to buildings where heat exchangers will take the heat from the steam and use it for space heating and/or water heating. D. Diesel Generation with Binary Cycie 1. Pian: Components The plan projects the continued use of the existing diesel-powered generating equipment with the addition of a binary cycle and waste heat recovery equipment to each diesel engine. The binary cycle would be accomplished with a new Organic-Rankine bottoming cycle system. The components for this energy plan would be housed in a new 45' X 100' powerhouse building, from which steam Piping system would transport the waste heat to other buildings supplied with heat exchangers, which would extract the heat from the hot steam. (More details of this plan are given in Appendix D.) Timing of System Additions This energy plan projects the completion of the new Powerhouse building with the Organic-Rankine bottoming cycle system, the waste heat recovery equipment, the distribuion system, and the exchangers by the end of 1982. Pian Description The existing diesel generating system is projected to continue supplying the electrical needs of Tanana, with no new generating capacity required. The binary cycle with the Organic-Rankine bottoming cycle system, using exhaust heat, would produce additional electrical energy from a new generator driven by the Rankine cycle equipment. The binary cycle should reduce diesel fuel requirements by 15%. Waste heat from the diesel jacket water and exhaust is to be recovered and utilized in space heating of building. The waste heat is not as great in this plan, because not as much diesel Power is used to generate the required electrical power and because some of the waste heat is used by the binary cycle. 1. 3. E. Coal-Fired Steam Generation Plan aoe team Generation Plan Plan Components The basic equipment required in this plan consists of three principal components: a furnace and boiler to convert coal into steam, a turbine for converting the -kinetic energy in the steam into mechanical energy, and a generator for converting the mechanical energy into electrical energy. A 200' x 200' coal storage yard is Projected. The existing diesel-driven generating equipment would be used as backup when the coal-fired equipment is out of service. Recovery of waste heat would require those components described in Section C above; the circulating medium would be water rather than steam, however. Water is not as suitable as hot steam, because hot water will require larger heat exchangers. The plan includes construction of a new 40' X 150! Power plant building. (See Appendix D for more details regarding this plan.) Timing of System Additions It is anticipated that Construction of the required facilitues will be complete by the end of 1983. Plan Description A single new coal-fired steam turbine generator is to Provide the electrical needs for Tanana. A large amount of waste heat will be Produced, because the system efficiency will be low. The waste heat, however, will largely be recovered from the furnace stack and condenser. Coal must be imported. The plan foresees that the coal will be transported to Tanana by river barge and then deposited at a storage area adjacent to the river. (See Appendix G regarding the coal supply and transportation Plan.) The recovered waste heat is to be piped in water lines to buildings to be used for space heating. F. G. Hydroelectric Generation Plan Plan Components The components for this plan include a 850-kW hydroelectric plant on Jackson Creek, along with a reservoir and a penstock. The existing units are to be moved into a new Powerhouse building, and the existing diesel generation System will be required as a standby source of generation. (See Appendices D and F for more information regarding this plan.) Timing of System Additions Construction of the required facilities is projected to be complete by the end of 1984, Plan Description This plan considers the construction of an 850-kW hydroelectric plant on Jackson Creek 9 miles east of Tanana. A reservoir with an active flow storage capacity of 5,000 acre-feet and a top-of-conservation level at elevation 660 is planned. A 25,000-foot-long, 36-inch- diameter pen stock will transfer the water to the power plant at elevation 230, and a 9-mile-long transmission line will transmit the energy to the community grid. The 5,000-acre-foot reservoir is necessary because flow in Jackson Creek is limited to warmer months. The hydroelectric plant would supply all requirements of the electrical system and would also generate surplus energy that could be used to replace other fuel needs. Transmission Plan mss ton rian Plan Components This plan projects the construction of a - 140-mile three-wire transmission line from the existing grid at Fairbanks to the community distribution system in Tanana. A single-line ground return 2. system is not considered acceptable because (1) it would be impossible to define the ground return path, and the stray currents would have a destructive effect on pipelines, etc.; (2) high reactance values would cause high losses in the line; and (3) only single-phase power could be transmitted, which would limit the end use of the power. The only advantage of a single-wire line is a reduction in cost, and this is small because it is related only to the wires. The existing generation units would be used as a backup. (More details on transmission are included in Appendix D.) Timing of System: Additions Construction of the transmission line is projected to be complete by the end of 1983. Plan-Description This plan projects the construction of a 140-mile transmission line from near Fairbanks to Tanana. No waste heat would be produced. The existing units to be used as a standby source are to be housed in a new 30' x 100' building. H. Wood-Fired Steam Generation: Plan 1. Pian-Components The basic wood-fired steam generating equipment consists of three principal components: a furnace and boiler to convert wood into steam, a turbine for converting the kinetic energy in the steam into mechanical energy, and a generator for converting the mechanical energy into electricity. A wood storage yard 250' X 500! adjacent to the river is also projected. The existing diesel-driven generating equipment will be used as backup to provide generation when the wood-fired equipment is out of service. Waste heat is to be utilized and will require those components cited for other plans, with hot water as the circulating medium for the waste heat loop. This plan also includes a new 40' X 150' power plant building. (More details are shown in Appendix D.) VI-7 2. 3. 1. 2. Timing: for System Additions The completion of construction of the required facilities is foreseen by the end of 1983. Pian Description A single new wood-fired steam turbine generator is to provide the electrical needs for Tanana, and a large amount of waste heat will be produced, because the system efficiency will be low. The waste heat, however, is largely to be recovered from the furnace stack and condenser. The plan projects harvesting the wood near Tanana, transporting it to Tanana by river barge, and depositing it at a storage area adjacent to the river. (See Appendix F for more information on the possible supply of wood.) The plant is to be located adjacent to the wood storage area, and the recovered waste heat is to be piped in water lines to buildings to be used for space heating. I. Wood Gas Generation: Plan Pian Components The components for this plan will consist of two wood gasifiers, two engines that would use a 90% wood gas and 10% diesel mixture for fuel, and two 500-kW generators. (Appendix D contains more information about this plan.) A 200' x 350' wood storage area adjacent to the river and a new 50' x 120' building are also projected. Waste heat is to be utilized and will require those components described in Section C above. The existing generating equipment will be needed for backup. Timing for System Additions Construction of the required facilities is projected to be complete by the end of 1983. 3. Pian Description The plan includes a 50' x 120' building to house two 500-kW wood gas generators with gasifiers, a 200' x 350' storage area for a 12-month supply of wood, and shredder for the wood. The plant will be situated near the river to reduce the cost of moving the wood from the river barge to the storage area adjacent to the plant. The second wood gas generator with gasifier and a capacity of 500 kW will be required in the year 1983 to meet demands that are projected to exceed 500 kW. Waste heat from engine jacket water, engine exhaust, and the gasification process will be recovered to heat water and space for selected buildings in the community. (See Appendix K for information about wood harvesting and transportation.) A. 1. Economic Evaluation VII. ENERGY PLAN EVALUATION Method The economic evaluation is detailed in Appendix —. The total Present-worth costs of each plan were calculated, along with the total present worth of utilized waste heat and utilized surplus electrical energy. Evaluation Results Table VII-a shows the total present-worth cost for each plan related to supplying the electrical demands of Tanana, as well as the present worth of net benefits beyond supplying the community's electrical energy. For several of the plans, the extra benefit is usable waste heat. For the hydroelectric plan, the extra benefit is electrical energy that exceeds the projected electrical demands and that can replace propane or other fuels used for hot water heating and space heating. The net benefits of waste heat and surplus electrical energy are based on the value of the fuel that would be displaced. See Appendix E for details on fuel values. The lowest total present-worth cost minus the Present-worth value of benefits will be provided by the hydroelectric steam alternative at $13,185,000. A second low total will be Provided by the coal-fired steam plan at $15,937,000 and a close third by the wood gas plan at $16,566,000. Environmental Evaluation Community Preferences The following are preferences expressed by those citizens who attended the community meetings: o Wind Generation - Interest in wind power was expressed in the community meeting, along with the hope that wind can be harnessed to provide energy for the community. Oo Hydroelectric Generation - The owner and Operator of the power company in Tanana has a preference for hydroelectric generation, Probably on the basis of low operating and maintenance requirements. 0 Wood Fuel Alternatives - The owner and operator of the power oe A ternatives company expressed concern about Procuring the labor necessary for timber harvesting. Impact on Community Infrastructure and Employment Continuing to generate with the existing diesel system would have little or no impact on the community infrastructure and employment. A hydroelectric plan would affect community employment during the construction phase. The transmission plan, on the other hand, would reduce employment needs associated with Present diesel generator Operation. The wood-fired steam, coal-fired steam, and wood gas alternatives would require a Maintenance and operating staff of five, rather than the two now required for the diesel. The wood-fuel alternatives would also require a labor force of 14 for harvesting wood during the summer months.. The wood-fuel alternatives, with their large lapor requirements, will have the greatest impact on the community. Timing in Relation to Other Planned Capital Projects Other significant capital projects are planned during the projected construction periods, as outlined in Section IV, and are expected to generate an increase in energy use. Air Quality The plans for diesel generation, transmission, hydroelectric generation, and wood gas generation should have no significant impact on air quality. The harvesting of wood and the construction associated with the hydroelectric reservoir would cause small dust problems. The wood-fired steam plan should have no significant impact, but control of particulates may be necessary. With appropriate emission control measures, the coal-fired plant should have no significant impact on air quality. (See Appendix L for additional information.) Water Quality The plans for diesel generation and transmission should have no impact on water quality. For the wood fuel and coal alternatives, ash will have to be disposed of in such a way that it will not return to the stream. For wood harvesting, prudent forestry practices must be observed to limit runoff/silting into streams from harvest areas. Fish and Wildlife The plans for diesel generation and transmission should have no impact on fish and wildlife. For the coal and wood fuel plans, ash must be disposed of in such a way that -it will not return to the streams, and silting of streams adjacent to the harvest area must be prevented. Potential positive benefits for moose and small mammals in the timber harvest areas might result from improvement of their habitat. The reservoir for the hydroelectric alternative, however, would inundate about 600 acres of land and displace the wildlife. 7s 8. Land Use_and Ownership The plans for diesel generation will have no significant impact on the land. The transmission alternative will require a 140-mile right-of-way that will need clearing. For the wood fuel alternative, significant land planning for the harvest area must be undertaken to ensure access, minimize territorial damage, and maximize regrowth and health of available timber stocks on potential harvesting areas. For the wood and coal fuel alternatives, large amounts of ash will be Produced, and land disposal planning will be necessary. The reservoir for the hydroelectric project will require 600 acres of land. The land in and around Tanana has mostly been selected for ownership by the village corporation, Tozitna, Ltd.; a small number of tracts along the river and in the village proper are designated as "individual" native selections. Areas outside the corporation lands are managed by BLM and Doyon, Ltd. Individual selection lands, BLM lands, and the village proper have been removed from consideration as Potential harvesting areas. Terrestrial Impact The plans for diesel and coal generation will have no terrestrial impact. For the wood fuel alternatives, the impact will involve significant short-term effects of vehicle use and change in the vegetation of harvest lands. Possible permanent impacts could be caused by road construction, erosion, and significant changes in viewsheds. For the tramsmission line, Changes in the vegetation along the right-of-way will occur as long as the line is in service and the right-of-way is kept cleared. There will also be short-term effects caused by construction equipment. For the hydroelectric alternative, a permanent impact will be left by the presence of the embankment, the reservoir, and the borrowing area for the embankment. The water in the reservoir will inundate an area of trees and other vegetation and displace the small mammals and other animals now inhabiting the area. Permanent as well as short-term impact will result from the construction of the penstock pipeline. C. Technical Evaluation 1. Safety None of the energy plans can be considered unsafe. The _ wood gasification alternative, with the production of gas that can be explosive, presents the greatest safety hazard. The two plans that employ steam will have pressure boilers, which could rupture and thus Prove a safety hazard to workers. The reservoir for the hydroelectric plan is moderate in size and is to be located in a remote area; therefore, it cannot be considered a significant safety hazard. Transmission and diesel plans must be considered most safe, with almost no safety hazards involved. 2. Reliability Each energy plan involves standby generating capability. The projected diesel system plans have extra standby diesel units that can be used to produce electrical energy when needed. The same is true for the steam generating and wood gas systems. The hydroelectric system will rely on diesel generation when the reservoir level is low during periods of no flow in Jackson Creek. For its part, “the transmission alternative will probably be most reliable, but standby generation capability is also projected. The wood gasification system is complex, with many possible trouble areas that could result in use of the diesel standby units more often than for other alternatives. The same is true to a lesser extent for the steam Plans. The complex nature of the wood gas and steam plans makes those Plans less attractive. In summary, all plans with their standby diesel units must be considered reliable. 3. Availability The term availability, as used here, is a subjective assesssment of the level of confidence with respect to implementation of the plan as outlined. The assessment for each plan is as detailed below. VII-5 a. Diesel Generation with Waste Heat Recovery This plan deserves a high level of confidence, because the technology is widely used, is not complex, and does not represent a great departure from the present system. The use of the waste heat will have to be made economically attractive before building owners will wish to use the waste heat energy. This fact is applicable to all plans that use waste heat. Coal-Fired Steam Generation This plan rates a high-to-medium level of confidence. The technology has been well proven at many locations. Before steps are taken to implement this plan, community acceptance of a coal-burning plant and the associated coal storage should be determined. The coal is to be supplied by the one active coal mining operation within a reasonable distance from Tanana. The likelihood that this source of supply will continue through the years should be established before a commitment is made to adopt this plan. More thorough cost estimates should also be made. (See Appendix G for more information about coal.) d. Hydroelectric Generation This plan deserves only a low level of confidence. Hydroelectric technology is not in question, but the information that provides the basis for determining the amount of hydroelectric energy Produced is not as thorough as desired. The estimated cost for the hydroelectric facilities should also be based on more thorough information than has been developed here, such as geotechnical and topographic information. Before a commitment is made to Proceed with the hydroelectric alternative, a feasiblility study that will thoroughly formulate the project facilities and costs, along with expected flows in the stream and geolagical condition, should be undertaken. e. Transmission This plan deserves a high level of confidence. Before this plan is adopted, however, a feasibility study that will cover the availability and terms for power to be purchased, formulation of a definite alignment, questions of right-of-way, and a more nearly definitive cost estimate should be undertaken. Wood=F ired’ Steam This plan deserves an average level of confidence. The technology has been well proven at many locations, but community acceptance of a wood-burning plant, the large seasonal labor force, and the associated wood storage should be determined before steps are taken to implement this plan. A rather large continuing labor force wil be needed. The availability of forest areas for harvesting trees must also be established before a commitment is made to proceed with this alternative. (See Appendix K for more information about wood.) Wood Gasification This plan deserves an average-to-low level of confidence, because experience with wood gas plants of the type in this application is limited. Questions concerning wood also apply here, as in the wood-fired steam plan. (See Appendix K for more information about wood. ) TABLE VII-a ECONOMIC EVALUATION RESULTS 1 2 3 PRESENT WORTH COST PRESENT WORTH OF BENEFITS COLUMN 1 MINUS COLUMN TO SUPPLY ELECTRICAL FROM NON-ELECTRICAL 2 DEMAND OUTPUT Base Case Diesel $26,421,000 . -0- © $26,421,000 (Plan A) Diesel w/Waste Heat | $28,363,000 $ 9,336,000 $19,027,000 Utilized Diesel w Binary Cycle | $25,453,000 $ 6,788,000 $18,665,000 (Plan C) 4 Coal-Fired Steam $28,848,000 $12,911,000 $15,937,000 (Plan D) 5 Hydroelectric : (Plan E) $14,673,000 $ 1,488,000 . $13,185,000 6 Transmission (Plan F) $43,047,000 -0- $43,047,000 7 Wood-Fired Steam $33,798,000 : $12,911,000 $20,887,000 (Plan G) 8 Wood Gas (Plan H) $25,495,000 $ 8,929,000 $16,566,000 Table VII-a A. VIII. RECOMMENDATIONS Preferred Energy Alternatives The preferred energy alternatives are: 1. Hydroelectric with surplus electrical power 2. Diesel with waste heat utilization The preference for the hydroelectric and diesel plans jis based on economic, environmental, technical, maintenance, safety, and community preference factors. The hydroelectric plan offers economic advantages over other plans. It will have Jess environmental impact than other alternatives. The technology is simple and well proven. Maintenance should be low and it should offer no safety hazard to the community. A limited number of members of the community have also expressed a preference for the hydroelectric alternative. The diesel with waste heat utilized is not the second least costly, but it does offer other advantages. Environmental impact is small. The technology is well proven, the diesel units are now in operation, and maintenance should be relatively low. The diesel plan with waste heat utilized and with a binary cycle offers a slight economic advantage over the preferred diesel alternative. However, the binary cycle is technically more complex and is not as well proven. This is regarded as an important factor for a remote community like Tanana. The coal-fired steam plan with waste heat utilized also offers a slight economic advantage over the preferred diesel plan. However, the coal-steam alternative is complex with many cycles involved and many features that can cause problems. This is regarded as a definite disadvantage for the remote community of Tanana. The coal-fired alternative also has environmental disadvantages including air emission, ash disposal, dust from the coal storage pile, and the Presence of the large coal storage fill in the community. The steam boiler also Presents some safety hazards. The base case diesel plan offers only a small environmental impact, the technology is well proven, the equipment and personnel are now in Place but the economics with the high annual fuel costs make this alternative unattractive. The transmission plan is very costly. This fact makes the alternative unsuitable even with other advantages such as proven technology, safety, low environmental impact and simple operation. The wood-fired steam alternative with waste heat utilized is only slightly more expensive than the preferred diesel plan. In addition, like the coal-fired plan, the wood steam alternative is complex with many cycles involved and many features that can cause problems. This is regarded as a definite disadvantage for the remote community of Tanana. The wood-fired alternative also has environmental disadvantages including air emissions, require harvesting from a large area, ash disposal, and the presence in the community of a large wood storage area. The steam boiler also results in a safety hazard. The wood gas plan with waste heat utilized offers a slight economic advantage over the preferred diesel plan. However, the wood-gas alternative is complex, involving many features that subject to failure and special technical attention. The equipment required is not as well Proven as desired. The fuel demands will require harvesting from a large forest area, a large wood storage area will be required in the community and the possibility of escaping wood gas presents a health and safety hazard for the workers in the powerhouse. These features combine to rank this alternative among the less suitable. B. Required Resource Assessments and Feasibility Studies 1. 2. Resource Assessments .For the hydroelectric plan, the stream flows should be studied and gauged, if necessary, to firmly establish projected flows in Jackson Creek. The geological conditions at the dam site should be investigated and evaluated. More accurate topographic information should also be secured or developed. Feasibility Studies Before any steps are made to firmly commit to either of the preferred plans, a feasibility study should be made. The feasibility study should address the resource assessments outlined in the previous Paragraphs. The study should also formulate plans that would more definitely identify project features so more reliable cost estimates can be made. The study should identify any critical features that may prove a hindrance in implementing the project. The study must be prepared in thorough detail to provide a sound basis for the Authority to select an alternative. APPENDIX A COMMUNITY MEETINGS Two community meetings were held regarding this study, one on September 10, 1980, and the other on January 30, 1981. Notes on the two meetings are shown on the following pages. The community meeting dates were posted at the Village Council Hall and at the village store several days before the meetings were to be held. It should be noted that few persons attended the meetings to express their concerns and energy preferences. COMMUNITY MEETING NOTES September 10, 1980 Notification Procedure Mr. Steve Schwab, Village Administrator, posted meeting notices in Tanana on September 9, 1980 to inform the Public that a Public Meeting would be held in their community hall to hear and discuss the Tanana Reconnaissance Study regarding energy requirements and alternatives. Attendance The Public Meeting was held on September 10, 1980 at the Village Community Hall-at 1:30 p.m. and those present were: Mr. Steve Schwab, Village Administrator, Tanana Mr. Kurt Lotspeich, Pilot, Tanana Air Service Mr. Clifton Eller, Tanana Power Co. Mr. Carl Fick, Brown & Root, Inc., Houston Mr. Joe A. Marks, Marks Engineering, Anchorage Content of Meeting & Public Comment Mr. Marks opened the meeting by stating that Marks Engineering/Brown & Root had been retained under contract by the Alaska Power Authority to conduct a Reconnaissance Study and that the objective of the Tanana Power Reconnaissance Study of Energy Requirements and Alternatives was to identify the electric Power requirements of the Village of Tanana and to identify and assess the alternative available. Mr. Marks explained that the Reconnaisance Study would Survey all the alternative power sources available to the community and would evaluate economic and environ- mental merits of the alternatives. Mr. Schwab asked if the study would address alternative energy sources for individual homesteads; Mr. Fick responded that the scope of the study did not include alternative energy sources for individual homesteads, rather, that the study would focus on the Village of Tanana, its energy requirements and the alternatives available to serve the village as a whole. Mr. Lotspeich asked if the the study would address wind power in Tanana and if so, how would data be otained; Mr. Marks replied that it would address wind power and that wind data would be obtained from the FAA Flight Service Station in Tanana. Mr. Lotspeich offered that the U.S.A.F. White Alice site near Tanana may have addi- tional wind data and should be contacted, although the site has been closed down recently. Mr. Lotspeich asked for the alternatives that would be addressed by the study; Mr. Marks responded that diesel, diesel-waste heat recovery, wood fired stear, wood gasification, coal fired steam, hydrcelectric, wind, and interconnection would be addressed. Mr. Marks Stated that the hydroelectric site reconaissance would be carried out by Ott Water Engineers on a separate contract with the U.S. Corps of Engineers, and that Marks Engineering/Brown & Root would review their fin- dings to incorporate the evaluation in the Preliminary Tanana Reconnaisance Report to be submitted to the Alaska Power Authority by January 31, 1980. Mr. Schwab offered that Ott Water Engineering would be in Tanana on September 15, 1980 to conduct their meeting. Mr. Schwab offered that the village of Tanana has purchased an anemometer and a small tower to obtain wind speed readings at the top of Mission Hill just east of Tanana. Mr. Schwab stated that the intent of the Village was to restore the old Mission near the hill and wanted to restore the wind generator that was on top of Mission Hill also. Mr. Fick offered that the anemometer should be placed in accordance with the manufactaurer's instructions. large output or reliability were not factors were suc- cessful for the most Part, on the other hand, large Power wind generators have not yet proven reliable, that they are not economical in areas where average wind velocities are less than 14 miles per hour. Mr. Lotspeich offered that an Alaskan manufacturer of wind power generators quoted a price of $8,000 for a 2.5 kw wind generator, installed. Mr. Marks added that a backup generator and/or battery bank would be required to compensate for the times when the wind does not blow and would drive the cost to about $15,000. Mr. Schwab offered that coal could be obtained upriver on the Yukon River at 12 Mile (about 12-16 miles upstream. from Tanana), that a blacksmith used it in his forge. Mr. Eller offered that the coal was. hard, black, and shiny, that it burned with little ash residue and sulfur could be smelled. Mr. Eller stated that he had been at the site and that the coal seam was inclined, possibly 7-8 foot thick, and that coal mining had taken place at the turn of the century to fuel the steamboats that Plied the Yukon River. The location of the coal was said to be near Coal Creek. Mr. Schwab requested the cost of the Reconnaisance Study. and asked if funds would be available to conduct wind measurements; Mr. Marks responded that $35,000 had been made available for the study and that it did not include funds for wind measurements, that existing wind data would be obtained from FAA records to assess the wind potential. Mr. Fick offered that small wind generators could be used to heat water if and when the wind blows stating that reliability and frequency regulation of the gener- tors output would not be critical in this application. Mr. Lotspeich asked if geothermal would be addressed; Mr. Fick stated that it would not. Mr. Lotspeich offered that fuel oil prices in 1979 were 1.29 per gallon and 1.55 per gallon, 56.00 for 100 lbs of propane, 2.20 for aviation gasoline, 1.72 per gallon for automotive gasoline, and 60-70.00 per cord of wood, usually driftwood snagged from the Yukon River, spruce and birch. Mr. Lotshpeich offered that his home (1200 sq.ft.) was heated with oil and wood during the winter, that only 800 sq.ft. was heated to conserve oil, that his annual feasibility Study, and then by construction Starting in 1983 or 1984, the study of all sources referenced; Mr. Marks and Mr, Fick agreed that a bibliography would be included. consisted of young spruce and birch trees, that the Army used to cut wood from the surrounding area to heat Fort Gibbons. Mr. Eller Stated that wood could be obtained for about 60-70 dollars per cord if people could be found to do the work. Mr. Eller stated that there was no skilled labor pool in Tanana capable of constructing large facilities, Mr. Marks inquired as to the amount of fuel oil storage for the PHS Hospital, FAA, Tanana Power Co., School, and other large users. The following was offered: PHS Hospital 140,000 gallons storage FAA 80,000 School 30,000 Tanana Power Co, (storage provided by Coghill Fuel) Coghill Fuel Co. 310,000 USAF Site 300,000 (closed down) Mr. Eller offered that his generating capacity consisted of one 800, one 500, one 350, and one 300 kw diesel generators, that annual power generation was approxima- tely 2,000,000 kwhr. Copies of these notes have been forwarded to the following persons: Mr. Steve Schwab, Village Administrtor, Tanana Mr. Cliff Eller, Tanana Power Co. Mr. Carl Fick, Project Manager, Brown & Root -~ J.A. Marks, P.E. LECEIVED SEP 16 1980 BROWN & RUvI, IN” ee. TANANA RECONNAISANCE STUDY January 30, 198) COMMUNITY MEETING NOTES OF MEETING HELD IN TANANA, ALASKA ON JANUARY 30, 1981 AT THE COMMUNITY HALL THOSE ATTENDING: Mr. Mr. Mr. Mr. Mr. Mr. Mr. 1. 7. Mark Choate Tanana City Council Kurt Lotspeich Tanana Air Service Paul Verhagen Native Store Manager Tom Mogg Tanana John Huntington Tanana Jerry Larsen Marks Engineering/Brown ¢ Root Joe Marks Marks Engineering/Brown ¢& Root investigated and evaluated with a brief discussion regarding the technological, environmental, safety, reliability, availability, and economic aspects. bility for utilization in Tanana. A summary of the alternatives evaluated and selected was Passed out to all the Participants for their review and comment, and is attached as Exhibit I of this report. Mr. Marks explained that the Coal-Fired Steam utilizing all the waste heat throughout the entire year was evaluated as the most economical but the least desireable from environmental, technological, and safety standpoints throughout the twenty year evaluation period. Mr. Marks explained that it was not reasonable to assume that all the waste heat could be utilized during the entire year since summer use for space heating is minimal. Mr. Verhagen inquired if hydrogen production by the electrolysis of water had been considered; Mr. Marks responded that it had not 10. ll. 12. 13. 14. 15. 16. been considered due to the inefficiencies of the cycle to produce the hydrogen gas. utilized to serve the Village Safe Water facility; Mr. Marks stated that waste heat recovery from the present diesel genera- tion was a promising alternative and could supply heat for the large users such as the Safe Water Facility, the Public Health Service Hosipital, and the High School. Mr. Mogg stated that discussions were held with Tanana Power Co. to recover waste heat from the diesel generators to serve the Village Safe Water Facility but action had not been yet taken. Mr. Marks explained that the alternative Plan called for relocating the plant next to the Safe Water Facility so that waste heat could be utilized to serve it. Mr. Marks explained that waste heat recovery from the diesel generation system looked very attractive in the short run, 5 to 7 years but after that, the economics were not as attractive as hydro since the cost of fuel oil was expected to increase in the long run. : Mr. Verhagen inquired about a vapor phase system utilizing waste heat from the diesel generation; Mr. Marks responded that a diesel binary cycle using a vaporizing fluid in a closed system was eva- luated and consisted of a small turbine putting power back into the mechanical shaft or driving a small, auxiliary generator. Mr. Lotspeich stated that Fish and Game were looking for a winter supply of water for fish Spawning in the nearby creeks, that Perhaps a hydroelectric dam could Supply that water and more fish would eventually be available for harvesting by the local fishing industry. Mr. Mogg and Mr. Choate indicated that the Public Health Service Hospital was to be turned over to the Village but that there were reservations on the availability of funds to continue with its Operation. They also indicated that the Village Safe Water was a very expensive operation to operate. Mr. Larsen indicated that many of the homes were not properly insulated, that substantial savings could be realized if proper insulation were installed in most homes; there was general agreement among the participants that most homes could benefit from proper insulation. Mr. Marks indicated that wood fuel was an excellent substitute for fuel oil in space heating of homes, that it represented the lowest cost fuel available in Tanana. Participants indicated that most of the wood was snagged from the river during the spring floods. Mr. Marks stated that a preliminary wood resource assessment around Tanana indicated that a plentiful Supply of wood could be harvested across the river from Tanana. Mr. Verhagen stated that he had contacted the Bureau of Land Management Office in Fairbanks to obtain permits to harvest wood A-8 17. 18. 19. 20. upriver from Tanana, but that the official had indicated an unwillingness to cooperate or provide information due to Staffing problems. Mr. Marks stated that there was a possibility that a hydroelectric dam and power generation source could be developed on Jackson Creek that could serve the community of Tanana for well over 20 years, that electricity could possibly replace the use of cooking with propane but not for Space heating. Mr. Lotspeich indicated that the anemometer acquired by the Village last year had not yet been installed but that there were Plans to install it soon. Mr. Marks asked the Participants if they had any objection to hydroelectric power generation, none of the Particpants had any objections; Mr. Lotspeich indicated that a hydro plant would last much longer than a coal fired Plant which would have to be replaced in twenty to twenty five years. Mr. Mogg and Mr. Choate inquired as to the next step beyond the reconnaisance study; Mr. Marks responded that the Draft Reconnaisance Report would be submitted to the Alaska Power Authority for their distribution and review. The Power Authority could then select one or two of the most promising alternatives to conduct a Feasibility Study and determine the best source of electrical and heat energy for Tanana in the coming years. EXHIBIT I TANANA RECONNAISANCE STUDY JANUARY 1981 RATINGS OF ENERGY RESOURCE TECHNOLOGIES RATING 40 23 20 18 30 30 29 19 14 20 28 43 6 39 35 * EVALUATION OF SELECTED ALTERNATIVES A-10 Hydro Trans Diese Wood Coal 1 RELIABILITY COMMUNITY PREFEREN Hydro Trans Diesel Wood Coal SUMMARY TECHNOLOGY 1 Coal-Fired Steam 2 Conservation 3 Gas Turbine 4 Geothermal 5 Hydroelectric 6 Diesel Oil 7 Diesél Oil/Binary Cycle 8 Peat Conversion 9 Solar 10 Solid Waste Conversion 11 Transmission Line 12 Waste Heat ( 13 Wind 14 Wood-Fired Steam 15 Wood Gasification * These alternatives were selected for further study. CRITERIA ECONOMIC ENVIRONMENTAL TECHNOLOGICAL SAFETY Coal Hydro Hydro Wood Diesel Diesel Hydro Trans Trans Diesel Wood Wood Heat Diesel Coal Coal Binary SS APPENDIX B DATA: ON EXISTING CONDITIONS AND_ENERGY BALANCE Data on existing conditions and energy balance were gained by investigations at the site. The results of the investigations are shown in the trip report by Mr. Joe Marks on pages B-2 through B-8. a7 ’ ’ ‘ TANANA RECONNAISANCE STUDY APPENDIX B REVISED MARCH 2, 1981. FIELD REPORT-ENERGY BALANCE-TANANA Et BALANCE~TANANA I arrived at Tanana Airport on January 15, 1981. The Wien Agent gave me a ride to the hospital where Karla Bonney, Hospital Administrator, checked me into a room in the old nurses quarters, While still at the hospital, I met Vern Eller, Tanana Power Co. Operator, explained what My purpose was, and then drove to the village offices to meet Steve Schwab, City Manager, and Mike Andon, Village Corporation President. After an explanation to the officials of what information was needed they agreed to help. Vern Eller and I left the City Offices and went to the Safewater Building. We talked with the Assistant Manager and explained what. information I wanted. All the fuel records had been sent to Fairbanks to an accounting firm and were not available. Vern then drove me to the hospital for dinner and arranged for a thorough “walk thru" of the village on Friday. ‘ On Friday, I met with the Manager of the Alaska Commercial Store. I explained the data required and its end use. He was very cooperative and provided the data I needed. (See data sheet) My second stop was -at the Native Store. I went through the same explanation, etc. This store manager was also very helpful. data sheet). (See I then proceeded to the hospital for lunch but was too late, everything had closed up. REVISED MARCH 2, 1981 I interviewed the Maintenance Manager at the hospital, who is also the Mayor, and received good information on both the hospital use and residential uses. From the hospital, I walked to the school and met with the principal. He had fuel records for 1979 and 1980, for the school only, but not for. the Vocation Education Building. He suggested I call Charlie Channey, in Nenana. All records are kept by the Yukon/Koyukuk School REAA in Nenana. The principal also provided information on the four trailers used for teacher housing. I then met with Vern Eller at the Alaska Commercial Store. Vern and I walked to the Coghill Fuel Depot:'and measured all fuel tanks. Vern informed me of the fuel that Tanana Power Co. had stored in the tank farm, and will have to estimate the particular type of fuel in the balance of the tanks. All tanks were locked and no one was in town to verify what material was in each tank. Vern and I then walked to the Safe Water Building and measured their fuel tank for capacity. They have only one tank and had consumed. 40-45% of the tank at the time of the inventory. Besides the managers or maintnance people interviewed for the commer- cial establishments, an additional 20-25 residents were interviewed for individual fuel uses, insulation in homes, etc. Through several walk-through inspections of the residences enroute to commercial establishments, several notes and photos were taken for the overall end use of product by the residential consumer. (3) 35,000 gallons yearly 1,200 gallons STATE DIVISION OF AVIATION 6,000 gallons yearly 90 drums #1 Arctic (psl00) stove oil Regular gas #1 Arctic stove oil Regular gas - 4,950 gallons REVISED. MARCH 2,, 1981 REVIEW OF RESIDENTIAL HEATING REQUIREMENTS a EES REET REMENTS There are approximately 100 residences in Tanana: 5 - conventional frame 9 - trailers 86- log construction (estimated) Company housing for hospital and FAA personnel were not included with residences, but rather a part of commercial, for fuel purposes. Most all individual residences have installed or are installing wood burning stoves, predominantly oil barrel types with a pot burner stove as a back up for the woodstove. It is estimated that 85-90 residents have, or sometimes use, an oil pot burner stove with 4-5 using gun-type forced air or hydronic systems. Of the residences surveyed, °85-90% of all homes use wood heat to some extent. The estimated use of cord wood used ranges from 10-15 cords per year, depending on the size of residence and temperature. This year is very mild and esti- mated use is from 6-12 cords per year. While propane is utilized in over 90% of all residences, cooking with wood on the stove top is pre- ferred by approximately 10% of the people. Stack robbers are utilized in approximately 25 homes to increase the efficiency of the stove. In interviews with the residents, I found that most homes five years old and older have no ceiling or floor insulation. exclusively of log construction. These are almost The ceilings are open pole type with plywood on shiplap roofing with sheet metal covering. Floors are built over log Sleepers with plywood or plank overlay. An estimated 10% of the houses use an Arctic storm entrance and perhaps an additional 30% of the houses have a three sided porch with no door. I assume this area prevents snow infiltration and provides a limited shelter for snowshoes, etc. Thermo-pane windows were evident only on the newest buildings and homes. An estimated 45-50% of the older homes used a Plastic covering over the windows. to retard infiltration. Most of the log homes are older and partially buried in the ground giving an overall: low silhouette to the structure. B-4 REVISED MARCH 2, 1981 ‘ The residents of the community of Tanana are rapidly converting to ‘wood use.in all private homes. Wood appears to be in sufficient supply and a viable alternate to oil heat. The total quantity of wood used by the residents, by year, would amount to an estimated 1000 to 1500 cords. While exact figures or estimates were not available, I was informed by several people that during break-up, many trees and drift logs come down the Yukon. The people snag the logs as they pass both from the bank and from boats. They obtain as Many logs as possible from the river and cut standing timber only as required. The fuel oil supplied for residential heating loads has in years past _averaged 50,000 to 60,000 gallons of stove oil #1 Arctic. However, with the conversions to wood, this year's stove oil use should be con- siderably less. The trend, interpreted from interviews, is likely to continue in conversion to a wood heat source. There are many improvements which could be utilized in residential heating. The first item of improvement would be in the heating envelope. Insulation should be installed, storm entries built, thermo panes and or storm windows installed, and stack robbers installed. Interior space temperatures need to be lowered from 75-80 degrees F to- 68-70 degrees F resulting in lower fuel consumption. ‘ All commercial installations are oil heated, including the commercial housing units. The type of heating used varies from low pressure steam, hydronic, and forced air depending on the type of end use.. B-5 TRIP REPORT TANANA - ENERGY BALANCE - DATA SHEET eee ee eee eer ALASKA COMMERCIAL STORE - SALES: SS SURES SALES 3 200 - 100 lb. tanks of propane 700 - 5 gallon cans regular gas 100 - 55 gallon drums regular gas pe aeapecty Se Leltel oA for fishing and trapping. 45 - 5 gallon cans Blazo og 25 cases - 1 gallon cans Blazo Fishing and trapping Store use - 4,500 gallons of #1 fuel oil for space heating Storage for 9,500 gallons NATIVE STORE SALES: Note: All records at auditor in Fairbanks, but found most receipts 64,000 gallon Regular gas (estimated) : . Based on 23,993 gallon ordered and 10,000 gallon ordered for 6 months use. 250 - 1 gallon cans Blazo 125 - 5 gallon cans Blazo 1-55 gallon drum Kerosene AVIATION GAS Storage - 7,000 gallons - 80/87 7,000 gallons - 100/130 7,000 gallons - Jet B Estimated Sales by Tanana Air Use - 3,000 gallons/yearly - 80/87 20,000 gallons/yearly -100/130 plus Fairbanks purchases 7,000 gallons/yearly - Jet B Estimated 3,000 gallons yearly - #1 fuel oil space heat for Native Store PHS HOSPITAL Annual average purchase - 140,000 gallon ‘#1 fuel oil based on an average of 120,000/160,000 gallons. depending on use, by stand-by generator set and weather severity. Also 10-100 lb. bottles of propane for the incinerator. B-6 (2) REAA YUKON- KOYOKUK SCHOOL DISTRICT jj DISTRICT 20,000 gallons - 1979 24,000 gallons - 1980 30,000 gallons - capacity Note: Principal did not have figures for Vocational Educational Building, but uses 1,000 gallon Storage tank for supply. He suggested I call Charlie Channey at Nenana for specific information. Estimated 2500/3000 Gal. per year. School Housing - Four house trailers 1,000 gallons each - 4,000 gallon per year total. COGHILL TANK FARM eA Tank #25 - 1 - 25,000 gallons #1 Diesel - Eller - Tanana Power Co. 25 - 2 = 25,000 gallons #1 Diesel - Eller - Tanana Power Co. 1 - 10,137 gallons 2- 10,214 gallons 3 - 10,132 gallons Note: Vern Eller stated 4 - 10,127 gallons Tanana Power Co. has 5 - 10,132 gallons 150,000 gallons in this 6 - 10,296 gallons tank farm ‘ 7 - 10,205 gallons 8 - 10,325 gallons 2 each 25,000 gallon plus 9 - 10,132 gallons 5 each 10,000 gallon tanks 10 - 10,130 gallons 11 - 10,125 gallons Note: Also at Coghill Tank: Farm 1 - Oval truck tank on logs apparently full and locked with unknown material stored. 1 - Small oval truck tank, on logs, full and locked with unknown material stored. i - Underground tank, lid. locked, no known.capacity or materials contained. No one in town to help. Mike McCann out of town till February, Steve ? out of town 40 miles on trapline. Both of these people work for Coghill. SAFEWATER FACILITY ee tt 1 - tank - 8' diameter x 14' long estimated 5,462 gallons capacity, filled this fall, estimated 40% use to January 15, 1981. Also noted 80,000 gallon tank located on tundra - behind Safewater Facility, owned by Coghill, for possible use by powerhouse if moved. Tank empty. (2) REAA YUKON=- KOYOKUK SCHOOL DISTRICT 20,000 gallons - 1979 24,000 gallons - 1980 30,000 gallons - capacity Note: Principal did not have figures for Vocational Educational Building, but uses 1,000 gallon storage tank for supply. He suggested I call Charlie Channey at Nenana for specific information. Estimated 2500/3000 Gal. per year. School Housing - Four house trailers 1,000 gallons each - 4,000 gallon per year total. COGHILL TANK FARM A FARM Tank #25 - 1 = 25,000 gallons #1 Diesel - Eller - Tanana Power Co. 25 - 2 = 25,000 gallons #1 Diesel - Eller - Tanana Power Co. 1 - 10,137 gallons 2 - 10,214 gallons 3 - 10,132 gallons Note: Vern Eller stated 4 - 10,127 gallons Tanana Power Co. has 5 - 10,132 gallons 150,000 gallons in this 6 - 10,296 gallons tank farm , 7 - 10,205 gallons 8 - 10,325 gallons 2 each 25,000 gallon plus 9 - 10,132 gallons 5 each 10,000 galion tanks 10 - 10,130 gallons 11 - 10,125 gallons Note: Also at Coghill Tank: Farm 1 - Oval truck tank on logs apparently full and locked with unknown material stored. 1 - Small oval truck tank, on logs, full and locked with unknown material stored. 1 - Underground tank, lid. locked, no known..capacity or materials contained. No one in town to help. Mike McCann out of town till February, Steve ? out of town 40 miles on trapline. Both of these people work for Coghill. SAFEWATER FACILITY eet 1 - tank - 8' diameter x 14! long estimated 5,462 gallons capacity, filled this fall, estimated 40% use to January 15, 1981, Also noted 80,000 gallon tank located on tundra - behind Safewater Facility, owned by Coghill, for possible use by powerhouse if moved. Tank empty. APPENDIX C TRSAC ENERGY FORECASTING PROCEDURE AND CALCULATIONS Tanana Population and Housing Data 1970 census data: 406 persons 1980 census data: 400 persons (estimated) 2000 population projection 600 persons (400 x 1.02/year, calculated) 1970 housing units 122 housing units 1980 housing units 145 housing units (estimated) Tanana Electric Energy Consumption Data Annual kilowatt hours, residential 679, 948 (1979) Average residential customers 134 (1979) Annual energy consumption/customer 5,000 kwhr/year Alaska Village Electric Coop. (48 villages) Average annual energy consumption/cust. 2,200 kwhr/year Anchorage Average annual energy consumption/cust. 9,600 kwhr/year Tanana Power Co. residential rate $ 0.31/kwhr Alaska Village Electric residental rate $ 0.37/kwhr Chugach Electric residential rate $ 0.04/kwhr Recent Energy User Additions 1980 Fish Processing Plant 150 kw load, seasonal 1980 Bureau Land Management Camp 50 kw load, seasonal 1980 Village Safe Water & Laundry 50 kw load, year-round Projected Energy User Additions 1981 Twenty six new Housing Units 50 kw load, year-round 1981 Cold Storage Facility 50 kw load, year-round 1981 Community Building 10 kw load, year-round Assumptions Due to increased economic activity and additional housing units in Tanana, population is expected to increase at an assumed rate of 2% per year. Due to recent and projected additions of large, medium, and residen- tial power users, electric energy consumption is assumed to increase at an assumed rate of 3% per year and takes into account the seasonal nature of the Fish Processing and Fire Fighting loads. The seasonal loads occur during the summer months and are not expected to impact the winter peak loads now experienced in Tanana. However, C-1 these loads will improve the utility's load factor and provide for better utilization of generation capacity now installed. The appliance saturation level is not expected to increase signifi- cantly since residential consumers in Tanana now consume twice as much energy as the average of the 48 AVEC Villages and the cost of electric energy is expected to increase due to increasing fuel oil prices. C-2 €-9 vom TANANA POWER CO. ANNUAL DATA YEAR PEAK DEMAND GROSS GENERATION COMM. KWHR RES. KWHR OTHER KWHR M & O EXP. FUEL OIL EXP, . FUEL OIL UNIT EXP. ~ RW Kwhr Kwhr ~ Kwhr Kwa > > ‘$7 kwhr 1973 na 1,661,326 1,190,984 470,342 na na 37,448 +0225 1974 na na na : na na “ona na na 1975 425 1/ 1,724,551 1,182,800 437,541 104,210 12,294 3/ 78,355 -0454 1976 425 1/ 1,757,446 1,196,799 452,197 108,450 9,745 3/ 140,480 0799 1977 425 1/ 1,706,630 2/ 1,171,600 2/ 535,030 na 4,799 3/ 142,580 -0835 1978 na 1,736,722 2/ 1,029,840 2/ 706,882 na 32,269 155,595 - 0896 1979 500 1/ 1,579,224 2/ 899,276 2/ 679,948 na 49,409 147,915 0937 1980 base 470 2,000,000 4/ 1,200,000 700,000 100,000 60,000 260,000 base year -1300 year NOTES: 1. Peak demand figures have been estimated; there are no reliable recording instruments or Plant logs to indicate demand. 2. The annual gross generation figures are low since generation equipment was down part of the time and large power users were required to utilize their standby generation equipment; note 1979 commercial kwhr. 3. The annual maintenance and operating figures do not represent wages and eependitures actually expended in the operation of Tanana Power Co.'s equipment; qanana Fower Co.'s accounting has consis ently understated these costs by not including the Owners’ actual labor in operating and maintaining the equipment, 4. The 1980 figures have been assumed taking note of the generation and cost understatements in the Previous years and arriving at’a reasonable set of data for’ the base year. C-3 Annual Report v2 Year Ended eee 31, .19:79 Sere mere ererersens ‘Ly peat ae) a eee Eo ae a SALES OF ELECTRICITY BY RATE SCHEDULES SE ees “Number and Title of Rate Schedule * KWH Sold Revenue Number of Customers KWH of Sales Per Customer Revenue Per KWH Sold (Cents Residential 127,055 5,074 18.7 Commercial 128,269 365,638 17.5 Large 22032 168,000 13.1 Interest PARTICULARS CONCERNING NON-UTILITY DEDUCTIONS ACCOUNTS eee Item —_ os ES NUMBER OF EMPLOYEES : gg 1. Total regular full-time employees 2. Total part-time and temporary employees 3. TOTAL EMPLOYEES dt Aunual Report of .LAWANA .ROWER..CO........ er Year Ended Vecawber,.31,.1979..... ELECTRIC ENERGY ACCOUNT Llowatt Hours ~~” guees of Energy | REL To Sources of Energy Generation Purchases Total Disposition of Energy Sales : Energy Furnished Without Charge Energy Used by the Company Energy Losses Total Energy Loss as a Percent of Total of Sources of Energy 5 ee ~S 1,579,224 1,579,224 1,373,239 “0 137,323 ~ 68,662 : 4% estiamted MONTHLY PEAKS AND OUTPUTS MONTH January 508 February 450 March 346 April 258 May . . 167 June . 162 July 177 | August 175 September 277 October 300 November 330 December 351 Total Note: MONTHLY PEAK MONTHLY OUTPUT 229, 048 202,893 . 155,910 116,392 Se = 75,1527 =. 5 733134 79,971 79,070 125,074 135,382 148,994 158,199 This total should agree with the total Sources of Enerpy on Electric Energy Account Schedule above. ELECTRIC DISTRIBUTION METERS AND LINE TRANSFORMERS Number at beginning of year Additions during year: Purchases Associated with utility plant acquired Total Additions Reductions during year: Retirements Associated with utility plant sold Total reductions ‘Number at end of year Line Transformers umber of weet coer _| hour meters Total | wonder | Capacity (KV. APPENDIX D TECHNOLOGY PROFILES This appendix presents a brief outline of the technology of each energy plan. A’ summary of more important facts for each plan is shown in Table D-13. Costs are projected in Appendix E. Ts Base-Case Diesel Generation Sat reset veneration a. General Description The existing equipment is to be housed in a new 30' x 100! building (see Plate D- 1) and is to be used to generate the needed electrical power. (1) Thermodynamic and Engineering Processes Involved The existing diesel generators involve well-proven thermodynamic and engineering processes that are widely understood and accepted. The diesel engines drive generators that produce. the electrical power. (2) Availability Diesel generating units are available from many manufacturers and suppliers. Performance Characteristics racer istics (1) Energy Output The performance characteristics for the existing diesel units are shown in the diagrams of energy balance and performance on Plates D-2 and D-3. Optimal diesel engine efficiency is approximately 33% for the size of engines presently utilized in Tanana. However, the average overall plant efficiency for Tanana Power Company has been calculated at approximately 25% from oil to wire. The daily, seasonal, and annual dynamics of the system will parallel the electrical demand, as shown in Section III of this report. (2) Reliability (a) Backup A backup unit is needed and is included in this base-case plan. (b) Storage Requirements now include fuel oil storage only, since electrical energy from the generators cannot be stored. (3) Thermodynamic Efficiency The efficiency, shown on Plates 0-2 and 0-3, is 25%. C. Costs (1) Capital Capital costs ($191,000) for this base case include costs for construction of a new power plant building, and installation of the existing units (1,950 kW total capacity) in the new building, as listed in Table D-1. (2) Assembly and Installation Assembly and installation costs represent most of the $191,000. D-2 (3) Operation and Maintenance Costs Operating and maintenance costs for the diesel base case are Projected to be $57,000 per year on the basis of published reports by Tanana Power Company to the Alaska Public Utilities Commission. Fuel costs for the base case have been obtained from published reports by Tanana Power Company to the Alaska Public Utilities Commission. The diesel fuel cost for 1980 has been about $1.80 per galloon. (4) Cost Per Kilowatt Installed The cost per kW installed is the capital cost divided by installed capacity or $191,000 divided by 850 = $225 per kW. (5) Economics of Scale Not applicable d. Special Requirements and Impact (1) Siting The new powerhouse building is to be located at the present Powerhouse site. (2) Resource Needs No renewable resources will be required. The major nonrenewable resource is the fuel oil (17,807,000 gallons) that will be needed for the 54 years of operation projected here. Construction and Operating Employment There are no special requirements for the continued operation of the existing diesel generation units to meet Tanana's energy requirements. The generation equipment, fuel oil storage and e. (4) handling facilities, the fuel oil distribution network, and the local operating labor supply have been in place for several years. Construction labor will be needed to build the new powerhouse and to move the existing units into the new building. Environmental Residuals - None Health and Safety Aspects The health and safety aspects associated with the diesel generation are minimal. Summary and Critical Discussion (1) Summary - The production of electrical energy by continuing to utilize the existing diesel-powered generators is projected here. The system efficiency is 25%, and the existing system is safe and reliable. A new power plant building is projected. Capital costs and operating and maintenance costs are low, but fuel costs are high. The projected present-worth cost for electrical energy is $0.15 per kWH or $43.53 per million Btu. This is based on information developed in Appendix E£. Environmental impact from fuel oi] handling and combustion is considered minimal. Critical Discussion aott ical Viscussion The diesel power generation system is becoming increasingly expensive to operate in view of escalating fuel oil prices. Long-term detrimental economic effects in Tanana will continue under this plan. The only major disadvantage of continuing with the present diesel system is the high fuel costs. The technology is simple, proven, reliable, available, and safe; it is appropriate for the community, except for fuel costs. 2. Diesel Generation with Utilization of Waste Heat eee ization of Waste Heat a. General Description The existing diesel units in this plan are to be equipped with waste heat recovery systems that will take heat from both the jacket water and the exhaust. The recovered heat will be piped to buildings for water heating and space heating. The existing plant building will be abandoned and the plant relocated at another site, where a new 36' x 100' building (see Plate D-4) would be built to house all of the units and where the waste heat could be recovered and transported economically. (1) Thermodynamic and Engineering Processes Involved The existing diesel generators involve well-proven thermodynamic and engineering processes that are widely accepted. The technology to recover waste heat from diesel engines is now available. One example of successful heat recovery from diesel engines is at the San Jose/Santa Clara Water Pollution Control Plant in San Jose, California. Waste heat from both jacket water and exhaust gas would be recovered through packaged units and then piped through buried, insulated pipe to the village safe water facility, the Public Health Service hospital, the high school, and other buildings where the heat would be used. (2) Current and Future Availability Many types and sizes of heat recovery units are currently available worldwide at favorable costs and will undoubtedly be available in the future. The use of heat exchangers with diesel generation is a relatively simple _ application requiring modest capital investments in heat exchangers. A cross section of a heat recovery unit is shown on Plate D-5. b. (1) Performance Characteristics Energy Output The performance characteristics for the diesel system with waste heat recovery are shown in the diagram of energy balance on Plate D-6, and the diagram of performance is shown on Plate D-7. The diesel generating system would be operated to Produce the required 178,070,000 kWH of electrical energy through the year 2034. The projected waste heat energy resulting from electrical Power production that is projected to be utilized is 850,000 million Btu. The optimal diesel engine efficiency is about 33% for the size of engines presently utilized in Tanana. The sustained overall thermal efficiency for Tanana Power Company has been calculated at approximately 25% from oi] to wire, however. The lower 25% efficiency results from the fact that load variations do not always allow the engines to operate at their maximum efficiency points on the performance curves. The 75% loss is encompassed of about 31% to the cooling water jacket, 32% to exhaust, and the remaining 12% to miscellaneous losses, such as heat loss to lubrication oil, radiation, and generator efficiency. With the waste heat recovery system, the overall efficiency will increase to as high as 67%. This plan would utilize a large percentage of the heat now being wasted, since a substantial amount of the present 75% wasted energy is recoverable. The 31% entering the cooling water jis almost all recoverable, and a substantial portion of the 32% lost to the exhaust usually can be recovered, although this is limited by temperature and back pressure conditions imposed by the manufacturer on a particular model. Under a few circumstances, some of the 12% miscellaneous losses may be recoverable, but this is not considered significant, and no assumption to utilize it has been made in this reconnaissance study. It is probable that the miscellaneous losses provide a useful function in the Tanana climate by maintaining powerhouse space at an acceptable working temperature. (2) Several manufacturers in the U.S.A. produce equipment for extracting heat from the water jackets and exhausts of stationary diesel generators. Separate heat exchangers can be provided for each system, something of a customized design, or a standardized package that combines extraction of heat from the jacket water and exhaust in one unit can be obtained. For the existing diesel generators at Tanana, the standardized packaged unit is considered the most favorable in terms of cost, installation, and space requirements. The operating principle of such a unit is shown in Plate D-5. Exhaust gases are used to raise the temperature of jacket water to produce low-pressure steam at 15 psig for space heating or other purposes. A typical unit, tradenamed "Vaporphase," is supplied by Pott Industries of St. Louis, Missouri 63111. The manufacturer claims that the heat recovered by the Vaporphase unit from the jacket water and exhaust raises maximum overall thermal efficiency of a diesel system to in excess of 75%. In this plan, an overall thermal efficiency of up to 67% is assumed. Plate D-8 shows a typical installation of a Vaporphase packaged heat recovery unit in relation to the diesel generator. Waste heat amounting to 35% of the total energy input is projected to be put to beneficial use or 850,000 million Btu over the period 1983 to 2034. The daily, seasonal, and annual dynamics of the system will parallel the electrical demands, as shown in Section III of this report. It may be advantageous to provide a moderate-size hot water heat storage tank to balance more nearly the space heating demands and the waste heat available for use. This matter will require “further study and evaluation if this plan jis considered for adoption. Reliability (a) Backup The reliability of a well-maintained diesel generation and waste heat recovery system is judged to be good and is based D-7 on their long operating experience throughout the world. However, a backup is needed and is provided in this plan, using the extra existing units. Diesel generators must be shut down periodically to replace the lubricating oil contaminated by combustion and to perform preventive maintenance. Periodic maintenance of the circulating liquid system components is also a requirement. A well-maintained diesel engine generator and waste heat recovery system can last up to 30 years without major rebuilding, although the average period between major overhauls of the engine is approximately 16 years in Alaska. (b) Storage Storage requirements include fuel oil storage only. Electrical energy from the generators cannot from a Practical point be stored. A hot water storage tank to store a moderate amount of waste heat could be madé a part of the heating system, but it is not projected here. (3) Thermodynamic Efficiency The efficiency is shown on Plate D-6 and is 67 percent when waste heat is utilized and only 25 percent when waste heat is not utilized. There will be 2,420,000 million Btu input, 607,000 million Btu electrical output, and 850,000 million Btu waste heat utilized over the next 54 years. Not all the 42% recoverable heat shown on plate D-6 can be utilized.in the summer months. Therefore, the overall 54-year efficiency will drop to 60%. Cc. Costs (1) (4) Capital Capital costs for this plan are shown in Table D-2, including construction of the new building to house the existing diesel equipment, moving units to the new building, the new heat exchangers, piping to public buildings, and heat exchangers in public buildings. The total capital cost for the waste heat recovery system only is $741,000; the total including the new building is $932,000. Assembly and Installation Assembly and installation costs are estimated to be less than 35% of the $932,000. Operation and Maintenance Operating and maintenance costs for diesel generation are $57,000 per year and have been obtained from published reports by Tanana Power Company to the Alaska Public Utilities Commission. Operating and maintenance costs for the waste heat recovery system have been estimated to add $30,000 per year to the overall operating and maintenance costs, resulting in an annual total of $87,000. Fuel costs for diesel generation have been obtained from published reports by Tanana Power Company to the Alaska Public Utilities Commission. The diesel fuel cost for 1980 has been $1.80 per gallon, and the future fuel costs have been projected from the 1980 price. Cost Per Killowat Installed The cost per kW installed is the capital cost divided by installed capacity or $932,000 divided by 850 = $1096 per KW. (5) Economics of Scale - Not applicable d. Special Requirements and Impact (1) (3) Siting It would be advantageous in this plan utilizing waste heat to locate the power plant near the larger users of the waste heat. Such a site adjacent to and east of the village safe water facility is being contemplated, and vacant land is located at the planned site. Resource Needs No major renewable resources will be required. The major nonrenewable resource is the fuel oi] (17,807,000 gallons) that will be needed for the 54 years of operation projected. Construction and Operating Employment There are no special employment requirements for the operation and installation of existing diesel generation units and the new waste heat recovery system. The generation equipment, fuel oil storage and handling facilities, the fuel oil distribution network, and the local operating labor supply have been in place for several years. Construction labor will be needed to build the new powerhouse, move the existing units to the new building, and install the waste heat utilization system. Environmental Residuals - None Health and Safety Aspects The health and safety aspects associated with the plan are minimal. e. Summary and Critical Discussions (1) Summary The production of electricity by diesel-powered generators and the utilization of waste heat from the engines are technically feasible, and the necessary equipment is commercially available. Power output through the year 2034 jis projected to be 607,000 million Btu, and utilized waste heat is projected to be 850,000 million Btu, with an overall efficiency of 60%. The system would be reliable, with a backup needed only during stoppages required for repair and maintenance. The system is safe, and environmental impact is less extensive than for other alternatives. The capital costs and the operating and maintenance costs are low, but the estimated fuel cost is high. Construction and operating employment will be low compared to other alternatives. The projected present-worth cost of electrical energy is $0.11 per kWH or $31.35 per million Btu. These figures are based on information developed in Appendix E. Environmental impact from fuel oi] handling and combustion is considered minimal. Critical Discussion The use of diesel generators to supply the electrical energy needs at Tanana, along with the utilization of waste heat from the diesel, results in a moderate cost per million Btu, but it is a great improvement over the existing system. The diesel Power generation system is becoming increasingly expensive to Operate in view of escalating fuel oil prices. Long-term detrimental economic effects. will continue under this plan. The only major disadvantage is the high diesel oil price. The technology is simple, proven, reliable, available, and safe, and it is appropriate for the community, except for high fuel costs. D-11 3. Diesel Generation with Binary Cycle and Utilization of Waste Heat a. General Description This alternative consists of using the existing diesel engines in a new 45' x 100' building (see Plate D-9) and equipping each machine with a new Organic-Rankine bottoming cycle system and waste heat recovery equipment. The bottoming cycle would recover energy from the exhaust heat of the diesel engine. Diagrams of energy balance and performance for this compound engine alternative are shown in Plates 0-10 and D-11. The major components of the bottoming cycle system are the turbine, generator, vapor generator, condenser, and regenerator. The exhaust gases from the engine vaporize the working fluid of the bottoming cycle system in the vapor generator. The vaporized working fluid then expands through the turbine, which provides power to drive an additional generator. The working fluid is then cooled in a water condenser and again enters the vapor generator heated by the diesel exhaust. Waste heat recovery units will also be required, as in the previous plan. Since the existing buildings are in poor condition, this development plan would require a new 45' x 100' power plant building to house all four units. (1) Thermodynamic and Engineering Processes The processes involved are outlined on Plate D-11 and in the general description. (2) Current and Future Availability The technology and equipment for a bottoming cycle system are Presently available. The use of a Rankine bottoming cycle system is also being tested in a program conducted under a Department of Energy contract by Thermo Electron Corporation and Mack Trucks, Inc. Rankine bottom cycle system equipment now being manufactured could be installed on a diesel engine at Tanana. One manufacturer, Sunstrand Energy Systems, has five units in operation, three installed at power plants where the units recover energy from diesel or dual-fuel engines. One such installation is in the Beloit, Kansas, Municipal Power Plant. Waste heat exchangers are available as outlined above. b. Performance Characteristics Q) Energy Output The performance characteristics for the bottoming cycle system are shown in the diagram of performance on Plate D-11. It is predicted that the use of a compound engine would reduce diesel fuel requirements by 15%, from 17,807,000 gallons to 15,136,000 gallons through the year 2034. At the Tanana diesel power plant, with diesel fuel use of over 200,000 gallons per year, over 30,000 gallons of fuel could be saved annually. Production efficiency should be increased from 25% to 29% by the addition of the binary cycle. The waste heat recovery system cannot recover as much waste heat as in the preceeding alternative plan, where it was projected that up to 42% of the total energy input could be utilized as waste heat. For this alternative, it is projected that only 31% of the total energy input or 602,000 million Btu can be put to beneficial use as waste heat between the years 1983 to 2034. The 31% is made up of almost all of the jacket water heat and a small percentage of the exhaust heat. After passing through the vapor generator, the exhaust gases would be forced through the waste heat exchanger and would transmit heat to the jacket water used for heating. The daily, seasonal, and annual dynamics of the system will be parallel to the electrical demands shown in Section III of this report. A moderate-size hot water heat storage tank May prove advantageous in meeting varying waste heat demands. This matter must be evaluated further if this plan is considered for adoption. (2) Reliability (a) Backup The reliability of this plan is much like that of the earlier diesel plans outlined. The binary cycle introduces an additional complexity, but the system will operate without it. The extra existing units will be needed as backup in this plan and are provided. (b) Storage Requirements include fuel oil storage only, since electrical energy from the generators cannot be stored in a practical manner. A hot water storage tank to store a moderate amount of waste heat could be made a part of the heating system, but it is not projected here. (3) Thermodynamic Efficiency The efficiency of the electrical system only with the binary cycle is 29%. When utilization of waste heat is considered, the efficiency is 60%. There will be 2,065,000 million Btu fuel input, 607,000 million Btu of electrical output, and 602,000 million Btu of utilized waste heat over 54 years of operation. Not all the 31% recovered heat can be utilized in summer months. Therefore, the overall 54-year efficiency will drop to 58%. c. Costs (1) Capital Total capital costs are estimated to be $1,195,000. A total of $741,000 is attributable to the waste utilization system and $263,000 to electrical generation. (2) Assembly and Installation Assembly and installation costs are estimated to be less than 35% of the total figure. (3) Operation and Maintenance Costs Total operating and maintenance costs are Projected to be $97,000 per year, $10,000 per year more for this system than for the diesel with waste heat recovery. Diesel fuel costs are Projected to increase from the 1980 price of $1.80 per gallon. (4) Cost Per Kilowatt Installed The cost per kW installed is the capital cost divided by installed capacity or $1,195,000 divided by 850 = $1406 per kW. (5) Economies of Scale - Not applicable d. Special Requirements and Impact (1) Siting It would be advantageous in this plan utilizing waste heat to locate the power plant near larger users of the waste heat. Such a site adjacent to and east of the village safe water facility is being contemplated, and vacant land is located at the Planned site. (2) Resource Needs No major renewable resources will be required. The major nonrenewable resource is the fuel oi] (15,136,000 gallons) that will be needed for the 54 years of operation projected. (3) Construction and Operating Employment There are no special employment requirements for the operation (4) and installation of existing diesel generation units with binary cycle and the new waste heat recovery system. The generation equipment, fuel oil storage and handling facilities, the fuel oil distribution network, and the local operating labor supply have been in place for several years. Construction labor will be needed to build the new powerhouse, move the existing units to the new building, and install binary equipment and the waste heat utilization system. Environmental Residuals - None eta) Residuals (5) Health and Safety Aspects The health and safety eeecrs associated with the plan are minimal. e. Summary and Critical Discussion (1) Summary The existing diesel engines at Tanana can be made more efficient, reducing diesel fuel consumption by as much as 15%, by adding a Rankine bottoming cycle system to each engine. The bottoming cycle system, which utilizes exhaust heat to drive a turbine that would drive an additional generator, is now being manufactured and jis available. Electrical Power production through the year 2034 is projected to be 178,070,000 kWH or 607,000 million Btu, and utilized waste heat is Projected to be 602,000 million Btu. The overall system efficiency is projected to be 58% for 54 years of Operation. The system would be reliable, with a backup needed during stoppages required for repair and maintenance. The system is safe, and environmental impact is less extensive than for other alternative. The capital costs and the operating and maintenance costs are low, but the fuel cost is high. Construction and operating employment should D-16 be low. The present-worth cost of electrical energy is $0.10 per. KWH or $30.74 per million Btu ($18,665,000 divided by 178,070,000 and $18,665,000 divided by 607,000). This is based on information developed in Appendix E. (2) Critical Discussion The 15% savings in diesel fuel will partially be offset by costs related to adding the new equipment. This alternative should be considered for possible adoption only if the existing diesel system is employed. as the primary generating source in the future and waste heat is utilized. The Organic Rankine bottoming cycle system is complex, with Many working parts. This is a definite disadvantage at Tanana and makes the binary cycle less appropriate. 4, Coal-Fired Steam Generation a. General Description This plan considers the use of coal as an energy source to drive a steam turbine generator. (A plant layout is shown on Plate D-12.) The basic equipment consists of three principal components: a furnace and boiler to convert the coal into steam, a turbine for converting the kinetic energy in the steam into mechanical energy, and a generator for converting the mechanical energy into electrical energy. A diagram of the energy balance and the thermodynamic and engineering Processes involved is shown on Plate D-13, and a diagram of performance is shown on Plate D-14. The existing diesel driven generating equipment would be used as backup to provide generation when the coal-fired equipment is out of service. Peak demand is projected to reach 850 kW in the next 20 years, as outlined in Secton IV. A nominal plant capacity of 1,000 kW is therefore considered to be reasonable and is projected in this alternative. As a practical matter, the rated capacity chosen for the equipment, within a reasonable range, does not have a critical effect on the economic evaluation in this plan. A large proportion of the cost of the equipment is concerned with the boiler, since steam boilers are not available in numerous sizes, as are internal combustion engines, hydraulic turbines, and other equipment associated with power generation. A single size of boiler is used for a variety of generating capacities by adjusting boiler temperature, pressure, and rate of fuel feed to supply steam over a wide range of Pounds per hour. Waste heat utilization will be accomplished by taking waste heat from the furnace flue and the condenser, as shown on Plate D-15. (1) Thermodynamic and Engineering Processes Processes involved are shown in Plate 0-14, (2) Current and Future Availability The means of generating electrical power from coal-fired steam has long been available, for the use of coal to fire steam boilers involves an old and well established technology. Concerns about air pollution and the low price of natural gas and oil have gradually replaced coal in many installations, however, although recent increases in the price of oil have renewed interest in the use of energy from coal. Equipment for coal-fired steam generation is similar to that for other solid fuels and is commercially available. The availability of waste heat recovery equipment has been covered in earlier plans. b. Performance Characteristics ee ormance Lnaracter istics (1) Energy Output The generating system is projected to be operated to produce the required 178,070,000 kWH of electrical energy through the year 2034. A critical factor in the production of steam generated electricity is the net heat rate, which is the ratio of the rate at which power is supplied to the electrical system, usually expressed as Btu/kWH. This value can be converted to overall thermal efficiency using the following equation: thermal efficiency = 3412.14 net heat rate A typical current value for net heat rate is 9,000 Btu/kWH for fossil-fuel steam-generated electricity, giving an efficiency of 38%. This is for a large central station with high-pressure, high-temperature steam, and sophisticated controls to optimize the generating cycle, however. For the small output required at Tanana, a tube-fired boiler is applicable. The steam would be 400°F and 250 pisa. This low steam pressure and low temperature result in low turbine efficiency. Therefore, a more realistic figure for the type of equipment applicable at Tanana is considered to be 34,000 Btu/kWH, giving an efficiency of about 10% on the basis of operation near capacity. The heat rate is used to estimate the fuel consumption and total amounts of fuel for a particular installation and rated output. The coal-fired boiler considered is sized to produce the 18,420 pounds of steam per hour needed to drive a generator with a peak output of 1,000 kW. The estimated 1984 energy consumption of 2,250,000 kWH (with 95% supplied by the steam turbine and 5% by diesel standby) will require about 4,000 tons of coal. This figure is based on the coal having a heating value of 8,000 Btu per pound and an overall efficiency of 10.3%. The theoretical furnace temperature for the furnace projected here is in the 2,500°F range. The steam generation process produces a large amount of waste heat. As can be seen by Plate D-14, the furnace/boiler losses approach three times the electrical energy output, and the waste heat loss from the condenser is four times the electrical energy output. (2) The circulating water rates are shown along with temperatures on Plate D-15. The waste heat will not be easily utilized, because the temperature of the water is comparatively low. This will necessitate forced air movement in space heaters that may be utilized. The circulating water reentering the condenser must be cooled to a lower temperature to have minimal adverse effects on the performance of the turbine. Therefore, if the heat is not removed from the circulating water in the buildings, it must be removed by an exchanger before it reenters the condenser. This cooling provision must be provided even if no effort is made to utilize the waste heat. The plan projected here Proposes to use 31% of the condenser heat in the circulating water and furnace flue or 1,207,000 million Btu through year 2034. The net energy Projected to be produced and utilized by this coal-fired alternative with utilization of waste heat is 607,000 million Btu of electrical energy and 1,207,000 million Btu of waste heat. The daily, seasonal, and annual dynamics of the system will be parallel to the electrical demands shown in Section III of this report. It may be advantageous to supply a moderate-size hot water storage reservoir to meet waste heat demand peaks. This matter will require further investigation before adoption of this alternative plan. Reliability The reliability of a coal-fired system is judged to be low in comparison with other electrical generating systems because of the number of stages through which the coal energy must be Processed before conversion into electrical energy. In addition, the coal-fired boiler, along with the steam turbine and generator, will require periodic maintenance. It is projected that 3 weeks per year should be anticipated for maintenance and repair of the plant, assumping prompt and efficient execution of the work required. During the 3-week period, the diesel power generation system should be in operation. The reliability of the waste heat utilization system is good, but it depends on the operation of the steam plant. (a) Backup The existing diesel generating units are to be used for standby power supply. (b) Storage Requirements include a 200' x 200' coal storage area. A hot water storage tank for a moderate amount of waste heat could be made a part of the heating system, but it is not projected here. (3) Thermodynamic Efficiency The overall system efficiency, illustrated on Plate D-13, (coal to wire) at rated capacity is 10.3% on the basis of about 66% of the energy in the coal Producing steam. The thermodynamic efficiency of the steam to mechanical energy should be about 16%, and the efficiency of the generator is assumed to be 95%. (Therefore, 66 percent x 16 percent x 95 percent = 10% overall). Overall system efficiency is 34% when waste heat is utilized. There will be a fuel Btu input of 5,900,000 million Btu, the production of 607,000 million Btu of electrical energy, and the utilization of 1,207,000 million Btu of waste heat over the next 54 years. During summer months all the waste heat that can be extracted cannot be utilized. Therefore, the overall efficiency for 54 years of operation will become 31%. c. Costs (1) Capital Capital costs are estimated to be $4,965,000, as itemized in Table D-4. Waste heat utilization is estimated to require 0-21 additional capital costs of $1,225,000 as shown in Table D-5. Diesel standby capital costs are estimated to be $191,000. (2) (4) (5) Assembly-and Installation Assembly and installation costs are estimated to be about 40% of the total figure. Operation and-Maintenance Costs The operation and maintenance costs, detailed in Table D-6, assume a full-time attendant at the boiler. The total cost per year is $250,000. Fuel costs include the transportation of coal by barge to Tanana and storage of the coal adjacent to the river. The coal is to be secured from the Nenana coal field. The estimated cost is $69.86 per ton stacked in the storage pile. Cost Per Kilowatt Installed The cost per kW installed is the capital cost divided by installed capacity or $6,381,000 divided by 850 = $7,507 per kW. Economics of Scale The size of steam power plant projected here jis not an economical size. The equipment costs of a plant 100% larger are estimated to be only 30% greater, and the assembly and installation costs for a 2,000-kW plant are estimated to be only slightly greater. The operation costs of a 2,000-kW plant are estimated to be only 20% greater, while the maintenance costs are estimated to be only 30% greater. The coal fuel cost per ton could also be reduced slightly if the coal requirements were larger. d. Special Requirements and Impact Q) (2) (3) Siting Plant siting and layout for the development of this alternative are shown on Plate D-12. The plan includes a 40' x 150' building to house the steam generating equipment and the standby diesel units, and a 200' x 200! storage area for a 12-month supply of coal, the furnace, the steam boiler, the steam turbine, and the generator. Hot water from the condenser, utilizing waste heat, is to be piped to public buildings, laundry, shower building, school, and hospital. Siting of the plant in or near Tanana will reduce transmission line requirements, while siting the plant near the river will reduce the transportation costs for moving the coal from the river barge to the storage area adjacent to the plant. The wind is most frequently from the northeast. To minimize the impact of stack emissions on the local population, the plant should be located west of the community. Resource Needs eee ECCS No renewable resource jis to be used. Coal is the major nonrenewable resource to be used. For the projected 54-year period, 371,000 tons will be needed to supply electrical energy needs. Construction and Operating Employment It is anticipated that onsite construction of the power plant will be held to a minimum by preconstruction assembly of as much of the equipment as practical. It is anticipated that the coal furnace will have to be attended on a 24-hour basis. This would require five men, who would have to be trained to carry out the semiskilled duties of firing and attending the plant operation. (4) Environmental Residuals The burning of about 5,000 tons of coal per year will produce about 300 tons of coal ash, 20 tons of sulfur dioxide emmissions, 30 tons of particulate emissions, and 15 tons of nitrous oxides emissions. Adequate precautions will have to be made a part of the Project to control the environmental impact of a coal-fired plant. (5) Health and Safety Aspects Smoke from the boiler furnace will contribute to air pollution. The utilization of waste heat for space heating will reduce the individual space heater smoke production, however, and this may result in a net reduction in emissions. Steam boilers offer the possibility of malfunction of components and therefore the possibility of boiler rupture. This alternative should be judged safe in spite of the steam boiler, however. e. Summary and Critical Discussion (1) Summary The production of electrical energy from coal-fired steam is technically feasible, and equipment for such production is commercially available. Electrical power output through the year 2034 is projected to be 607,000 million Btu and utilized waste heat is projected to be 1,207,000 million Btu. The overall 54-year efficiency is 31% when waste heat utilized is considered. The system would be relatively reliable, with a backup needed only during stoppages required for repair and maintenance. Environmental impact is more extensive than for other alternatives with air emissions. The estimated installation, operating, and maintenance costs are high, and the estimated fuel cost is low. The present-worth cost per million Btu is $26.25 and $0.09 per kW when electrical energy only is considered. This is based on the production of 607,000 million Btu or 178,070,000 kWH and a total present-worth cost of $15,937,000. These costs are calculated in Appendix £. Operating employment would be high when compared to other alternatives. (2) Critical Discussion The coal-fired steam production of electrical energy is comp lex, involving many different features that are subject to failure and special technical attention. This is a definite disadvantage and must be emphasized. For the small installation, steam generation has definite technical disadvantages, including low turbine efficiency. The costs for this alternative when waste heat is utilized are attractive compared with some other alternatives. One positive aspect of this alternative is that a large amount of the waste heat can be utilized, but the low water temperature in the heating circuit is a disadvantage. This alternative is attractive only when a large amount of waste heat is utilized. The alternative is not particularly appropriate for Tanana. 5. Hydroelectric Generation a. General Description This alternative considers the construction of an 850-kW hydroelectric plant on Jackson Creek east of Tanana. (A layout of the hydroelectric facility planned for this alternative is shown on Plate D-16.) Information regarding stream flow in Jackson Creek was developed in a recent study performed by OTT for the Corps of Engineers and has been used in this assessment. The OTT study shows that meaningful flow in Jackson Creek occurs only during the period of May through December. The development plan would involve the hydroelectric plant plus the diesel generation plant as standby when water is not available for generation. The hydroelectric development will require construction of a dam to store water at elevation 580, as shown on Plate D-17. An intake structure in the embankments will transfer water to the 36-inch-diameter pipe pen stock. The power plant, located at about elevation 230, will receive the flow from the pen stock. The power plant is Projected to have three 283-kW units, each with a full gate flow capacity of 11 cfs. The effective head will be 350 feet at full gate flow, and friction loss in the 36-inch-diameter, 25,000-foot-long pen stock at full gate is calculated to be about 55 feet. At 50% gate, the loss is reduced to about 10 feet. The machines are projected to be small Francis turbines with the ability to produce power at a low rate of about 100 kW each. After flowing through the turbines, the water would Proceed back to Jackson Creek, which will be excavated to lower tail water levels. A transmission line and a service road are to be constructed from the Power plant to Tanana. The existing diesel powered generating equipment will be used as standby for hydroelectric generation. The existing diesel power generation facility consists of four diesel generators with a total capacity of 1,950 kW. The amount of Power that will have to be generated by the diesel units is projected to be zero, but they will be needed if water is not available for generation from the reservoir. A diesel plant layout is shown on Plate 0-18. Generation by the hydroelectric plant will depend on water in the reservoir. Flows will be small during January through April. A 5,000-acre-foot storage reservoir to supply a water source during those months is required. Diesel generation will be needed to supply electrical power during periods when no water is in the reservoir. Steam flow information is shown on Table D-7. (1) Thermodynamics and Engineering Processes A diagram of the energy balance of the hydraulic and engineering Processes involved for the hydroelectric system is shown on Plate D-17. (2) Current and Future Availability The technology for hydroelectric generation is well developed and available throughout the world, and many applications are now in service. b. Performance Characteristics eave wNaracter istics (1) Energy Output The Jackson Creek site will reasonably support an 850-kW hydroelectric plant, assuming a 5,000 acre-foot reservoir, and 15 cfs of flow into the reservoir. Annual energy production should be about 3,800,000 kWH. The monthly distribution of energy that. could be supplied by the 850-kW system during an average year shows that no deficiencies should occur. If deficiencies do occur, they will have to be supplied by the standby diesel generation system. The water passed through the power turbines will have to be about 11,000 acre-feet or 15 cfs to Produce 3,8000,000 kwWH of Power in 1 year. The average flow in the stream is greater than 15 cfs. The hydroelectric facility will have the ability to adjust output to meet electrical power demands that may put it at the limit of its Capacity. The upper reservoir, with its 5,000 acre-foot storage volume, should meet demands during periods of low flow. The seasonal and annual Power output dynamics of the system are such that variations in demand can be met. c. (2) (3) Reliability The reliability of the projected hydroelectric plant supplemented by a well-maintained diesel generation is judged to be good and is based on long Operating experience throughout the world. Hydroelectric units will require minimal time for maintenance. The reliability for Producing hydroelectric power will depend on flow to the reservoir and the amount of freezing in the reservoir. (a) Backup The existing diesel units are to serve as a backup to the hydroelectric facility. (b) Storage Requirements Storage requiremens will be met by the reservoir on Jackson Creek at the upstream end of the Pen stock. The active storage of 5,000 acre-feet at a head of 400 feet will Produce 1,900,000 kWH of energy. The reservoir's total’ storage volume has been made 5,700 acre-feet, which allows for 700 acre-feet of ice that would be inactive for hydroelectric generation. Thermodynamic Efficiency The efficiency for the hydroelectric plant is assumed to be 83%. Costs (1) Capital Total capital costs are estimated to be $13,350,000 for the hydroelectric system, as shown in Table D-8, $191,000 for the diesel system, and $50,000 for surplus electrical energy output utilization. (2) Assembly and Installation (3) (4) Assembly and installation costs are estimated to be about 70% of the total figures. Operation and Maintenance Costs The operation and maintenance costs for the hydroelectric plant are estimated to be $25,000 per year and $10,000 for the standby diesel plant. Cost per Kilowatt Installed The installed cost for this plan is $15,930 per kW or $13,951,000 divided by 850 kW = $15,930/kW. Economics of Scale Hydropower plants are generally more costly per kW for small plants. This is also the case for this plan, since a much larger plant on Jackson Creek is neither needed nor supportable. d. Special Requirements and Impact ; Q) (2) Siting The siting of the hydroelectric plant is dictated by the topography and stream flow. Resource Needs The renewable resource used in this plan is flowing water in Jackson Creek. The hydroelectric generation of electrical power does not require nonrenewable resources. (3) Construction: and Operating Employment It is anticipated that onsite construction of the hydroelectric plant and appurtances will be held to a _ minimum by Preconstruction assembly of as much of the equipment as possible. There are no special employment requirements for the operation and installation of existing diesel generation units. The generation equipment, fuel oil storage and handling facilities, the fuel oil distribution network, and the local operating labor supply have been in place for several years. (4) Environmental Residuals Environmental residuals are limited. The upper reservoir embankment will have about 400,000 cubic yards of fill. (5) Health and Safety Aspects The health and safety aspects associated with this plan are minimal. e. Summary and: Critical Discussion (1) Summary An 850-kW hydroelectric plant utilizing a 5,000-acre-foot reservoir on Jackson Creek would generate all electrical power requirements for Tanana. The production of electrical energy by a hydroelectric plant is technically feasible, and equipment is commercially available. Electrical power output through the year 2034 is projected to be 3,800,000 kWH per year. The system would be reliable, with a diesel backup needed only during stoppages required for repair and maintenance. The system is safe, and environmental impact is less extensive than for other alternatives. The capital costs are high, the operating and maintenance costs are low, and the estimated fuel cost is zero. Construction and operating employment will be low compared to (2) other alternatives. The projected present-worth cost of required energy is $0.08 per kWH of electrical power needed ($13,591,000 divided by 178,070,000). Critical -Discussion The use of hydroelectric generation to supply the electrical energy needs at Tanana results in a low cost per kWH. The system is not complex and would result in a diminished need for diesel fuel. The hydroelectric system with the diesel backup is Teliable, and all equipment is readily available. This plan is appropriate for the Tanana area, but implementation of the plan should not proceed until a feasibility study has been made that will provide a more definite description of the project, define with more certainty the flow in Jackson Creek, and estimate more accurately the cost of construction. The importance of the amount of flow in Jackson Creek must not be overlooked; 25% increase in flow would cause a 175% increase in the amount of surplus electrical energy produced. 6. Transmission a. General Description This alternative considers the transmission of electrical power from an existing grid in the Fairbanks area. (See Plate D-19 for the transmission line layout.) The transmission of electrical energy is to be accomplished with a 69-kVa line. No nearer source of electrical energy is available, and the power . Tequirements of Tanana will increase the load on the Fairbanks system by only a small percentage. The 140-mile-long line from Fairbanks would be subject to hazardous conditions but would have to be considered reliable. The electrical efficiency of a 69-kVa line 140 miles long is high for the amount of energy being transmitted, but electrical energy from the grid is reliable and must be considered safe. 0-31 (1) Thermodynamic and Engineering Process Electrical energy in this plan will be produced at an existing plant and transmitted by a 140-mile three-wire transmission line to Tanana. (2) €urrent:and Future Availability The technology and material are currently available and will undoubtedly be available in the future. b. -Performance Characteristics (1) Energy Output The energy output from the transmission line will equal the electrical demands of Tanana. (2) Reliability (a) Backup The transmission line will be very reliable but the existing diesel unit will be used for backup. (b) Storage Requirements There are no storage requirements. (3) Thermodynamic Efficiency The efficiency of the transmission will approach 100%. 0-32 c. Costs (1) €apital Costs The estimated construction cost for the 140 miles of line and associated substations is $28,200,000 on the basis of $200,000 per mile for the line proper and an allowance of $100,000 for substations at each end. The cost for standby is $191,000. (2) Assembly and Installation Costs Assembly and installation costs represent more than 50% of the capital costs. (3) Qperation and Maintenance Costs The operation and maintenance cost for the line is projected to be $500 per mile per year or $70,000 per year. The cost of energy from the Fairbanks grid is estimated to be $0.08 per KWH. (4) Cost per Kilowatt Installed The kW cost equals the capital cost divided by peak demand or $28,391,000 divided by 850 = $33,400 per kW. Economics of Scale The small size of Tanana's needs makes the cost per unit very large. If the use could be increased fourfold, the cost per kWH could be reduced by almost two-thirds. d. Special Requirements and Impact (1) Siting No effort has been made in this reconnaissance study to select the most suitable transmission line alignment. : 0-33 (2) Resource Needs (3) (4) (5) Resource needs at Tanana would be minimal. In addition to the construction resource requirements, fuel of some type would have to be supplied at Fairbanks to generate the energy to be consumed at Tanana. Maintenance of the transmission line and transmission line right-of-way would require very limited resources. Construction and Operating Employment Actual construction at Tanana would be slight, and construction employment would be expended along the transmission line route. No operating employment would be required. Limited emp loyment will be needed to maintain the right-of-way. Environmental Residuals No environmental residuals would be produced. Health or Safety Aspects Health and safety aspects would be minimal. e. Summary and Critical Discussion (1) Summary Interconnection to an existing electrical grid as an alternative energy source would require the construction of about 140 miles of three-wire line to the nearest electrical energy source, in Fairbanks. The system would be safe and reliable. The clearing of the long right-of-way would affect the environment, and capital costs would be high. The estimated present-worth cost for this alternative energy source is high, in the $0. 24-per-kWh range ($43,047,000 divided by 178,070,000). Operating employment would be very low compared to other alternatives. (2) Critical Discussion The interconnection to an existing electrical grid is very costly because of the great distance involved, and the cost per kWH is high because of the small amount of energy transmitted. If other users of electrical energy in the area and along the transmission line route could share the transmission and power costs, however, the cost per kWH could be reduced. For example, if other possible users along or near the transmission line route could increase by four the amount of energy transmitted along the line, the Projected cost per kWH would decrease significantly, although such an increase does not seem even remotely possible. Wood-Fired Steam Generation ES a team generation a. General Description This alternative projects the use of locally harvested wood as an energy source to drive a steam turbine generator. The wood would be harvested specifically for this purpose. (A plant layout is shown on Plate D-20.) A diagram of the energy balance and the thermodynamic and engineering processes involved is shown on Plate D-21, and a diagram of performance is shown on Plate D-22. The existing diesel-driven generating equipment would be used as the backup to Provide generation when the wood-fired equipment is out of service. Waste heat from the furnace flue and condenser is to be utilized. A peak demand is projected to reach 850 kW in the next 20 years, as outlined in Section IV. A nominal capacity of 1,000 kW is therefore considered to be reasonable and is Projected in this alternative. As a practical matter, the rated capacity chosen for the equipment, within a reasonable range, does not have a critical effect on the economic evaluation in the study. A large proportion of the cost of the equipment is associated with the boiler, since steam boilers are not available in as great a number of sizes as internal-combustion engines, hydraulic turbines, and other equipment associated with Power generation. A single size of boiler is used for a variety of generating capacities by adjusting boiler temperature, pressure, and rate of fuel feed to supply steam over a wide range of pounds per hour. Utilization of waste heat will be accomplished by taking waste heat from the furnace flue and the condenser, as shown on Plate 0-23. (1) Thermodynamic and Engineering Processes Processes involved are shown on Plate D-22. (2) Current and Future Availability The technology to generate electrical energy from wood-fired steam is presently available. Although wood was undoubtedly man's first source of thermal energy and remained the principal source for many years, more concentrated and convenient sources of energy, such as coal and oil, have gradually replaced it since the early nineteenth century. Now it is estimated that wood supplies only about 1% of the nation's energy. Recent market forces have renewed interest in the use of energy from wood, however, and the future availibility of the equipment will undoubtedly be good. The major difference between wood and other fuels occurs before the combustion process. It concerns the harvesting, handling, and reduction in moisture and particle size of the wood fuel. b. Performance Characteristics ete aracteristics (1) Energy Output The steam generating system is projected to produce the required 178,070,000 million kwWH of electrical energy through the year 2034. A critical factor in the Production of steam-generated electricity is the net heat rate, wnich is the ratio of the rate at which power is supplied to the electrical system. Net heat rate is usually expressed as Btu per kWH. This value can be converted to overall thermal efficiency using the equation: 3412.14 thermal efficiency = Tet heat rate A typical current value for net heat rate is 9,000 Btu/kwH for fossil-fuel steam-generated electricity, giving an efficiency of 38%. This is for a large central station with high-pressure, high-temperature steam and sophisticated controls to optimize the generating cycle, however. For the small Output required at Tanana, a tube-fired boiler is applicable, with steam at 400°F and 250 psia. This low steam pressure and low temperature result in low turbine efficiency. Therefore, a more realistic heat rate figure for the type of equipment applicable at Tanana is considered to be 34,000 Btu/kWH, giving an efficiency of about 10% (3,412 divided by 34,000) on the basis of operation near Capacity. The heat rate is used to estimate the fuel consumption and total amount of fuel for a Particular installation and rated output. The wood-fired boiler considered here is sized to produce the 18,420 pounds of steam per hour needed to drive the turbine to drive a generator with a peak output of 1,000 kW. The estimated 1984 energy electrical consumption of 2,250,000 kwWH (with 95% supplied by the steam turbine, 5% by the diesel generator) will require about 5,150 cords of wood. This figure is based on the use of wood having a heating value of 14 million Btu per cord and an overall efficiency of 10.3%. The theoretical furnace temperature for the furnace projected here is in the 2,500°F range but is dependent on fuel moisture and on the amount of excess air. The steam generation process Produces a large amount of waste heat. As can be seen in Plate 0-22, the furnace/boiler losses approach three times the electrical energy output, and the waste heat loss from the condenser is four times the electrical energy Output. The plan for utilizing waste heat would take heat from both the condenser and the furnace flue with one circulation water system (Plate D-23). The plan projected here proposes to put to beneficial use 34% of the total waste heat in the flue and condenser. The circulating water rates are shown on Plate D-23 along with temperatures. The waste heat will not be easily utilized, because the temperature of the water is comparatively low, as shown on Plate D-23. This will necessitate forced air Movement in any space heaters that may be employed in the buildings. The circulating water reentering the condenser must be cooled to a lower temperature to have minimal adverse effect on the performance of the turbine. Therefore, if the heat is not removed from the circulating water in the buildings, it must be removed by an exchanger before it reenters the condenser. This cooling must be provided even if no effort is made to utilize the waste heat. The net energy projected to be produced and utilized through the year 2034 for this alternative is 607,000 million Btu of electrical energy and 1,207,000 million Btu of waste heat. The daily, seasonal, and annual dynamics of the system will be parallel to the electrical demands shown in Section III of this report. A hot water storage tank for waste heat May prove advantageous in meeting varying waste heat demands. This matter must be evaluated further if this plan is considered further. (2) (3) Reliability The reliability of a wood-fired system is judged to be low in comparison with other systems because of the number of stages through which the wood energy must be processed before conversion into electrical energy. The wood-fired boiler, along with the steam turbine and generator, will require periodic maintenance. Three weeks per year should be anticipated for maintenance and repair for the plant, assuming prompt and efficient execution of the work required. (a) Backup The existing diesel generating units are to be used for standby power. (b) Storage Requirements include wood fuel storage in a 250' x 500! area. A hot water storage tank for a moderate amount of waste heat could be made a part of the heating system, but it is not projected here. Thermodynamic Efficiency The overall system efficiency (wood to wire), illustrated on Plate D-21, at rated capacity is 10.3% on the basis of 66% of the energy in the wood producing steam. The thermodynamic efficiency of the steam to mechanical energy should be about 16%, and the efficiency of the generator is assumed to be 95%. (Therefore, 66% x 16% x 95% 10% overall.) The overall efficiency is 34% when waste heat is utilized. An input of 5,900,000 million Btu, the production of 607,000 million Btu of electrical energy, and the utilization of 1,207,000 million Btu of waste heat are projected over the next 54 years. During summer months, all of the waste heat that can be extracted cannot be utilized. Therefore, the overall efficiency for 54 years of operation will become about 31%. c. Costs (1) (3) Capital Capital costs for wood steam generation are estimated to be $5,595,000, as itemized in Table D-9. Waste heat recovery is estimated to involve a capital cost of $1,225,000. Diesel standby capital costs are estimated to be $191,000. Assembly and Installation Assembly and installation costs are estimated to be about 30% of the total figure. Operation and Maintenance Cost The operation cost assumes a full-time attendant at the furnace and boiler. The total cost per year is $300,000, as shown in Table D-10. Fuel costs are based on harvesting, transporting, and storing the wood before introduction into the furnace. Harvesting of the wood as outlined requires about 1.7 man-hours of labor per cord. Transportation is to be by barge to Tanana, where the wood would have to be rehandled and moved to storage adjacent to the power plant. The transportation, unloading, and placing in storage as outlined will require about 0.5 man-hours of labor per cord. Storage capacity is based on a one-year minimum fuel supply, not only to cover periods when harvesting will not be carried on because of weather conditions but also to provide storage time to reduce the moisture content for increased burning efficiency. The estimated cost for harvesting the timber depends on such features as quantity of wood per acre, tree size, handling equipment, access to timber stands, and remoteness from Population centers. Most of the features mentioned above will be liabilities in harvesting wood for this alternative. The quantity of wood per acre will undoubtedly be low, and the utilization of large modern harvesting equipment will not be feasible because of the limited amount of wood needed. Access to the timber stands will be difficult when they are not near the river barge on which it is assumed that the wood will be transported. It is also projected that no wood should be taken from the area rivers or from any stand within five miles of Tanana on the north side of the Yukon River, because wood from these sources is used for home heating in Tanana. All of these facts combine to make harvesting no easy undertaking. The present-worth cost of fuel delivered to the storage area (including capital costs) is projected to be about $60 per cord. (See Table K-a.) About 80% or $48 per cord of the total figure is attributable to harvesting, and the balance, $12 per cord, is related to the transportation and placement in storage. The $60-per-cord figure is based on the use of 120,600 cords through year 2000 and the Present worth of the cost for 20 years of $7,226,000. This figure, when compared with other experiences and projections, is considered reasonable. (4) Cost per Kilowatt Installed The cost per kW installed is the capital cost divided by installed capacity or $7,011,000 divided by 850 kW = $8,248 per kW. Economics of Scale The size of steam power plant projected here is not an economical size. The capital costs of a plant 100% larger (2,000 kW) are estimated to be only 20% greater. The assembly and installation costs for a 2,000-kW plant are also estimated to be only slightly greater. The operation costs d. of a 2,000-kW plant are estimated to be only 20% more, while the maintenance costs are estimated to be only 30% greater. The fuel cost per cord could also be reduced if the wood requirements were larger. An annual wood requirement 100% larger than that projected here could be met with an increase in investment costs of about 60% and an increase in annual costs of 80%. Special Requirements and Impact (1) Siting A plant siting layout for the development of this alternative is shown on Plate D-20. The plan includes a 40' x 150! building to house the steam generating equipment _and the standby diesel units, a 250' x 500' storage area for a 12-month supply of wood, a shredder for the wood, the furnace, the steam boiler, the steam turbine, and the generator. Hot water from the condenser, utilizing waste heat, is assumed to be Piped to the laundry, shower building, school, hospital, and other buildings. Siting of the plant in or near Tanana will reduce transmission line requirements, while siting the plant near the river will reduce the transportation costs for moving the wood from the river barge to the storage area adjacent to the plant. The wind is most frequently from the northeast. To minimize the impact of stack emissions on the local population, the plant should be located west of the community. Resource Needs Wood fuel is the major resource needed for this alternative, and it is renewable. A readily available supply must be established. Production of timber varies in the Tanana area and is probably less than one cord per acre per year. On this basis, the average requirement of 6,000 cords of wood for one year will require 6,000 acres of timber growing area in order to supply the fuel (3) (4) needs for this alternative. This figure would, of course, be smaller if more productive land were utilized and greater if less productive land were used. No major nonrenewable resources are needed for this plan. Construction and Operating Employment It is anticipated that onsite construction of the power plant would be held to a minimum by preconstruction assembly of as much of the equipment as practical. It is anticipated that the wood furnace would have to be attended on a 24-hour basis, which would require five men, who would have to be trained to carry out the semiskilled duties of firing and attending the plant Operation. Employment in the harvesting and transportation of the wood fuel is projected to require fourteen men for a five-month period each year. Environmental Residuals a residuals The burning of about 6,000 cords of wood per year will produce about 960 tons of wood ash per year, and a disposal method must be planned. The harvesting of 6,000 cords of wood per year should have no significant impact on air quality, water quality, noise, or fish and wildlife. Harvesting operations will require 100 acres or more each year, and significant land planning must be undertaken to minimize territorial damage and maximize regrowth. Significant short-term terrestrial impact will occur in the harvest area. No significant impact on air quality, water quality, fish, wildlife and noise is anticipated, nor is any long-term terrestrial impact projected. (5) Health and Safety Aspects Smoke from the boiler furnace will contribute to air pollution. The utilization of waste heat for space heating will reduce the individual space heater smoke producton, however, and this may result in a net reduction in emissions. Steam boilers offer the possibility of malfunction of components and therefore the possibility of boiler rupture. This alternative should be judged safe in spite of the steam boiler, however. a. Summary’ and Critical Discussion (1) Summary The production of electrical energy from wood-fired steam is technically feasible, and equipment for such production is commercially available. Electrical power output through the year 2034 is projected to be 607,000 million Btu, and utilized waste heat is projected to be 1,207,000 million Btu. The overall 54-year system efficiency is 31% when waste heat utilized is considered. The system would be relatively Teliable, with backup needed only during stoppages for repair and maintenance. The system does present safety problems with the pressure boiler. Environmental impact is more extensive than for other alternatives when air emissions and the amount of forest consumed are considered. The estimated installation, operating, and maintenance costs are high, and the estimated fuel cost is low. The present-worth cost per million Btu is $34 and $0.12 per KWH. This is based on 607,000 million Btu or 17,807,000 kWH and a total present-worth cost of $20,887,000. (See Appendix E for cost calculations. ) 8. Operating employment, including wood harvesting and transportation, would be high and greater than for other alternatives. (2) €ritical-Discussion Wood-fired steam generation of electrical energy is complex, involving many different features that. are subject to failure and special technical attention. This is a definite disadvantage and must be emphasized. For the small installation, steam generation also has the disadvantage of low turbine efficiency. The wood fuel demands require harvesting from a large forest area, with adverse environmental impact. The costs for ‘the alternative when waste heat is utilized are attractive when compared with some other alternatives, and the large amount of waste heat. and the possible utilization of the waste heat have definite advantages. This fact is reflected in the cost per Btu of energy utilized. The low water temperature in the heating circuit is another disadvantage. This alternative is attractive only when a large amount of waste heat is utilized. The alternative is not particularly appropriate for Tanana. Wood Gas Generation a. General Description This alternative considers the use of wood gas as an energy source made of wood harvested locally specifically for this purpose. The wood energy would be converted to a gas in a gasifier to fuel a dual-fuel engine that would drive the generator. The dual fuel would be 90% wood gas and 10% fuel oil. (A plant layout is shown on Plate 0-24.) A diagram of the energy balance and the thermodynamic and engineering processes involved is shown on Plate 0-25. The existing diesel generating equipment would be used as backup to Provide generation when the wood-fired equipment is out of service. Waste heat from the operation would be utilized. b. (1) Thermodynamic and Engineering Processes Processes involved are shown in Plate D-26. The gasifier (2) (1) operation is a two-stage process of extracting useful energy from hydrocarbon combustibles such as wood by converting them into producer gas. In the first stage, partial combustion of the hydrocarbons occurs, yielding carbon dioxide, pyrolictic gases, acids, and tars. In the second stage, these byproducts are passed through an incandescant heat zone of coals formed by partial combustion and changed to hydrogen and carbon monoxide, a combustible low-8tu gas, along with small quantities of methane. The resultant gas is a combustible low-Btu gas, which can be fed directly into furnaces and boilers. Additional cooling and filtering are required for fueling an internal-combustion engine with the low-Btu gas. Current and Future Availability The technology for generating electrical energy with wood-gas- driven engines has been available since the turn of the century, but the advent of cheap fossil fuels such as diesel oil and their ease of handling restricted it to a very few cases where fuel oil could not be obtained. The equipment required is available only from foreign manufacturers, although Alaska Village Electric Cooperative, Inc., is now testing an American gasification unit. The writer knows of no wood gas generating system now in operation in the United States. Performance Characteristics erm omance Maracteristics Energy Output The energy output from the facility is projected to meet electrical energy needs of Tanana. For the life of the facility through the year 2034, the net electrical energy to be produced \ D-46 (2) is 178,070,000 kWH or 607,000 million Btu, 5% of which is to be Produced by the diesel Standby system and 95% by the wood gas system. Waste heat is to be utilized by taking up to 70% of the total of waste heat in the jacket water and the engine exhaust. The total waste heat utilized through the year 2034 will be 814,000 million Btu. The daily, seasonal, and annual dynamics of the system will be Parallel to the electrical demands shown in Section III of this report. It may be advantageous to provide a moderate-size hot water waste heat tank, from which heat could be drawn to meet peak space heating demands. No such storage tank is projected here, however. Reliability The reliability of a wood gasification generation system is judged to be less than that for a comparable diesel installation, since the reliability factor of the additional equipment must be taken into consideration. There are few records available from the few installations throughout the world from which reliability data can be obtained. (a) Backup The existing diesel generating units are to be used for standby power and standby waste heat. (b) Storage A 200' x 350' wood storage area has been sized to accommodate a one-year fuel requirement. A hot water storage tank for a moderate amount of waste heat could be made a part of the heating system but has not been projected here. c. (3) Thermodynamic Efficiency The overall system efficiency for generating electrical energy is 20%, as illustrated on Plate D-25. The overall efficiency is up to 49% when waste heat is utilized. : There will be a wood fuel and oi] input of 3,035,000 million Btu, the production of 607,000 million Btu of electrical energy, and the utilization of 814,000 million Btu of waste heat over the next 54 years. During summer months, all of the waste heat that can be extracted cannot be utilized. Therefore, the overall efficiency for 54 years will become about 47% instead of 49%. Costs (1) Capital Total capital costs are estimated to be $3,697,000, with $754,000 attributable to the waste heat system. (A cost breakdown is shown on Table D-11.) The cost attributable to the generating system only is $2,765,000. (2) Assembly and Installation (3) Assembly and installation costs are estimated to be about 30% of the total figure. Operating and Maintenance Costs Operating and maintenance costs for the wood gasification generation system, detailed in Table D-12, have been estimated from known labor costs and basic assumptions on the operation and maintenance of the gasification equipment. The operating cost assumes a full-time attendant. Wood fuel costs are based on harvesting, transportation, and storage of the wood before intro- duction into the gasifier. Harvesting of the wood as outlined requires about 2.2 man-hours of labor per cord. Transportation is to be by barge to Tanana, where the wood would have to be rehandled and moved to storage adjacent to the power plant. The transportation, unloading, and placing in storage as outlined will require about 0.6 man-hours of labor per cord. Storage capacity is designed for a one-year fuel supply, not only to cover periods when harvesting will not be carried on because of weather conditions but also to provide storage time to reduce the moisture content for increased burning efficiency. The estimated cost for harvesting depends on such features as quantity of wood per acre, tree size, handling equipment, access to timber stands, and remoteness from population centers. Most of the features mentioned above will be liabilities in harvesting wood for this alternative. The quantity of wood per acre will undoubtedly be low, and the utilization of large modern harvesting equipment will not be feasible because of the limited amount of wood needed. Access to the timber stands will be difficult when they are not near the river barge on which it is assumed that the wood will be transported. It jis also projected that no wood should be taken from the area rivers or from any stand within five miles of Tanana on the north side of the Yukon, because wood from these sources is used for home heating in Tanana. All of these facts combine to make harvesting no easy undertaking. The present-worth fuel cost delivered to the storage area (including capital costs) is projected to be about $79 per cord, or $51 per cord is attributable to harvesting and the balance, $28 per cord, is related to the transportation and placement in Storage. The $79-per-cord figure is based on the use of 54,210 cords through year 2000 and the present worth of the cost for 20 years of $4,274,000. This figure, when compared with other experiences and projections, is considered reasonable. (4) Cost per Kilowatt Installed The cost per kW installed is the capital cost divided by the installed capacity cost or $3,679,000 divided by 850 = $4,328 per kW. Economics of Scale The size of power plant projected here is an economical size. The capital costs of a plant 100% larger (2,000 kW) are estimated to be about 80% greater. The assembly and installation costs for a 2,000-kW plant are, however, estimated to be moderately greater. The operation costs of a 2,000-kW plant are estimated to be only 20% more, while the maintenance costs are estimated to be only 50% greater. The fuel cost per cord could also be reduced if the wood requirements were larger. An annual wood requirement 100% larger could be supplied at a price per cord of about 75% of the $79-per-cord figure. d. Special Requirements and Impact (1) Siting A projected siting plan for the development of this alternative is shown on Plate D-24. The plan includes a 50' x 120! building to house two 500-kW wood gas generators with gasifiers, a 200' x 350' storage area for a 12-month supply of wood, and a shredder for the wood. The plant is sited near the river to reduce the transportation costs for moving the wood from the river barge to the storage area adjacent to the plant. ~~ (2) (3) (5) Resources Needed Wood is the major resource needed for this plan, and it is renewable. A readily available supply of sufficient quantity "must be established near Tanana, so _that the price of wood projected here can be realized. If wood production is one cord per acre per year, about 3,000 acres will be needed to produce the required supply of wood fuel. No major nonrenewable resources are needed for this Plan. Construction and Operating Employment It is anticipated that onsite construction of the power plant will be held to a minimum by preconstruction assembly of as much of the equipment as Possible. Additional labor will be needed to handle, chip, and Process the wood fuel for the gasifier, as well as to dispose of the ash residue. It is anticipated that the plant will be attended full-time. This will require five men. Harvesting and transporting the wood fuel are projected to require fourteen men for three months. Environmental Residuals ental Residuals The burning of about 2,800 cords of wood per year will produce about 450 tons of wood ash..A suitable method and location for disposing of this residue must be established. Health and Safety Aspects Wood gasifiers offer the possibility of malfunction of components and therefore the possibility of escaping gas, which would affect the health and safety of workers in the Powerhouse. This alternative should not be judged unsafe because of the gasifier, however. e. Summary and-Critical Discussion (1) Summary The production of electrical energy by wood gasification generation equipment is technically feasible and commercially available from foreign manufacturers. At Present, there are no commercially available systems for power production with internal-combustion engines in the United States, but Alaska Village Electric Cooperative, Inc., is now testing an American gasification unit with a Caterpillar G353 gas engine generator that shows promise of being developed into a viable system for Alaskan Bush applications. Electrical output through the year 2034 is projected to be 607,000 million Btu, and utilized waste heat is projected to be 814,000 million Btu, with a system efficiency up to 49%. The system would be less reliable than some other alternatives because of the complexities associated with gasification, but the diesel backup increases the total system reliability. Environmental “impact is more extensive than for other alternatives because of the amount of forest consumed. The estimated installation, operating, and maintenance costs, along with the fuel costs, are moderate to ow. The Present-worth cost per kWH is $0.09 ($16,566,000 divided by 178,070,000) or $27 per million Btu. Operating employment, including wood harvesting and transportation, would be high and greater than for other alternatives. Critical Discussion The wood gasification plan with an internal-combustion engine cycle for electrical energy generation is complex, involving many different features that are subject to failure and special technical attention. The equipment required has not been proven as well as might be desired. These are definite disadvantages D-52 that make the plan not particularly appropriate for Tanana. The wood fuel demands require harvesting from a large forest area, with adverse environmental impact. The costs per Btu for this alternative are attractive when compared with those of some other alternatives. Much of the energy in the wood goes into the wood gasification process itself. TABLE D-1 Estimated Cost For Existing Diesel Base Generation Facilities (Base Case) Plan A Item Installed Cost ——— Power Plant Building (3,000 S.F. @ $33.33/S.F.) ws... $100,000 Installing Existing Units (4 @ 10,000) .........eeeeee 40,000 Subtotal $140,000 20% Contingency 28,000 Subtotal $168,000 Engineering 12% 20,000 * SubTotal $188,000 Interest During Construction 3,000 ae Total $191,000 SEE TABLE D-2 Estimated Cost For Waste Heat Utilization On The Existing Diesel Generation Units Item Installed Cost Power Plant Building (600 Extra S.F. @ $33.33/S.F.) ...... $ 20,000 Waste Heat Exchangers on Diesels ....cccsccecccccecccececs 100,000 Piping to Public Buildings (6000' @ $30/FT) ......ceeceees 180,000 Heat Exchangers in Public Buildings .....ccccccsccceceecce 200,000 Subtotal $500,000 20% Contingency 100,000 Subtotal $600,000 Engineering 12% 120,000 Subtotal $720,000 Interest During Construction 21,000 Total $741,000 Note: The diesels with the waste heat utilizing features require a 36' x 100' power plant building instead of a basic 30' x 100! building. Therefore, 600 extra square feet of building is required for waste heat utilization. Table D-2 ee ee TABLE D-3 Estimated Cost For Organic Rankine Bottoming Cycle System On The Existing Diesel Generation Facilities Plan c Item Installed Cost Power Plant Building (900 S.F. @ $33.33/S.F.) ..seeeeee $ 30,000 New Bottoming Cycle Units (4 @ 40,000 each).........005 160,000 Subtotal $190,000 20% Contingency 38,000 Subtotal $228,000 Engineering 12% 27 ,000 SubTotal $255,000 Interest During Construction 8,000 Total $263,000 Note: The diesel's bottoming cycle systems and waste heat utilization features require a 45' x 100' power plant building instead of a 36' x 100! building. Therefore, 900 extra square feet of building are required for the bottoming cycle systems. Table D-3 TABLE D-4 Estimated Cost For Coal Steam Generation Facilities Plan D Item Furnace and Boiler ..csccsesscccccccccvevccceceees Steam Turbine and Generator .....ccccccscccccceces co, Scrubber (Allowance) .....cccccccccccccevccece Coal and Ash Handling Equipment,..............0005 Power Plant Building (3,000 S.F. @ $33.33/S.F.)... Land 5 Acres @ $3,000 Per Acre ...... Pe rereescees Transmission Lines ...... Seer ee rcersccrcerecreressene Miscellaneous Items .....cececccccccccnvcccevecece Subtotal 20% Contingency Subtotal Engineering 12% Subtotal Interest During Construction Total Installed Cost $2,000,000 900,000 200,000 200,000 100,000 15,000 100,000 40,000 $3,555,000 710,000 a $4,265,000 510,000 __ $4,775,000 190,000 $4,965,000 Note: The total power plant building size is 6000 square feet. Only 3000 square feet is attributable to the coal steam generating system. The other 3000 square feet is attributable to the standby diesel units. Table D-4 Table D-5 Estimated Cost For Waste Heat Utilization On The Coal-Fired Steam Generation Plant Item Waste Heat Exchangers on Furnace & Condenser occcccspecens Piping to Public Buildings (11,000' @ $30/Ft.) Heat Exchanger in Public Buildings ....scsssccceccccceccce Subtotal 20% Contingency Subtotal Engineering 12% Subtotal Interest During Const. Total Installed Cost $ 105,000 330,000 440,000 $ 875,000 175,000 $ 1,050,000 125,000 $1,175,000 — 50,000 $ 1,225,000 Table 0-6 Estimate Operating and Maintenance Cost For Coal Steam Generation Facility Operation The furnace and boiler are assumed to be attended on a 24 hour basis. Five full-time employees would be required to meet the 24 hour manning requirement. The estimated cost per man year is assumed to be $30,000 in 1981 or $150,000 per year for the five men required. The operating cost includes $4,000 per year for cost for the standby diesel power. Maintenance Maintenance costs for the steam power plant are projected to be $38,000 per year. The maintenance cost also includes $4,000 per year for the standby diesel equipment. For the system utilizing waste heat, $62,000 per year has been added to the O&M costs resulting in a total annual O&M cost of $250,000. Month January February March _ April May June July August September October November December The average flows shown here are based on stream flow information in the Corp of Engineers report prepared by OTT. average flow was calculated to be 16 of 24 square m Table 0-7 JACKSON CREEK STREAM FLOW AT HYDROELECTRIC RESERVOIR LOCATION Average Flow 1.3 7 -6 8 55 36 24 2R 24 13 7 2.5 iles. cfs cfs cfs cfs cfs cfs cfs cfs cfs cfs cfs cfs The annual cfs with a drainace area Fable D-7 TABLE D-8 Estimated Cost For Hydroelectric Plant Item : : Plan — Upper Reservoir Embankment (90' X 700'). 2... Reservoir Spillway... .. 36" d Penstock (25,000' @ $I50/ft).. . el, Hydro Powerhouse Complete... ..........0,0,.., Transmission Line (9 miles @ $100,000/mile) .......,0.., Access Road to-Hydro Powerhouse (8 miles @ $25,000/mile) . . . Subtotal 25% Contingency* Subtotal Engineering 12% Subtotal Interest During Const. TOTAL Installed Cost $ 3,000,000 500 ,000 3,750,000 700 ,000 900,000 200,000 —_—_____ $ 9,050,000 2,250 ,000 $11,300,000 1,350,000 —_ $12,650,000 700 ,000 _—_————_ $13,350,000 *A 25% contingency is used here instead of the 20% used in other plans because of tne uncertainties in this plan. TABLE D-9 Estimated Cost For Wood Steam Generation Facilities Plan G Item Installed Cost Furnace and Boiler... 2... ee, $2,000 ,000 Steam Turbine and Generator... 2... ...,...,.,,.0..., 900,000 CO, Scrubber (Allowance). 2... ... 2. 200 ,000 Wood Harvesting Equipment... 2... 560,000 Wood Preparation Equipment... ........,..000..., 100 ,000 Power Plant Building (3,000' @ $33.33/S.F.).. 100 ,000 Land - Five Acres @ $3,000 Per Acre... .......,.2...., 15,000 Transmission Lines... ee ee ee ee 100,000 Miscellaneous Items...) eee 40,000 Subtotal $4,015,000 20% Contingency 800,000 Subtotal $4,815,000 Engineering 12% 580,000 Subtotal $5,395,000 Interest During Const. 200,000 TOTAL $5,595,000 NOTE: The total power plant building size is 6,000 square feet. Only 3,000 square feet is attributable to the wood steam generating system. The other 3,000 square feet is attributable to the standby diesel units. Table D-10 Estimate Operating and Maintenance Cost For Wood Steam Generation Facility Operation The furnace and boiler are assumed to be attended on a 24 hour basis. Five full-time employees will be needed to meet the 24 hour manning requirement. The estimated cost per man year is assumed to be $30,000 in 1981 or $150,000 per year for the five men required. The operating cost includes $4,000 per year for the operating cost for the standby diesel power. Maintenance Maintenance costs for the power plant are projected to be $84,000 per year. The maintenance cost also includes the $4,000 per year for maintenance cost for the standby diesel equipment. For the system utilizing waste heat, $62,000 per year has been added to the 0&M cost resulting in a total annual 0&M cost of $300,000. Table D-10 Table D-11 Estimated Cost For Wood/Gas Generation Facilities Plan H Item Two Gasifiers & Auxiliaries, 500 KWeeeccccccccccccccecves Two Engine-Generators, 500 kw pete eeeheeeeeshosteneopoece Power Plant Building (3,000 S.F. @ $33.33/S.F.)..cseseaee Wood Harvesting EQUIPMENt. .. cece cecceccecccecccscerece Land 5 Acres @ $3,000 per Acre ...cccccscccscceccccccecce Transmission Lines Miscellaneous Items. ..cccececececccscececectcececeeveveee Subtotal 20% Contingency Subtotal Engineering 12% Subtotal Interest During Construction Total Cost “ote: The total power plant building size is 6000 square feet. Only 3000 square feet is attributable to the wood/gas generating system. The other 3000 square feet is attributable to the standby diesel units. Installed Cost $ 800,000 400,000 100,000 560,000 15,000 100,000 40,000 $2,015,000 403,000 Sennen $2,418,000 300 , 000 — $2,718,000 47,000 $2,765,000 Table D-11 ee ner oe ee Table D-12 Estimate Operating and Maintenance Cost For Wood/Gas Generation Facility Operation The gasifier and engine generator are assumed to be attended on a 24 hour basis. Five full-time employees would be required to meet the 24 hour manning requirement. The estimated cost per man year is assumed to be $30,000 in 1981 or $150,000 per year for the five men required. The operating cost includes $4,000 per year for the standby diesel power, Maintenance ee, Maintenance costs for the gasifier and engine generator are projected to be about ten percent of their first costs or $124,000 per year. The maintenance cost for the standby diesel equipment is assumed to be $4,000 per year. For the system utilizing waste heat, $30,000 per year has been estimated for O&M, The total 0&M costs are $308,000. Table D-12 TABLE D-13 SUMMARY OF TECHNOLOGY PROFILES Initial Initial Capital Annual Efficiency in % Capital Cost O&M ‘onsidering Present Worth Alternative Plan Costs Per KW Elect, Output Cost Per In In And KWH In Dollars Dollars Waste Heat Used Dollars Base Case Diesel 191,000 225 57,000 2,420,000 607,000 B. Diesel W/Waste Heat 932,000 1,096 87,000 2,420,000 607,000 a Used C. Diesel W/Binary Cycle and W/Waste Heat Used 1,195,000 1,406 97,000 2,060,000 607 ,000 0, Coal-Fired Steam W/ 2 Waste Heat Used 6,381,000 7,507 250,000 5,900,000 607,000 1,207,000 .09 E, Hydroelectric W/Surplus r Electrical Output 13,591,000 15,989 36,000 -0- 607 ,000 69,000 08 F, Transmission 28,391,000 | 33,400 77,000 -0- 607,000 | -0- Not Appl. r . Not Appl. 224 G. Wood-Fired Steam W/ Waste Heat Used 7,011,000 [ 8,248 300,000 5,900,000 607 ,000 1,207,000 “10 31 012 H, Wood Gas W/Waste Heat | Used 3,679,000 4,328 308,000 3,035,000 607,000 814,000 20 47 09 Notes: 1, The initial capital cost per KW is the initial capital cost . divided by the required capacity of 850 KW. 2. The fuel input, electrical output, waste heat used and efficiencies are based on 54 year life for plan. 3. The present worth cost per KWH is based on total present worth cost minus present worth of waste heat used (as developed in Appendix E) divided by the total 178,070,000 KWH used as electrical energy in 54 years, Table D-13 4 Maintenance Area v PLANT LAYOUT Base Case Diesel Generation Showing new building to have the four existing units ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY BASE CASE DIESEL PLAN “A” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-1 APRIL, I981 Exhaust & Jacket Water Generator 95% E Electrical Output 25% Mechanical Drive 26% Misc. Engine Losses 10.5% DIAGRAM OF ENERGY BALANCE Base Case Diesel Generation NOTE: 1.All percentages shown are calculated on base being equal to 100%. 2. The overall efficiency is 25% (diesel fuel to wire). ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY BASE CASE DIESEL PLAN “A” DIAGRAM OF ENERGY BALANCE MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-2 APRIL, 1981 Exhaust & Jacket Water Losses 8.6 M BTU/Hr Electrical Output : 1000 kW or 3.41 M BTU/Hr Diesel Fuel In 100 GALS/Hr 13.5 M BTU/Hr Mechanical Drive Generator 3.6 M BTU/Hr 95% Misc. Engine Losses 1.3 M BTU/Hr DIAGRAM OF PERFORMANCE Based on Output Rate of 1000 kw Base Case Diesel NOTE: 1. The diagram of performance shown is based on a diesel generator output of 1000 kW. The 1000 kW rate isused for ease of translating to smaller output rates. ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY BASE CASE DIESEL PLAN “A” DIAGRAM OF PERFORMANCE MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-3 APRIL, !981 Steam Lines to Buildings Existing Diesel Units PLANT LAYOUT Diesel Generation with Waste Heat Utilization Showing building to house four existing units with heat recovery units. ALASKA POWER AUTHORITY - TANANA RECONNAISSANCE STUDY DIESEL W/WASTE HEAT PLAN ‘B” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-4 APRIL, 198! Steam Outlet Up to 250°F and 15 psig Jacket Water Inlet Toss ‘ cr3rsy f 3 Exhaust Out <q— ~=t———_ Exhaust In San Pe ej — > Jacket Water Return PSPs Cit ae Datel HEAT RECOVERY UNIT DETAIL ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY DIESEL W/WASTE HEAT PLAN “‘B”’ HEAT RECOVERY UNIT DETAIL MARKS ENGINEERING / PLATE NO, BROWN & ROOT, INC. piste D-5 APRIL, !981 Exhaust Loss 21.5% Heat Water Jacket & Exchanger Recovered Heat Exhaust 63.5% 42% Mechanical Generator Electrical Output Drive 26% 95% Eff. 25% Generator Losses 1.5% Engine Losses 10.5% Miscellaneous Losses DIAGRAM OF ENERGY BALANCE Diesel Generation with Waste Heat Recovery NOTES: (Annualized Basis) “ONI ‘LOON 8 NMONS 7 ONIMS3INIONS SMYVW SONV1V8 ADY3N3 JO WVYDVIG 1. All percentages shown calculated on base fuel 3. Not all the recovered waste heat can be put to being equal to 100%. beneficial use during summer months. 2. The overall efficiency is 67% considering waste heat recovered, but is only 25% when electrical energy output only is considered. Sixty-seven percent of the jacket water and exhaust heat are assumed to be utilized. LV3H 3LSVM/M 138310 AQNLS SONVSSIVNNOO3SY VNVNVL ALIMYOHLNVY YSMOd VHXSV1V ‘ON 31V1d Exhaust Loss 2.9 M BTU/Hr Heat Exhaust & Jacket . Exchanger Recovered Heat Water Losses 5.7 M BTU/Hr 8.6 M BTU/Hr . Diesel Fuel In Equals Mechanical Drive Electrical Output 100 ak 3.6 M BTU/Hr 1000 kW or 3.41 M BTU/Hr 13.5 M BTU/Hr Generator 95% Eff. Generator Losses .19 M BTU/Hr Misc. Engine Losses 1.3 M BTU/Hr 1861 “TlddV “ONI ‘LOON 8 NMONE DIAGRAM OF PERFORMANCE Diesel Generation with Waste Heat Recovery / ONINZ3SNIONS SHYVW SINVWHYOSY3d JO WVYD VIG NOTE: LW3H 31S¥M/M 7138310 AGNLS BONVSSIVNNODSY VNVNVL The diagram of performance shown is based on a diesel generator output of 1000 kW. The 1000 kw rate is used for ease of translating to smaller output rates. ALISOHLNY Y3MOd VXSVIV ‘ON 311d Recovery Unit HEAT RECOVERY UNIT (Showing Relation to Diesel Engine) ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY DIESEL W/WASTE HEAT . PLANT “B” HEAT RECOVERY UNIT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-8 APRIL, |98! Heat Recovery Unit Diesel Unit Main Generator Auxiliary Generator PLANT LAYOUT Diesel with Binary Cycle and Waste Heat Utilized ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY DIESEL W/WASTE HEAT AND BINARY CYCLE PLAN “C”’ PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-9 APRIL, (981 To Atmosphere Regenerator Vapor Generator Main Generator Electrical Electrical Auxiliary 7 95% Effic. | Output Output 4% Generator Exhaust 31% DIAGRAM OF ENERGY BALANCE Diesel-Organic Rankine Compund Engine “ONI ‘LOO’ 8 NMOYS 7 ONINZS3NIONS SHYVW 3ONVIVE ADY3N3 JO WVYDVIG wn NW1d All % shown calculated on base fuel being equal to 100% The overall efficiency (fuel to wire) is 29% without considering waste heat. When waste heat is considered the overall efficiency increased to 60% ALIYOHLNVY Y3MOd VXSVIV OL-ad ‘ON 31V1d AQNLS BONVSSIVNNOO3SY VNVNVL To Atmosphere a Regenerator To Radiator Water Cooled Condenser 174°F 17 PSIA From Radiator 309°F : Vapor 18 PSIA Generator 150 KW Flurinol 50 Main 1000 Kw = Generator_/ au. oe Generator output Generator uroine 820 PSIA Engine Exhaust DIAGRAM OF PERFORMANCE DIESEL-ORGANIC RANKINE COMPOUND ENGINE Based on Output Rate From Diesel of 1000 Net Kilowatt 1861 “TWedV ‘ONI] ‘LOON 8 NMONE / ONINZANIONS SHYVW SONVWYOSY3d JO WVeSOVIC wn NW1d ATOAD AYVNIE GNV 1V3H 31LSVM/M 138310 AQGNLS BSONVSSIVNNOOSY VNVNVL The exhaust heat of the diesel engine is sufficient to produce 150 KW of electrical power with a bottom cycling unit when net output from the diesel generator is 1000 KW. The added 150 KW of electrical output should improve efficiency (fuel to wire) by 15% from 25% to 29%. When waste heat utilization is considered, the efficiency is 60%. ALIYOHLNVY YSMOd VASV1V LL-G eld ‘ON 314d Waste Heat Pipelines Rtecieetiael 4 Diesel Generators Power Plant = 40’ x 150’ ad Furnace & Steam Turbine Generator fe Coal Storage Area 200’ x 200° | Unloading Conveyor | Coal Barge YUKON RIVER —=—__ PLANT LAYOUT Coal-Fired Steam Generation ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY COAL-FIRED STEAM PLAN “D” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. S Plate D-12 APRIL, |981 “ONI ‘LOO’ 8 NMONS / ONINZ3SNIONS SHVW INV 1VE ADYANS SO WVYSVIG EL-C Seid ‘ON 31V 4d #@., NW1d WV3LS G3uIs-1VOO AGNLS SONVSSIVNNOOSY WNYNVL ALIYOHLNVY Y3SMOd VXSVIV 29.25% Furnace & Boiler Losses 14.5% Turbine Loss Furnace ; 10.75% & 70.75% Turbine | Turbine Output Boiler Steam ene 4.5% to 41% to Auxiliaries Circulating & Misc. Losses Water DIAGRAM OF ENERGY BALANCE Coal-Fired Steam Generation . All percentages shown are calculated on base fuel being equal to100%. ~ . The overall efficiency is 10.3% (coal to wire). . Waste heat (furnace & boiler losses and circulating water) can be utilized. If 34% of the furnace & boiler loss and the circulating water loss is used, the overall efficiency becomes 34%. .5% Machine Loss Generator © 95% Flue Gas, Temp. = 2,500°F 9.74 M BTU/HR Mechanical Energy from Turbine Shaft = Machine Loss 1053 KWH 4.87 M BTU/HR 3.59 M BTU/HR 1000 KW Electrical Energy 3.41 M BTU/HR Coal In Furnace Generator 4170 Ibs/hr & Steam 18,420#/hr, 1200 Btu/Ib 95% 33.35M Boiler Temp = 400°F, P = 250 psia Effic. BTU/HR 22.11 M BTU/HR 13.65 M BTU/HR in Waste Heat from Condenser in cooling water 1.5 M BTU to Temp = 120°F Auxiliaries NOTE: 1. The boiler will require 4170 Ibs of coal per hour to produce DIAGRAM OF PERFORMANCE 18,420 Ibs of steam per hour. This is based on coal having a Based on Output Rate of 1000 KW heating value of 8,000 BTU/Ib. Coal-Fired Steam Generation . The turbine will require 18,420 Ibs of steam per hour to produce 1,053 KWH of mechanical energy. This is based on 250 psia and 400°F steam having 1,200 BTU per lb. . The generator will require 1,053 KWH shaft input from the turbine to produce 1,000 KWH. This is based on a generator efficiency of 95%. “ON! “LOOM ® NMOUS / ONIMZ3NIONZ SHYVW SONVWYOSYSd JO WVEDVIG #@., NW1d WV3SLS G3yld-1VO9 AGNLS SONVSSIVNNOOSY VNVNVL ALIMOHLNY YBMOd VAS IV . The overall efficiency shown is 10.3% (coal to wire). The 10.3% efficiency should be realized at the most efficient operating points. DL-C Seid ‘ON 31LV 1d Flue Waste Heat Exchange Rate Heat = 3.24 M BTU/HR, 6.5M Temp. Rise = 12°F BTU/HR Coal Furnace Turbine Condenser 4.8 M BTU/Hr, Temp Rise = 18°F © - o c © a c o £ ° x Ww ~ oS o = Auxiliary Cooling as required to limit Maximum Discharge Temperature to 113°F Water Flow Rate of 540 gpm or 268,000 LBS/Hr DIAGRAM OF HEAT TRANSFER UTILIZING WASTE HEAT WITH ONE CIRCULATING WATER SYSTEMS NOTES: 1. The flow and heat exchange rates shown are for a generation rate of 1,000 kW. Reduction in generation rate will reduce the heat exchange rate. ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY 2. It is assumed that 34% of the total waste heat in the condenser and flue is utilized or 34% (13.65 M BTU + COAL-FIRED STEAM . PLAN “D” INNS en ST. DIAGRAM OF HEAT TRANSFER 3. Not all the utilized waste heat shown here can be put MARKS ENGINEERING / PLATE NO. to beneficial use during summer months. BROWNS CROGT: LINC. Plate D-15 APRIL, !981 (‘xosdde) sayy GL =,,1 dVW V4auVv PLATE NO. EB” 1981 PLAN PROJECT LAYOUT HYDROELECTRIC ALASKA POWER AUTHORITY APRIL TANANA RECONNAISSANCE STUDY MARKS ENGINEERING / BROWN & ROOT, INC. > 3sno “3s Storage Reservoir Vol = 5,000 Ac-Ft “ONI ‘LOOM @ NMONE / ONINZ3SNIONS SHYVW S3YNLV3d JO WVHOVIG LL-G 8elg ‘ON 31V1d wi. NW1d 91YLOST3SONGAH AGNLS BONVSSIVNNOOSY WNVNVL ALIYOHLAY Y3BMOd VySY IV 25,000 of EL 580.0 36” d penstock EL.660 Loss in Pipe = 55’ at q = 33 cfs Hydro Turbine, 87% Efficient Turbine Output = 895 kw DIAGRAM OF FEATURES NOTES 1. Average Q through unit = 15 cfs. 2. Q at rated output = 33 cfs, head = 350 feet. 3. Average Annual Electrical Power Output = 3,800,000 kWH based on q = 15 cfs, average head = 400 feet. Generator 95% Efficient Rated output = 850 kw Tailwater EL.230 Maintenance PLANT LAYOUT Hydroelectric Generation Showing New Building to House the Four Existing Units as Standby Capacity ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY HYDROELECTRIC PLAN “E” LAYOUT OF STANDBY DIESELS MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-i8 APRIL, 1981 a ARCTIC OCEAN BERING SEA 69 KVA LINE TANANA FAIRBANKS ANCHORAGE id Sh PACIFIC OCEAN « BRISTOL BAY AREA MAP (Showing 69 KVA Transmission Line from Fairbanks to Tanana) ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY TRANSMISSION PLAN “F”’ AREA MAP MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. D-19 APRIL, !981 Waste Heat Pipelines 4 Diesel Generators as Standbys 40’ x 150’ Powerhouse Housing Steam and Diesel nee, pe * Turbine, and Generator Equipment : . Wood Storage Area 250’ x 500 (1 year storage capacity) Wood Carrying Barge, 240 Ton Capacity YUKON RIVER ——_— PLANT LAYOUT Wood-Fired Steam Generation ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY WOOD-FIRED STEAM PLAN “’G” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-20 APRIL, |981 29.25% Furnace & Boiler Losses 14.5% Turbine Loss -5% Machine Loss Furnace . 10.75% Generator & Turbine | Turbine Output — 95% : 16% Boiler Efficient 41% to 4.5% to <—Circulating Auxiliaries Water & Misc. Losses DIAGRAM OF ENERGY BALANCE Wood-Fired Steam Generation NOTE: 1. All%‘s shown are calculated on base fuel being equal to 100%. / ONIMSSNIONS SHYVW “ON! ‘LOOS 8 NMONS SJONVIVE ADYSNS SO WVYSVIG Dn NWI1d WV3LS G3yYls-dOOM AQGNLS BONVSSIVNNOOSY VNVNVL . The overall efficiency is 10.3% (wood to wire). . Waste Heat (Furnace & Boiler losses and circulating water) can be utilized. If 34% of the furnace & boiler loss and the circulating water loss is used, the overall efficiency becomes 34%. ALIYOHLNVY Y3MOd VASVIV LZ- 8eld ‘ON 31V1d Flue Gas, Temp. = 2,500°F 9.74 M BUT/HR Machine Loss . 4.87 MBTU/HR Mechanical Energy from Turbine Shaft =1053 KWH 3.59 M BTU/HR Generator = Furnace Wood In Effici 2.4 cords/hr Boiler Steam 18,420#/hr, 1200 Btu/Ib ficient 7000 Kw Electrical 33.35 M BTU/HR Temp = 400°F, P = 250 psia Energy 22.11 M BTU/HR 13.65 M BTU/HR in 3.41 M BTU/HR Waste Heat from Condenser ° - to in cooling water uxiliaries Temp. = 120°F & —————— 95% DIAGRAM OF PERFORMANCE Based on Output Rate of 1000 KW Wood-Fired Steam Generation NOTE: 1. The boiler will require 2.4 cords of wood per hour to produce 3. The generator will require 1,053 KWH shaft input from the 18,420 Ibs of steam per hour. This is based on wood having an turbine to produce 1,000 KWH. This is based on a generator as-fired moisture content of 12% with a heating value of 14M efficiency of 95%. BTU/cord. ‘ONI ‘LOON 8 NMOUS / ONIMZ3NIONS SHYVW JONVWYOSYsd JO WVYDVIG Dee NWId WV3LS G3uYls-GOOM AGNLS BSONVSSIVNNOO3SY VNVNVL 4. The overall efficiency shown is 10.3% (wood to wire). The -, The turbine will require 18,420 Ibs of steam per hour to 10.3% efficiency should be realized at the most efficient produce 1,053 KWH of mechanical energy. This is based on operating points. 250 psia and 400°F steam having 1,200 BTU per Ib. ALIMOHLNVY YSMOd VASVIV 72- Skid ‘ON 31V1d Flue Waste Heat Exchange Rate Heat =3.24M BTU/HR, 6.5 Temp. Rise = 12°F M BTU/HR ooeu So Cro asa Wood . ce Turbine Sa 3 Furnace Condenser gan re) «© ¢ av 3 no = e Auxiliary Cooling as required to limit Maximum Discharge Temperature to 113°F Water Flow Rate of 560 gpm or 279,000 LBS/HR DIAGRAM OF HEAT TRANSFER UTILIZING WASTE HEAT WITH ONE CIRCULATING WATER SYSTEMS ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY WOOD-FIRED STEAM PLAN G” DIAGRAM OF HEAT TRANSFER - MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. Plate D-23 APRIL, I98I NOTES: 1. The flow and heat exchange rates shown are for a generation rate of 1,000 KW. Reduction in generation rate will reduce the heat exchange rate. 2. It is assumed that 34% of the total waste heat in the condenser anf flue is utilized or 34% (13.65 M BTU + 9.74 M BTU) = 8.04 M BTU/HR. . Waste Heat to Buildings 4 Diesel Generators 50’ x 120’ Power Plant Housing Wood/Gas and Diesel Equipment Wood Gas Engines & Generator Wood Storage Area 200’ x 350’ +1 year storage capacity) Cable Unloading System Wood Carrying Barge, 240 Ton Capacity YUKON RIVER a PLANT LAYOUT Wood/Gas Fired ation el nee enee ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY WOOD/GAS FIRED ENGINE PLANT “H”’ PLANT LAYOUT MARKS ENGINEERING / PLATE NO, BROWN & ROOT, INC. Plate D-24 APRIL, |981 186i “Wed “ONI| ‘LOON @ NMOUS SZ-C S32ld 7 ONINZ3NIONS SHYVW JONVIVE ADY3NS JO WV¥dVId ‘ON 311d 3NIDN3 G3uld SVD/GOOM AGNLS SONVSSIVNNOOSY VNVNVL ALISNOHLNY Y3MOd VXSVIV 23% Radiation & Ash Gasifier 70% Producer Gas NOTES: Recovered 29% | Heat Exchanger Exhaust Loss 13% 42% Exhaust & Jacket Water Scrubber- Producer ; Mechanical} Generator Cooler Gas 63% __| Engine Drive 21% 95% Efficient Diesel 7% 7% Misc. Engine Losses DIAGRAM OF ENERGY BALANCE Wood/Gas Generation 1. All % shown are based on fuel into the total system being equal to 100%. 2. The overall efficiency is 20% when only electrical energy is considered but is 49% when recovered waste heat is considered. Electrical Output 20% 1861 ‘TWdv ‘ONI ‘LOON @ NMONS 7 ONINZ3NIONS SHYVW JONVWYOsY3Sd JO WVYDVIG 97-C 81eId Wood In 1.14 Cords/hr. or 15.95 MBTU/HR Wood & Diesel 17.15 MBTU/HR wH., NW1d ANIDN3 G3uls SVD/GOOM AGNLS BSONVSSIVNNOO3SY VNVNVL ALIYOHLNVY Y3MOd VXSV IV ‘ON 31V1d Loss 2.18 MBTU/HR Radiation & Ash Recovered Heat | 5.03 MBTU/HR | 3.95 MBTU/HR Toss Heat 1.20 MBTU/HR Exchanger Water, 7.21 MBTU/HR- Gasifier Producer Gas, Scrubber 12.0 MBTU/HR Cooler Diesel Fuel, 1.3 MBTU/HR Exhaust & Jacket Generator 95% Eff. Mechanical Energy 3.59 MBTU/H Misc. Engine Losses 1.3 MBTU/HR DIAGRAM OF PERFORMANCE Based on Output Rate of 1000 KW Wood/Gas Generation Electrical Energy 1000 KW, 3.41 MBTU/HR APPENDIX E ENERGY PLAN COSTS AND NONELECTRICAL BENEFITS EEL TRITCAL_ BENEFITS General The results of this economic evaluation were presented in Section VII of this report. The data developed to support the results are presented in this appendix. The total present-worth costs for eacn plan are shown in Tables E-1 through E-8 and described in Section 2 of this appendix. The economic analysis in each plan is based on the following: a. The economic evaluation Period is 54 years. Tnis figure was selected because tne longest-lived project, the hydroelectric plan, begins operating after 4 years and has an expected life of 50 years. The interest rate for Purposes of present-worth calculations, interest during construction, and interest and amortization calculations is 3%. The inflation rate is assumed to De zero. The petroleum fuel costs are escalated at 3.5% compounded annually for 20 years. Coal costs are not escalated. The projected diese] fuel costs were based on the 1980 cost of $1.80 per gallon. Capital costs are treated in the following manner. The investment cost are as of the project's date on-line. The investment cost is the sum of the capital costs over the construction period plus interest during construction at 3%. The annual capital cost of the investment Over the components' economic life is based on an interest rate of 3%. (This is the annual uniform interest and amortization payment. ) The equivalent average annual cost is assigned to each year from the date on-line through the end of tne 54-year economic evaluation Period. f. Since inflation is assumed to be zero and since there is no escalation beyond the 20-year planning period, yearly plan costs beyond the 20-year planning period are the same as the costs of the last year of the planning period. It is assumed that demand remains constant after the 20-year planning period and that components are replaced as required. Yearly plan costs are therefore assumed to be uniform until the end of the 54-year economic analysis period. g. Costs downstream of the bus bar common to all plans are not considered. h. All costs over the 54-year economic analysis period are discounted at a rate of 3% to the reference date. Discounted costs are summed to give tne present-wortn-of-plan costs. i. Operations, maintenance, and fuel costs are assigned to the year in which they occur. Certain plans have benefits that result from nonelectrical Output (space heating) or surplus electrical output. These are described in Section 3. The present-worth costs of the heat utilized are also projected in the tables and are founded on the same economic assumptions as those for the electrical production. Estimated capital, operation, maintenance, and fuel cost are detailed in Appendix 0. 2. Present-Worth Costs of Plans — een sts of Fians a. Base-Case Diesel Generation (Plan A) soesme ase Miese! Generation (Plan A) This alternative projects tne use of tne existing diesel units and relocation of them in a new powerhouse, as shown on Plate E-]. Capital costs are projected during the first year, and Payment is projected to start during the second year. The toal present-worth cost for the plan is $26,421,000, as shown in Table E-1. Diesel Generation with Utilization of Waste Heat (Pian B) This alternative projects the use of the existing diesel units with added heat recovery units, as shown on Plate E-2. The waste heat recovery feature will add to the cost of the base-case diesel generation plan. The costs for the diesel generation are the same as for Plan A; the capital costs for waste heat include those for a portion of the powerhouse required and other items related to utilization of waste heat totaling $741,000, as shown in Table E-2. The operation and maintenance cost to use the waste heat is estimated to be $30,000 per year. The total present-worth cost for this plan is $28, 363,000. Diesel Generation: with Binary Cycle (Pian C) This plan projects the use of the existing diesel units with new Organic-Rankine bottom cycling systems added to each. Waste heat would also be utilized. (See Plate E-3 for the plant layout.) Costs for this plan are shown in Table E-3. The costs include costs of Plan 8 plus costs for the bottoming cycle system. The total present-worth cost for this plan is $25,453,000. The binary cycle is assumed to be in operation at the beginning of the third year, and reduced fuel costs during the third year reflect that fact. Coal-Fired Steam Generation (Plan D) This alternative projects the use of coal to fire a boiler to produce steam, which would drive a turbine generator to produce electricity. (A layout is shown on Plate E-4.) The cost include costs for standby diesel generation, waste heat recovery, and coal-fired steam generation. The total present-worth cost for this plan is $28,848,000, as shown in Table E-4. The steam plant is projected to start producing electrical energy at the beginning of the fourth year. (A layout is shown on Plate E-5.) The fuel costs are annual costs for the coal and the diesel fuel for the backup diesel units, which are assumed to supply 5% of the energy needs as standby power. Delivery of the coal is projected to begin in the third year, but use e. g. of the coal is projected to start in the fourth. Waste heat utilization is based on a capital expenditure of $1,225,000 during the third year and continued operating and maintenance cost of $62,000 per year beginning with the fourth year. Hydroelectric Generation (Plan E) The total present-worth cost for this plan is $14,673,000, as shown in Table E-5. This alternative will require construction of an 850-kW hydroelectric plant on Jackson Creek east of the community. A 5,000-acre-foot reservoir will also be a part of the development. Total costs includes costs for the standby diesel generation, utilization of surplus electrical energy, and hydroelectric generation. Output from the hydroelectric plant is projected to begin at the start of the fifth year, with electrical needs for the first 4 years to be supplied by the existing diesel system. Transmission (Plan F) Electrical energy for this alternative would be taken from the existing grid at Fairbanks, (A layout is shown on Plate E-6.) The cost includes diesel generation costs for the first three years of operation and transmission costs for years 3 through 54. The total Present-worth cost for this plan, shown in Table E-6, is $43,047,000. During the first, second, and third years of the economic analysis, the electrical energy requirements are to be supplied by the existing diesel system. The energy costs under transmission are annual costs for the electrical power from Fairbanks, assumed to be 8¢ per kWH with no escalation in price. Wood-Fired Steam Generation (Plan G) This alternative projects the use of wood as a fuel to produce electrical power. The existing diesel equipment will. be used for standby power. (The plant layout is shown on Plate E-7.) The total Present-worth cost for this plan, shown in Table E-7, is $33,798,000. 3. During the first, second, and third years of the economic analysis, the electrical energy requirements are to be supplied by the existing diesel system. Diesel generation is to supply 5% of the electrical energy needs as standby power. Harvesting of wood is projected to begin in the third year, but use of wood is projected to start in the fourth year. , h. Wood Gas Generation (Plan H) This alternative involves the use of locally harvested wood, which is to be converted to gas in a gasifier. The wood gas would be the fuel for an internal-combustion engine that would drive a generator. (The layout for this alternative is shown on Plate E-8.) The total Present-worth cost for this plan is $25,495,000, as shown in Table E-8. During the first, second, and third years of the economic analysis, the electrical energy requirements are to be supplied by the existing diesel system. Diesel generation is to supply 5% of the electrical energy needs as standy power. Harvesting of wood is Projected to begin in the third year, but use of wood is projected to start in the fourth year. Present Worth of Nonelectrical and/or Surplus Electrical Benefits Se or one ectrical and/or surplus clectrical Benefits Certain plans offer nonelectrical or surplus electrical benefits. The amount of waste heat that can be used for space heating varies with the season, with winter months showing a greater heating requirement than summer months. (The projected variation is shown on Table E-9.) The waste heat that can be recovered exceeds the waste heat that can be put to beneficial use during the summer months. The electrical use and therefore the waste heat generation are projected as constant during the year. The waste heat that can be utilized in July, for instance, is 3.1% of the annual need, and for December the figure is 12.6 % of the annual need. (The waste heat that is to be used is shown in the Tables E-10 through E-14.) The waste heat from the several generation plans evaluated in this study is to supply part or all of the heat required by up to six of the larger buildings in the community. These buildings and their 1980 annual fuel consumption for space heating are: Building Fuel Oil in Gallons o PHS school 140, 000 © School housing 4,000 0 School 24,000 o AC store 4,500 o Safe water facility 15,000 o FAA facility 35,000 Total = 222,500 gallons The 222,500 gallons are projected to produce 20,356 million Btu of heating on the basis of 0.135 million Btu per gallon and an efficiency of 68%. The 1981 value is 20,970 million Btu. The waste heat that can be used was calculated on the basis of the heating requirements distribution shown on Table E-9 and a waste heat production rate that is equal for each month of the year. Nonelectrical benefits are the subject of separate calculations. The benefits are assigned to the year in which they occur and discounted in the same way as costs, thereby giving the present worth. For instance, in the case of Plan B, the utilization of waste heat saves fuel oil that would otherwise be consumed for space heating. The nonelectrical benefit calculations as shown in Tables E-15 through E-19. The present worth of a plan's nonelectrical benefits is treated as a credit that offsets, dollar for dollar, the present-worth-of-plan costs. In the case of Plan B, for example, the present worth of nonelectrical benefits is subtracted from the present worth of costs to give the adjusted present-worth cost of $19,027,000. a. Base-Case Diesel Generation (Plan A) This plan has no nonelectrical benefits. Diesel Generation with Utilization of Waste Heat (Plan B) This plan will utilize waste heat beginning with year three, as shown in Table E-10. The value of the waste heat utilized is based on the value of fuel oil replaced in central heating of public buildings. The total present worth of the benefits is $9,336,000, as shown in Table E-15. The value of the heat utilized is based on a fuel oil cost of $1.80 per gallon in 1980 and a furnace efficiency of 68% for a 1981 fuel cost of $20.15 per million Btu or $21.59 in 1983. Diesel Generation with Binary Cycle (Plan C) This plan will provide waste heat beginning with year three, as shown in Table E-11. The value of the waste heat utilized is based on the value of fuel oi] replaced in central heating of public buildings, as in Plan B. The total present worth of the benefits is $6,788,000, as shown in Table E-16. Coal-Fired Steam Generation (Plan D) This plan will provide waste heat beginning with the fourth year, as shown in Table E-12. The value of the waste heat utilized is based on the value of fuel oi] replaced in central heating of public buildings as in Plan B. The total present worth of the benefits is $12,911,000, as shown in Table E-17. Hydroelectric Generation (Plan E) This plan will provide surplus electrical energy beginning during the fifth year, as shown in Table E-13. The value of the surplus electrical energy is based on the value of propane fuel and fuel oi] used in cooking and space heating that it is to replace. The total present worth of benefits is $1,488,000, as shown in Table E-18. The E-7 f. value of the surplus electrical energy replacing propane and fuel oil is $23.15 per million Btu in 1981 and is based on a propane gas cost in 1981 of $0.66 per pound and an efficiency of 95%. The propane is assumed to yield 21,846 Btu per pound. Transmission (Plan F) This plan has no nonelectrical benefits. Wood-Fired Steam Generation (Plan G) This plan will provide waste heat beginning during year four, as shown in Table E-12. The value of the waste heat utilized is based on the value of fuel oil replaced in central heating of public buildings, as in Plan B. The total present worth of the benefits is $12,911,000, as shown in Table E-17. , Wood Gas Generation (Plan H) This plan will. provide waste heat beginning during year four, as shown in Table E-14. The value of the waste heat utilized is based on the value of fuel oil replaced in central heating of public buildings, as in Plan B. The total present worth of the benefits is $8,929,000, as shown in Table E-19. Table E-] Estimated Costs of Plan “AY Diesel Generation (Base Case) Years YU Plan Component 1 2 3 4 5 6 7 . 8 9 1, Diesel Generation Capital Cost -0- 7,0003/ 7,000 7,000 7,000 7,000 7,000 7,000 7,000 ORM 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 Fuel 5/ 383,000 408,000 435,000 463,000 493,000 525,000 559,000 596,000 635,000 Total Cost 440,000 472,000 499,000 527,000 557,000 589,000 623,000 660,000 699,000 Discounted Cost 4/ ~ 427,000 445,000 457,000 468,000 480,000 493,000 506,000 521,000 536,000 Total Present Worth of Plan Cost - $11,358,000 over a 20 year period Total Present Worth of Plan Cost - $26,421,000 over a 54 year period Page 1 of 2 Jo 7,000 57,000 676,000 740,000 551,000 Table E-1 Estimated Costs of Plan “q" (continued) Diesel Generation (Base Case) Years 1/ ’ 21 thru, u 2 3 u 15 16 v 18 iy 20 5A 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 720,000 766,000 816,000 869,000 926,000 , 986,000 1,050,000 1,118,000 1,191,000 1,269,000 1,269,000 784,000 830,000 880,000 933,000 990,000 1,050,000 1,114,000 1,182,000 1,255,000 1,333,000 1,333,000 566,000 582,000 599,000 617,000 635,000 654,000 674,000 694,000 716,000 738,000 15,063,000 Planning period is 20 years. Economic evaluation period is 54 years. The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period, This annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 percent, Reference year is year zero, or one year prior to the start of the planning period. This row is summed to give the unadjusted percent worth of plan costs, Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 Table E-2 Estimated Costs of Plan "B" Plan Component 1 2 3 1, Diesel Generation Capital Cost -0- 7,0003/ 7,000 O&M 57,000 57,000 57,000 Fuel 6/ 383,000 408,000 435,000 2. Waste Heat Utilization 4/ Capital Cost -0- -0- 50,000~ O&M -0- -0- 30,000 Total Cost 440,000 472,000 579,000 Discounted Cost 5/ 427,000 445,000 530,000 Diesel Generation with Waste Heat Utilized Years 1/ 4 5 7,000 7,000 57,000 57,000 463,000 493,000 50,000 50,000 30,000 30,000 607,000 637,000 539,000 549,000 7,000 57,000 525,000 50,000 30,000 669,000 560,000 Total Present Worth of Plan Cost = $12,396,000 over a 20 year period, Total Present Worth of Plan Cost = $28,363,000 over a 54 year period. Page 1 of 2 7,000 57,000 559,000 50,000 30,000 703,000 572,000 7,000 57,000 596,000 50,000 30,000 740,000 584,000 7,000 57,000 635,000 50,000 30,000 779,000 597,000 7,000 57,000 676.000 50,000 30,000 820,000 610,000 y 2/ 3/ 4/ 5/ jig Table E-2 Estimated Costs of Plan “B" (continued) Diesel Generation with Waste Heat Utilized Years 1/ . 2i thrug, 1 2 B 4 45 16 n 1s ay 20 54 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 720,000 766,000 816,000 869,000 926,000 986,000 1,050,000 1,118,000 1,191,000 1,269,000 1,269,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 864,000 910,000 960,000 1,013,000 1,070,000 1,130,000 1,194,000 1,262,000 1,353,000 1,413,000 1,413,000 624,000 638,000 654,000 670,000 687 ,000 704,000 722,000 741,000 761,000 782,000 15,967,000 Planning period is 20 years. Economic evaluation period is 54 years. The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period, This annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 percent. This annual cost is based on an investment cost of $741,000 amortized over 20 years at 3 percent, Reference year is year zero, or one year prior to the start of the planning period. This row is summed to give the unadjusted present worth of plan costs. Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 Plan Component 1, Diesel Generation Capital Cost O&M Fuel 7/ 2. Waste Heat Utilization Capital Cost O&M 3. Bottoming Cycle System Capital Cost 08M Total Cost ° Discounted Cost §/ -0- 57,000 383,000 440,000 427,000 7,0003/ 57,000 408,000 472,000 445,000 Total Present Worth of Plan Cost - $11,317,000 over a 20 year period. Total Present Worth of Plan Cost - $25,453;000-over a 54 year period. Table E-3 Estimated Costs of Plan "Cc" Diesel Generat and with Waste 7,000 57,000 370,000 50,0004/ 30,000 18,0002/ 10,000 542,000 496,000 Wears 4) lized 4 5 7,000 7,000 57,000 57,000 394,000 419,000 50,000 50,000 30,000 30,000 18,000 18,000 10,000 10,000 566,000 591,000 503,000 510,000 Page 1 of 2 ion with Bottom Cycle System 7,000 57,000 446,000 50,000 30,000 18,000 10,000 618,000 518,000 7,000 57,000 475,000 50,000 30,000 18,000 10,000 647,000 526,000 7,000 57,000 507,000 50,000 30,000 18,000 10,000 679,000 536,000 7,000 57,000 540,000 50,000 30,000 18,000 10,000 712,000 546,000 Jo 7,000 57,000 575,000 50,000 30,000 18,000 10,000 747,000 556,000 y 2/ 3/ 4/ 5/ 6/ Table E-3 Estimated Costs of Plan "C" (continued) Diesel Generation with Bottom Cycle System and with Waste Hegf iki |jzed ‘ = 21 thru 2/ u @ 1 4 1s 1s u 1a re) 20 54 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 57,000 +57 ,000 57,000 57,000 612,000 652,000 693,000 739,000 788,000 839,000 892,000 950,000 1,014,000 1,079,000 1,079,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 18,000 18,000 18,000 18,000 18,000 18,000 18,000 18,000 18,000 18,000 18,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 784,000 824,000 865,000 911,000 960,000 1,011,000 1,064,000 1,122,000 1,186,000 1,251,000 1,251,000 567,000 578,000 589,000 602,000 616,000 630,000 644,000 659,000 676,000 693,000 14,136,000 Planning period is 20 years. Economic evaluation period is 54 years. The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period. The annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 Percent. The annual cost is based on an investment cost of $741,000 amortized over 20 years at 3 percent, The annual cost is based on an investment cost of $263,000 amortized over 20 years at 3 percent. Reference year is year zero, or one year prior to the start of the Planning period. This row is summed to give the unadjusted present worth of plan costs, Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing py 3.5% per year. Page 2 of 2 I= Plan Component 1. Diesel Generation Capital Cost -0- O&M 57,000 Fuel 7/ 383,000 2. Waste Heat Utilization Capital Cost -0- O&M -0- 3. Coal Steam Generation Capital Cost -0- O&M -0- Fuel -0- Total Cost 440,000 Discounted Cost6/ 427,000 i) 7,0003/ 57,000 408 ,000 472,000 445,000 Table E-4 Estimated Costs of Plan "D" [wo 7,000 57,000 435,000 -0- -0- -0- 302,000 801,000 733,000 Coal-Fired Steam Generation With Waste Heat Utilized Years 1/ 4 5 7,000 7,000 8,000 8,000 23,000 25,000 82,0004/ 82,000 62,000 62,000 334,0002/ 334,000 180,000 180,000 311,000 321,000 1,007,000 1,019,000 895,000 879,000 Io 7,000 8,000 26,000 82,000 62,000 334,000 180,000 331,000 1,030,000 863,000 Total Present Worth of Plan Costs - $14,881,000 over a 20 year period. Total Present Worth of Plan Costs - $28,848,000 over the 54 year period. Page 1 of 2 In 7,000 8,000 28,000 82,000 62,000 334,000 180,000 341,000 1,042,000 848,000 lo 7,000 8,000 30,000 82,000 62,000 334,000 180,000 351,000 1,054,000 832,000 7,000 8,000 32,000 82,000 62,000 334,000 180,000 361,000 1,066,000 817,000 10 7,000 8,000 34,000 82,000 62,000 334,000 180,000 372,000 1,079,000 803,000 Table E-4 Estimated Costs of Plan “D" (continued) Coal Fired Steam Generation With wages dea} Utilized u R 3 M 5 16 7,000 7,000 7,000 7,000 7,000 7,000 8,000 8,000 8,000 8,000 8,000 8,000 36,000 38,000 41,000 43,000 46,000 49,000 82,000 82,000 82,000 82,000 82,000 82,000 62,000 62,000 62,000 62,000 62,000 62,000 334,000 334,000 334,000 334,000 334,000 334,000 180,000 180,000 180,000 180,000 180,000 180,000 383,000 395,000 407,000 419,000 431,000 443,000 1,092,000 1,106,000 1,121,000 1,135,000 1,150,000 1,165,000 789,000 776,000 763,000 750,000 738,000 726,000 Planning period is 20 years. Economic evaluation period is 54 years. Vv 7,000 8,000 52,000 82,000 62,000 334,000 180,000 456,000 1,181,000 715,000 18 7,000 8,000 56,000 82,000 62,000 334,000 180,000 470,000 1,199,000 704,000 19 7,000 8,000 59,000 82,000 62,000 334,000 180,000 485,000 1,217,000 694,000 . 20 7,000 8,000 63,000 82,000 62,000 334,000 180,000 500,000 1,236,000 684,000 21 thru, 54 7,000 8,000 63,000 82,000 62,000 334,000 180,000 500,000 1,236,000 13,967 ,000 The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period. This annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 percent. This annual cost is based on an investment cost of $1,225,000 amortized over 20 years at 3 percent. This annual cost is based on an investment cost of $4,965,000 amortized over 20 years at 3 percent. Reference is to year zero, Or one year prior to the start of the planning period. This row is summed to give the unadjusted present worth of plan costs. Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 Table E-5 Estimated Costs of Plan "E" Hydroelectric . Years 1/ Plan Component i 2 3 4 5 6 7 8 9 1, Diesel Generation Capital Cost -0- 7,000 a/ 7,000 7,000 7,000 7,000 7,000 7,000 7,000 O&M 57,000 57,000 57,000 57,000 10,000, 10,000 10,000 10,000 10,000 Fuel 7/ 383,000 408,000 435,000 463,000 -0- -0- -0- -0- -0- 2. Surplus Power Utilization 4/ Capital Costs -0- -0- -0- -0- 4,000~/ 4,000 4,000 4,000 4,000 08M -0- -0- -0- -0- 1,000 1,000 1,000 1,000 1,000 3. Hydroelectric 5/ Capital Costs -0- -0- -0- -0- 519, 000-! 519,000 519,000 519,000 519,000 O&M -0- -0- -0- -0- 25,000 25,000 25,000 25,000 25,000 Total Cost 440,000 472,000 499,000 527,000 576,000 576,000 576,000 576,000 576,000 Discounted Cost9/ 427,000 445,000 457,000 468,000 497,000 483,000 468,000 455,000 441,000 Total Present Worth of Plan Costs - $ 8,221,000 over a 20 year period. Total Present Worth of Plan Costs - $14,673,000 over the 54 year period. Page 1 of 2 Table E-5 Estimated Costs of Plan “E" (continued) Hydroelectric Years 1/ \ ‘ 2 they Jo un RB B M 3 16 vu 18 aE} 20 54 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 . 7,000 7,000 7,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 10,000 -0- -0- -0- -0- -0- -0- -0- -0- -0- -0- -0- -0- 4,000 4,000 4,000 4,000 4,000 4,000 4,000 4,000 4,000 4,000 4,000 -0- 1,000 1,000 1,000 1,000 1,000 1,000 1,000 1,000 1,000 1,000 1,000 -0- 499,000 519,000 | 519,000 519,000 519,000 519,000 519,000 519,000 519,000 519,000 519,000 519,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 25,000 576,000 576,000 576,000 576,000 576,000 576,000 576,000 576,000 576,000 576,000 576,000 571,000 429,000 416,000 404,000 393,000 382,000 369,000 358,000 348,000 338,000 . 328,000 320,000 6,452,000 / Planning period is 20 years. Economic evaluation period is 54 years. 2/ The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period. 3/ This annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 percent. 4/ This annual cost is based on an investment cost of $50,000 amortized over 16 years at 3 percent. 5/ This annual cost is based on an investment cost of $13,350,000 amortized over 50 years at 3 percent. 6/ Reference year is year zero, or one year prior to the start of the planning period. This row is summed to give the unadjusted present worth plan costs. J/ Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 Table E-6 Estimated Costs of Plan "F" Transmission : . Years 1/ Plan Component 1 2 3 4 5 6 7 8 9 1. Diesel Generation Capital Cost -0- 7,000 3/ 7,000 7,000 7,000 7,000 7,000 72000 7,000 O&M 57,000 §7,000 57,000 10,000 10,000 10,000 10,000 10;00 10,000 Fuel5/ 383,000 408,000 435,000 -0- -0- -0- -0- -0- -0- 2. Transmission Capital Cost -0- -0- -0- 1,439, 0004/ 1,439,000 1,439,000 1,439,000 1,439,000 1,439,000 O&M -0- -0- -0- 70,000 70,000 70,000 70,000 70,000 70,000 Energy -0- -0- -0- 180,000 185,000 191,000 196 ,000 202,000 208,000 Total Cost 440,000 479,000 599,000 1, 706,000 1,711,000 1,717,000 + ~* 1,722,000 1,728,000 1,734,000 Discounted Cost 427,000 452,000 548,000 1,516,000 1,476,000 1,439,000 1,400,000 1,364,000 1,329,000 Total Present Worth of Plan Costs - $16,438,000 over a 20 year period. Total Present Worth of Plan Costs - $43,047,000 over the 54 year period. Page 1 of 2 10 u 7,000 7,000 10,000 10,000 1,439,000 1,439,000 70,000 70,000 215,000 221,000 1,741,000 1,747,000 1,295,009 1,262,000 Planning period is 20 years. | of Ss ss 1,439,000 70,000 228,000 1,754,000 1,230,000 1,439,000 70,000 235,000 1,761,000 1,199,000 Table E-6 Estimated Costs of Plan "F" (continued) 14 00 }00 oo 7, 10, 1,439,000 70,000 247,000 1, 768,000 1,169,000 Transmission Years V/ 4s 1s 7,000 7,000 10,000 10,000 1,439,000 1,439,000 70,000 70,000 249,000 257,000 1,775,000 1, 783,000 1,139,000 1,111,000 Economic evaluation period is 54 years. v 7,000 10,000 1,439,000 70,000 265,000 1,791,000 1,084,000 18 7,000 10,000 1,439,000 70,000 273,000 1, 799,000 1,057,000 19 7,000 10,000 1,439,000 70,000 281,000 1,817,000 1,036,000 20 7,000 10,000 1,439,000 70,000 289,000 1,815,000 1,005,000 21 thruy, 54 7,000 10,000 1,439,000 70,000 289.000 1,815,000 20,509 ,000 The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period. The annual cost is based on an investment cost of. $191,000 amortized over 53 years at 3 percent. The annual cost is based on an investment cost of $28,200,000 amortized over 30 years at 3 percent, Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 Plan Component 1 1. Diesel Generation - Capital Cost -0- O&M 57,000 Fuel 7/ 383,000 2. Waste Heat Utilization Capital Cost -0- O&M -0- 3. Wood-Fired Steam Generation Capital Cost -0- O&M -0- Fuel -0- Total Cost 440,000 Discounted Costs®/ 427,000 In 7,0002/ 57,,000 408,000 472,000 445,000 Table E-7 Estimated Costs of Plan "G" Wood-Fired Steam Generation With Haste gat Utilized 3 4 5 & 7,000 7,000 7,000 7,000 57,000 8,000 8,000 8,000 435,000 23,000 25,000 26,000 -0- 82,0004/ 82,000 82,000 -0- 62,000 62,000 62,000 -0- 376,000/ 376,000 376,000 -0- 230,000 230,000 230,000 400,000 412,000 4247000 437,000 899,000 1,200,000 ~—*'1,212,000 ~—«*1,225,000 828,000 1,066,000 1,045,000 ~—‘1,026, 000 Total Present Worth of Plan Costs - Total Present Worth of Plan Costs - $17,424,000 over a 20 year period. $33,798,000 over the 54 year period. Page 1 of 2 In 7,000 8,000 28,000 82,000 62,000 376,000 230,000 451,000 1,239,000 1,007,000 8 9 7,000 7,000 8,000 8,000 30,000 32,000 82,000 82,000 62,000 62,000 376,000 376,000 230,000 230,000 464,000 478,000 1,252,000 1,266,000 988,000 970,000 Table E-7 Estimated Costs of Plan "G" (continued) Wood-Fired Steam Generation Years 1/ 21 thrug, 1 u 1 13 M4 1s 16 wv 18 19 20 54 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 34,000 36,000 38,000 41,000 43,000 46,000 49,000 52,000 56,000 59,000 63,000 63,000 82,000 82,000 82,000 82,000 82,000 82,000 82,000 82,000 82,000 82,000 82,000 82,000 62,000 62,000 62,000 62,000 62,000 62,000 62,000 62,000 62,000 62,000 62,000 62,000 376,000 376,000 376,000 376,000 376,000 376,000 376,000 376,000 376,000 376,000 376,000 376,000 230,000 230,000 230,000 230,000 230,000 230,000 230,000 230,000 230,000 230,000 230,000 230,000 492,000 507,000 522,000 537,000 555,000 572,000 589,000 607,000 626,000 645,000 661,000 661,000 1,280,000 1,295,000 1,310,000 1,325,000 1,343,000 1,360,000 1,377,000 1,395,000 1,414,000 1,432,000 1,449,000 1,449,000 952,000 936,000 919,000 902,000 888,000 873,000 858,000 844,000 831,000 817,000 802,000 16,374,000 J/ Planning period is 20 years. Economic evaluation period is 54 years. 2/ The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period, 3/ This annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 percent. 4/ This annual cost is based on an investment cost of $1,225,000 amortized over 20 years at 3 percent. 5/ This annual cost is based on an investment cost of $5,595,000 amortized over 20 years at 3 percent. 6/ Reference is to year zero, Or one year prior to the start of the Planning period. This row is summed to give the unadjusted present worth of plan costs. 7/° Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 Plan Component 1 1, Diesel Generation Capital Cost -0- O&M 57,000 Fuel 7/ 383,000 2. Waste Heat Utilization Capital Cost -0- O&M -0- 3. Wood-Gas Generation Capital Cost -0- O&M -0- Wood Fuel -0- Oil Fuel -0- Total 440,000 Discounted Cost §/ 427,000 In 7,0003/ 57,000 408,000 472,000 445,000 Table lw 7,000 57,000 435,000 221,000 -0- 720,000 659,000 E-8 Estimated Costs of Plan “H" Wood-Gas Generation With Waste Heat Utilized Years I/ 4 5 & 7,000 7,000 7,900 8,000 8,000 8,000 23,000 25,000 26,000 50,0004/ 50,000 50,000 30,000 30,000 30,000 186,000 186,000 186,000 270,000 270,000 270,000 227,000 234,000 241,000 46,000 49,000 52,000 847,000 859,000 870,000 753,000 741,000 729,000 Total Present Worth of Plan Costs - $12,997,000 over a 20 year period. Total Present Worth of Plan Costs - $25,495,000 over the 54 year period. Page 1 of 2 7,000 8,000 28,000 50,000 30,000 186,000 270,000 248,000 56,000 883,000 718,000 lo 7,000 8,000 30,000 50,000 30,000 186,000 270,000 256,000 60,000 897,000 708,000 Io 7,000 8,000 32,000 50,000 30,000 186,000 270,000 264,000 64,000 911,000 698,000 Table E-8 Estimated Costs of Plan “H" (continued) Wood-Gas Generation With Wage, dept Utilized ‘ 2l thru, 10 u i B M 1s 1s v is 19 20 54 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 7,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 8,000 34,000 36,000 38,000 41,000 43,000 46,000 49,000 52,000 56,000 59,000 63,000 63,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 50,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 30,000 186 ,000 , 186,000 186,000 186,000 186,000 186,000 186,000 186,000 186,000 186,000 186,000 186,000 270,000 270,000 270,000 270,000 270,000 270,000 270,000 270,000 270,000 270,000 270,000 270,000 272,000 280,000 289,000 297,000 306,000 315,000 325,000 335,000 345,000 355,000 355,000 355,000 68,000 72,000 77,000 82,000 87,000 93,000 99,000 .105,000 112,000 120,000 127,000 127,000 9255000 939,000 955,000 971,000 987,000 1,005,000 1,024,000 1,043,000 1,064,000 1,085,000 1,106,000 1,106,000 688,000 678,000 669,000 661,000 653,000 645,000 638,000 631,000 625,000 619,000 612,000 12,498,000 1/ Planning period is 20 years. Economic evaluation period is 54 years. 2/ The costs for the last year of the planning period is used for each of the remaining years of the economic evaluation period. 3/ This annual cost is based on an investment cost of $191,000 amortized over 53 years at 3 percent. 4/ This annual cost is based on an investment cost of $741,000 amortized over 20 years at 3 percent. 5/ This annual cost if based on an investment cost of $2,765,000 amortized over 20 years at 3 percent. 6/ Reference year is year zero, or one year prior to the start of the Planning period, This row is summed to give the unadjusted present worth of plan costs, 7/ Fuel costs are based on fuel consumption increasing at 3% per year and the unit cost of fuel increasing by 3.5% per year. Page 2 of 2 NOV DEC OCT MONTHS HEATING REQUIREMENTS DISTRIBUTION SINAWIYINDIY TWANNY TWLOL 40 % NI SLINAWJYINDAY ONTLWIH ATHLNOW > TABLE E-10 UTILIZED WASTE_HEAT DIESEL GENERATION PLAN B Annual Waste Heat Utilized ] 0 2 0 3 10,559 4 10,876 5 11,202 6 11,538 7 11,884 8 12,241 9 12,608 10 12,986 1 13,376 12 13,777 13 14,190 14 14,616 15 15,055 16 15,506 17 15,971 18 16,451 19 . 16,944 20 17,452 21-54 17,452 x Total = 849,600 Million BTU Jable E-10 TABLE E-11 UTILIZED WASTE HEAT DIESEL GENERATION W/BINARY CYCLE PLAN C Annual Waste Heat Utilized Year in Million BTU 1 0 2 0 3 7,672 4 7,903 5 8,140 6 8,389 7 8,640 8 8,900 9 9,173 10 9,449 1 9,732 12 10,025 13 10,325 14 10,636 15 10,946 16 11,274 17 11,612 18 11,969 19 12,328 20 12,698 - 178,911 21-54 12,698 601,643 Million BTU Table E-11 TABLE E-12 UTILIZED WASTE HEAT COAL-FIRED & WOOD-FIRED STEAM PLAN D & G Annual Waste Heat Utilized Year in Million BTU 1 0 2 0 3 0 4 15,358 5 15,818 6 16,293 7 16,782 8 17,286 9 17,804 10 18,338 i 18,888 12 19,455 13 20,039 14 20,640 15 21,260 16 21,900 7 22,537 18 23,230 19 23,927 20 24,645 344,200 21-54 25,384 Total 1,207,358 Million BTU Table E-12 Year ao ao FF WwW DY 10 nN 12 13 14 15 16 17 18 19 20 21-54 TABLE E-13 SURPLUS ELECTRICAL ENERGY PLAN E HYDROELECTRIC GENERATION _ Annual Surp Elec. Power lus BTU in Million 0) 0 0 0 5,055 4,818 4,569 4,318 4,058 3,792 3,509 3,226 2,933 2 632 2,322 2,012 1,684 1,346 989 630 630 Total = 69,313 Million BTU Table E-13 TABLE E-14 UTILIZED WASTE HEAT WOOD GAS GENERATION PLAN _H Annual Waste Heat Utilized Year in Million BTU ] 0 2 0 3 0 4 10,635 5 10,954 6 11,283 7 11,621 8 11,970 9 12,329 10 12,699 i . 13,080 12 13,472 13 13,877 14 14,293 15 14,721 16 15,163 17 15,618 18 16 ,086 19 16 569 20 17 ,066 21-54 — : 17,066 Total = 813,580 Million BTU Table E-14 Table E-15 Estimated Non-Electrical Benefits of Plan “B" eet tcal Benefits of Plan SB" Diesel Generation with Waste Heat Utilized Year Benefit Category 1 2 3 4 5 6 7 8 9 10 1. Space Heating Fuel Displacement Benefit Q) -0- -0- 228,000 243,000 259,000 276,000 294,000 314,000 334,000 357,000 Discounted . : Benefit (2) -0- -0- 209,000 216,000 223,000 231,000 239,000 248,000 256,000 266,000 Notes: (1) As with the treatment of fuels in the cost calculations, the value of fuels displaced is estimated on the basis of 3.5 percent annual real escalation, and the amount of fuel displaced is projected to increase 3 percent annually. (2) Same reference year as assumed in the cost calculations. This row is summed to give the present worth of plan" “ non-electrical benefits. Total Present Worth of Non-Electrical Benefits - $5,110;000 over a 20 year period. Total Present Worth of Non-Electrical Benefits - $9,336,000 over the 54 year period. Page 1 of 2 Benefit Category i 1. Space Heating Fuel Displacement Benefit (1) 380,000 Discounted Benefit (2) 275,000 Table E-15 Estimated Non-Electrical Benefits of Plan "B" ene tits of Plan bt Diesel Generation with Waste Heat Utilized Year 12 13 14 15 16 V7 18 405,000 432,000 461,000 491,000 523,000 558,000 595,000 284,000 294,000 305,000 315,000 326,000 338,000 349,000 Page 2 of 2 634,000 362,000 21 thru 676,000 676,000 374,000 4,226,000 Table E- 16 Estimated Non-Electrical Benefits of Plan "C" cal Benefits of Plan *C" Diesel Generation with Bottom Cycle System and With Waste Heat Utilized Year Benefit Category i 2 3 4 5 6 7 8 9 10 1, Space Heating Fuel Displacement ~ Benefit (1) -0- -0- 166,000 177,000 188,000 201,000 214,000 228,000 243 ,000 259,000 Discounted z Benefit (2) -0- -0- 152,000 157,000 162,000 168,000 174,000 180,000 186,000 193,000 Notes: (1) As with the treatment of fuels in the cost calculations, the value of fuels displaced is estimated on the basis of 3.5 percent (2) annual real escalation, and the amount of fuel displaced is projected to increase 3 percent annually. Same reference year as assumed in the cost calculations. This row is summed to give the present worth of plan" “ non-electrical benefits. Total Present Worth of Non-Electrical Benefits - $3,715,000 over a 20 year period. Total Present Worth of Non-Electrical Benefits - $6,788,000 over the 54 year period. Page 1 of 2 Table E-16 Estimated Non-Electrical Benefits of Plan “c" th tne its of Plan C’ Diesel Generation with Bottom Cycle System and With Waste Heat Utilized Year 21 thru Benefit Category i 12 3 4 45 16 i 18 dg 20 54 1. Space Heating Fuel Displacement Benef it (1) 277,000 295,000 314,000 335,000 357,000 381,000 406,000 433,000 461,000 492,000 492,000 Discounted Benefit (2) 200,000 207 ,000 214,000 221,000 229,000 237,000 246,000 254,000 263,000 272,000 3,073,000 Page 2 of 2 2t-3 FLqeL Table E-17 Estimated Non-Electrical Benefits of Plan “2” & Plan "G" Steam Generation with Waste Heat Utilized Year Benefit Category 1 1. Space Heating Fuel Displacement In lw [> Ion Ia IN lo lw s Benefit q) -0- -0- -0- 343,000 366,000 390,000 415,000 443,000 472,000 503,000 Discounted ; - Benefit (2) -0- -0- -0- 305,000 316,000 327,000 338,000 350,000 362,000 374,000 Notes: (1) As with the treatment of fuels in the cost calculations, the value of fuels displaced is estimated on the basis of 3.5 percent annual real escalation, and the amount of fuel displaced is projected to increase 3 percent annually. (2) Same reference year as assumed in the cost calculations. This row is summed to give the present worth of plan“ “ non-electrical benefits. . Total Present Worth of Non-Electrical Benefits - $ 6,907,000 over a 20 year period. Total Present Worth of Non-Electrical Benefits - $12,911,000 over the 54 year period. Page 1 of 2 Benefit Category n 1. Space Heating Fuel Displacement Benefit (1) 537,000 Discounted Benefit (2) 387,000 Table E-17 Estimated Non-Electrical Benefits of Plan "p" & Plan "G" — eee eee Steam Generation with Waste Heat Utilized Year 12 13 14 15 16 V7 18 19 572,000 610,000 650,000 693,000 739,000 787,000 839,000 895,000 401,000 415,000 430,000 445,000 461,000 476,000 493,000 510,000 Page 2 of 2 954,000 * 527,000 21 thru 54 954,000 5,994,000 Table E-18 Estimated Non-Electrical Benefits of Plan "E" et etcirical Benefits of Plan “E" Hydroelectric with Surplus Electrical Power Year Benefit Category 1 2 ia 4 5 6 7 8 9 10 1, Space Heating Fuel Displacement Benefit Q) -0- -0- -0- -0- 134,000 133,000 132,000 131,000 129,000 127,000 Discounted [ Benefit (2) -0- -0- -0- -0- 116,000 111,000 107,000 103,000 99,000 94,000 Notes: (1) As with the treatment of fuels in the cost calculations, the value of fuels displaced is estimated on the basis of 3.5 percent annual real escalation, and the amount of fuel displaced is projected to increase 3 percent annually. (2) Same reference year as assumed in the cost calculations. This row is summed to give the present worth of plan" “ non-electrical benefits. Total Present Worth of Surplus Electrical Energy - $1,239,000 for a 20 year period. Total Present Worth of Surplus Electrical Energy - $1,488,000 for the 54 year period. Page 1 of 2 Benefit Category i 1. Space Heating Fuel Displacement Benefit (1) 124,000 Discounted Benefit (2) 90,000 121,000 85,000 Table E-1g Estimated Non-Electrical Benefits of Plan _ 117,000 80,000 Hydroelectric Generation with Surplus Electrical Power Year 4 15 16 V7 18 19 113,000 108,000 102,000 93,000 77,000 58,000 75,000 69,000 64,000 56,000 45,000 33,000 Page 2 of 2 39,000 22,000 21 thru 54 39,000 249,000 Benefit Category 1 Table E-19 Estimated Non-Electrical Benefits of Plan “H" Wood-Gas Generation with Waste Heat Utilized Ino Jw 1. Space Heating Fuel Displacement Benefit (1) -0- Discounted Benefit (2) -0- -0- Notes: (1) (2) Year 4 5 & 238,000 253,000 270,000 211,000 218,000 226,000 InN 288,000 234,000 8 2 10 307,000 327,000 349,000 242,000 251,000 260,000 As with the treatment of fuels in the cost calculations, the value of fuels displaced is estimated on the basis of 3.5 percent annual real escalation, and the amount of fuel displaced is projected to increase 3 percent annually. Same reference year as assumed in the cost calculations. benefits. Total Present Worth of Non-Electrical Benefits - Total Present Worth of Non-Electrical Benefits - $4,793,000 for a 20 year period. $8,929,000 for the 54 year period. Page 1 of 2 This row is summed to give the present worth of plan“ “ non-electrical Benefit Category i 1. Space Heating Fuel Displacement Benefit (1) 372,000 Discounted Benefit (2) 269,000 396,000 278,000 Table E-19 Estimated Non-Electrical Benefits of Plan "y" cat Benefits of Plan “H" Wood-Gas Generation with Waste Heat Utilized Year LB M 5 1s uv 423,000 450,000 480,000 511,000 546,000 288,000 298,000 = 308,000 318,000 330,000 Page 2 of 2 582,000 342,000 620,000 354,000 21 thru 2 sh 661,000 661,000 366,000 4,136,000 Maintenance PLANT LAYOUT Base Case Diesel Generation Showing new building to have the four existing units ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY BASE CASE DIESEL . PLAN “A” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. E-1 > APRIL, (98! Steam Lines to Buildings Maintenance Area Existing Diesel Units PLANT LAYOUT Diesel Generation with Waste Heat Utilization Showing building to house four existing units with heat recovery units. ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY DIESEL W/WASTE HEAT PLAN ‘B” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. E.2 APRIL, '98! Heat Recovery Unit Diesel Unit Main Generator Auxiliary Generator PLANT LAYOUT Diesel with Binary Cycle and Waste Heat Utilized ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY DIESEL W/WASTE HEAT AND BINARY CYCLE PLAN “C”’ PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. E-3 APRIL, (98! Waste Heat Pipelines Someta 4 Diesel Generators Power Plant Cc 40’ x 150’ . Furnace & Steam Turbine Generator A Coal Storage Area 200’ x 200° | Unloading Conveyor | Coal Barge YUKON RIVER —= PLANT LAYOUT Coal-Fired Steam Generation ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY COAL-FIRED STEAM PLAN “‘D” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. E-4 APRIL, 198! ee are (‘xosdde) say! G'} = dVW VAYV PLATE NO. PLAN “E” PROJECT LAYOUT HYDROELECTRIC APRIL, !98! ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY MARKS ENGINEERING / BROWN & ROOT, INC. ANI NOISSINSNVUYL © e ‘ ere. LS we? \ bean yIOAUaSau, "— ARCTIC OCEAN BERING SEA 69 KVA LINE TANANA FAIRBANKS ANCHORAGE Ip? PACIFIC OCEAN K BRISTOL BAY AREA MAP (Showing 69 KVA Transmission Line from Fairbanks to Tanana) ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY TRANSMISSION PLAN “F’”’ AREA MAP MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. E-6 APRIL, 1981 a ea Waste Heat Pipelines 4 Diesel Generators as Standbys 40’ x 150’ Powerhouse Housing Steam and Diesel Equipment Furnace, Boiler Turbine, and Generator Wood Storage Area 250’ x 500 (1 year storage Capacity) Wood Carrying Barge, 240 Ton Capacity YUKON RIVER —_—_—— PLANT LAYOUT Wood-Fired Steam Generation ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY WOOD-FIRED STEAM PLAN “G” PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN @ ROOT, INC. E-7 APRIL, (98! : Waste Heat to Buildings 4 Diesel Generators 50’ x 120’ Power Plant Housing Wood/Gas and Diesel Equipment Wood Gas Engines & Generator Wood Storage Area 200’ x 350’ (1 year storage capacity) Cable Unloading System Wood Carrying Barge, 240 Ton Capacity YUKON RIVER Smeg PLANT LAYOUT Wood/Gas Fired Generation - ai = ' ALASKA POWER AUTHORITY TANANA RECONNAISSANCE STUDY WOOD/GAS FIRED ENGINE PLANT “H”’ PLANT LAYOUT MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. E-8 APRIL, !98! APPENDIX F DETAILED DESCRIPTION OF ELON OF THE RECOMMENDED PLANS mee ANS ]. General Two energy plans have been recommended for further study. They are: a. Hydroelectric with surplus electrical energy b. Diesel with waste heat utilization Descriptions of each plan are outlined in the following paragraphs. 2. Hydroelectric With Surplus Electrical Energy a. General Description The electrical Power requirements are to be supplied by a hydroelectric plant located on Jackson Creek about 9 miles east of Tanana. The four existing diesel units are to act as standbys when the hydro facility is out of service. b. Components 1) Hydroelectric Powerhouse - The hydroelectric powerhouse is to be located about 9 miles east of Tanana and is to house three 283 kW vertical Francis-type turbines with a total capacity of 850 kw. 2) Penstock - Water is to be conveyed to the powerhouse by a 36-inch diameter buried pipe penstock about 25,000 feet in length, 3) Reservoir - A 5,000- acre-feet storage reservoir is to be formed by an earth embankment on Jackson Creek. The reservoir is to store runoff produced during high creek flow periods and supply water to the turbines throughout the year. 4) Transmission Line - A 9-mile transmission line is to convey the electrical energy from the Powerhouse to tne community. 5) New Diesel Powerhouse - A new Powerhouse 30' x 100' in size, to house the existing diesel units, is projected. The units are to * be used as a standby power supply. Fuel Requirements The hydroelectric facility will require no fuel. The hydroelectric plant will be remotely and automatically operated. The power output will meet the system's electrical power demand. No attendant at the powerhouse will be needed. 3. Oiesel with Waste Heat Utilization See We maste neat Utilization General Description The existing diesel generating system would be used to meet the future electrical needs of Tanana. The four existing generating units are to be moved to a new power plant building and each unit equipped with a waste heat recovery unit to take waste heat from the jacket water and tne exnaust. Tne recovered heat will be converted to steam that carries the heat to the buildings that are to be heated. The steam will be passed through exchangers in the buildings where the heat will be extracted and used for water heating or space heating. Components 1) New Powerhouse Building - The four existing diesel units with their new waste heat recovery units will require a new 36' x 100! building. A maintenance area about 36' x 30' has been allowed in the building. Tentative plans visualize a new location for the powerhouse adjacent to the Village Safewater Facility, a location advantageous to the utilization of waste heat for heating water and space. In addition, the Public Health Service Hospital and the High School are less than 2,000 feet away and could be served with a waste heat loop from the new location adjacent to the Village Safewater Facility. Diesel Generating Units - The existing diesel power generation facility consists of the Caterpillar D397, D398, and D399 Diesel Engine Generators capable of producing 350, 500, and 800 kW, respectively, and one Detroit Diesel V-1271 capable of Producing 300 kW. These units will be used in this plan. Waste Heat Recovery Units - The waste heat in the jacket water and exhaust will be recovered by units similar to "Vaporphase" units, supplied by Pott Industries of 611 E. Marceau, St. Louis, MO, 63111. In this unit, the jacket water passes into the Vaporphase exchanger where the water takes on additional heat from the diesel exhaust as shown on pages F-5 through F-6. Details of the Vaporphase units are shown on pages F-9 through F-13. A condensate return unit will be part of the system. (See Pages F-21 through F-24.) A vapor phase separator will also be required. (See pages F-25 through F-28). : 4) Waste Heat Transportation System - The waste heat to be utilized and moved to the buildings to be heated is in the form of hot steam. The hot steam is to be conveyed in buried insulated pipes. The steam will be taken from the hot steam loop line at each building and the condensate returned to the powerhouse in a relatively cool return condensate line. 5) Heat Exchangers in Buildings - Each building which is to utilize the waste heat will have to be equipped with exchangers to extract heat from the hot steam. The steam can also be used for water heating and hot water heaters will have to be provided that are capable of taking the heat from the hot steam. Each building would be equipped with a line to take steam from the hot side of the loop and return condensate to the condensate return line. Fuel Requirements - Fuel requirements for this system will not be different from the present system. Fuel storage and fuel transportation requirements are now in place. Operation - The operation requirements now needed for the diesel units should not change. The exchangers along with the steam loop with associated pumping requirements will require additional operation and maintenance attention. VAPOR PHASE® SEPARATOR Gam STEAM MME WATER & STEAM CONDENSATE ENGINE vee on COOLING Liouio Le - CONTROLLER INC OMING MAKE-*UP WATER CONOENSATE CYCLE How Vapor Phase Functions The system is filled with water, or a solution of anti-freeze and water where required to the half full point in the Vapor Phase Separator: When the engine is started rejection of heat to the water causes THERMAL CIRCULATION through the engine and the Separator. Except for radiation no cooling occurs in the primary or engine cooling water circuit. The water quickly comes to the boiling point and the en- gine heat rejected to the water is removed in the Separator in the form of steam. The hot water and steam, entering the Separator through a tangential inlet swirls with continu- ous centrifugal force, which, with internal baffling separates the steam from the water. Dirt and scale is collected in the mud drum and may be removed by periodic blow-down. Steam and non-condensible gasses then pass to the secondary circuit which includes some type of a condensing unit. Here the steam is condensed and the condensate is returned to the primary circuit either by gravity or by a condensate return unit. Vapor Phase is a simple, closed, trouble-free cooling system. ENGINEERING CONTROLS, INC., Sole Developers and Manufacturers of VAPOR PHASE® Thermal Circulation (Ebullition) Engine Cooling Systems F-5 ENGINEERING CONTROLS, INC., Pot. No. 2,681,643 This type of circulation in the Primary circuit is eccomplished by utilizing the natural law of cir- culating coolants by thermal energy. It is a function of the difference in the weight of water in the system. Boiling of the water on the metal surfaces of the combustion chamber creates ctural turbulence, thereby utilizing the latent heat of vaporization for cooling. F-6 FOREIGN MATTER Sizing and arranging of the Piping inthe system is critical, Water flow ond tempercture throughout the.engine is naturally adjusted and differential between water and metal temperature is minimized. Elimination of the water Pump, as indicated, re- duces parasitic horsepower and the need for fre- quent service. “Sole Developers and Manufacturers of Vapor Phase® Thermal Circulation (Ebullition) Engine Cooling Systems” Vaporphase c Packaged Heat Recovery Unit: od Combining Jacket Water and Exhaust with Integral Silencing ENGINEERING CONTROLS DIV. POTT INDUSTRIES GROUP— HOUSTON NATURAL GAS CORP 811 EAST MARCEAU ST., ST. LOUIS, MO. 63111 & P E a Axe ORPHAS Over 1,250,000 hp. of VAPORPHASE Heat Recovery Units are now in operation... twice that of any other competitor. In addition to the VAPORPHASE units in the new A.G.A. laboratories, Engineering Con- trols also engineered and furnished: a) The back pressure valve for the engine system. b) Excess steam valve. c) Air cooled excess steam condenser. d) Condensate return system. e) Automatic pump control panel. f) Dry air radiator for oil cooling water. A pioneer in the industry, with more than 30 years of experience, VAPORPHASE Heat Re- covery Equipment is your assurance of expe- rience, and satisfaction. To Maintain our proven leadership in the industry, Engineering Con- trols has recently expanded and modernized its manufacturing facilities to meet increasing demand for VAPORPHASE Equipment. IF you are contemplating a total energy system, or if you are now in the planning stages, it will Pay for you to investigate VAPORPHASE, the industry leader and pioneer. Call (314) 638-4000 or write: ENGINEERING CONTROLS Div. LV {sine HASE POTT INDUSTRIES GROUP— HOUSTON NATURAL Gas comp ates 611 EAST MARCEAU ST., ST. LOUIS, MO. 63111 F=8 Introduction The What and Why of Waste Heat Recovery One of the most important equipment components in an engine driven equip- ment installation, particularly Total En- ergy installations, is the Waste Heat Recovery System. This system must be designed to FIRST provide positive en- gine cooling and SECOND obtain maxi- mum economical heat recovery while insuring reliability and longevity of equip- mert. As a “rule of thumb,” reciprocating engines are 30% efficient. That is, of the fuel energy input; 30% goes to shaft horsepower; 30% to jacket water heat; 30% to exhaust heat; and 10% to radi- ation, oil heat, and other losses. One of the oldest and most successful forms of heat recovery employs VAPOR- PHASE (ebullient) cooling of the recipro- cating engine. Ebullient cooling involves the natural circulation of the jacket water at or near saturation temperature and engine cooling is accomplished through utilization of the heat of vaporization. This is the simplest and least costly form of waste heat recovery. Some of the bene- fits of VAPORPHASE cooling are, elim- ination of the jacket water circulating Pump, extended engine life due to uniform temperatures throughout the engine (nor- mally 2-3° differential between inlet and outlet), recovered heat in the form of low Pressure steam (up to 15 PSIG) and all F-9 of the heat rejected to the jacket water is recovered. Today's Total Energy installations pro- duce large amounts of steam for building heat, building cooling (absorption air con- ditioning), domestic hot water and various other uses. To provide as much steam as Possible for these loads from the engine installation, the heat rejected to the ex- haust is also recovered. Because exhaust temperature cannot be lowered to ambi- ent air temperature, only a portion of this exhaust waste heat can be economically recovered. Systems wherein both jacket water and exhaust waste heat are recov- ered are yielding system efficiencies in excess of 75%. There are several methods of recover- ing waste heat. One employs recovery of jacket water heat only. Another employs recovery of exhaust heat only. Still an- other recovers both jacket water and ex- haust heat in separate units. Today, however, the most popular and least ex- pensive method is to recover both jacket water and exhaust heat in a single unit. These units are “Packaged” at the factory and include controls, safety devices, in- strumentation and insulation. Only simple field connections are required. The following pages of this brochure describe a newly designed packaged unit which is giving excellent service in actual Total Energy installations. VAPORPHASE Waste Heat Recovery System VAPORPHASE Heat Recovery equipment has been applied to over 1,000,000 en- gine horsepower all over the world. Instal- lations range from single units through 7 units per site. VAPORPHASE is exclu- sively designed and fabricated by Engi- neering Controls. Engineering Controls was incorporated in 1939 and has been Successfully serving the Prime Mover In- dustry ever since. Ebullient cooling, as it is known today, is the result of research and development by Engineering Controls. VAPORPHASE MODEL VPV WASTE HEAT RECOVERY SYSTEM The VAPORPHASE ‘‘Model VP” Packaged Heat Recovery Silencer is specif- ically designed to provide maximum economical recovery of waste heat from engine jacket water and exhaust while satisfying the countered in existing Total Energy and other waste many problems en- heat recovery installations. SIZES: Standard 100 thru 1500 Horsepower. For larger sizes consult factory. F-10 Tt _ © Features 1. Vertical unit occupies minimum floor space - resulting in lower initial construc- tion cost and lower Operating square footage cost. 2. Horizontal unit is suitable for hang- ing, wall, or floor mounting, if desired. °3. Unit is easily cleaned, inspected and/or maintained as tubes are exposed thru simple removal of access panels— resulting in lower maintenance costs and maximum generating income. 4. Mud drum gives dead water space for Precipitating out the solids and chemi-_ cals of water treatment—resulting in more positive boiler water control with daily blow-off which reduces to a mini- mum the shut downs necessary for water washing. 5. Submerged Pressure parts insures long life. Tubes, tube sheets, exhaust inlet and outlet and shell are submerged to maintain saturated temperature. Uniform temperatures throughout eliminates stresses normally present with varying temperatures. 6. Single unit Provides both jacket water and exhaust recovery. Each engine generator heat recovery package is unit- ized to provide greater system versatility than available with multi-engine heat re- covery units and also gives true standby. 7. Internal tube nest shroud insures solid water to the engine jacket water inlet for uniform engine cooling and directs water for maximum efficient contact with the heating surface. This means Positive circulation and maximum steam produc- tion. 8. Permanent blanket insulation is at- tached to the self supporting steel casing which is completely removable without disturbing the Piping. Shell side inspect- tion openings are exposed for insurance or state inspection by removal of one Quarter panel only. Outer casing protects F-11 insulation from water damage and result- ant high replacement cost. 9. Liberal steam space coupled with adequate steam separating space and in- ternal baffling insures saturated steam with a maximum 2% moisture content. 10. Factory mounted controls and safety devices provide single responsi- bility for entire unit and insures compati- bility of base unit and accessories. 11. Sufficient water volume to prevent low water shut down due to wide load fluctuations, or false low water shut down requiring manual reset when engine shuts down under normal operating conditions. This insures adequate head on engine at all times and prevents engine damage Possible with inadequate volume. 12. Provides true residential silencing of engine exhaust. 13. Back pressure is held well within engine manufacturers limitations. 14. Standard controls and instruments consisting of level control, 3-way by-pass, low water shutdown switch, combination air vent-vacuum breaker, Pressure gauge and full range tubular gauge giass pro- vide adequate operation on most systems. Optional controls consisting of (but not limited to) city water emergency feeder, low water alarm switch, high water alarm switch, high water shutdown switch and high pressure alarm switch are available for more critical systems. 15. Tubes are expanded into reamed tube holes thereby eliminating difficult and unreliable welding. Welded joints are subject to early fatigue failure with attend- ant leaks, costly repair and lost operating revenue. 16. Designed, fabricated and stamped in accordance with the latest edition of the ASME Code Section VIII and National Board. Vaporphase Model VPV VAPORPHASE Jacket Water Inlet weg Exhaust in Vertical Unit rs — > Jacket Water Return St Blow Down AY y N ESSeiemeetea eee SSSSSSSSSSSS SSSoss Corer y perry SS Sosss H ered Steam Outlet<g—_. Packaged Waste Heat Recovery Silencer F-12 9 i use “wool | tense [clo etc | an tly | w | x]y¥ vev:2260 26 fis} a fal al2]a 118% 9m | 11a vPVv.2460 zefizsf6{e|«|{3|« ae ne 9% | 15 vev 2860 32 fizex] 6 | 6] 4] ala 105 [120%] 13 [10% [ui7% VPV.3060 34 fiszml @ |e] 6 | 3 | 6 105 [123%] 14 [io]i20% VPV.3660 40 fize4] 10 [ 10] 6 | 3 | 6 129% 17 fram 127 VPV.4060 a fisefizfiz] elas |e 114 [129% 19 fis| 125% vPv.4860 s2[isola[ ul alas |e 120 | 139 | 23 frovaliz2n] vPv.5460 ss |isa] 6] t6| o | 6 | 129 | 156] 26 [22] 153 | VPV.6060 oa [ive] 2zfaz{el]e |e 132] 164] 29 | 26 | 155 VPV-6660 69 | 180] 24 [24 [e@ | 6 | 10 133 | 166 | 312 [29% | Note All Dumensions Are Given in Inches Legend © Vanabte Nozzle Sie Note2 Capacities Based On F uit Load Conditions Producing Saturated Steam (> Variable Dimension AL ISP S.1G Capacities Gren in BTUMHr. x 1000 [1 Constant Norzte Suze Note 3 The Low Water Levet Alarm Is Not Necessary When The PLAN City Water Feeder & Alarm Is Used Pressure Gauge © Satety vaive Sanisesig f Yo" da Gauge Glass W/ Automatic Gauge Cocks & Guard © mater intet Hugh Water Level Alarm *Optionaly © Exhaust tolet + (D) Exhaust Outre €l-4- Make Up Water Feeder Normat Water Level SS *” Customer Make Up Water Conn Low Water Level ,O w a) Removable insulated Casing. (Without Disturbing Piping) Inspection . Opening Low Water Level Alarm and or City Water Feeder (Optional) Top Ot Head Or Water Cooled Manutold. Whichever ts Higher Customer To Specity Low Water Levet Shut Ol Switch 18° Menmum Control Piping, Code Name Plate On Casing Equalrer 1 Blowdown Connections By Customer iB) ov Removable insulated Rottomn Cover ~y F] 11+" Blowdown Draw ) (i) "Ke" dia Hole Standard Model VPV—Vertical Waste Heat Recovery Silencer ! Customer To Specity 18° Minvmum AV $an Jose-Santa Clara Water Pollution Control Plant San Jose, California Consulting Engineers: Consoer, Townsend & Associates, Chicago, lil. and AV Kings Plaza Shopping Center Brooklyn, New York Consuiting Engineers: Cosentini Associates, New York, N.Y. Above: 1,000,000 square feet total! enciosed. Plant power rated at 17, h.p., consisting of five 3.087 h.p. (2,200-kw) ing sets and three 784 h.p. Waukesha gas oak rigeration machines, equipped with VAPORPHASE Packaged units. Below: One of five Nordberg dual fuel 514 RPM, 2,200-kw Kenerator sets with VAPORFHASE exhaust heat, = recovery silencers. jacity is es equipped with VAPORPHASE ecovery equipment. of six Cooper Bessemer Model LS8-GorT, 345 h.p. 360 RPM engi in the blower building VAPORPHASE jacket water Separators, and -exhaust waste heat recovery silencers mounted on baicony. i om : ay, re ~ = EA =< aa ae Over a longer period of time than anyone else F-14 kV Molybdenum Corporation of America, Questa, New Mexico Above: Power for mine Producing 20°; of the nation’s molybdenum is supplied by plant rat 'd at 21,500 hip. (15,000-kw), and is largest installed gas engine piant in Gountry. with exhaust waste heat recovery equipment. All VAPORPHASE. Below: Four Enterprise dual fuel 5,300 h.p. (3,750-kw) generator sets with VAPORPHASE exhaust units. = MV Westcoast Transmission Office Building Vancouver B.C.—Canada Consulting Engi Phillips, Barratt, er, Jones and Partners Above: Note unique central core Construction and gantilevered floors. Total Energy Power Plant is rated at 2,550 h.p. (1,800-kw). Below: Two of three Caterpillar G-399TA gas engines Sonnected to VAPORPHASE VP Model jacket waver and exhaust recovery silencers. oe Over 1,250,000 hp. of VAPORPHASE Heat Recovery Units are now in operation. Twice that of any competitor. VAPORPHASE heat recovery equipment now in opera- tion, ranges from smaller, single engine, packaged, 100-kw installations (approx. 150 h.p.); up to 15,000-kw (approx. 21,500 h.p.); in the form of 4, low speed, large bore (17” pistons), 16 cylinder, dual fuel, generating sets. VAPORPHASE installations, by Engineering Controls, have been made in all 50 States, as well as in Europe, Asia, Africa, Australia, New Zealand, South America, Central America, Mexico, Canada, and inside the Arctic Circle. Engineering Controls is the only company in the field that F-15 Specializes in the engineering and manufacturing of heat recovery equipment. Our broad and long experience in engineering the largest number of applications will be a great assistance to you. Please call us at (314) 638-4000 or write: AV, VAPORPHASE ENGINEERING CONTROLS DIV. POTT INDUSTRIES GROUP— HOUSTON NATURAL GAS CORP eaten 611 EAST MARCEAU ST., ST. LOUIS, MO. 63111 Construction Details MATERIALS: All materials are in compliance with the ASME Code, Division 1, Section VIII for Unfired Pressure Vessels. Pressure Shell (all sections) are SA285 Gr. C steel of % inch minimum thickness. Tube Sheets are SA 285 Gr. C steel of 54 inch minimum thickness. Tube Holes are drilled, reamed with tubes roller expanded. Tubes are 114 inch 12 gauge SA178 Gr. A steel. All materials are welded in accordance with the latest ASME Code requirements by Code Qualified Welders and are in- spected by National Board registered inspectors. Completed units bear the “U"" Symbol and are National Board registered. INSPECTION AND ACCESS OPENINGS: Access to the gas side of the tube bundie is provided by removable bolted closure Plates at both top and bottom. Closure Plates are protected inside with insulating, hi-temperature castable refractory. Water side inspection and access is Provided by upper and lower 4 x 6 handholes. INSULATION ON CASING: There are two types of insulation avail- able. One is the removable insulated steel! casing consisting of a self supporting 15 CONNECTIONS: Exhaust Gas Inlet Exhaust Gas Outlet Jacket Water Iniet Jacket Water Return Steam Outlet Safety Vaive Surface Blow-off Blow-down Equalizer Control Column Air Vent/Vacuum Breaker Gas Side Drain 1 inch 14 inch 1% inch 1 inch 34 inch ¥% inch Per Engine Requirement Same size as inlet Per Engine Requirement Per Engine Requirement As Required Per ASME Code Requirement F-1g Sauge painted steel casing that encloses the entire unit except for the controls. The casing is so designed as to permit complete removal without disturbing the Piping. Access Panels are provided in the Casing for the gas side access openings and the two water side inspection openings. The other is an aluminum jacketed blanket insulation using 20 gauge alu- minum wrapped around the insulation, which is attached directly on the shell. CONTROLS AND INSTRUMENTATION: Water feeder, low water cut-off, gauge glass with guard and automatic shut-off cocks, pressure Bauge, safety vaive and combination vacuum breaker-air vent are furnished as standards. All controls and instrumentation are factory piped and Mounted on the unit. SUPPORTS: Four sturdy angle legs of required length are provided on vertical unit to Place unit water level at adequate height above engine heads and water cooled exhaust manifolds. Horizontal unit is Provided with hanger brackets or saddles, as required, for ceil- ing or wall Mounting. ASA Flanged Nozzle ASA Flanged Nozzle ASA Flanged Nozzle ASA Flanged Nozzle ASA Flanged Nozzie As Required Screwed IPS Screwed IPS Screwed IPS Screwed IPS Screwed IPS Screwed IPS NOTE: All nozzies ere 150 Ib. ASA rating. VAPORPHASE a — eee Sa aammmmmeenn s acae e e e Se ee _*\ Typical Specification Furnish and install Combination Engine Jacket Water and Exhaust Gas Heat Re- covery Silencer, Engineering Controls Model Or approved equal. Each Silencer shall be designed to re- duce the exhaust gas temperature to °F. and recover the heat available in the engine jacket water. Steam leaving the unit shal! contain a maximum of 2 per cent moisture. Silencers shall be constructed in ac- cordance with the ASME Code, Section Vill, Unfired Pressure Vessels. In addi- tion, tube to tube sheet or header joints shall be made by mechanically expanding tubes into reamed tube holes. Boiler de- Sign pressure shall be 20 psig. Silencer shall be arranged as a vertical unit with straight bare tubes, gas thru tubes with water outside tubes. Remov- able cover plates shall be Provided top and bottom for access, tube cleaning and tube removal. Provide a minimum of two 4x6 inch inspection and access openings, one each top and bottom, arranged for water side inspection of tubes and tube sheets. Silencer shall be insulated and covered with external lagging or remov- able No.15 gauge steel! casing. Insulation and casing shall be designed to provide a maximum casing temperature of 150°F. with 80°F. ambient and 50 fpm surface velocity. To facilitate control of water, solids concentration Provision must be made for a settling basin or mud drum in bottom of unit. The Silencer shal! be Provided with the following connections: Exhaust Gas inlet-—Fianged—For gas temperatures equal to or greater than 1200°F. this connection shal! be 304L Stainiess Steel.* Exhaust Gas Outlet—Fianged.* 144" Blowdown and Drain from Mud Drum. 1° Surface Biow-Off. Jacket Water iniet-—Fianged.* The following accessories and trim shall be Make-up Water Feeder, McDonnell & Miller #551S-B with 3-way By-pass. Low Water Level Switch, McDonnell & Miller #61. Gauge Glass, 54” Dia. glass with automatic shut- off cocks. Air Vent and Vacuum Breaker, Sarco #6T. ‘Jacket Water Return—Fianged.* 2—1" Control Column. 1—%3%” Feedwater. 1—%" Vent. Safety Vaive or Vaives per ASME Code. 1—1}4* Equalizer Connection. shop mounted and Piped on the unit: Pressure Gauge, 0-30 PSI, 444" dia., with syphon and shut-off cock. Safety Vaive, Kunkie (Sized per ASME Code). Support legs of length to meet instaliation requirements. Heat Recovery Silencer Manufacturer to provide the following performance with his Proposal: Total Steam Production—ibs. / Hour—Operating Pressure__psig. Feedwater Temperature 200°F. Pounds of Exhaust Gas/Hour.** Exhaust Gas Temperature to Unit.** Exhaust Gas Temperature from Unit. Heat Recovered from Exhaust Gas—BTU/Hour. Jacket Water Heat Rejection—BTU/Hour.** Total Heat Recovered—BTU /Hour. Maximum Gas Side Pressure Drop thru Unit— inches water gage. TYPICAL ATTENUATION CAPACITY OF MODEL VP PACKAGED WASTE HEAT RECOVERY SILENCER. Octave Bands in Hz. *Size determined by Engine Manufacturer. **Data to be provided by Engine Manufacturer. VAPORPHASE a Controls & Instrumentation SS rear. Standard Controls CONTROL FUNCTION Water Contro! Vaive Maintains normal water * Modulating, float operated for ciose level control. level. nnn FEATURES * Tight shut-off. * Union mounted with isolation vaives for easy service. * Popular control insures availability of replacement, parts or Low Water Shut-off Switch Stop engine in event of low water. service. * Union mounted for quick change out or service. * Popular contro! insures availability of replacement, parts or service. * Properly located to prevent false shut downs. Blow Down Vaives Optional! Controls High Water Alarm or Shut-down switch Low Water Alarm Low Water Alarm and Emergency feeder High Pressure Switch 3-Way By-pass Allows by-pass of water * Single lever vaive operation alows manual feed to unit in Vaive level contro! vaive. event of level control failure or normal service operation. Air Vent-Vacuum Discharge air out of J. * Thermostatically operated. Breaker W. System and prevents * Provides reliable air elimination. vacuum. a —— Tubular Gauge Allows visual check of |. Covers full range of control column for constant knowledge Glass water level. of actual water level. * Provided with gauge guard for maximum Protection against breakage. * Provided with automatic shut-off cocks for protection in event of glass breakage. Safety Vaive Pressure relieving device * Sized for 100% production capacity of unit. to protect system from overpressures. * Quality valve provides tight shut-off. « ASME Approved. Pressure Gauge Indicates operating pres: | sure of system. + 414" dial gauge insures easy readability from distance. * 0-30# range places normal operating pressure in middle of range with 2% accuracy. * Mounted with shut-off vaive and syphon. Provide surface and mud drum biow off for solids concentration control. FUNCTION Sounds alarm or shuts . down engine in event of high water level. Sounds alarm in event low water level is occur- ring. Sounds alarm and feeds treated city water in event of failure of nor- mal feed system. Sounds alarm or shuts down engine in event of high steam pressure. $$ * Surface blow-off facilitates removal of foaming agents thereby eliminating priming and carry over of solids that can foul heat transfer surface of absorption equipment and other steam users. * Blow down located in mud drum (dead water space) where solids formed by water treatment are precipitated out. ee FEATURES $$ Union mounted for quick change out or service. * Popular contro! insures availability of replacement, parts or service. + Properly located to prevent false shut downs. * Union mounted for quick change out or service. * Popular control insures availability of replacement, parts or service. * Properly located to prevent false alarm signal. + Union mounted for quick change out or service. * Popular contro! insures availability of replacement, parts or service. * Properly located to prevent unnecessary city water feed. * Alarm sounds at same time as city water feeds. * Allows operator to determine source of normal system failure and correct condition without shut down. * Mounted on contro! column. * Popular control insures availability of replacement, parts or service. Fe18 ) Heat Recovery System For Typical T.E. Plant 8 VALVE & PILOT For this typical installation Engineering Controls provides the following major pieces of heat recovery equipment for the system @ vaPorPHase MODEL vv S44 PACKAGED JACKET WATER &EXHAUST HEAT RECOVERY SILENCERS © varorPHase MODEL ECCR CONDENSATE RETURN UNIT © varorPHase MODEL st EXCESS STEAM CONDENSOR 0 VAPORPHASE MODEL ESB PNEUMATIC EXCESS STEAM VALVE & PILOT © varorPHasE MODEL BPB PNEUMATIC BACK PRESSURE VPV MODEL JACKET WATER & EXHAUST WASTE HEAT RECOVERY SUENCER ENGINEERING CONTROLS DIV. POTT INDUSTRIES GROUP—WOUSTON NATURAL GAS CORP ems 611 EAST MARCEAU ST., ST. LOUIS, MO. 83111 LV, VAPORPHASE F-19 Partial List of Vaporphase Installations SHOPPING CENTERS Kings Plaza Shopping Center Brooklyn, New York Westroads Shopping Center Omaha. Nebraska Merritt Square Shopping Center Merritt Island, Florida Springmall Shopping Center Greenfield, Wisconsin Chapel! Hill Shopping Center Akron, Ohio Western Mall Shopping Center Sioux Falls, South Dakota University Plaza Shopping Center Little Rock, Arkansas Park Plaza Shopping Center Little Rock, Arkansas Regency Shopping Center Jacksonville, Florida HOSPITALS AND SCHOOLS Kings County State School Brooklyn, New York West Side Vo-Tec School Pringle, Pennsyivania Melfort Comprehensive High Schoo! Melfort, Saskatchewan—Canada Paoli High Schoo! Paoli, indiana St. Edwards University Austin, Texas Maiden Catholic High Schoo! Maiden, Massachusetts Jacksonville Memorial Hospital Jacksonville, Florida Victoria Union Hospital Victoria B.C.—Canada Prince Albert Hospital Prince Albert, Saskatchewan—Canada Missouri State Sanitorium Mt. Vernon, Missouri John F. Kennedy Memorial Hospital Stratford, New Jersey lowa Methodist Hospital Des Moines, lowa New England Memorial Hospital Stoneham, Massachusetts Wilford Hall Medical Center Lackland A.F.B., San Antonio, Texas Faulkner Hospital Jamaica Plain, Mass. MANUFACTURING PLANTS & MINES Giles & Ransome, inc. Cornwelis Heights, PA Anamax Mining Co. Sahuarita, Arizona American Gas Association Independence, Ohio Marigold Foods, Inc. Rochester, Minnesota Waukesha Motor Company Waukesha, Wisconsin United Fuel Gas Company St. Albans, West Virginia Molybdenum Corp. Questa, New Mexico Sears, Roebuck & Company Columbus, Ohio MOTELS. APARTMENTS. OFFICE BUILDINGS Greater Winnipeg Gas Co. Winnipeg, Manitoba—Canada Toliway North Office Center Deerfield, Illinois Teamsters Council Plaza St. Louis, Missouri Pima County Tucson, Arizona KFVS-TV Station Cape Girardeau, MO Florida Gas Company Winter Park, Florida Caterpillar Tractor Co. Peoria, Illinois Battlecreek Gas Company Battlecreek, Michigan Kings Cove Apartments Merriam, Kansas Georgetown Apartments Merriam, Kansas WHIS-TV Studio Bluefield, West Virginia Tenco Tractor Company Marysville, California U.S. Post Office Pittsfield, Massachusetts Western Kentucky Gas Co Owensboro, Kentucky ESSO Hote! Antwerp, Belgium Commonwealth Gas Company Southboro, Massachusetts Western Union Complex Middletown, Virginia MUNICIPAL POWER PLANTS OR WATERWORKS Municipal Water Works Minneapolis, Minnesota Municipal Power Plant New Prague, Minnesota Nantucket, Gas & Electric Co Nantucket, Massachusetts F-20 Naknek Electric Naknek, Alaska Kotzebue Electric Kotzebue, Alaska Municipal Power Piant Unalakieet, Alaska Municipal Power Plant City of Highiand, Illinois lsachsen Weather Station Northwest Territories, Canada NASA Mius Program Clear Lake City, Texas Hydro-Quebec Magdalene Isiand, Quebec SEWAGE TREATMENT PLANTS Blue Plains Poliution Control Plant ington, D.C. San Jose-Santa Clara Sewage Treatment Piant San Jose, California Newtown Creek Sewage Treatment Piant New York City, N.Y. West Point Sewage Treatment Piant Seattie, Washington Orange County Sewage Treatment Plant Fountain Valley, California Atlanta Water Pollution Plant Atlanta, Georgia Nassau County Sewage Treatment Piant Nassau County, New York MARINE U.S. Naval Ship Sealitt Pacitic U.S. Naval Ship Sealitt Arabian Sea U.S. Nava! Ship Sealift China Sea U.S. Naval Ship Sealift Indian Ocean Zapata Patriot Zapata Ranger Zapata Rover Zapata Courier GAS COMPRESSION STATION Princess Compressor Station Alberta Gas Trunk Lines Princess, Alberta—Canada OIL DRILLING RIGS Commonwealth Hi-Tower Alberta—Canada Pan Arctic Oils Ltd REA Point N.W.T.—Canada om ENGINEERING CONTROLS CONDENSATE RETURN UNIT CONDENSATE RETURN UNITS ARE BUILT IN TWO SERIES: © CR-105-160 single Pump units © CR-205-260 dual Pump units To accomplish this the return of condensate is con- trolled by changes of the level in the Vapor Phase Unit; and not in accordance with the rate at which it accum- ulates in the receiver tank. This operation is carried out in the Vapor Phase System by controlling the water level with: 1. A liquid level contro] valve mounted at the correct water level on the Vapor Phase Unit to control the quantity of water admitted from the condensate return unit, or a liquid level control switch to start and Btop the return pump as Tequired. If “on-off” Pump control operation is selected it is usually necessary to use either two switches with a spread between them or a single Switch incorporating at least a 2” to 4” differential. 2. An automatic make-up water feeder, mounted on the condensate return unit and connected to the plant 611 E. Marceau Street water supply system to maintain an adequate supply of water in the condensate receiver at all times. As the water to be handled is often above 200‘F. the high receiver mounting of these condensate return units gives sufficient head at the Pump suction to min- imize the flashing of water into Vapor at this point. A standard boiler return unit is normally not satisfac- tory for these systems because of this and the fact that they utilize smaller receivers. As these are non-unloading pumps a relief valve is installed in the Pump discharge line of each unit. This Serves as a safety and permits continuous operation without overloading the motor. The dual units are recommended as they are sized for satisfactory operation on one Pump and are arranged with shut-off valves so that one pump can be serviced without interfering with the Plant operation. Turbine type pumps are used exclusively because of their ability to handle a mixture of water with steam or air without vapor locking, and their ability to deliver a fairly constant volume of liquid against varying heads. STANDARD EQUIPMENT RECEIVER: All Receivers are fabricated of minimum yy” flange quality steel and mounted .on heavy angle iron legs. The receiver has a Capacity equal to approximately ten times the pump Capacity in GPM at 80 foot head. MAKE-UP WATER VALVE: An automatic make-up water vaive is flanged directly into one end of the tank to maintain an adequate supply of water at all times. A cleanable strainer is integral with the valve. VENT: An Opening is supplied in the top of the receiver to Provide for a vent line or a vent vaive if required. GAUGE GLASS: A standard 5%" ¢ boiler gauge glass with auto- matic shut-off cocks and guard is mounted on one head of the tank. PUMPS: Turbine type with stainless steel shafts, bronze im- pellers and mechanical seals mounted on channel bases. MOTORS: Open dripproof — ball bearing — directly coupled to the pumps by heavy duty flexible couplings with coupling Guards. (Fractional H.P. — single phase) (integral H.P. — three Phase) PIPING: All units are completely assembied and ready for Operation when connected to the utilities and condensate supply and return lines. St. Louis, Mo. 63111 F-21 ‘ VAPOR PHASE CONDENSATE RETURN UNIT VENT PUMP SUCTION (§) RELIEF RETURN - GENERAL DIMENSIONS ® F G H 115-215 55} 25 | 20% | 10 125-225 140-240 55 | 31 | 24% | 12 55 | 43 26 E 160-260 ¢ All dimensions in inches 73 | 43 | 26%, F-22 ® ENGINEERING CONTROLS SECTION 2-2 All dimensions in inches. GALS.* {LBS.STEAM] RECEIVER] MOTOR TANK SIZE SHIPPING WEIGHT PER HOUR | CAPACITY] SiZE {DIAMETER | LENGTH | SINGLE DUAL 105-205 109-209 600 115-215 750 | ——| 40 31.5 : . 125-225 80 30.0 6250 265 lyre 36 60 1100 | 1200 40 61.0 . 140-240 80 50.0 10,000 470 26 48 60 | 1500 1650 160-260 2000 ¢ Refer to factory for pump capacities at heads other than those given above. * — 110/220 Volt — 60 Cycle — 1 Phase 1750 RPM. ** — 220/440 Volt — 60 Cycle — 3 Phase 1750 RPM. fe Motors with other characteristics available on special order. F-23 VAPOR PHASE OPTIONAL and EXTRA EQUIPMENT (At Extra Cost) Motor starters with built-in overload and under- voltage cut-out relays are desirable on single phase motors and required on poly-phase motors. These are available with manual reset buttons and built-in or remote push-button stations. Alternaters may be used with the dual pump units to automatically switch pumps in operation with each start. A low water or high water switch to sound an alarm or for other uses may be desirable in some cases. These can be supplied with any switching arrangement required. A pump control switch may be used if the water level in the receiver is to determine the pump operation. Explosion proof or totally enclosed fan cooled motors and controls are available and are often required on equipment going into gas compressor Stations, pipe line Pumping stations, drill rigs, Marine or other hazardous locations. Protective coatings such as galvanizing, or special materials for the receiver or pump can be supplied On special order. Units having a greater receiver or pumping capac- ity than those shown can be furnished if required. OTHER VAPOR PHASE PRODUCTS STEAM SEPARATORS EXHAUST HEAT RECOVERY SILENCERS PACKAGED WASTE HEAT RECOVERY UNITS DRY AIR COOLERS SHELL & TUBE HEAT EXCHANGERS COMMERCIAL & RESIDENTIAL EXHAUST MUFFLERS COMPRESSOR MOUNTING AIR & GAS RECEIVERS SUCTION & DISCHARGE DRUMS FOR GAS COMPRESSORS STARTING AIR RECEIVERS LOW PRESSURE STEAM WATER STILLS PROPANE VAPORIZERS AUTOCLAVES STAINLESS STEEL PRESSURE VESSELS ENGINEERING CONTROLS, Sole Developers and Manufacturers of VAPOR PHASE Thermal Circulation (Ebullition) Engine Cooling Systems F-24 ENGINEERING CONTROLS, Inc. Vapor Phase Separators specifically for the efficient removal of the relatively small quantity of vapor mixed with the liquid flowing through these systems. The patented tangential entry nozzle swirls the liquid-vapor mixture inside the vessel The resultant compression together with the interior caffling separates the steam which rises to the upper chamber from which it is Piped to the condenser or to the process steam requirement. Any air or other non- condensable gases are also removed in this chamber and vented to the atmosphere. The liquid remaining in the lower chamber flows out of the bottom where the vortex effect is arrested by a set of vertical fins and a horizontal haffle plate over the water outlet. This outlet is extended into the bottom head of the vessel. forming a patented sediment chamber or mud-drum from which a blow-down line is taken. The water outlet is flanged and is made over-size so that it seTVes as a pedestal on which the unit may he mounted. €2 V por Phase Cyclonic Steam Separators are designed ~ ‘ 1 All units are made and stamped in accordance with the A.S.MLE. code for unfired pressure vessels for the oper: ating pressure required for any particular application Vapor Phase Thermal Circulation Cycle 611 E. Marceau Street St. Louis, Mo. 63111 Fe25 2 ” < 2 ° ow ° > < ° Steam Separators MAAKE UP ATER conpmwsare errunn “ave Vertical Steam Separators [ lem V-10 v-25 V-50 io V-100 V-150 V-250 V-3250 V-500 a —l- aaa A Diameter 12 {| 1 | 20 | 24 | 24 30 36 42 ‘ 48 B Height over Heads 30 | 36 | 42 “| 66 72 | 78 84 % C Height over all 36 _| 42 | 48 [ 54 | 72 80 86 92 | 104 D Centerline of iniet 21 24 27 32 5 | E Normal Water Line [18] a | 2 [a F Low Water Switch Level 8 de, 9 | 1 | 2 G Inlet Nozzle Length = 9 11 13 15 [# Blowdown Length 9 [a2 | a3 | a5 } as N Inlet Nozzie—150 Ib. ASA-FL. 3 4 4 6 + — © Steam Outlet-—150 Ib. ASA-FL. 3 Al 4 4 | 6 6 P Water to Engine—150 Ib. ASA-FL. 3 [47 el] ele R Safety Valve SIZED TO HANDLE FULL STEAM OUTPUT T a Maximum Flow Rate with forced 100/150 | 200 | 300 | 450 | 750 | 1200 | 1700 | 2400 Circulation—GPM at +- a + Total Volume—Gallons 14 | 30 | 52 [ 88 | 122 | 208] si0 "[ 702 Volume to Normal Water Line T | 1s E an " B ] 15 | 2 | 44 | 68 | aza | 175 | 246 | aos Avg. Hdig. Cap. Engine Jacket Water] 1 T et vg. Hdig. Cap. Engine Jac fater plus Wet Exhaust Silencer—Gals, a ene eo = a6 Oe a t a0 800 | Dry Weight—Lbs. 165 [240 | 310 | 380 | 460 | 760 1950 1350 [2900 | Wet Weight—Lbs. (Normal W.L) 230 [360 | 525 | 750 [i025 | 1795] bans 3415 7 5250 Shipping Weight—Lbs. ‘| 240 | 330 | 415 [300 | 600 | 975 [2200 [3700 [2500 | Horizontal Steam Separators os am Model Number #10 425 lt age ws | -100 H-150 250 H-250 H.500 { | + a A Diameter 12 I ye | 20 | 24 | 24 30 36 42 48 Is Length 30 | 3 | 42 | 48 | 6 72 78 | 84 9% C Total Height 21 [<2], ar ah. 360) ae 45 53. | 61 67 D Centerline of Inlet 15 | 20 | 25 | 28 1 28 36 43 El 50 55 | —— E Normal Water Level 2 | as [ae | a] a + 2 31 36 39 F Low Water Switch Level | 7 9 | 1 | un | 1 5 16 18 18 G Inlet Nozzle Length ~ [oie | a4 Peden ass] as | 32 25 28 31 M Inlet and Outiet 6 Pal 102) 11 | ie [3 192] 21 24 N Inlet Nozzie—150 Ib. ASA-FL. | 3 4 4 6 é] 8 10 12 14 0 Steam Outlet—150 Ib. ASA-FL. 3 4 {41 616 6 8 10 12 [P Water to Engine—150 ib aSA-FL. | 3 | 4 | 6 ew ee 14 R Safety Vaive SIZED TO HANDLE FULL STEAM OUTPUT - +—— > r 1 Maximum Flow Rate with forced 100 | 150 | 200 | 300 | 450 | 750 | 3100 | 1700 | 2500 Circulation—GPM Ae Total Volume—Galions 1s [31 [ 54 | 9% | 125 | 20] ais) aes 700 Volume to Normal Water Li 2 ets ake focal ta 8 | 16 | 28} 48 | 6 | 110 | 160 | 240 | 360 Gallons Avg. Hdig. Cap. Engine Jacket Water. | | T plus Wet Exhaust Silencer—Gals. 20 i 7 130 f 180 vat is ae ae ae | _Dry Weight—Lbs. 175 | 250 | 320 400 | 480 | 600 | 960 ‘| 3400 1900 Wet Weight—Lbs. (Normal W.L) 240 | 380 | 550 | 800 [1030 | i720 | 2290 | 3400 | as00 |__ Shipping Weight—Lbs. "| 250 | 340 | 425 | 525 [725 | 1000 | 1200 | 1750 | 2a00 | All dimensions in inches. F-27 Standard Equipment WATER LEVEL CONTROL. The standard units are equipped with an externally Piped liquid level control valve which may be used to feed the condensate return or the make-up water to the separator. This control is mounted so that the water in the system is maintained at the proper level. It is actuated by a heavy brass float ball linked to a stainless stce! valve. The water fed by the valve is piped externally to the make-up water con- Rection on the tangential inlet nozzle from the engine. The float chamber Piping is equipped with shut-off valves so that the control can be isolated for servicing. LOW WATER SWITCH. A low water alarm and/or cut-off switch is also standard on this serics. This switch may he utilized to actuate an alarm signal or to stop the engine hy shutting off the fucl supply or grounding the ignition. PRESSURE GAUGE. A suitable dial type pressure fauge its rigidly mounted on the tank and is equipped with a syphon and shut-off valve. SAFETY VALVE. A. standard AS.M.E. pop safety valve with operating lever is supplicd with cach unit. These valves are sized to relieve the full steam capacity of the system. They are available with cither 15 or 20 PSI settings as desired. If not otherwise specified the valve will be furnished with a 20 PS] setting. GAUGE GLASS & COCKS. A sight-level glass with automatic shut-off valves, a drain cock and guard cage is standard equipment. VENT VALVE. A thermostatic vent valve is mounted on cach unit. Optional Equipment* EXPLOSION PROOF CONTROLS. If the unit is to be installed in a location where electrical controls could constitute a fire hazard, explosion proof controls. arc recommended. SPECIAL MOUNTING PEDESTALS Mounting rings, or extended or enlarged pedestals are available if desired. SPECIAL NOZZLES Nozzles of different size or other than right hand as shown are available on special order. Side or bottum steam outlet nozzles can he supplied if required. MULTIPLE INLETS If more than one engine is to be connected to one separator. or if an exhaust boiler or electric heater is attached. multiple tangential inlet nozzles may be furnished. * (Available at extra cost.) Steam Separators Extra Equipment" HIGH WATER ALARM & CUT-OFF SWITCH, A high water alarm or a Separate low water shut down switch of the same type as the low water alarm switch are available and are recommended under some operat ing conditions, PUMP CONTROL SWITCH. A Pump cut-in and cut-off switch may be used to control the water level in the tank in place of the level control valve. Application Data SIZING: These units should be sized on the hasis of the approximate volume of water contained in’ the engine jackets and/or the exhaust recovery silencer connected to them. The volume that cach size sepia rator will handle is given in the specification tables This figure is hased on the expected amount of surge with average operating conditions and normal Pipe lengths. MOUNTING: If Vapor Phase Thermal Circulation is employed the unit must be mounted high enough s. that the water level is over the top of the eylinders and/or wet manifuld when the Jow level alarm. or fuel cut-off switch is actuated. It should also he high enough to give a rise of at least one inch Per foot in the line from the engine manifold to the separator inlet great enough to prevent cavitation at the pump inlet. This will normally be somewhat more elevation than that required for thermal circulation. PIPING. Water openings in the engine jackets. jump- ers to the water cooled manifold. and the manifold stzes should be carefully checked to make sure that the openings are large enough to permit Proper circulation of the liquid and the liquid vapor mixture. In some cases it may be necessary to hive @ Separate and par allel cireut for a water cooled manifold, For thermal circulation the outlet: manifold from the engine, and the circulating line from the manifold to the separator should he sized for not more than 100 tps velocity, based on the amount of stcam produced hy the unit at maximum load. The line from the separator to the engine and the engine inlet manifold should he sized for a velocity of not more than § fps, hased on the assumption that there will be 18 Tbs. of water circulated for every Ib. of steam produced. With forced circulation the outlet and inlet are usually the same and should he sized on the hasis of a velocity of not more than § fps at the rated Capacity of the engine water circulating pump. The recommended allowable flow is given in the accompanying table F-28 APPENDIX G COAL General The purpose of this investigation is to identify and establish the estimated cost of coal that would be required to fire a steam generator at Tanana, Alaska. , The annual demand for coal for the Tanana power plant is projected to be 4,400 tons in 1984. The 4,400 tons is projected to be delivered to Tanana in 1983. Annual coal requirements are projected to increase three percent per year as electrical power demands increase. Transportation Considerations —atsportation vonsiderations As a bulk commodity, the total cost of coal in any considerable quantity is greatly influenced by the cost of surface transportation. For the community of Tanana, surface transportation means freighting by river barges during the summer navigation season. A coal source must, therefore, be identified which is on or within close proximity to the navigable portions of the Yukon-Tanana River System; or which is located on an existing highway or railroad connecting with the river system. These potential sources meeting this criteria are evaluated in the following paragraph, Aiternative Sources and Transportation Assessment Ean transportation Assessment a. Yukon River (Upstream) 1) Rampart Vicinity - A series of coal-bearing sediments extend discontinuously along the Yukon River from Tanana to Hess Creek, a river distance of nearly 80 miles. Other than occasional thin beds observed along the river banks no detailed exploration for coal potential is known to have been made. Production for local use during the early placer mining activities reportedly occurred 3) 1) near Rampart Village and on Minook Creek. Commercial Production of 1,200 tons for river steamer use is reported to have taken place prior to 1902 opposite the mouth of Hess Creek. At that location, seven beds were identified ranging from 1 to 7 feet in thickness. The coal is Classified as lignite to Sub-bitmuinous. No recent mining or development activities are known. The Eagle Coal Field - Extending from tne Canadian Border westerly to the vicinity of Woodchopper a sequence of coal-bearing rocks parallels the course of the Yukon River five to 20 miles to the south. The coal beds range in thickness from a few inches to 6 feet and are variously classified as black lignite or sub-bituminous. All minor Past production has been for local use. These deposits are between 370 and 470 river miles upstream from Tanana. Nation River - A single occurrence of bituminous coal is located near the mouth of the Nation River, a northerly tributary of the Yukon. The deposit is described as consisting of discontinuous Pods and lenses within vertical dipping sediments. About 2,000 tons for river-steamer use was produced prior to 1900. Reserves are unknown. The river distance above Tanana would be about 430 miles. b. Yukon River (Downstream) Between Ruby and Galena - Occurrences of bituminous coal are known in the vicinity of Nulato, and between Kaltaq and Anvik. Generally, the beds are from 1 to 3 feet in thickness and, where exposed, are subject to river flooding. Several of these deposits were mined prior to 1920 for local use and as river steamer fuel Prior to 1900. There apparently have been no recent attempts at development. The nearest of these deposits is about 150 river miles downstream from Tanana. 2) North Slope Haul Road - South of the Brooks Range, two coal deposits within close proximity to the Haul Road are noted: a) Tramway Bar - This bituminous coal deposit is located about 15 miles: below Coldfoot on the Middle Fork of the Koyukuk River. Little information is available. It was used as a local fuel source during the early placer mining activities. Transport distances would be approximately 110 miles by road to the Yukon River and thence 120 river miles downstream to Tanana. ~ Dall River - On the Coal Creek tributary of the Dall River, several miles east of Hau] Road, an 11-foot thick bed of coal is reported. The extent is unknown, although the coal-bearing formation may extend north-eastward through the upper basin of the Hodzana River where coal has also been reported. The coal is apparently lignite to Sub-bituminous in rank and similar to that found on the Yukon above Rampart. The distance from Coal Creek to tne Yukon along the Haul Road would be about 40 mles. From the Haul Road to Tanana via the Yukon is about 120 river miles. Jarvis Creek Coal Field - The Jarvis Creek Coal Field is considered an eastern extension of the Nenana Coal Field. It is situated several miles east of the Richardson Highway near Donnelly. The coal is ranked as sub-bituminous and potential reserves are established. Sporadic mining has taken place in recent years, but the market is limited. Freighting would be by truck via the Richardson and Alaska Highways to Fairbanks (140 miles) and thence by railroad or truck to Nenana (60 miles). From Nenana transport would be by barge via the Tanana River to Tanana (150 miles). Alternatively, the coal could be trucked from Fairbanks to the Yukon and thence via the river to Tanana (140 miles and 120 miles respectively). d) Nenana Coal Field - The Nenana Coal Field is situated in the northern foothills of the Alaska Range and is bisected by the Nenana River, the Alaska Railroad, and the Parks Highway. Commercial mining has been in Progress at this coal field continuously over the past 60 years. Presently mining is conducted by the Usibilli Coal Company at Healy with production utilized for power generation in the Fairbanks area and for a mine-moutn plant at Healy. Considerable proven reserves of sub-bituminous coal exist within the Usibilli leases. The railroad and highway distance from Healy to Nenana is 60 miles. From Nenana to Tanana by river is about 150 miles. e) Summary of Transportation Requirements - A summary of transportation requirements for moving coal from different mines to Tanana is shown in the following table. Table of Transport Distances, Various eee tb istances, Various Potential Coal Sources to Tanana en ouricles tO TL anana ource ailroad ignway iver ota Miles Miles Miles Miles Rampart - - 80 80 Eagle Coal Field 10 400 410 Nation River - - 430 430 Ruby/Galena - - 150* 150 Tramway Bar - 110 120 230 Dall River - 40 120 160 Jarvis Creek - - - - via Tanana R. - 200 150 350 via Yukon R. - 280 120 400 Nenana Coal Field 60 - 150 210 60 150 210 *Upstream freighting from closest occurrence 4. Coal Composition and Heating Value The composition and heating value for the coals from each of the sourcés considered in paragraph 3 are shown in the following table. Table of Coal Composition s Receive asis Source Moisture Volatile Fixed Ash Sulfur — BTU % Matter Carbon % % % % eee ee Rampart 11 4) 37 10 0.3 ? Eagle 10 42 40 7 1.3 ? Nation R. 2 40 56 3 3.0 ? Ruby/Galena, Etc. 5 31 56 8 0.5 ? Tramway Bar 5 34 48 13 2? ? Dall River** 17 45 34 3 0.5 9400 Jarvis Cr. 22 39 30 9 0.8 8600 Nenana 27* 38 31 6* 0.2* g000** Note: Percentages may not total due to averaging of individual items. * Usibilli Coal Co. sales specifications averages. ** Float sample from Hodzana River. 5. Estimated Costs Only the Nenana Coal Field at Healy offers an active mine coal source. Several potential coal sources have direct access to river transportation. However, these sources are not active. The other potentially attractive sources (Rampart, Nulato, and Dall River) would require the expense of exploration, development, and Production facilities prior to actual production. It is not deemed feasible that the estimated rate of coal consumption for Tanana alone (4,400 tons per year) could justify such expenditures. At Healy the operations of the Usibilli Coal Company are established, reserves are proven, and required loading and transportation facilities are already in existence. These facts make the Healy source most attractive. The cost of coal delivered to Tanana from the Usibilli Coal Company at Healy is estimated as follows: 1. Cost at Usibilli Coal Company's mine loaded in railroad 2. Cost of rail transportation, Healy to Nenana via the Alaska Railroad (tariff)........... sla lu atlas ble eine 2 eles Ale old . 4.36/Ton 30 Cost of barge transportation, Nenana to Tanana via Yutana Barge Lines including railcar unloading, barge loading at Nenana, and unloading to stockpile at Tanana (estimated)... 42.50/Ton Total Cost at Tanana $69.86/Ton The quoted Usibilli price is essentially a current "spot price" and is subject to change. It may be possible to negotiate a lower unit Price under a long term contract in the range of $18 to $20 per ton (current basis). The Alaska Railroad tariff is fixed for present purposes, but May be subject to change. A reduced rate could be effected on a “unit train" basis, but the tonnage for Tanana alone is insufficient to meet minimum requirements. Also a “unit train" would impose unloading and storage requirements at Nenana not presently existing. For regular car loadings demurrage may also become a cost factor. As an alternative to rail freighting from Healy to Nenana, the Alaska Carriers Association was consulted. Presently there is no truck tariff for bulk coal. Under a general commodity classification the rate would be $0.78/100 1b or $15.60/ton. Presently, Yutana Barge Lines, Inc. does not have a tariff for bulk coal. According to the Alaska Transportation Commission, the only current tariff (5/1/80) is for handling, wharfage, loading, and unloading of coal in sacks and sacks on pallets. Effective 6/30/80, the State of Alaska no longer regulates inland water freight except for insurance. Yutana does not presently operate hopper barges but has the capability of transporting up to 250 tons of coal per trip as deck cargo between Nenana and Tanana. The limiting factor is barge draft on the Tanana River. They could only estimate a probable cost range of between $40 and $45 per ton, including rail-car unloading and barge loading at Nanana and unloading at Tanana. A similar price range would be effective for upstream freighting from a Nulato coal source to Tanana. If transport were from the Rampart coal source or at the Yukon Haul Road crossing, the rate would likely be approximately $20/ton due to back-haul Capability on barge runs to Ft. Yukon. Separate deck loads of up to 600 tons would be possible between the Haul Road crossing, or Rampart, and Tanana because of greater river depth and back-haul considerations. ; 6. Summary and Conclusions Eight potential coal sources, all within 430 transportation route miles of Tanana, were evaluated. Of the eight sources, only the Nenana Coal Field at Healy has an active mining operation. The coal at the Healy fiela is relatively low sulphur (0.2%) and has a Btu value of 8,000 per pound. The estimated cost delivered to the storage pile at Tanana is $70 per ton. Based on the investigation and the information presented here, the Nenana Coal Field source is concluded to be the most advantageous source of coal available. 1. APPENDIX H CONSERVATION General Description The consumption of energy can be reduced by conservation at Tanana. In this section, annual energy usage and energy loads are outlined, along with measures that would have to be implemented to conserve energy. The amount of energy that can be saved by conservation has also been estimated. Annual Energy Usage_and Energy Loads Annual energy usage at Tanana consists primarily of electricity (2,000,000 kWH), fuel oil for heating (282,500 gallons), and wood for heating (1,200 cords). It is estimated tnat 75% of the electrical energy consumed is for lighting. Other uses of electrical energy are for kitchen appliances and ventilation. Fuel oi] is used principally for space heating, while wood is used almost exclusively for space heating in residences. The hospital uses a large percentage of the electrical energy and 50% of the fuel oi] used annually for heating. The school uses a small percentage of the electrical energy and 10% of the fuel oil for heating, while the FAA facility uses 12% of the fuel oil. The balance of the electrical energy and the balance of the fuel oi] are used by the safe water facility, residences, business establishments, and others. Implementing Conservation a. Electricity Lighting, being the major use of electrical power, offers the greatest possibilities for conservation. Energy use for lighting can be reduced in the following ways. 2) 4) 1) Eliminating Overillumination Buildings are often overilluminated. Reducing the level of illumination can be achieved in most cases by reducing the size of the bulbs in present fixtures. A high level of effective illumination can likewise be achieved by painting or covering walls, ceilings, and floors with light-colored finishes; rooms with dark surfaces and furnishings that absorp light require more wattage in order to maintain a desired level of illumination. The lighter surfaces in a room will not only reduce the wattage necessary to achieve suitable illumination at night but will also result in use of the lights during fewer daylight nours, when sunlight furnishes the desired lighting. Light Falloff Sources of electric light usually experience light falloff, because the output decreases with the age of the lamp and because dirt accumulation on lamps, fixtures, and lenses decreases the quantity of light. Light falloff can be reduced by an improved maintenance system. Turning Off Lights Letting a light burn rather than turning it off always uses electrical energy. When electric lights are not required, tney should always be turned off. Use of Daylight for I]lumination Windows can serve effectively as the primary lighting source in perimeter spaces in buildings in Tanana. Often blinds or drapes remain closed during daylight hours, and electric lights remain on. 5) Substitution of More Efficient Lamps The use of more efficient lamps can reduce the electrical energy requirements for lighting. More efficient lamps generally produce less heat, but the loss can be made up by the heating system at a lower cost. Other uses of electrical energy are associated primarily with household appliances. The households in Tanana contain fewer appliances than are normally found in an American home, and energy use is about one-half of that of a fully equipped home. Efficient electrical appliances presently appearing on the market are supposed to reduce energy consumption by as much as 25%, but the purchase of new appliances to reduce electrical energy costs can generally not be justified even in Tanana. Therefore, efficient appliances will become a part of the pattern of electrical use in Tanana over the next 5 to 10 years, with no abrupt drop in electrical energy use. b. 011/Wood Space heating is the major end use of oi] and wood in Tanana and offers the greatest possibility for conservation. The use of fuel oi1 and wood for heating can be reduced significantly in the following ways: 1) Reducing Building Heat Load A building heat load depends on the average difference between the indoor and outdoor temperatures. This difference can be reduced by lowering the temperature in occupied areas, maintaining even lower temperatures in less critical areas, and not heating some parts of a building. 2) Avoiding Radiation to Cold Surfaces In the cold climate of Tanana, the temperature of the interior Surface of exterior walls or windows is mucn lower than room temperatures. People near these cold surfaces radiate heat to them and feel cold even if the room temperature is 70°F, Therefore, overheating the room to offset the effects of the cold interior surface occurs. The effects of cold interior surfaces can be reduced by covering them with drapes, wall carpets, or blinds. 3) Reducing Infiltration Infiltration often accounts for a major portion of the heating load. For well-insulated houses, the infiltration loss can be in the 40% range. Infiltration cannot be turned off and on, but it can be reduced with very effective measures, such as caulking cracks around windows and door frames and weatherstripping windows and doors. Plugging air leaks is generally very economical, with weatherstripping for wooden doors costing about $50 to $75 per door. The cost of weatherstripping for windows depends on the size and type but should be between $25 and $50 Per window. Other air leaks include entrances of cables, kitchen and bathroom vents, and joints between floors and outside walls. 4) Increasing Solar Heat Gain Solar heat gain can be achieved by permitting sunshine to enter the the building through the windows and by refinishing the exterior south wall in particular to absorb solar radiation. 5) Improving Building Insulation Many homes in Tanana have no insulation. (See Section II of this report.) Installing or upgrading insulation can greatly reduce the heat loss, and other improvements could be made, as well. Installing double glass in windows instead of single glass will reduce the heat loss from 1.1 Btu per square foot per degree of difference in temperature to 0.55 Btu. For an average well-insulated home, it is estimated that 16% of the heat loss is through windows (single glass). Other average losses are 3% through doors, 5% through ceilings, 17% through walls, and 1% through the foundation. These five ways of reducing heating energy needs can be implemented, but their effectiveness depends on the Owners, operators, and occupants of buildings. If all buildings in Tanana took steps to reduce tne heating energy needs listed here, the heating energy requirements could easily be reduced by 30%. Improvements of public building could be made by the owners of those buildings. An education Program could be also initiated to promote improvements, but any reduction in heating requirements of over 15% should be considered a major accomplishment. 4. Summary and Critical Discussion Summary Major reductions in the use of electrical energy for lighting can be achieved if all users adopt conservation practices. These users are numerous, however, and they will not all adopt such energy-saving practices. A 10% reduction in the use of electricity for lighting is thus a reasonable expection if a good effort can be made to promote conservation. Similar major reductions in the use of oil and wood for space heating can be achieved if all users adopt energy-saving improvements and practices, although this will not be easy. A 15% reduction in oil/wood consumption for space heating should be a reasonable expectation if a good effort can be made to promote conservation practices and improvements. Critical Discussion Energy conservation can reduce the consumption of electrical energy and fuel oi] in Tanana. In themselves, however, the reductions will not have a great impact on the high total costs for electrical energy and fuel oi] now being experienced in Tanana. Wood is a much more economical fuel for space heating, and many residents are converting from fuel oi] to wood for heating in individual dwellings. APPENDIX I GEOTHERMAL ENERGY General Description When underground water comes into contact with molten rock, or magma, near the earth's surface, natural geysers and wells of steam and/or hot water can result. This form of energy can be tapped for useful Purposes. Geothermal steam nas been used to produce electrical energy for many years, notably in Italy, New Zealand, Japan, and California. The techniques are now well established. In essence, the geothermal steam replaces the boiler in a fossil-fuel generating plant and is used to drive a steam turbine generating unit directly. Geothermal hot water, which is more abundant than geothermal steam suitable for driving turbines, is used for space neating in buildings. In colder climates, such as Iceland, geothermal heat is used for the production of fruit and végetables in greenhouses outside the natural limited growing season. The application of geothermal energy also includes extraction of heat from the ground by a heat pump, tne most common use of which is in refrigeration and air conditioning. A gas, such as freon 12, is compressed and then rapidly expanded through a valve into an evaporator. The evaporator extracts the latent heat of vaporization from a heat source, such as the inside of a refrigerator or a building. The expanded gas is tnen recompressed and passed through a condenser, where it gives up the absorbed heat to the atmosphere surrounding the refrigerator or building before being delivered back to the supply side of the expansion valve to repeat the cycle. These more common forms are known as air-to-air heat pumps. Water can also be used as tne heat source or sink to form water-to-air and air-to-water heat Pumps. Such equipment is supplied commercially in standardized models by well-known manufacturers, including Westinghouse, Carrier, and York, and can be used to extract heat from natural water of moderate temperature. 2. 3. Steam and Hot Water The most promising areas for the development of geothermal power from steam and hot water are associated with volcanic regions, earthquake faults, and areas of hot springs and geysers. Such areas are prevalent in the Pacific area, extending from countries of western South America up through several of the western 48 contiguous United States, southern Alaska, and Japan and on to New Zealand. Earthquakes have been recorded in the Tanana area, but there is no volcanic activity or evidence of geothermal steam or hot water on the land surface. Furthermore, geological, tetonic, and other geophysical records contain no indication of subsurface hot dry rock, geopressured zones, or magma that might be discoverable by drilling. This is no guarantee that geothermal energy does not exist below the Tanana area, but it does indicate that the chances of finding it at a Practical depth are small. On the basis of this evidence, geothermal steam and hot water are not viable considerations for Tanana. In view of the limited total energy requirement, high cost of drilling, and apparently small possibility of discovery, a subsurface investigative program to determine whether a geophysical source of steam or hot water exists in the Tanana area is not recommended at this time. Heat Pump A typical heat pump for extracting heat from the earth is of the water-to- air type. The heat source is a well, from which water is pumped to a heat exchanger, where the heat is extracted by the evaporator section of the heat pump and then released through the condenser coils for space heating of buildings. The used water is returned to a second well, where it can percolate back to the first well and recover heat from the surrounding earth. Commercial units are usually of the reversible type, allowing heat from inside the building to be extracted when necessary and dissipated in the earth. The design is adapted to provide automatic year-round air conditioning in climates where seasonal heating and cooling are desirable. Important factors in the operation of the heat pump are the availability of the wells and the temperature of the water and surrounding earth. For a single-family domestic dwelling, two wells about 50 feet deep containing water at 50°F , typically available in many parts of the U.S., are sufficient for full air conditioning. Multifamily dwellings and larger buildings for commercial and industrial purposes usually require wells of | up to several thousand feet deep in order to obtain water of a higher temperature for greater efficiency. The possibility of using heat pumps to extract geothermal energy at Tanana depends on subsurface conditions. Permafrost maps of Alaska show Tanana to be in an area of discontinuous permafrost but close to areas generally underlaid by continuous permafrost. It is therefore unlikely that earth of the required temperature will be found near the surface. The actual depth to which wells would be required to go can be determined only by experimental drilling. Heat pumps do not eliminate other sources of energy. Power is still needed to drive the gas compressors and for nonheating purposes, such as lighting. The energy required for operation of the compressors can be almost totally absorbed into the heating cycle, however, and the additional heat absorbed from the earth can increase the energy output from two to five times, depending on the thermal conditions. Combined with a system for waste energy recovery in the prime mover, such as that described in the section devoted to diesel power generation with recovery of waste heat, the heat pump cycle can be made very efficient for space heating. An investigation of earth conditions and temperatures by drilling is not included in the scope of work for this report, but it is suggested that at least one small bore hole be drilled at Tanana to obtain some reasonably reliable data. 1. APPENDIX J WIND General Description Small-scale wind generation of electricity (a few kilowatts) has been feasible commercially for more than 50 years. A typical installation consists of a low-voltage propeller-driven DC generator mounted on a Simple structural steel tower and used to charge a bank of lead-acid cells. Such installations found favor for many years at geographically remote sites, such as hunting and fishing lodges and isolated farms, where they were used for Powering electric lights, radios, and small motors. The advent of rural electification, however, reduced such installations to only a few instances beyond the extended reach of large commercial Power systems. A small revival has taken place with the advent of microwave radio communication in recent years. Small wind-driven generators are - sometimes used to power microwave relay stations where other sources of electrical power are not economically available. The beginning of the energy crisis in 1973 renewed interest in wind power. The principal attraction is, of course, that the energy source (wind) is in virtually infinite supply and is provided by nature without cost or human effort. In addition, the environmental effect of a wind-driven power generator is almost zero compared with that of other forms of energy generation. This has resulted in much government-supported research into wind power in North American and Europe, where the technology and industrial capabilities for this type of work are concentrated. Original concepts included wind farms, consisting of numerous small wind-driven generators distributed over a large area and connected to a common system, and large-scale wind-driven generators using various methods of converting the wind energy to mechanical and electrical power. To date, economy of scale seems to have had a strong influence, and effort has been concentrated mostly on developing ever-larger propeller-type wind-driven generators. 2. Technology Profile Large Propeller Requirements - Wind-driven generators can be conveniently compared to propeller-type water-driven generators, with which they share a common fundamental theoretical background. Both use a propeller to convert the kinetic energy in the flowing fluid (air or water) to mechanical power, which is in turn converted to electrical power by the generator. The amount of power developed by both types of generators is directly related to the rate of mass flow through the propeller. This is the Principal reason for the differences in equipment size between the two methods. With water at 62.4 pounds per cubic foot and air at 0.075, it is apparent that a much greater volume of air is needed to generate a given amount of power, resulting in very large propeller diameters for wind-driven turbines in comparison to runner diameters in hydraulic turbines. For example, a four-blade hydraulic turbine Propeller runner with a diameter of 7.4 feet will develop 2,500 kW under an hydraulic head of 27 feet. To develop the same amount of Power, a wind-driven turbine with a two-blade propeller requires a propeller diameter of 300 feet and a wind velocity of 27.5 mph. Assuming the use of a horizontal- Shaft unit, total powerhouse height for the hydraulic installation would be about 18 feet, with 10 feet above ground level. The 300-foot-diameter wind-driven propeller, when mounted on a 200-foot tower, has a swept distance reaching 350 feet above ground level. Wind Direction and Speed - The wind is capricious, not only in the poetic sense but also from an engineering point of view. Its direction and velocity can change from minute to minute, even from second to second. Yaw devices are required for automatic facing of the propeller into the wind. This is simple on small generators, requiring only a tail vane similar to that on a weather vane. Larger generators, however, require wind direction sensors, servocontrol systems, and power-operated drives in order to cause azimuth settings of the propeller shaft to follow changes in wind direction. d. Fluctuations of wind velocity are a particular problem. Unlike river water, which can be dammed to Provide pressure head, storage for future use, and controlled release to meet power demands on a hydroelectric station, continuously variable wind Power must be converted as it occurs. This means that wind power that cannot be absorbed by the load at a particular time must be shed (e.g. by feathering the Propeller blades) or stored after conversion by some means, such as _ pumped storage or electrical storage batteries. Downstream storage jis expensive and, depending on the method used, will at least double the cost of a wind-powered installation. Propeller Speed - Electrical frequency control is also a special consideration for wind-driven AC generators. Frequency is determined by the speed of the generator, which is geared to the Propeller. Generator frequency is therefore regulated by close control of Propeller speed. On the larger installations, this is accomplished by feathering all or some of the propeller blades, as for the load control mentioned above. The usual method is to operate the blade feathering mechanism with an hydraulic servomotor controlled by a governor system responsive to propeller speed. Close speed control is critical if the generator is to be used as the primary source of Power in an isolated system. It is not quite so critical where the generator is to supply supplementary power to an electrical system large enough and stable enough to be regarded as an infinite bus. In the latter case, speed control is required primarily for synchronizing the generator with the system before electrical connection and for overspeed control on load rejection. The system frequency controls speed when the generator is on-line. Control Complexity - An unattended wind-driven generator also requires load sensing control for automatic placement of the generator on and off the line as wind speed and electrical load Change. Along with automatic yaw and speed controls, these lead to increasing complexity in control requirements as the size of the generator increases above the limit (about 20 kW) for the simplest battery charging systems. e. Research and Development - Prodded by government incentives and the + ever-rising costs of other forms of energy, design difficulties are being overcome, and some viable designs for larger wind-driven generators are now emerging from the research and development stage. Several are being used in commercial power systems ready for long-term durability and reliability testing. These are used exclusively for supplementing existing generation, particularly fossil-fuel generation. The advantage is that variations jin output resulting from changes in wind speed are automatically and continuously compensated by other generation in the system to meet load requirements. 3. Equipment Availability Wind-driven generating equipment is available but only on a limited basis. A search of literature was made for information about wind-driven generating equipment. This produced a number of designs, several of which could only be described as designers' dreams, with little if any commercial hardware available. After elimination of the more exotic designs, the remainder indicated a predominance of propeller-driven equipment, with the number of blades on each propeller ranging from about eight in the smaller sizes to two for the largest generators. Contact with manufacturers of Propeller-type wind-driven generating equipment disclosed the fact that some of the higher capacities advertised are presently still in the design concept stage. Since Tanana is not considered for this study as a research and development site, the review of equipment is limited strictly to commercially available equipment that has at least some record of successful operation. Accordingly, four models were chosen, with a range of capacities covering individual to community installations. Principal data for the four models are listed in Table J-1. The two smaller units, Hamilton models B5 and B20, are suitable for application to individual dwellings. Model B5, assisted by a rechargeable battery pack and inverter to raise the output to 120 VAC, is suitable for supplying power to a small dwelling to operate electric lights and small appliances. Model SK20 could be used in a similar capacity for large re Co community buildings, such as meeting halls and schools, and for small commercial and industrial establishments. Both types require some gasoline-driven or other backup installation for supplying power and charging batteries during periods when the wind velocity is too low to meet energy requirements. The two larger units, WTG model MP1-200 and Boeing model MmOD-2, are suitable for supplying supplementary power to community sytems served primarily by other, more dependable generation. They are designed for unattended automatic operation in isolated locations and are equipped with the previously described controls for operating the yaw mechanism, governing propeller speed, and switching the generator in and out of the system in response to the vagaries of wind speed. A model MP1-200 is presently installed at Cuttyhunk Island, Massachusetts, and is operating in parallel with 465 kW of diesel generation to supply a small community. The changes in system balance as the wind-driven generator cuts in and out. appear to the diesel governors as variations in load, and they automatically throttle up or down accordingly. The first of three model MOD-2's is presently installed as an experiment for the Department of Energy about 13 miles east of Goldendale, Washington, and is scheduled to go on-line in December 1980. The Hawaiian Electric Company has signed contracts for the installation of 32 similar wind-driven generators on the island of Oahu. The first of these is scheduled to be in operation in early 1983 and the last by the middle of 1984. The total output of 80 Mw represents about 8% of the Hawaiian Electric Company's peak. The most notable of the characteristics given in Table J-1 is the high wind speed required, particularly for the larger units. This is the result of the fact that power output varies with the cube of wind speed. Higher outputs with the same size of propeller or smaller equipment for the same output can be obtained by utilizing the highest practical wind speed. The effect is particularly noticeable in model MP-200, where output increases from 200 to 313 kW with a wind increase from 30 to 35 mph. The economic advantages of high wind speed are clear, but they restrict ideal locations to those areas that have an average wind speed in the general range of 10 to 20 mph for the smaller units and 20 to 40 mph for the larger ones. 5. Application at Tanana The first objective in determining the applicability of wind power to Tanana was to obtain suitable data on wind velocity. A record of typical wind speeds at the Tanana air Strip is shown in Table J-2. These data were obtained from the Department of Commerce and are from a single anenometer located 10.1 meters (33 feet) above the ground. The wind speeds were averaged and then used to develop a synthetic wind velocity duration curve in accordance with the Wentink function. The result is shown in Figure J-1. As a check, a synthetic wind velocity curve was also developed in accordance with the Weibull function; there were no significant differences. It was therefore decided to use the Wentink curve in power generation considerations. Figure J-1 shows that the wind speed of 6 mph required in order to raise the small Hamilton wind-driven generator models B5 and B20 to the start of generation would be attained 45% of the time, but the wind speed needed to raise the same generators to rated output would be attained less than 2% of the time. The output for each machine at a wind speed of 6 mph is less than 19% of rated Capacity. The wind speed of 8 mph needed to raise the larger WTG model MP1-200 to the start of generation would be attained 30% of the time, and the wind speed of 11 mph needed to raise the large Boeing model MOD-2 to the start of generation would be attained 9.5% of the time. The output of model MP1-200 at a wind speed of 8 mph is about 2% of rated capacity, while that of model MOD-2 at a wind speed of 11 mph is only about 6% of the rated capacity. Neither the MP1-200 nor the MOD-2 could attain rated output. With generator output varying with the cube of the wind speed, very little energy would be obtained from these machines at the low wind speeds and short durations realized at Tanana. Reliability and Energy Production Wind generation at Tanana jis not reliable. One small 5-kW generator, Hamilton model B5, would generate only a small amount of energy annually. On the basis of the information presented in paragraph 4 above and the synthetic wind velocity duration curve shown in Figure J-1, the output for model B5 would be about 3,800 kWH per year. Similarly, for the next size of generator, the 20-kW Hamilton model B20, the output would be about 8. 7. 15,200 kWH per year. Furthermore, the larger sizes of generators would not produce much energy. Based on the wind velocity duration curve shown in Figure J-1, the output of model MP1-200 would be about 66,000 kWH per year, and that of model MOD-2 would be only 155,000 kWH per year. These amounts of energy constitute a very small proportion of the approximately 2,000,000 kWH per year presently required by the customers of the Tanana Power Company. Estimated Costs The estimated installed cost for each machine is shown in Table J-1. The installed cost of energy generated annually is $3.96 per kWH for the small 5-kW machine, $2.96 per kWH for the 20-kW machine, $6.06 per kWH for the 200-kW machine, and $29 per kWH for the 2,500-kW unit. These costs are unreasonably high and warrant no future consideration. Economic Analysis No economic analysis has been made for wind-generated power, because the excessive costs per kilowatt-hour generated do not justify such action. Summary Clearly, the installation of wind-driven equipment at Tanana cannot be considered technically feasible or economically viable. This conclusion is based on the wind speed data obtained at the air strip, and it holds true even it substantial error is considered in the figures and the method of calculation. The conclusion is also based on the high equipment costs for the small amount of energy produced. This is disappointing, because the situation at Tanana is similar to that at Cuttyhunk Island, and the installation of an MP1-200 wind-driven generator to supplement diesel generation would at first seem an attractive means of reducing energy costs. Higher wind velocities may be found at a site at higher elevations than the Tanana air strip. The top of Mission Hill has been suggested as one possibility. No wind velocities and other essential data for such sites are Fe available, and obtaining suitable data, including the establishment of anenometers and recording of wind speeds over an extended period of time, is not within the scope of this reconnaissance study. If, however, all of the possibilities for wind-driven generation are to be fully explored, such work should be done. The most expeditious approach would be to select several possible sites and investigate them concurrently. The probability that required wind speeds will be available on adjacent hilltops does not seem high when such low wind speeds are experienced at the Tanana air strip, however. Certain observations are appropriate for sites remote from the village of Tanana. Such sites require the community approach to power supply, with the installation of the larger-capacity units and their sophisticated automatic control systems. The installation cost for the equipment, delivered in large assemblies, will be much higher at remote sites than near the village. In addition, the cost of extended transmission lines and their electrical loss must be taken into account. The larger wind-driven generators are still newly developed pieces of equipment. Some problems, however minor, are to be expected from time to time in their Operation. For this reason alone, it is better to have the generators installed in locations that are accessible with reasonable convenience under all weather conditions. Table Jel Wind Driven Generators 1 2 3 4 WTG Energy Boeing Engineering be Gregory P. Gregory P. System and Construction Manufacturer Hamilton Co. Hamilton Co. Incorporated Company Model BS B20 MP1-200 MOD-2 Capacity, Rated, KW 5 20 Maximum, KW _ 71.3 30 Number of Propellers 2 2 =— —— * wes " pe fm Number of propeller blades 2X8 2X 12 3 2 Wind speeds for: Start of generation, mph 6 6 8 3 Rated capacity, mph 15 15 30 27.5 Maximum capacity, mph 23 23 35 27.5 Estimated installed cost $15,000 $45,000 $400,000 $4,500,000 (1981) including including including including batteries & batteries & transmission transmission inverter inverter line line Table J-1 J-2 AVERAGE WIND SPEEDS (M/SEC) BY HOUR AND MONTH AT TANANA Data Period July 1, 1948 to December 31, 1964 Roof Top Reference: 10.1 Meters Anemometer Height: HOUR 22 23 ALL 19 20 21 12 13 14 15 16 17 #18 1 10 02 03 04 05 06 07 08 09 00 01 MONTH SHBADOMTHMMnwH NANNNNAIN SNA TE SUN OF Gots COVED Sr NNNNRMReRKReennAN SAIIASARQEMNNN NNN RR Re NN NEQETANQecsernanm co 8 8 © ee . NANNNANN RK NNN SASSeereonsarmmn . NNN CEOSHMANNNMHOTMN NAN mmainnanainda SSVRSyanensna Nanennnnnnnan NSTteTesqraracnnoe NOMmnannndann NSOSeestvronoatnre ° NOanninnnnnnnn SVNERQMe KM Hee Noannnnnnaadn STII ASetNessNN NOM mannnaann SITS Qermwenwan NON anaann CAVE OMAUGS OHMS NAUMMMM MMM ABNAE WOnNRK SRMUDCRK Agen NNUMMMOMNMOMNNWW CLAZTOLINAROMNG NANO ONAN MMOCUINAGCNRAEOMMNw NNN ONNNNNAA OBMOMOMSENMSE NS NNNNNN NAN MOTT NDSTORKOMAMOM NNNNNNN NN NNN SE OMIASCOGINMR RK ce ee ee © © ew NNNNRE NRK Re NNN LLTALGLOARAMMNS NNNR RR Ree COEmMawMnsnoonremo NNNR RRR enn SOVATOZNOKMMo NNNR KR ee NN FTEQAALOONAKEMNS NNR RP RRP ee Nd AVERAGE WIND SPEED (M/SEC) BY SEASON SPRING SUMMER AUTUMN ANNUAL WINTER HEIGHT OLN co 8 NNO ee Nie sso Saw 2 Ow Nan mmnw NNO J-2 5.65 mph) (Based on Wentink Function, w/b = 1, a=.7 & .80 and historical mean velocity % OF TIME WIND VELOCITY EXCEEDS SYNTHETIC WIND VELOCITY DURATION CURVE ° N WIND GENERATION VELOCITY-DURATION CURVE MARKS ENGINEERING / PLATE NO. BROWN & ROOT, INC. ie 2 APRIL, 1961 ——— YNOH 3d S3TIW NI G33dS GNIM 1. 2. APPENDIX K WOOD HARVESTING, TRANSPORTATION, AND STORAGE AT PLANT ——— a STORAGE AT PLANT General The purpose of this appendix is to outline a specific harvesting, transportation, and storage plan that is best suited to the needs of the village of Tanana. The costs of equipment and man-hours are outlined, and certain aspects of wood harvesting are also discussed in paragraph 3 below. This harvesting plan assumes that wood will be taken from along the river and islands, rather than from uplands, and that harvesting will be done in the summer. Advantages and disadvantages of upland harvesting, harvesting along the river, winter harvesting, and summer harvesting are outlined in paragraph 3. Harvesting The amount of wood that would be needed annually during the first years of operation is about 5,150 cords for the steam alternative and about 2,440 cords for the wood gas alternative. These annual requirements are not large when “compared to the capacities of available harvesting systems. Investment cost for a harvesting system could easily exceed one-half million dollars (not including barges and towboat), but such a large investment to meet the needs being considered would not be justified. The saw/yarder/cableway harvesting system has been selected for evaluation here because it is low in investment costs. It also is well suited to steep terrain, has minimal effect on remaining stands, creates little soil disturbance, uses a small amount of petroleum fuel, requires a minimum of roads in the harvesting area, and should not require extensive maintenance. The disadvantage of the system is that labor requirements will be higher and production lower when compared to the high-investment, highly mechanized harvesting systems. The harvesting system planned here would involve installing a lasso-type cableway. Trees would be felled and cut to size with chain saws, and the sized logs would be moved to the cableway with a yarder attached to a farm tractor and manually hooked to the cableway. The cableway would then move the logs to the barge on the river, where the logs would be unhooked from the cableway. The harvesting is planned to be a thinning Process, in which smaller trees would be left to reforest the harvest area. The harvesting rate is assumed to be 60 cords per harvesting day using an 1l-man crew (five or six men for ‘cutting, sizing, hauling to the cableway, and hooking, plus four men for unloading onto the barge and one or two men for operation and maintenance of the drive unit). It is projected that the cableway system will have to be moved twice a year to harvest the 5,150 cords required annually. If 55 cords of wood can be harvested per acre, about 100 acres will have to be harvested each year. The installation of a 20,000-foot cableway should require about 10 days for the 11-man crew. With a harvesting season of 23 weeks or 115 days, with 20 days devoted to installation and moving of the cableway, 90 days (95 less the loss allowed for bad weather and holidays) could be devoted to harvesting. At a harvesting rate of 60 cords per day for 90 days, the annual harvesting Capacity should be 5,400 cords, which would meet the initial requirements for the steam system. Only about 45 days of harvesting should be required in order to harvest the 2,440 cords needed during the early years for the wood gas alternative. As wood requirements increase through the years, either more harvesting days or greater production per day will be required. Transportation Transportation from the harvesting area to Tanana is projected to be by river barge pulled by a tow boat. Snow machines will not be practical because of their limited capacity (in the 1/4-cord range) and because of the hauling distances involved. For this plan, two barges are required, each with a capacity of 120 cords. To haul the 5,150 cords of wood needed annually, 45 round trips would have to be made to the harvest area, which in this plan is assumed to be about 10 miles from Tanana. With an average barge speed on the river of 10.0 miles per hour, 1 hour of travel time would be required for each leg of a one-way trip. One barge would be at the harvest area being loaded while the other barge is enroute to Tanana or is being unloaded and then is enroute back to the harvest area. With a harvesting rate of 60 cords per day, 2 days would be needed to load a barge. This would require that the barge moving from the harvest area, 6. unloading, and returning to the harvest area also have a turnaround time of 2 days. For estimating purposes, the barge is assumed to have a three-man crew, which would also do the unloading and stacking in the storage area near the Power plant. The unloading and moving to the storage area is to be accomplished with a lasso- -type cableway. If an individual piece of wood weighs 80 pounds, there will be 50 pieces per cord and 6,000 pieces per barge load; and if one log is unloaded every 8 seconds, 450 can be unloaded in 1 hour. This should require 13 hours for unloading at Tanana. Stacking is to be accomplished with a farm-type tractor-yarder, which would also be used to move the wood to the shredder at the furnace. Transportation of the workers from Tanana is to be accomplished by the river barge; no other special transportation is Projected. Harvest workers would be housed at the harvest area. Storage The wood is to be placed in Storage by the three-man barge crew in an open area adjacent to the plant. The wood is to dry while in storage. The storage area required for the steam alternative is 250' x 500' and for the wood gas alternative 200' x 350'. Processing Processing is defined here as chipping the logs before they are introduced into the furnace. This work is to be a Part of the operation of the plant and will be a year-round effort. Estimated Costs a. Estimated Investment Cost for Equipment 0 20,000-foot lasso cable system $100,000 Oo Farm tractor with grapple-skidder $ 30,000 0 Farm-type tractor-yarder $ 30,000 © Two 240-ton barges (26' x 100' x 7') $200,000 Oo Tow boat $ 70,000 ~ b. © 4,000-foot lasso cable system at Tanana $ 20,000 0 Camp facilities for harvest workers $100,000 0 Miscellaneous tools and equipment $ 10,000 Subtotal / $560,000 Contingencies at 20% $112,000 Total $672,000 Annual Costs for Harvesting 5,150 Cords Oo Labor - Harvesting crew (11 men for 115 days at 8 hours per day = 10,120 man-hours at $20 per hour) = $202,400 - Barge crew (three men for 115 days at 9 hours per day = 3,100 man-hours at $21 per hour = $ 65,300 Total annual labor costs = $267,700 © The cost per acre for the right to harvest the trees is assumed to be $10 per cord, for an annual cost of $51,500 for the first year of harvesting. © Miscellaneous annual costs (fuel, parts, special Maintenance, etc.) = $50,000 0 Subsistence for workers ($100 per week per worker, $100 x 14 x 23) $32,000 o A summary of costs indicates that the total investment cost is $672,000 and that first-year annual costs are $400,500. c. Annual Costs for Harvesting 2,440 Cords Oo Labor - Harvesting crew (11 men for: 60 days at 8 hours per day = 5,280 man-hours at $20 per hour) = $105,600 - Barge crew (three men for 60 days at 9 hours per day = 1,620 man-hours at $21 per hour = $ 34,100 Total annual labor costs = $139,700 © The cost per cord for the right to harvest the trees is assumed to be $10 per cord, for an annual cost of $24,400 for the first year. oO Miscellaneous annual costs (fuel, parts, special maintenance, etc.) = $ 40,000 oO Subsistence for workers ($100 per week per worker, $100 x 14 x 12) = $ 16,800 o A summary of costs indicates that the total investment cost is $672,000 and that first-year annual costs are $220,900. 7. Economic Analysis An economic analysis of the wood fuel system is shown in Tables K-a _and K-b. The capital costs are for the initial investment, and the first year is assumed to be 1981. Harvesting of wood begins during the third year for the fourth year of operation. Wood requirements are projected to be 2.3 cords per 1,000 kWH for the steam plant and 1.1 cords per 1,000 kWH for the gas plant. In 1981, with a power demand of 2,250,000 kWH, the wood requirement is about 5,150 and 2,440 cords for the wood gas alternative. (This assumes that only 5% of the energy demand will be supplied by the standby diesel unit.) The wood requirements increase 3% per year, as do the energy requirements. The Operation and maintenance costs in the table are projected to increase 3% as the use of wood increases. Inflation in assumed to be 0, and the discount rate is assumed to be 3%. The table shows the P.W. cost for the wood fuel needs for the 20-year period to be $7,226,000 for the steam plant and $4,274,000 for the gas plant. TABLE K-a ECONOMIC ANALYSIS WOOD HARVESTING, TRANSPORTATION AND PLACEMENT INTO STORAGE (For Steam Alternative) Amount Harvested. Costs in $1,000 P.W. of Costs in $1,000 Annually PW. Total P.W. Year In Cords Capital Annual Factor Capital Annual _ Costs ‘in $1,000 ] 0 172 0 -97087, 118 0 167 2 0 500 0 -94260 471 0 471 3 5,150 0 400 -91514 0 366 : 366 4 5,310 0 412 -88849 0 366 366 5 5,470 0 424 -86261 0 366 366 6 5,630 0 437 -83748 0 366 366 7 5,800 0 451 -81309 0 366 366 8 5,970 0 464 78941 0 366 366 9 6,150 0 478 -76642 0 366 366 10 6,320 0 492 -74409 0 366 366 1 6,520 0 507 +72242 0 366 366 12 6,720 0 522 -70138 0 366 366 13 6,910 0 537 -68095 0 366 ; 366 147,120 0 555 -66112 0 366 366 15 7,330 0 572 -64186 0 366 366 16 7,550 0) 589 -62317 0 366 366 7 7,780 0 607 -60502 0 366 366 18 8,110 0 626 58739 0 366 366 19 8,250 0 645 -57029 0 366 366 20 8,500 0 661 - 55368 0 366 366 TOTAL 120,600 Cords TOTAL PRESENT i aie eat WORTH OF ANNUAL COSTS = $7,226,000 an TABLE K=b ECONOMIC ANALYSIS WOOD HARVESTING, TRANSPORTATION AND PLACEMENT INTO STORAGE (For Gas Alternative) Amount Harvested Costs in $1,000. . P.W. of Costs in $1,000 Annually . PW. Total P.W. Year__In Cords Capital Annual Factor Capital Annual Costs _in $1,000 1 0 172 0 -97087 58 0 167 2 0 500 0 -94260 471 0 471 3 2,440 0) 221 91514 0 202 202 4 2,510 0 227 -88849 0 202 202 5 2,580 0 234 -86261 0 202 202 6 2,660 0 241 -83748 0 202 202 7 2,740 0 248 -81309 0 202 202 8 2,820 0) 256 78941 0 202 202 9 2,910 0 264 + 76642 0 202 202 10 3,000 0 272 -74409 0 202 202 | 3,190 0 280 «72242 0 202 202 12 3,180 0 289 -70138 0 202 202 13 3,280 0 297 -68095 0 202 202 14 3,380 0 306 -66112 0 202.—. 202 15 3,480 0 315 64186 0 202 202 16 3,580 0 325 -62317 0 202 202 7 3,700 0 335 -60502 0 202 - 202 18 3,810 0 345 - 58739 0 202 202 19 3,920 0 355 -57029 0 202 202 20 4,030 0 365 55368 0 202 202 TOTAL 54,210 Cords TOTAL PRESENT ——______ WORTH OF ANNUAL COSTS = $4,274,000 — K-b APPENDIX L ENVIRONMENTAL ELEMENTS The purpose of this appendix is to detail the environmental elements associated with alternative electrical genération sources for the community of Tanana, Alaska. The following specific alternatives are described: ° Wood gasification Wood-fired steam Coal-fired steam ° ° ENVIRONMENTAL ELEMENTS Tanana Reconnaissance Study of Energy Requirements and Alternatives submitted to Marks Engineering/Brown & Root, Inc. Prepared by Environmental Services Limited 835 West Ninth Avenue Anchorage, Alaska 99501 L-2. Wood Gasification Environmental Impacts two discrete Parts: operation of a wood gasifier in Tanana and local harvest activities to supply the gasifier with fuel. Wood Gasifier Operation: Environmental products of the gasifier are Noise, ash, liquid waste and stack emissions. The potential volumes of these Products are estimated as follows: Tanana Projected fuel demand: 40 billion BTU per year Wood fuel requirement: 4 x 10?° BTU/yr 1.4 x 10” BTU/cord 2,857 cords/yr, or 365,714 ft?/yr, or 5,714 dry tons/yr of wood. Ash volume: (5,714 tons) x (5% ash content) = 285.7 tons/yr of wood ash. Water byproduct volume: (5,714 tons) x (103 reaction water content) = 574 tons/yr of water. Noise and stack gas emissions would Probably be similar to a diesel or natural gas-fired generator of comparable power output, and thus would be below the emission applicability limits of federal and state regula- tions. They are deemed to have no significant impact. The water byproduct of wood gasifier operation is removed from the reaction zone and thus may contain the organic chemicals characteristic of the destructive distil- lation of wood; such compounds are often carcinogenic. L-3 For the purposes of this assessment it is assumed that this product water will be evaporated in situ and the resulting solids destroyed by cycling through the reac- tion chamber. If this water was discharged into the environment it might constitute a significant health ha- zard. chemical danger, and might be put to environmentally benign uses such as road surfacing or Sanitary landfill. It would have no significant impact on the environment of Tanana. Specific assessment of environmental impacts of Possible wood gasifier power generation operations in Tanana: i Air Quality: no Significant impacts L Water Quality: no Significant impacts if no ash is disposed of near an active drainage into a stream or Noise: no significant impacts Fish and Wildlife: no significant impacts 7 Land Use: significant amounts of ash are produced and land disposal planning is indicated Terrestrial Impacts: none Wood Harvest Operations Environmental assessment of potential wood harvest operations to fuel a wood gasification or wood-fired gen- eration system must take into account various sets> of Parameters. An inventory and evaluation of the tree re- densities and wood volumes available for harvest, and the physical and ecological character of Potential harvest lands. This Process generally indicates areas inappro- Priate or sensitive to harvest activity, total biofuel Quan- tities, and would Provide a basis for selecting harvest methods. With this information and knowledge of energy requirements in Tanana, an assessment of the potential scale and environmental impacts of a Sustained biofuel Supply program might be made. Criteria for selection of potential harvest lands: Proximity to streams and wetlands Topography and soil characteristics Erosion and vegetative damage potential Tree species and density Wildlife use Presence of critical habitats and/or endangered species Ownership of lands Historical/archaeological potential An examination of aerial photographs of the Tanana region (see Figure 1).will indicate that the greatest wood volumes occur in the margins and islands of the Yukon River. These are typically dense white spruce stands, with smaller amounts of birch, poplar, aspen and willow. Such lands are usually poorly drained and occasionally flooded, and are interfingered with bogs, wetlands and sloughs. Substantial wood volumes are also located on the hills and highlands above the Yukon. These trees are mostly white spruce or white spruce/birch complexes, and the stands are usually much less dense than those along the river or on islands. The highlands often have thin soils and are subject to erosion problems. The Tozitna River is the only stream in the Tanana area which bears a significant population of salmon. However, most of the smaller rivers and creeks have small populations of grayling, whitefish, and other aqua- tic life. Since logging activities on the slopes above creek drainages might cause runoff/silting problems in these streams, tree stands on these slopes are excluded from possible harvest inventory (see Figure 2). The bogs, lowlands and wetlands on islands and river mar- gins are unsuitable for vehicle traffic in the summer and are very susceptible to vegetative and soil damage; the white and black spruce in these areas are also excluded from harvest activity consideration (Figure 2). Except for the salmon spawning beds in the Tozitna, the Tanana area is free of critical or unique wildlife hab- itat. A variety of subarctic mammals and birds live in the study area, but no known endangered or protected species are present. The closest such inhabitation is a suspected peregrine falcon nesting site about eighteen miles up the Yukon from Tanana. Moose and bear are the only big game species present; the moose browse throughout the area, but mostly on the brush along the river, according to residents. The moose population is heavily predated upon by the villagers and to a lesser extent by bears and wolves. Tree harvesting activities should improve moose habitat by increasing the supply of small trees and bushes. In fact, the ADFG strongly supports this tree harvest concept because of the possi- L-5 ble benefits to the Tanana moose herd. The bear population, both grizzly and black, is concentrated along the Tozitna and other streams, another reason for avoid- ing harvest activities in these areas. Many other small mammal species inhabit the Tanana vicinity, and many of these (rabbit, fox, lynx, weasel, muskrat, etc.) are trapped by the villagers. Disruption of trapping grounds by tree harvest is a real concern of the com- munity. Prudent cutting activities, especially in white spruce stands, should actually improve the populations of furbearers such as weasel and pine marten; the har- vest produces brush, creating cover and forage for the microtene rodents which are the main food supply of these small predators. Cutting the birch/spruce stands on the slopes above the town might also boost local rabbit stocks, the principal prey of foxes and lynx. On a whole, tree harvesting with reasonable forestry and management practices should actually have a Positive benefit to local animal populations. The land in and around Tanana has mostly been selected for ownership by the village corporation, Tozitna, Ltd.; a small number of tracts along the river and in the village proper are designated as "individual" native selections. Areas outside the corporation lands are managed by BLM and Doyon, Ltd. Individual selec- tion lands, BLM lands, and the village proper have been removed from consideration as potential harvest areas (Figure 3). Tanana is a natural trading and subsistence site, as it is located at the confluence of the Yukon and Tanana Rivers; it has probably been at least intermittently in- habited for several thousand years and has been the site of a permanent Indian trading community for several hundred. American trading and missionary activities took place at several locations in and near Tanana begin- ning a hundred years ago, and the U.S. Army operated Fort Gibbon in Tanana from 1900 to 1923. The sites of some of these activities (such as Mission Hill) are well known, but many historic and pre-European sites have not been located. These unknown sites and the high Prehistoric/archaeological possibilities of the region indi- cate that field surveys of proposed harvest areas are in order before they are significantly disturbed. The people of the village have indicated that they consider these surveys very important. Areas with obvious high historic site potential, such as along streams or near Tanana village proper, have been eliminated from harvest land consideration (excluded in Figure 2 and 3). L-6 With the removal of sparsely forested areas from those lands which were not Previously eliminated from tree harvest consideration (Figures 2 and 3), there are several thousand acres of forested lands which could be cut (see Figure 4). These are two zones: upland birch/white spruce stands and river and island margin white spruce/poplar groves. The upland trees are relatively open in nature and are in scattered locations across the hills. Though no Surveys have been made in this area, similar stands in Swamp Island, twelve miles downstream from Tanana, in- dicated that Sapling, pole and timber sized trees on these plots had a total volume of over 7,000 ft? per acre. Such dense tree stands occurring in large plots cover more than twenty-three hundred acres of Tozitna, Ltd. corporate lands (Figure 4). The acreage extent of tree harvest each year is a function of the fuel energy demand of Tanana and the fuel energy available per acre. Tanana has a Present rough fuel input energy of about thirty-five billion BTU per year for electrical power generation; forty billion will be the demand figure used here for the next twenty years of power generation input. (Actual Projections of Interior Alaska electrical demand growth rates are little better than a guess. If large-scale conversion from fuel oil home heating to wood stove or wood-fired electric heating takes place, then this fuel energy input demand will climb greatly.) The energy available for power gen- eration from each acre harvested is dependent not only on the volume of wood Present, but the tree species cut wood moisture in the combustion chamber). At twelve Percent moisture content, white spruce contains about sixteen million BTU Per cord (128 ft? of solid wood), Poplar about fourteen million BTU/cord, alder seventeen million, and birch up to twenty million. However, the L-7 Birch/white spruce uplands: 2500 ft? x 1 cord x 1.4 x210" BTU = acre 128 ft? cord 2.7 x 10*°BTU/acre 4x 10?*BTU/yr_ = 148 acres/yr to satisfy 2.7 x 10°BTU/acre energy demand 2.7 x 10*BTU/acre x 12,500acres = 3.37 x 10??BTU, total energy stock or an 84-year energy supply River margin and island spruce/poplar stands: 7000 ft? x 1 cord x 1.4 x 10’BTU = acre 128 ft? cord 7.65 x 10*BTU/acre 4 x 10?°BTU/yr = 52 acres/yr to satisfy 7.65 x 10*BTU/acre energy demand 7.65 x 10°BTU/acre x 2,300 acres = 1.75 x 10??BTU total energy stock or a 44-year supply Total potential standing wood energy stock: 5.12 X 1032BTU ora 128-year supply at a4 x 10°°BTU yearly fuel energy input rate. L-8 It is now possible to estimate more clearly what potential harvest activities in Tanana might take place, and the harvest terrain, scale, and resultant environ- mental impacts of those activities. It might be noted that the simplified McHargian analysis of the Tanana region (presented graphically in Figure 1-4) is a very broad-brush approach. ft might very well eliminate Many stands of timber Perfectly acceptable for harvest operations, if the cautionary criteria for rejecting those lands are carefully addressed. For example, a harvest on Mission Hill or on the middle of Tanana Island might be acceptable if detailed on-site analyses of archaeologi- cal potential or erosion/vegetation disruption potentials are made before operations commence. The McHargian Process is simply a conservative and cautionary practice for accessing any given use of an area's resources. Tanana would potentially harvest between 50 and 150 acres per year of timbered lands to satisfy an elec- trical energy demand some ten Percent to fifteen percent above today's two million KWH/yr. The actual amount of acreage would depend on the sites or mix of sites har- vested. Each of the two basic types of harvest areas - “uplands” and "riverlands" - have particular and specific Problems associated with harvest activities on them. The tree stands on uplands are scattered and rather open, and so large acreages must be harvested each year (150*) to satisfy Tanana's energy requirements. Since nearly any sized tree might be used for fuel, clearcut- ting would be the most efficient use of each acre. Accepted forestry practice for interior Alaska dictates that clearcutting should be limited to ten to fifteen con- tigious acres at a time: "patch cutting". This has been found to minimize soil and vegetation damage and stimu- late natural regrowth activity. This implies at least ten active "patch" harvest sites in any year of operation, and thus a Scattering of cutting activities over a consi- derable area. Road transport of cut wood is very con- venient and economical, if the roads are in existence al- ready. Cutting and building roads through the hills above Tanana would be an environmental issue of some scale, given the erosion and soil instability potential of hilly lands in Interior Alaska. Roads would probably be necessary for any type of summer harvest activities, as the collection of over 7,000 (green) tons/yr. would have to be a fairly mechanized operation - winches, yarders, tractors, and trucks might all be necessary to harvest this extensively from such open forest lands. However, L-9 it might be possible to conduct some of these harvest operations in the winter; by using sleds and snow-tracks to transport wood and equipment, the soil and vegetation disruption of vehicle operation and roadbuilding might be avoided. Though this option might minimize environ- mental damage, the efficiency of men and equipment in cold weather and the safety of harvest equipment opera- tion on snowy hillsides might make it unfeasible. Ano- ther issue unaddressed in hillside harvest operations is the visual effect on Tanana. Given the low, rolling nature of these uplands, extensive harvest cuts would Probably be extremely visable and would probably de- stroy the viewshed of the village. Harvest of the timber along the river and islands has several advantages over upland harvests. These tree stands are in much less environmentally and cultur- ally sensitive areas, and they are much denser; three or four "patch" harvest sites per year might yield enough wood. Access to these harvest sites is provided by the Yukon, though landing equipment and transporting wood might be akward in the summer. Though the river lands outlined in Figure 4 are comparatively drier than the bogs and sloughs surrounding them, these spruce stands could be wet enough to pose significant vehicle operation problems in the summer; construction of roads or tractor trails between harvest sites might be very difficult. A winter harvest in these areas would allow direct sur- face travel across the Yukon ice and direct access over swamps, sloughs, and wetlands without soil or vegetation damage. Sleds might carry harvested cordwood or wood chips directly back to Tanana. This problem of summer vehicle operation is not the only difficulty of the river margin harvest program. Of concern is the necessity for leaving adequate timber margins along riverbanks and island edges, as these lands often disappear ‘the next spring after deforestation. Another significant question is the management of lands after tree harvest. These dense spruce stands on river bottoms are typically 70 to 150 years old. Ona superficial analysis, if Tanana harvested these stands and let them regenerate natural- ly, they would have a twenty-five year wait for mature timber after they cut the last of their forty-four year Present inventory. White spruce grows very quickly after it is established, but it does very poorly in coloni- zing recently cleared ground (alder and poplar crowd it out). An option is to trim the deciduous brush and pro- tect spruce seedlings, or to shift the vegetative pattern to another primary species such as alder or poplar. These grow more quickly than spruce and easily regener- ate from cut stumps. Such Practices would substantially reduce regrowth times and limit the necessity of cutting more and more virgin timberlands. The need for de- veloping a sustained-yield harvest Program on Tanana L-10 10 lands could become very important if electrical power demands climb above the Projected level used here and if the substitution of wood for home heating oil becomes significant. The drain on timber resources might be somewhat offset by efficient collection of driftwood from the Yukon, a supply not addressed in this wood re- source assessment. Specific assessment of environmental impacts of possible wood harvest activities to fuel Tanana power operations: 7 Air Quality: no significant impacts beyond possible small dust problems on hillside roads Water Quality: no significant impacts if Prudent forestry practices are observed to limit runoff/silt- ing into streams from slopes below harvest areas Noise: no significant impacts beyond temporary avoidance by wildlife of areas near active harvest operations ° Fish and Wildlife: no significant negative impacts if silting is prevented in nearby streams, and poten- tial positive benefits might occur to moose and small mammal populations by improvement of habitat ° Land Use: significant land planning must occur to ensure access, minimize territorial damage, and maximize regrowth and health of available timber stocks on potential harvest lands Terrestrial Impacts: significant short-term impacts of vehicle use and change in vegetation on harvest lands; possible permanent impacts caused by road construction and erosion; possible significant change in viewsheds L-11 Wood-fired Steam Environmental Impacts Environmental assessment of a wood-fired power system is reasonably broken down into two separate areas: operation of the power plant in the Village and the wood harvest activities that would supply it. Since the character of wood fuel for this option is not significantly different than that for wood gasifica- tion, the wood harvest assessment for this potential wood-fired power system is the same as given under Wood Harvest Operations in the Environmental Impacts of this section of alternative (2), Wood Gasification. Wood-fired Powerplant Operation: Environmental products of &@ wood-fired powerplant are noise, ash, and stack emissions. Ash volume is the only one of these Products that can be easily estimated. Standard wood-fired boilers do not utilize the reaction systems that allow a wood-gasifier to reduce wood to five Percent of its original weight. For the purposes of this discussion, it is assumed that such standard combustion technology (as opposed to a fluidized bed system, for example) will be utilized and will Produce about an eight Percent ash product. Tanana Projected fuel demand: 80 billion BTU per yéar Wood fuel requirement: 8 x _10?* BTU/yr = 1.4 x 10” BTU/cord 5,714 cords/yr, or 731,428 {t?/yr, or 11,428 dry tons/yr of wood. Ash volume: (11,428 tons) x (8% ash product) 914.2 tons of wood ash/yr. The majority of this wood ash is made up of sili- cates (from entrapped dirt) and carbon Particles. It also contains the salt products of sodium, potassium, and ammonium with phosphates, nitrates, and sulfates. In high concentrations these wood salts can Produce alkaline leechates. Surface disposal of this ash should bear no L-12 12 environmental hazard if no large ash concentrations are placed on an active drainage into a nearby stream. Otherwise, this ash could be safely utilized in Sanitary landfill, road surfacing, and as a soil conditioner/fertili- zer. The production of noise and gaseous stack emissions are similar to a diesel or natural gas-fueled generator/ boiler of similar size and output, and are not deemed to be significant. However, the potential stack particulate emission levels are unknown. These emissions must not exceed 0.15 grains per cubic foot of effluent or reduce the visibility through the exhaust by more than twenty Percent, according to Alaska State Air Quality statutes. It is predicted that these Particulate levels will not be exceeded and that no emission control devices will be necessary. : . : Specific assessment of possible wood-fired power generation operations in Tanana: ° Air Quality: no significant impacts, but control equipment for particulates might be necessary Water Quality: no significant impacts Noise: no significant impacts Fish and Wildlife: no significant impacts Land Use: significant amounts of wood ash are produced and land disposal planning is indicated Terrestrial Impacts: none L-13 3. 13 Coal-fired Steam Environmental Impacts The critical element for assessing the ‘potential environmental impacts of coal-fired power generation in Tanana is the source of the coal. The half-dozen-odd potential sources of coal for Tanana very greatly in such important properties as sulfur, ash, and BTU content. Thus the source could directly necessitate the application of specific regulatory standards and control equipment. For the purposes of this discussion, it is assumed that coal from the Usibelli mine at Healy will be the only source; the properties of this coal are very well known. It must be strongly emphasized that if other coal sources are used the volumes of coal and coal waste products could be substantially different than those given below. Tanana projected fuel demand: 80 billion BTU per year. Coal fuel requirement: 8 x 103° BTU/yr = 1.6 x 107 BTU/ton 5,000 tons of coal per year. Ash volume: (5,000 tons) x (6%) = 300 tons per year of coal ash. Emissions: Usibelli coal sulfur content: 0.2% SO? emission volume: (5,000 tons) x (0.2% sulfur content) 5 tons per year of sulfur content. 10 tons sulfur = 20 tons of SO? after combustion 20 tons per year of SO? emissions. L-14 14 Particulate emission volume (pounds): 200 (ash content) x (tons burned) 200 (0.06) x (5,000) = 60,000 Ibs. or 30 tons Per year of Particulate emissions. Nitrous oxides emission volume (pounds): 6 (tons of coal burned) = 6 x (5,000) = 30,000 Ibs. or 15 tons of NOx emissions per year. Noise production of this Power system is deemed to be not significant. Coal ash contains dirt (silicates and other minerals), carbon, and varying quantities of nitrates, carbonates, and sulfates. Leechates from coal ash are typically acid Products (HNO?, H?SO*, etc.) and are Potentially hazar- dous. The disposal of this ash must take this acid drainage into account, and must specifically avoid the special potential for damage to aquatic life it presents. Alaska State solid waste management specialists have in- dicated that use of this coal ash as Sanitary landfill would probably be environmentally safe. It is recom- mended that a study of leechate Product effects on As this Proposed coal-fired Power plant would consume much less than the 250 million BTU/hr. fuel in- put applicability limit set for the Federal Air Quality Act's Prevention of Significant Deterioration (PSD) stand- ards, these would not apply to the proposed Power sys- tem. However, the installation of a new coal-fired power sion level of 250 tons per year (each) for SOx, NOx, CO, and particulate Pollutants. Since these levels are far above the Projected emissions for this power facility, and since the stack gas levels for SO? should be well under the 500 ppm federal standard, none of the above The Alaska State Statutes governing air quality (18 AAC 50.020, .050) also use the SO? 500 ppm stand- ard for “industrial processes and fuel burning equip- ment." Particulate emissions are restricted to 0.1 grains L-15 w equipment (for SOx, NOx, etc.) will be necessary, and that particulate emission control might not be necessary. Specific assessment of environmental impacts of a coal-fired power plant in Tanana: ° Air Quality: with appropriate emission control measures, no significant impact ° Water Quality: with Proper land disposal of coal ash, no significant impacts Noise: no significant impacts 7 Fish and Wildlife: if ash is prevented from leeching or washing into streams, no significant impacts 7 _ land Use: significant amounts of coal ash would be fully; land disposal Planning is indicated Terrestrial Impacts: none L-16 FIGURE 1: Aerial View of Tanana Region 1) 2) 3) 4) 5) 6) 7) 8) AREAS OR ISSUES MERITING SPECIAL ATTENTION, CAUTION, OR FURTHER RESEARCH: Accurate, on-site assessments of timber volumes on hillsides and on river margins. Air photo examination and representa- tive timber volume estimates from other regions are not suffi- cient for decent standing wood volume assessments and realis- tic planning Programs. Assessment of soil character and road construction suitability Properties of the hilly lands above Tanana. Erosion and water quality impact Potentials are little better than guesses without this data; much timber might be unnecessarily ex- cluded. Archaeological site surveys must be made in detail before any large-scale disruption or change in character is undertaken for any lands in the Tanana region. This is an important issue for the Tanana villagers. Assessment of the short and long term effects of tree harvest on the trapping activities of each area cut. Local trappers are very concerned about this. The particulate emission of a wood-fired power plant should be assessed. The potential for ground and surface water contamination by land disposal of coal ash should be studied. The particulate emission levels of a coal-fired power plant should be Carefully assessed. L-17 17 FIGURE II: Areas not Suitable for Tree Harvest: Wetlands, Streams, and Adjacent Slopes L-18 18 FIGURE III: Land Ownership in the Tanana Region L-19 WwW FIGURE IV: Lands Suitable for Harvest Upland White Spruce/Birch Stands: River and Island Spruce/Poplar Stands: L-20 Reus HR 20 REFERENCES Alaska State Legislature. Environmental Conservation Statutes. July, 1972. Environmental Protection Agency. Ambient monitoring quidelines for the prevention of Significant deterioration (PSD). QAQPS No. Environmental Protection Agency. Compilation of Air Pollution Emission Factors. Publication No. AP-42. EPA 1975, Environmental Services, Ltd. Environmental assessment report for the proposed Nulato wood-energy Project. August, 1980. Farr, Wilbur A. 1967. Growth and yield of well-stocked white spruce stands in Alaska. USDA, USFS Research Paper PNW-53. - 30 pp. Galliet, Harold H., Joe A. Marks, and Dan Renshaw. 1980. Wood to gas to power: a feasibility report on conversion of village Gregory, Robert A., and Paul M. Haack. 1965. Growth and yield of well-stocked aspen and birch stands in Alaska. USDA, USFS, Research paper NOR-2. 28 Pp. Hartman, Charles W., and Philip R. Johnson. 1978. Environmental Atlas of Alaska. University of Alaska. 95 pp. Klinkhart, Edward G. 1978. Alaska's Wildlife and Habitat, Vol. 11. ADFE&G. Leckie, Jim, Gil Masters, Harry Whitehouse, Lily Young. 1975. Other Homes and Garbage. Sierra Club Books. S.F. 302 Pp. McLean, Robert F., and Kevin J. Delaney. 1978. Alaska's Fisheries Atlas, Vols. | and Il. ADFéG. Portola Institute. 1974. Energy Primer: Solar, Wind, and Bio- fuels. 200 pp. : Reiger, Samuel, Dale B. Shoephorster, and Carence E. Furbush. 1979. Exploratory soil survey of Alaska. USDA, SCS. 213 pp. Renshaw, Dan. 1979. Coal and wood resources examinaton - mid- Yukon. AVEC and APA. 16 pp. Seifert, Richard, and John Zarling. 1978. Solar Energy Resource Potential in Alaska. Institute of Water Resources. University of Alaska. 80 pp. . L-21 Van Cleve, Keith. 1973. Energy and biomass relationships in alder ecosystems developing on the Tanana River floodplain. Arctic and Alpine Research Vol. 5, No. 3. 7 Pp. Viereck, Leslie A., and Elbert L. Little Jr. 1972. Alaska Trees and Shrubs. USDA, USFS, Agric. Handbook No. 410. 265 Pp. L-22 Person Contacted eon tontacted Dennis Ward Jim Venard Dave Rosenau Jack Utton Dean Argyle Ann Guthrie Jim Sweeny Steve Shwab Harry Reynolds Jim LaBau Coghill Fuel Co. Dave Bray Dale Haggstrom Fred Anderson Mike Johnson Paul Boise A.L. Renshaw CONTACT LIST Tanana EA-500-239 Agency ADEC USFS LGL Tanana Chiefs Inst. Northern Forests Tanana City Hall EPA Tanana City Gov't. ADFG USFS EPA ADFG ADFG EPA EPA Mining Engineer L-23 Phone # 907-452-1714 907-276-0939 907-479-6519 907-452-8251 907-479-441] 907-366-7160 907-274-2533 907-366-7159 907-452-1531 907-272-5502 907-832-5476 206-442-1226 907-452-1531 907-452-1531 206-442-7176 206-442-1106 206-344-1814 ENERGY AND TREE GROWTH The potential for intensive cultivation of trees as an energy stock for community powerplants is dependent on the species used, climate, soils, and scale of operation. An energy or biomass plantation acts as a storage device for solar energy. The energy capture by photosyn- thesis is transformed into the tissues of a tree (wood, leaves, roots) and also powers the plant's metabolism. This capture efficiency rarely exceeds one percent of sunlight energy falling during the growing sea- son, and often does not approach that level. In practical terms, the effective capture rate for fuel biomass is even less, given that the leaves and roots are not utilized and they often take a substantial por- tion of the plant's energy; this is especially true of young plants. It has been found that trees such as alder, willow, and poplar increase the efficiency of energy capture with age, and that after five years of growth very little energy goes into the development of roots and leaves. The root system is established, and the same amount of leaves serves the tree adequately from five years onward; most of the incoming energy goes to metabolism and bole and stem growth. So, a stand of trees becomes a considerably more efficient fuel biomass collec- tor after its first five years. That is why it is extremely beneficial to use a tree species which will regenerate from a cut stump ("coppicing"), so utilizing the fully developed root system and avoiding expensive re- planting. The growing season for interior Alaska is roughly three months long, and a great deal of the year's total insolation takes place in these months. Areas with a climate and latitude similar to Fairbanks receive about 88,000 langleys per year, or an average of 890 BTU/ft? per day. With an eighty-five day growing season, 2 x 10? kilocalories/hectare of solar energy is available for plant assimilation per year in interior for- ests. A twenty year old alder stand in this region can typically con- vert 0.98% of this insolation (or about 20 million kilocalories/hectare) to biomass in the three month season. In physical terms, this represents the fixture of 2,000 kg/hectare/year of bole and stem biomass or 69 million BTU/acre/year of potential wood energy. This correlates exactly with the experience of silvaculturists in the Northwestern states that typically yield about a ton a year per acre of closely planted deciduous trees. Hybrid trees will shorten the natural growth period of such stands, and fix twenty tons Per acre of solid wood in eight to ten years instead of the twenty it usually requires. They will often re- generate from cut stumps, especially hybrid poplars. The use of such hybrids as an energy stock in interior Alaska is open to question. The soils in this area are often Poor, even in riverbottoms. The tremen- dous growth rate of these trees takes a great toll on soil nutrients, especially nitrogen. Extraction of the plant mass for burning elsewhere creates a nitrogen sink that would be very hard to alleviate. Northern soils are especially nitrogen poor to begin with; and natural. mechanisms L-24 24 for soil nitrogen replacement are very slow. The economics of importing nitrogen fertilizers for large acreages is very dubious. The response of hybrid species to interior Alaskan climate, soils, pests, and diseases is unknown. The topic deserves a great deal of research. L-25 25 REFERENCES Ek, Alan R., and David H. Dawson. 1976. Actual and projected growth and yields of Populus “"Tristis #1" under intensive culture. Can. J. For. Res. 6:132-144. Farr, Wilbur A. 1967. Growth and yield of well-stocked white spruce stands in Alaska. USDA, USFS Research Paper PNW-53. 30 pp. Gordon, John C. 1975. The productive Potential of woody plants. lowa State J. Res. Part 2, 49(3):267-274. Gregory, Robert A., and Paul M. Haack. 1965. Growth and yield of well-stocked aspen and birch stands in Alaska. USDA, USFS, Heihman, P.E., D.V. Peabody, Jr., D.S. DeBell, and R.F. Strand. 1972. A test of close-spaced short-rotation culture of black cottonwood. Can. J. For. Res. 2:456-459. Mitre Corporation. 1977. Silvicultural biomass farms. MITRE Tech. Rep. 7347, Vol. 1-6. Rose, D.W. 1977. Cost of Producing energy from wood in intensive cultures. J, Environ. Manage. 5:23-35. Seifert, Richard, and John Zarling. 1978. Solar Energy Resource Potential in Alaska. Institute of Water Resources. University of Alaska. 80 pp. Sezego, George C., and Clinton C. Kemp. 1974. The energy plantation. For. Prod. Res. Soc. FPRS Sep. CC-74-550, 15 Pp. Van Cleve, Keith. 1973. Energy and biomass relationships in alder ecosystems developing on the Tanana River floodplain. Arctic and Alpine Research Vol. 5, No. 3. 7 pp. Viereck, Leslie A., and Elbert L. Little Jr. 1972. Alaska Trees and Shrubs. USDA, USFS, Agric. Handbook No. 410. 265 pp. L-26 APPENDIX M COMMENTS BY REVIEW AGENCIES EH NTE Preliminary draft copies of this report were sent to various review agencies for their comments. The review agencies' letters are part of this appendix. The responses by Marks Engineering and Brown & Root to the review agency comments are as follows. Department of Energy Alaska Power Administration Juneau, Alaska The preliminary draft reviewed by “the Department of Energy (DOE) recommended further study of existing diesels, along with coal-fired steam and hydroelectric generation. This is brought out in the DOE comments. This final report does not include coal-fired steam for further study. The DOE comments also stated reservations about the economic feasibility of the hydropower plan recommended. We share the DOE's concern. Further studies must be made before any firm commitments are made by the Power Authority. The DOE likewise had reservations about the viability of a small coal-fired steam plant. We recognize the many disadvantages of such a facility (as pointed out in this report) and do not recommend coal-fired steam as an alternative worthy of further study. Department of The Army Alaska District, Corp of Engineers Anchorage, Alaska a. e. Repetitious Tendency We have eliminated repetitions where we judged them to be unnecessary. Tables, Graphics, and Figures More tables, graphs, and figures have been added to Appendix D to illustrate important facts. Diesel Efficiencies Diesel efficiencies in Appendix D are explained differently. Transmission Line Efficiency The statement regarding transmission line efficiency has -been changed on sheet D-32. Hydropower Evaluation Different designs have been presented. The design in this report projects a higher head than that cited in the OTT Water Study. The reservoir capacity and dam quantities were based on limited contour information, which must be refined in a feasibility study. The on-line dates have been changed from January 1, 1984, to January 1, 1985. The general terms of the economic analysis will have a major impact on the economic analysis. The stream flows in this report were projected from the only two points on flow-duration relationships shown in the OTT Water Study. Stream flows are an important part of the hydropower alternative and must be refined in a feasibility study. 3. U.S. Department of Commerce 2 epartment ot Commerce National Oceanic and Atmospheric Administration National Marine Fisheries Service Anchorage, Alaska The U.S. Department of Commerce had no comment. i rs ‘A. o DEPARTMENT OF THE ARMY ALASKA DISTRICT. CORPS OF ENGINEERS P.O. BOX 7002 ANCHORAGE, ALASKA 99510 REPLY TO ATTENTION OF: NPAEN-PL-R 19 MAR 1981 necélved iA22) 1981 Eric P. Yould, Executive Director Alaska Power Authority PLASKA Loeles AUIMORITY 333 West 4th Avenue, suite 31 Anchorage, Alaska 99501 Dear Mr.Yould: Thank you for the opportunity to review the Marks/Brown and Root Tanana Report. Generally the report comprehensively reports existing conditions and options at Tanana. | There is a slight repetitious tendency, so perhaps a bit more polishing and editing can be recommended. In general, reduced vertical tables are easier to read rather than the horizontal full page tables such as 3-1. A subjective nature permeated the text and reduced the impact of important facts. This could be avoided by using more tables, graphs, and figures, especially in Appendix D. Specifically, the reference to diesel efficiency between pages 3-2 and D-1 could be better explained; 10 kWh/gal and 33 percent, respectively. Similarly, the statement of efficiency for a 140 mile 69 kv transmission line on page D-32 could be tempered. Regarding hydropower evaluation, references are made to our Ott Water study. The figures presented in the two reports are not similar. Different designs are presented, making the Marks report appear more optimistic in terms of capacity, dam cost, and on-line date. The general terms of the economic analysis presented on page E-] may account for the differences. The Corps uses a 50-year hydropower life, a 7 3/8 percent discount rate, and assumes a 0, 2, and 5 percent fuel cost escalation rate, Also the stream flows presented by Marks are more conservative than those reported by Ott Water. No other areas of specific comment were located which would affect the report. M-4 en ty NPAEN-PL-R Eric P. Yould, Executive Director 19 MAR 1981 If we can be of further assistance, please contact Mr. Scott Shupe of the . Reports Section, at 752-3461. Sincerely, bebe ie Chief, Engineering Division M-5 Department Of Energy Alaska Power Administration P.O. Box 50 : Juneau, Alaska 99802 March 16, 1981] Mr. Eric Yould, Executive Director . pyaay Alaska Power Authority hoe dae 333 W. 4th Avenue - Suite 31 , Anchorage, AK 99501 Di ity Rae ten Peer tT Dear Mr. Yould: We have four draft reports on Alaska Power Authority studies for which you are asking comments on March 16: 1) " Reconnaissance Study of Alternatives for Akhiok, King Cove, Larsen Bay, Old Habor, Ouzinkie and Sand Point - CHoM Hill 2) Reconnaissance Study of Energy Requirements and Alternatives for Kaltag, Savoonga, White Mountain and Elim - Holden and Associates, 3) Reconnaissance Study of Energy Requirements and Alternatives for Togiak, Goodnews Bay, Scammon Bay and Grayling - Northern Technical Services and VanGulik & Associates 4) Tanana Reconnaissance Study of Energy Requirements and Alter- natives - Marks Engineering/Brown & Root Inc. I regret that we have only been able to make brief reviews of these reports, and therefore our comments are Perhaps less complete and thoughtful than we would like. The central finding is that there are very few apparent alternatives to continue use of diesel electric Power systems for the villages covered other energy uses in these villages. With this in mind, continual efforts towards maximizing efficiency in the diesel electric systems-- including waste heat application--as well as means to improve efficiency of energy use Probably amount to the priority areas for fucure work. I was quite surprised that the studies made little use of previous reports/investigations/experience for remote villages. Particularly on . the diesel systems, the data in the reports does not seem to recognize best current practice for remote communities in Alaska. Such things as fuel storage requirements and costs, matching size of machines to load in a manner that optimizes efficiency, and basic O&M requirements seem very weak, M-6 C The CHoM Hill report does not appear to make allowance for future escalation in fuel costs, hence the comparison between oil-fuel gener- ation and the alternatives may be very misleading. Some additional staff comments on the reports are enclosed. We appreciate the opportunity to comment. Sincerely, C vil _* Robert J. Cross < ¢ ‘Administrator Enclosure © \ 5 Comments on Tanana Reconnaissance Study of Energy Requirements and Alternatives, April 1981 by Marks Engineering/Brown and Root, Inc. The study recommends feasibility study evaluation of three electric energy sources which appear reasonable to us. They were: l. Existing diesels with use of waste heat. 2. Coal-fired steamplant generation using waste heat and local coal . 3. Hydroelectric generation. The study is well organized, concise, easy to understand, and appears to build on a base of existing studies. The appendix contains considerable useful support data and appears to adequately examine the topic. plan described and the viability of a small coal-fired steamplant depending on around-the-clock Operation and quite distant coal mine. We to Tanana. M-8 701 C St. Box 43 Anchorage, Alaska 99513 March 2, 1981 haewei¥ ed Mr. Eric P. Yould, Executive Director has 131984 Alaska Power Authority 333 West 4th Avenue, Suite 31 Dee Ve eeie euler PY Anchorage, Alaska. 99501 Dear Mr. Yould: We have reviewed the draft reports for the reconnaissance study of energy requirements and alternatives for the village of Tanana and for the villages of King Cove, Sand Point, Akhiok, Ouzinkie, Larsen Bay and Old Harbor. We have no comments to offer at this time. Si ely, ~ iA, {yh Ro’ a rkis ( Supervisor, Anthorage Field Office M-9 WN U.S. DEPART }NT OF COMMERCE National Ocexu...c and Atmospheric Administration Nattonal Marine Fisheries Service gl