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HomeMy WebLinkAboutBeluga Coal Fired Power Plant Project Feasibility Study 1-1985035 Alaska Energy Authority e. 2 LIBRARY COPY _ BELUGA COAL FIRED POWER PLANT PROJECT FEASIBILITY STUDY FOR DIAMOND ALASKA COAL COMPANY VOSS INTERNATIONAL CORPORATION JANUARY 1985 aN &, Gilbert /Commonweaith Gilbert/Commonwealith Inc. of Michigan engineers and consuitants FEASIBILITY STUDY OF THE BELUGA COAL-FIRED POWER PLANT PROJECT FOR DIAMOND ALASKA COAL COMPANY voss INTERNATIONAL CORPORATION ENGINEERING REPORT NO. R-2693 JANUARY 1985 Prepared By: Approved By: Gilbert/Commonwealth Inc. ; 209 East Washington Avenue Jackson, Michigan 49201 <R. Calvert, P.E. Vice President and General Manager ower & Industrial Systems Division CoA 0350 CZ. Chapter 1. 2. 3. Appendix A. TABLE OF CONTENTS Introduction Market Potential Design Concepts Costs and Cash Flow Cost of Product Conclusions Load Forecasts and Existing Generation of the Railbelt Utilities Conceptual Design Drawings Licensing Requirements Cost Estimating Details Detailed Development of Beluga Power Cost 456/A3523-1/D3 18 23 26 CHAPTER 1 INTRODUCTION Diamond Alaska Coal Company is in the process of developing a mine and associated infastructure in the Beluga Region of Southcentral Alaska. Initial production is expected to commence in 1989-90. The output of the mine will be carried by an overland conveyor system to a dedicated port facility on Cook Inlet, and there loaded on ocean-going vessels for export. It is estimated that the mine will require approximatley 40 MW of electric power when in full operation. Diamond Alaska and Voss International Corporation are interested in exploring the possibility of installing more generation than is needed at the mine, and offering the excess for purchase by the Railbelt Utili- ties. It is perceived that the parties to such a transaction may receive economic benefits from economy of scale by installing generating units of a size larger than might otherwise be appropriate, and using mine- mouth coal that involves a small expense for transportation to the place of consumption. Accordingly, Diamond Alaska and Voss have jointly engaged Gilbert/Common- wealth Inc. to explore the feasibility of such a venture, herein called the Beluga Coal-Fired Power Plant Project. SCOPE Specifically, this report addresses the feasibility of installing a coal- fired electric generating power plant rated at approximately 150 MW and located at the port facility associated with the Chuitna mine. It is estimated that the first such unit could be placed in service in the fall of 1990, assuming preparations to do so begin immediately. Pro- visions would be made to install a second such unit later when and if the need exists. Subsequent chapters of this report will address the following aspects of feasibility: ° Chapter 2 contains a projection of future capacity needs of the Railbelt Utilities to the year 2000, thus defining potential market for Beluga power. ° Chapter 3 contains conceptual design drawings and specifications for the Beluga power plant, thus providing tentative assurance of praticability and a basis for estimating capital costs dnd operating expenses. 456/1A3523-1/03 : Chapter 4 presents an estimate of the required capital investment and ongoing costs of operation. : Chapter 5 projects the cost of power produced by the Beluga plant. ° Chapter 6 gives Gilbert/Commonwealth's findings and recommendations. 456/2A3523-1/D3 CHAPTER 2 MARKET POTENTIAL This chapter sets forth the results of Gilbert/Commonwealth's analysis of future need for bulk power in the Alaska Railbelt. The purpose is to estimate who might purchase a portion of the output of the Beluga Plant, when, and how much. 1. 5. CONCLUSIONS The potential market for Beluga power lies mainly in the southern part of the Railbelt, i.e., in the Anchorage area. Anchorage Municipal Light and Power, Chugach Electric Association, Homer Electric Association, Matanuska Electric Association and/or Seward Electric System are potential buyers, if Beluga power proves to be competitive with the other options available to these utilities. These other options conceivably include the Susitna Hydro Project, gas or oil-fired combined cycle units, other coal-fired steam plants, and gas or oil-fired combustion turbines. Because these utilities are closely interconnected and cooperatively share or trade in bulk power supply resources, it is not informative to attempt to assess their individual needs. Due to a combination of anticipated load growth and retirement of older generating units, the Anchorage utilities appear to require new bulk power supplies as shown in Exhibit 2.1. That is: : They will begin to run short of capacity in 1988. : They will require approximately 650 MW of new capacity by the year 2000. : It is possible that the Anchorage utilities can postpone the retirement of older units in order to defer the need for new capacity, if that is a necessary or economical thing to do. Assuming all retirements are deferred 5 years, the results as developed in Exhibit 2.2 are as follows: : They will begin to run short of capacity in 1991. ° They will require approximately 450 MW of new capacity by the year 2000. Thus it is concluded that there is a potential market for 100 to 150 MW of Beluga power beginning in the early 1990's. For this to become a reality, Beiuga power must be competitive with the cost of 3 456/3A3523-2/D3 alternative new resources available to the utilities in the Anchorage area. 8. With respect to the utilities in the northern part of the Railbelt (Fairbanks Municipal Utility System and Golden Valley Electric Association), the market for Beluga power is not as promising as in the Anchorage area. The amount of power needed by the year 2000 is relatively small as evidenced in Exhibits 2.3 and 2.4. The first need does not occur until 1996. Moreover, Beluga power generation that is located in the Anchorage area may not be regarded as a reliable way to meet the need for capacity in the Fairbanks area, as long as there is only one interconnection between Anchorage and Fairbanks which is inherently subject to outage from time to time. DISCUSSION Appendix A shows the data used in developing Exhibits 2.1 through 2.4, and thus arriving at the conclusions stated above. All of this informa- tion is taken from a data base being assembled by the Alaska Power Authority with the cooperation of the Railbelt Utilities. To be more exact, it is taken from a preliminary draft of that data base that was assembled in early November of 1984. The purpose of that data base is to make a power. production costing model for the integrated Railbelt systems, to which interested parties may have access in order to measure the economics of the Susitna Hydro Project against alternative energy resource developments of whatever nature postulated. Given this data, the calculations underlying Exhibits 2.1 through 2.4 seem self-evident. 456/4A3523-2/03 Year 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 Generating Capacit Retired Total Added 39 (b) 90 (c) rors 129 72 36 19 38 148 1 2 56 143 1 516 FUTURE GENERATION NEEDS OF THE SOUTHERN RAILBELT SYSTEMS ASSUMING ON-TIME RETIREMENTS 826 793 793 793 757 847 828 790 642 642 641 639 639 639 583 440 439 (Megawatts) Requirement Demand Reserve(a) Total 597 633 661 690 719 752 772 790 805 821 836 853 871 890 920 944 (a) Assuming 15 percent minimum reserve requirement. (b) (c) Bradley Lake Hydro Plant. Soldotna Unit 1. 456/3A3523-2/D3 90 95 99 104 108 113 116 119 121 123 125 128 131 134 138 142 687 728 760 794 827 865 888 909 926 944 961 981 1002 1024 1058 1086 Long (Short) 106 65 33 (37) (37) (98) (267) 284 (303) (322) (342) (363) (441) (618) (647) T°? «!TaTuVvI LAMLDLI Goce €0/2-E2SEVb/9Sb *quet dg OupAy aye] Aatpeug (9) “TL ytun euqoptos (q) *quawautnbau aAvasau wnwtuLw yuaduad GT Butwnssy (Pe) Ole an TAL (Lbb) 980T 2b1 bb6 6£9 2 = 0002 (Z1b) 8501 BET 026 1b9 I ' 6661 (28€) 201 vel 068 2v9 - 7 8661 (09€) Z00T T€1 148 2b9 8bT - 1661 (161) 186 821 £58 06 BE - 9661 (€€T) 196 G2l 9£8 8z8 61 - S661 (26) bbe E21 128. Lb8 - - v661 (62) 926 T2I S08 v8 9£ - £661 92 606 611 064 £88 - - 2661 (s) 888 911 2L £88 - - 1661 81 598 Il 2G £88 8b - 0661 vO 128 801 6IZ 1€6 = (2) 06 6861 lb v6L vol 069 18 8 = 8861 68 092 66 199 6v8 91 - L861 LET 82/ 66 ££9 698 - - 9861 8L1 189 06 16S S98 7 (q) 6€ G86T - = - - 928 : - b86l (q404s) [P30] BAASSAY “‘puruwag LP30] past yey Pappy JTPaK Buo7 quaweastnbay z19ede) But yeuauayg (s37emebay) SINIWINTLIY JO LN3WY3IID YVIA-S ONIWNSSV SWILSAS LIFATIVY NYIHLNOS FHL 4O SOJ5N NOTLWYINID JUNLN4 Generatin Ca acit Year Added 1984 1985 1986 1987 1988 1989 1990 - 1991 1992 1993 - 1994 - 1995 - 1996 - 1997 - 1998 - 1999 - 2000 - Retired - iie~n met wii 10 25 22 86 FUTURE GENERATION NEEDS OF THE NORTHERN RAILBELT SYSTEMS ASSUMING ON-TIME RETIREMENTS Total 301 301 301 298 298 294 277 277 277 277 272 262 262 237 237 237 215 (Megawatts) Requirement Demand Reserve(a) Total 120 129 137 146 155 166 176 186 196 207 218 230 243 256 272 287 (a) Assuming 15 percent minimum reserve requirement. 456/5A3523-2/D3 18 19 21 22 23 25 26 28 29 31 33 35 36 38 41 43 138 148 158 168 178 191 202 214 225 238 251 265 279 294 313 330 Long (Short) 163 153 140 130 116 86 75 63 52 34 11 (3) (42) (57) (76) (115) €°2@ LIGIHX3 Generating Capacit Year Added 1984 1985 1986 1987 1988 1989 1990 1991 1992 - 1993 - 1994 - 1995 - 1996 - 1997 - Sra re 1998 1999 2000 - ASSUMING 5-YEAR DEFERMENT OF THE RETIREMENT OF CERTAIN UNITS (a) Retired - rindi wit _ rrretiot “39 FUTURE GENERATION NEEDS OF THE NORTHERN RAILBELT SYSTEMS Total 301 301 301 298 298 294 277 277 277 277 272 262 262 262 262 262 262 (Megawatts) Requirement Demand Reserve(b) Total 120 129 137 146 155 166 176 186 196 207 218 230 243 256 272 287 18 19 21 22 23 25 26 28 29 31 33 35 36 38 41 43 138 148 158 168 178 191 202 214 225 238 251 265 279 294 313 330 Long (Short) 163 153 140 130 116 86 75 63 52 34 11 (3) (17) (32) (51) (68) (a) I.e., of the Healy unit (25 MW) and Chena Unit 5 (22 MW), both of which are coal-fired units. (b) Assuming 15 percent minimum reserve requirement. 456/6A3523-2/D3 4°97 «I! TaTuVI CHAPTER 3 DESIGN CONCEPTS This chapter sets forth preliminary concepts of the design of an electric generating power plant to be fueled with coal from the Chuitna mine. The purpose is to determine how and where such generation can be installed to best advantage, and to establish a basis for estimating its capital and operating costs. UNIT SIZE For purposes of this preliminary feasibility assessment, a nominally rated 150 MW unit size was selected with the design based on the plant ultimately consisting of two identical units. This report specifically addresses the first such unit, with provisions made for installing the second when or if there is a market among the Railbelt Utilities for additional bulk power supply. It is assumed that approximately 40 MW of the capacity of the first unit is reserved for use at the mine itself, leaving approximately 100 MW available for purchase by the utilities. This sizing criteria was considered a reasonable approach based on the following factors: 1. As indicated in Chapter 2, there appears to be a market for at least 300 MW of bulk power, beginning in the early 1990's. 2. The installation of a single 300 MW unit was not considered acceptable from the standpoint of system reliability. Utilities generally prefer to limit the size of their largest units to approximately 15 percent of peak demand. This would result in a preferred unit size of 120 MW in 1991 and 150 MW by the year 2000. 3. A second 150 MW unit can be readily installed to give a total of 300 MW as projected power demands may dictate. LOCATION It appears that the generating plant is best located at the port facility on Cook Inlet rather than at the mine proper. The reasons are as follows: 1. This would greatly simplify the coal handling system and reduce its cost, 2. The problem of hauling heavy components of the plant overland to the mine site is avoided, 456/9A3523-3/D3 3. The cost of bringing in quicklime to supply the system for removing sulfur from the stack gases is reduced, 4. Potentially less stringent licensing requirements could pertain than in the upland areas where the mine is located. The area required for this project is estimated to be approximately 200 acres, including the plant proper (two units) and provision for the disposal of solid wastes, assuming a 30-year period of operation. The Chuitna mine port facility has adequate space available to accommodate this installation. Exhibit 3.1 shows the general layout of the site. A 30-day inventory of coal is proposed for the plant, or approximately 70,000 tons per unit. For reasons of economy, it is recommended that a portion of the stackout of the coal in transit be dedicated to this pur- pose. Two sites near the mine were also considered but not evaluated in detail. Both would require the construction of a separate conveyor belt approxi- mately 2 miles long to carry coal from the nearest transfer point to the plant. By locating at the port facility, this is avoided and the first cost, operating costs and maintenance costs associated with the plant are thereby reduced. Additionally, the boiler drum, generator stator and main power transformer will each weigh in excess of 100 tons and the service road from the port facility to the mine could require additional work and costs to reinforce the roads and bridges over a span of roughly 8 miles to support these loads. DESIGN CRITERIA A conceptual design was developed for a nominally rated 150 MW power plant fired with pulverized coal and located at the Chuitna mine port area. Emphasis was placed on developing a design philosophy appropriate to the specific site and climatic conditions that prevail. Exhibit 3.1 and Appendix B show the plant design concept in terms of plot plans, general arrangements, and a system flow diagram. The plant would use a standard 1,450 psig/1,000F/1,000F single reheat cycle with five stages of feedwater heating. This cycle was chosen based on the results of a preliminary optimization analysis which compared 1,450 psig and 1,800 psig steam pressures as well as non-reheat and reheat designs. It was determined that the slight increase in efficiency asso- ciated with the 1,800 psig cycle was not sufficient to justify the addi- tional capital cost, compared against the relatively low fuel cost. A reheat cycle was selected because it results in reduced moisture content in the low pressure turbine exhaust enabling the plant to take advantage of low condenser backpressure without sacrificing turbine blade life. A relatively low fuel cost was also a factor in selecting a five heater cycle rather than six for feedwater heating. The net plant heat rate is 10 456/10A3523-3/D3 estimated to be approximately 10,400 Btu/kWh at the maximum continuous rating. The steam generator would be a balanced draft, natural circulation, boiler designed to fire pulverized sub-bituminous coal with a maximum continuous output of 1,040,000 Ibs/hr at 1,450 psig/1,000F/1,000F. Four 50 percent capacity roller-race type pulverizers are included to accommodate routine maintenance outages. A regenerative type air heater is proposed in connec- tion with a steam coil air preheater to heat primary air to the temperature required to reduce the moisture content of the coal. The steam turbine generator would be a tandem compound, two flow, conden- sing type unit, with five uncontrolled extractions: for feedwater heating. The maximum continuous gross output would be approximately 150,000 kW and 157,500 kW with valves wide open and 5 percent overpressure. Flue gas desulfurization equipment is provided to ensure compliance with the New Source Performance Standard, i.e., 70 percent sulfur removal for new coal-fired utility power plants. Two 100 percent capacity dry S09 scrubber trains utilizing high calcium lime as the absorption media is used as the design approach. A dry scrubber system was determined to have many advantages over a wet system, including greater simplicity, lower cost, and a much simpler and environmentally acceptable ash dis- posal system. Following the dry scrubber system, a reverse air fabric filter would be utilized to collect particulate matter. The stack would be fully instrumented for continuous monitoring of all emissions as re- quired by Federal and State regulations. Measurements would include particulate loading, opacity, CO, C0g and SOo. A six-cell mechanical draft cooling tower with provisions for cold weather operation, including two 50 percent capacity circulating water pumps, cell isolation, 100 percent water bypass, and two speed reversing fans, was selected for the purposes of this study. It is assumed that potential problems with ice fogging from the tower plumes can be mini- mized by proper tower design, placement and operation. Should additional investigation or regulations require a wet-dry tower, only minor adjust- ments to the cycle and cost estimate are necessary. A makeup water treatment system utilizing two 100 percent capacity mixed bed demineralizer trains rated at 100 GPM each, and a 250,000 gallon insulated and lined storage tank would be provided. It is assumed that raw makeup water for the steam cycle and cooling water system will be provided from deep wells. Of the two primary waste disposal systems, (wet or dry), the dry method of disposal was selected because it reduces cold weather handling prob- lems and provides a higher level of environmental compliance. Ash and FGD waste material would be conveyed from the spray dryer absorbers and fabric filter to a 40-hour central waste disposal site. A dilute phase pneumatic conveying system would be utilized for the entire fly ash/FGD 11 456/11A3523-3/03 waste handling system except at the absorber outlets. Upsets in opera- tions could result in wet, sticky waste material in an absorber hopper. Therefore, a mechanical conveyor is used for this service. Bottom ash would be sluiced into dewatering bins prior to being trucked to disposal at scheduled intervals. The disposal area would consist of imperviously lined ponds with runoff collection to prevent groundwater contamination. The individual ponds would eventually become finished landfills. Depending on the specific ash content of the coal and site topography, approximately 150 acres would be required for the 30-year project life. It was assumed that no acceptable regenerative use for fly ash/FGD wastes is available at this location. The S02 absorption media (quicklime) would be delivered to the Cook Inlet in 3,000 1b "bin bags." The bags incorporate a loop system for off-loading by lift trucks onto flat bed trucks for delivery to the plant site. At the plant, the bags would be bottom-emptied into a hopper which feeds a pneumatic transfer system that conveys the lime to two main storage silos. Based on the composite coal analysis and the NSPS 70 per- cent sulfur removal criteria, it is estimated that 1,300 to 1,700 tons of lime per year will be required. The coal handling system would consist of a buried reclaim hopper at the pile base. This would allow transfer of coal to the plant without addi- tional stackout and storage. A 36-inch, 400 tons per hour belt would transfer coal to the plant from the reclaim hopper. This conveyor would pass through a transfer house which would include the capability to crush frozen and oversize coal. A second reclaim conveyor would be required to feed the crushed coal to the inplant storage silos via a travelling tripper. Exhibit 3.2 is a summary of the prominent operating characteristics of the proposed plant. It also shows the anticipated fuel analysis. 12 456/12A3523-3/D3 LICENSING The licensing process for a 150 MW coal-fired mine-mouth power plant is outlined in Appendix C. Of major importance to the power plant licensing process are considerations for: Air quality Water quality Solid waste disposal Land use Environmental report and impact statement oe e@ @ Air Major areas associated with the air quality requirements for a coal- fired power plant include the attainment status in the area, New Source Performance Standards, prevention of significant deterioration (best available control technology), and ice fog. The ambient air quality in the project area meets both the primary and secondary national ambient quality standards for suspended particulates, sulfur oxides, nitrogen oxides, and ozone. However, the ambient air quality for carbon monoxide in the Anchorage area does not meet national ambient air quality standards. r The EPA has promulgated new source performance standards for fossil- fueled steam generators similar to the unit proposed. New source per- formance standards are a technology-based standard and specify a percent removal efficiency for particulate matter, sulfur oxides, and nitrogen oxides. The EPA also has regulations that are air quality-based standards. In areas that meet NAAQS, these standards include avoidance of significant deterioration of air quality and use of the best available control tech- nology (BACT) which could be more stringent than NSPS. In areas that do not meet NAAQS, the air quality-based standards require obtaining offsets from existing facilities that emit the same pollutant that is violating the NAAQS and the use of the lowest achievable emission rate which could be more stringent than NSPS and BACT. The Alaskan Department of Environmental Conservation can, at its discre- tion, require anyone proposing to build or operate an industrial process, fuel burning equipment, or incinerator in areas of potential ice fog, to reduce water emissions. This ice fog phenomenon can be formed by wet scrubbers, wet cooling towers, disposal ponds, or water discharges. These and other water emission sources for the power plant will have to be studied to determine their impact on ice fog generation and possible mitigation measures should a problem exist. 13 456/13A3523-3/D3 Preapplication activities may be needed prior to preparation and sub- mittal of the actual permit. These activities could include the performance of air quality monitoring in the area. This monitoring could be required over a period of 12 months which may be waived if the state/EPA has sufficient background level to make their attainment status determination. In order to demonstrate that the emissions from the proposed source will not cause a significant deterioration in air quality, an air quality dispersion model would need to be run based on projected emission data and meteorological data. ‘!f the modeling indicates that significant deterioration increment levels are not violated, then the likelihood of more stringent emission controls than new source performance standards is remote. Water The state of Alaska has promulgated comprehensive water quality stan- dards to protect the public health, safety, and welfare, and also to allow the growth and propagation of aquatic life. This protection is also afforded to groundwater. The U.S. EPA has standards of performance for new sources of discharges resulting from the construction and operation of steam electric power generating units. Point source discharges of pollutants are required to comply with these requirements. Permits issued under the National Pol- Jutant Discharge Elimination System will be conditioned such that water quality standards are not violated. Stream and/or groundwater sampling in the vicinity of the proposed discharge location may have to be per- formed in order to determine existing water quality. Permit conditions are not anticipated to be more stringent than the standards of perform- ance. Solid Waste The EPA has promulgated regulations to promote the protection of public health and the environment. This includes regulating the treatment, storage, transportation, and disposal of hazardous wastes. Fly ash waste, bottom ash waste, and flue gas emissions generated from the combustion of coal are not currently classified as hazardous wastes. Other wastes. generated by the plant will have to be analyzed to determine if they are hazardous wastes and come under the hazardous waste management regulations. The disposal of fly ash, bottom ash, and scrubber waste will be done in a manner that does not impact groundwater. Groundwater protection is one of the vital concerns of the U.S. EPA and the State of Alaska. 14 456/14A3523-3/D3 Land Use Construction of a 150 MW coal-fired power plant could be considered to have a relatively minor incremental impact on the total development of the Chuitna mine. However, construction and operational impacts on land use, wild life, and the ecosystem will have to be reviewed and mitigated. Environmental Report and Impact Statement It is almost certain that an activity of this magnitude will require the preparation of a full environmental report and resultant “lead" agency environmental impact statement review process. Determination of the lead agency is a high priority item and should be addressed early in the schedule. 15 456/15A3523-3/03 CONSTRUCTION SCHEDULE A conceptual project schedule is presented in Exhibit 3.3 showing a 41 month period from start of construction to commercial operation. The licensing activities must precede construction and could require between 22 to 30 months from commencement of environmental studies to final project approval. The shorter period assumes the Diamond Alaska Project environmental studies would be partially usable for licensing of the power plant. Total project schedule has been based. on the longer environmental effort which would result in 71 months overall project duration. 16 456/16A3523-3/03 see) 4 aoe wets — ee — Wats Bes cs tas was 2,264,000 gS _ PORT AREA Facies |, £436 BowPRy (repicac) 7o Mine 40D Road BI KY TRAN SASION LINE a oo ee =< Jd 300 To TAT OW NIE Teay rte? 4 EXHIBIT 3. | | , oo * DIAMOND/ SHAMROCK — POWER PLANT | \ FEASIBILITY STUDY PLANT LAYOUT ‘ SK-005 gangers “LOCATION MAP” 1 3 3 GRANITE POINT COAL PORT | N 4 EXHIBIT 3.2 SUMMARY _OF BELUGA POWER PLANT DESIGN DATA Maximum continuous gross output VWO/5 percent overpressure output Maximum continuous net output Fuel Steam conditions Steam flow Fuel consumption Gross cycle heat rate Net plant heat rate Boiler type Air quality control system Ultimate Coal Analysis(% Wt) Moisture Carbon Hydrogen Sulfur Oxygen Nitrogen Ash Higher heating value 456/17A3523-3/D3 17 150 MW 157.5 MW 141 MW Subbituminous coal 1450/psig/1,000F/1,000F 1,040,000 1b/hr at maximum output 96 tons/hr at maximum output 8,270 Btu/Kwh 10,400 Btu/Kwh Pulverized coal, balanced draft Ory FGD system with fabric filter Ss Gal ae bo A3331/G - DIAMOND SHAMROCK 150 MW BELUGA COAL FIRED UNIT CONCEPTUAL PROJECT SCHEDULE EXHIBIT 3.3 =o. ee 6 17 se 109 BID BID a Re es ne ne ee COMPLETION DRUM | COMPLETE T-G PREOP COMMERCIAL MILESTONES T- Re es ne ne ee fd MOBILIZE ERECTION ERECTION TESTING OPERATION ENVIRONMENT/LICENSING oT Be ta Collection Tp DateRes fies — HA Hee setetocoaeua He a — i = =EH | He : ae - FL bine e OD atio | Major Equipment $pec Prep _1 pt tpt Lor jOeigns. } —Petailed Desian oe Se eee eee [CONSTRUCTION | Mo bilige 20m ee b Pressure Parts Ereciton Hydro Boiler Trimandinsulation Sd [Chem Clean/BolOut [T-GPedestal [Condenser Erection Puma Pp O e econdary Piping stem Boiler Feed Pumps . Aux Equipment Installation Insulation and Lagging ue water Piping rT |__| e | au HH | (i 1 | | | 210 fs rs witchyard Tastruments and Controls Oal Handling Finds oa Hane ing Structures " Ash Ha idling and Disposal Equipment Bit Gust ny Contre Equipment Fl Stack Adminisatration Facilities [Plumbing and Arch Feature TEST AND START-UP | Preop Testing and Insrtument Calb tart-up Commercial Operation _ I CHAPTER 4 COSTS AND CASH FLOW This chapter sets forth Gilbert/Commonwealth's estimate of the expenses associated with the construction and operation of the first 150 MW electric generating power plant located at the port facility of the Chuitna Mine. CAPITAL COST ESTIMATE A capital cost estimate was made for the power plant that is described in Chapter 3 using standard estimating methodology. Estimates for the steam generator, turbine generator, flue gas desulfurization system, particulate control system and other major mechanical equipment were obtained from the manufacturers thereof, and compared against historic information to ensure validity. The costs of structures and piping were estimated by the parametric method. Site specific costs as for coal handling, water supply and preparation and development of the plant area were estimated based on analyses of the requirements. The instrumen- tation and control costs were estimated on the basis of experience. The cost of transmission and substation facilities that would be required for interconnection with the utility distribution network have not been addressed in this report. The craft labor wage rate is based on the use of non-union personnel working a 10-hour shift per day, 6 days per week. It is assumed that work would be curtailed during the first winter until the buildings can be enclosed. A cost allowance for housing and feeding the construction personnel at the remote site is included at the rate of $50 per day. Other than this, no camp costs were allocated to this project. The assumption was made that the labor peaks for the mine and the power plant would be non-coin- cident. No capital costs associated with the mining operation have been allocated to this project. The man-hours used in developing the esti- mate are typical. The estimated 11.1 man-hours per Kw to construct this unit is in the middle band of published data for the construction of coal-fired power plants. The indirect construction cost was estimated to be equal to the labor costs. This is made higher than is usual for the lower forty-eight states to account for additional temporary en- closures and higher heating costs. Freight costs to transport equipment and material is calculated on the basis of estimated weights and current costs for barge shipment. 18 456/1A3523-4/D3 The engineering, construction management and owner's costs are estimated based on experience and foreseeable requirements of this project. Twenty- five percent contingency has been applied. Exhibit 4.1 shows the resultant estimate of labor and material costs, and applied additions for shipping costs, indirect construction costs, board and lodging of the construction force, engineering and licensing activities, construction management, owner's costs, and allowance for contingencies. The total figure, before adding interest during construc- tion and financing costs, is approximately $320 million. Exhibits 0.1 through D.6 that are contained in Appendix D show the develop- ment of this cost estimate in more detail. Exhibit 4.2 illustrates the estimated cash flow in the course of construc- tion, totalling approximately $320 million. Appendix 0, Exhibit 0.7, shows the exact figures and their breakdown by plant components. FUEL COST The Diamond Alaska Coal Company estimates that the cost of coal for the Beluga Power Plant may range from $14 to $18 per ton at the port. Using the mid-range value, $16 per ton, the annual cost of fuel will be approx- imately $10.8 million in 1985 dollars. This is based on the following assumptions and estimates, some of which were first set forth in Chapter 3: 141 MW maximum net output 80 Percent average annual capacity factor 7,650 Btu per pound of coal 10,400 Btu/kWh average annual heat rate OPERATION AND MAINTENANCE EXPENSES Operation and maintenace expenses were estimated in terms of fixed and variable components. Fixed costs are based mainly on plant staffing requirements and are essentially independent of annual operating sched- ules. Variable costs include maintenance materials, subcontracted repairs, general supplies, and chemicals. These are directly propor- tional to the amount of power produced by the plant. Total staff requirements were estimated at 145 people comprised of 50 operators, 60 maintenance men, 10 administrators, and 25 swing shift personnel. The latter fill in for vacations and sickness and also per- form miscellaneous jobs such as janitorial or cleaning services. It is assumed that the work shifts would be the same as for the mining opera- tion, i.e., 12 hours per day, 4 weeks on, 4 weeks off, and that the living quarters for the mine wouid be sized to accommodate power plant staff. An average salary of $90,000 per man was applied, including 19 456/2A3523-4/03 fringe benefits. Additionally, a $50 per work day for living expense and $2,000 per year for transporation is included. The result is a total annual fixed cost of approximately $13 million per year in 1985 dollars. Variable costs are based on data from EPRI's* Technical Assessment Guide as well as information made available to Gilbert/Commonwealth by certain clients. Based on a capacity factor of 80 percent, the variable opera- tion and maintenance is projected to be $4.5 million per year. *Electric Power Research Institute 20 456/3A3523-4/03 T2 DIAMOND SHANROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA * TOTAL PROJECT « POP) ITEM DESCRIPTION MAMHOURS MATERIAL LABOR TOTAL WEIGHT(THD STEAM GENERATOR 247,500 $19, 800, 000 $9,900,000 $29, 700, 000 4, 000 TURBINE GENERATOR 47, 000 11, 000, 000 1, 880, 000 12, 880, 000 630 DRY SO2 & FABRIC FILTER 226, 620 11, 057, 300 9, 064, 800 20, 122, 100 2,577 COAL HANDLING 45,777 2, 664, 900 1, 631, 080 4, 695, 980 710 MECHANICAL EQUIPMENT . 61, 215 14, 266, 900 2, 448, 600 16, 715, 500 4, 140 ELECTRICAL EQUIPMENT 139, 177 4, 892, 000 5, 567, 080 10, 459, 080 1,872 INSTRUMENTATION & CONTROL 48, 000 3, 107, 500 1, 920, 000 5,027, 500 141 SITEWORK 25, 680 332, 400 1,027, 200 1,359, 600 4,923 CIVIL/STRUCTURAL- BUILDINGS 179, 165 8, 491, 300 7, 166, 600 15, 657, 900 1,795 CHIMNEY & FOUNDATION 19, 350 581, 000 774, 000 1,355, 000 2,700 COOLING SYSTEM-COOLING TOWERS 166, 645 2, 940, 200 6, 665, 800 9, 606, 000 1, 448 PIPING 388, 258 5, 571, 600 15, 530, 320 21, 101, 920 1,547 SUBTOTAL ; 1,594,387 $84,905,100 $63,775,480 6148, 680, 580 23, 483 FRT. & SPEC. HNDLNG @ $250/TON 78, 000 5, 870, 750 3, 120, 000 8, 990, 750 CONSTRUCTION INDIRECT COSTS 66, 807, 000 66, 807, 000 BOARD & LODGING 9, 718, 000 9, 718, 000 ENGR., ENVIR. PERMITTING & LICEW. 14, 000, 000 14, 000, 000 CONSTR. NGNT. & OWNER’S COST 7, 445, 890 7, 445, 890 CONTINGENCY @ 25% 63, 910, 555 63, 910, 555 SUBTOTAL 78,000 100,945,195 $69,927,000 $170, 872, 195 Sescassesses 0 ssscssssseas | sseceseesess 0 eeeceesceecs | susesseezass TOTAL PROJECT-1985 DOLLARS 1,672,387 $185, 850,295 133,702,480 $319, 552,775 23, 483 1TaTUYS Teh 22 DOLLARS (Thousands) 320 300 280 260 240 220 200 180 160 140 120 100 80 60 40 20 CUMULATIVE CASHFLOW 150 MW COAL FIRED POWER PLANT YEAR 3 QUARTERS YEAR 4 YEAR 5 r CHAPTER 5 COST OF PRODUCT This chapter sets forth Gilbert/Commonwealth's projection of the total capital investment required to construct the Beluga Coal-Fired Power Plant, and the subsequent cost of the energy that it can produce. ASSUMPTIONS Gilbert/Commonwealth used its Project Analysis Model to make these pro- jections. The complete input and output of this computer routine are contained in Appendix E, but for the reader's convenience, we here list the principal assumptions used: 1. The base case assumes a capitalization ratio of 75 percent debt and 25 percent equity. A 12 percent interest rate on construction loans and long-term debt was applied as well as fixing the yield on equity at 15 percent during construction and 20 percent thereafter. 2. A second case was run on the basis of 100 percent debt at 11.61 per- cent interest rate as deemed appropriate for REA financing. It is assumed that construction loans are obtained on a rollover basis at 10 percent through R.E.A. 3. Each of these cases was run on the basis of 6 percent per year infla- tion for both construction expenses and operating costs. In other respects, the projections are based upon the estimates con- tained in Chapter 4. RESULTS Exhibit 5.1 shows the resultant estimate of the total capital require- ments for each case. Exhibit 5.2 shows the annual cost of energy in cents per kilowatthour for 30 years of operation, assuming debt/equity funding and REA funding, respectively. 23 456/1A3523-5/D3 TOTAL CAPITAL REQUIREMENTS (Thousands of Dollars) Total direct cost Total interest charges Total financing cost Less: Interest earned Total capitalization Less: Financing costs Tax effect of interest Total depreciable plant 456/2A3523-5/D3 75/25 Capitalization 388,170 133,689 13,979 (3,281) 532,557 (13,979) (54,754) 463,824 24 EXHIBIT 5.1 R.E.A. Financing 388,170 107,902 (2,655) 493,417 493,417 EXHIBIT 5.2 ANNUAL ENERGY COST (Cents per Kilowatthour) Year 75/25 Capitalization R.E.A. Financing 1991 11.36 9.99 1992 9.63 10.45 1993 10.28 10.48 1994 11.96 10.75 1995 11.72 11.04 1996 12.06 11.35 1997 12.83 11.68 1998 13.22 12.02 1999 13.63 12.39 2000 14.07 12.78 2001 18.23 13.23 2002 : 18.73 13.67 2003 19.27 14.14 2004 19.84 14.63 2005 20.45 15.16 2006 21.11 15.71 2007 21.81 16.31 2008 22.56 16.93 2009 23.36 17.60 2010 24.22 18.31 2011 25.18 19.06 2012 26.17 19.86 2013 27.23 20.70 2014 28.37 21.60 2015 29.60 22.55 2016 30.92 23.56 2017 32.34 24.63 2018 33.86 25.77 2019 35.51 26.97 2020 37.28 28.26 25 456/3A3523-5/D3 CHAPTER 6 CONCLUSIONS AND RECOMMENDATIONS From the results of this investigation, Gilbert/Commonwealth concludes as follows: 1. There is a potential market in the Anchorage area for 100 to 150 MW of new base load generation in the 1990-1995 time frame, and three to four times this amount may be needed by the year 2000. The construction of a 150 MW coal-fired steam turbine-generator unit at the port facility associated with the Chuitna Mine, and the addition of a second such unit later, appears entirely practicable and should not present any extraordinary technical difficulties. It should not be exceptionally difficult to secure the necessary permits and licenses to construct such a plant. The proper environ- mental safeguards are incorporated in its conceptual design. In fact, the licensing process may be facilitated by the fact that the power plant is adjacent to the port facility. It is understood that head-end work necessary to license the port facility is already under way. The first 150 MW unit could be placed in commercial operation as early as the fall of 1990, or thereafter as may suit the needs of the Anchorage area utilities. The second such unit can be brought on-line to suit the subsequent needs of the utilities, but the interval between the two units would preferably be one year at least. To meet the earliest possible schedule, the engineering and licensing effort must begin by the summer of 1985. On the basis of this finding, Gilbert/Commonwealth recommends that this report and these results be disclosed by Diamond Alaska and Voss to State officials and the utilities who may have an interest in this matter. If their reaction is encouraging, these activities should follow as quickly as possible: Tr Define and expand this feasibility study with the cooperation of, and to the satisfaction of, all interested parties. Begin preparations to license the Beluga coal-fired power plant. Begin preliminary engineering to optimize and better define the design of plant and equipment, the construction schedule, the funding requirements, and method of funding. 26 456/1A3523-6a/03 4. ~ Begin negotiations with the utilities that are aimed toward the consummation of contracts or letters of intent for purchase of the plant output, as needed to justify the commitment of capital to construction. 27 456/2A3523-6a/D3 APPENDIX A LOAD FORECASTS AND EXISTING GENERATION OF THE RAILBELT UTILITIES 456/6A3523-7/D3 Year CEA 1985 165 1986 166 1987 166 1988 164 1989 162 1990 160 1991 173 1992 187 1993 196 1994 205 1995 213 1996 221 1997 230 1998 225 1999 230 (a) 2000 230 (a) (a) Extrapolated. Legend: NEA 139 154 168 184 201 220 216 210 205 200 195 190 185 192 198 205 CEA - Chugach Electric Association HEA - Hatanuska Electric Association HEA - SES i= AHLP- Homer Electric Association Seward Electric System PROJECTED ANNUAL PEAK DEMANDS OF THE SOUTHERN RAILBELT SYSTEMS HEA 85 92 99 107 116 125 130 134 138 143 148 153 158 165 173 180 Anchorage Municipal Light and Power (Megawatts) SES 10 11 ll 12 12 14 15 15 16 16 16 16 16 16 17 17 399 423 444 467 491 519 534 546 555 564 572 580 589 598 618 632 AMLP 198 210 217 223 228 233 238 244 250 257 264 273 282 292 (a) 302 (a) 312 (a) Total 597 633 661 690 719 752 772 790 805 821 836 853 871 890 920 944 T°VY LIGIHX3 EXHIBIT A.2 EXISTING PLANTS AND RETIREMENT SCHEDULE SOUTHERN RAILBELT SYSTEMS Avg. Ann. Nameplate Generating Net Prime Fuel Installation Retirement Capacity Capacity Heat Rate Plant/Unit over Type Date Date (HW) GO°F (MW) «© (Btu/kWH) CHUGACH ELECTRIC ASSOCIATION (CEA) Beluga Unit 1 SCCT NG 1968 1988 15.25 18.0 13,800 Unit 2 SCCT NG 1968 1988 15.25 18.0 13,800 Unit 3 RCCT NG 1972 1992 53.3 46.0 13,800 Unit 4 SCCT NG 1976 -- 10.0 = 13,800 Unit 5 RCCT NG 1972 1992 58.5 70.0 13,800 Unit 6&8 CCCT NG 1976 2006 - 90.0 9,878 Unit 7&8 CCCT NG 1976 2006 - 90.0 9,878 Cooper Lake Unit 1, 2 H -- 1961 2051 17.2 = aT International . Unit 1 SCCT NG 1965 1985 14.0 14.5 34,100 Unit 2 SCCT NG 1965 1985 14.0 14.5 34,100 Unit 3 SCCT NG 1965 1985 17.0 19.2 34,100 Bernice Lake Unit 1 SCCT NG 1963 1983 7.5 7.8 20,000 Unit 2 SCCT NG 1971 1991 16.5 19.6 20,000 Unit 3 SCCT NG 1978 1998 23.0 28.0 20,000 Unit 4 SCCT NG 1978 1998 23.0 28.0 20,000 Total CEA 463.6 HOMER ELECTRIC ASSOCIATION (HEA) Seldovia Unit 1 0 0 1952 1990 0.3 0.3 15,000 Unit 2 D 0 1964 1994 0.6 0.6 15,000 Unit 3 0 0 1970 (used) 2000 0.6 0.6 15,000 Unit 4 0 0 1982 (used) 2012 0.6 0.6 15,000 Total HEA 2.1 SEWARD ELECTRIC SYSTEM (SES) Unit 1 0 0 1965 1990 1.5 1.5 15,000 Unit 2 0 0 1965 1990 1.5 1.5 15,000 Unit 3 o 0 1965 1995 2.5 2.5 15,000 Unit 4 D 0 1984 2004 2.5 2.5 15,000 Unit 5 o 0 1985 2005 2.5 2.5 15,000 Total SES 10.5 ANCHORAGE MUNICIPAL LIGHT AND POWER (AILP) Station 1 Unit 1 SCCT NG/O 1962 1982 14.0 16.0 14,000 Unit 2 sccT NG/O 1964 1990 14.0 16.0 14,000 Unit 3 SCCT NG/O 1968 1991 18.0 18.0 14,000 Unit 4 SCCT NG/O 1972 1992 28.5 32.0 12,500 Diesel 1 0D 0 1962 - 1.1 -- 10,500 Diesel 2 D 0 1962 _ 1.1 -- 10,500 Station 2 Unit 5&6 CCCT NG 1979 1999 a 48.0 8,500 Unit 7&6 CCCT NG 1979 1999 == 95.0 8,500 Unit 8 SCCT NG/O 1984 2004 77.6 94.8 12,000 Total ANLP 319.8 Utilities’ Total 796.0 Alaska Power Administration 30.0 Grand Total 826.0 Legend H - Hydro D - Diesel sccT - Simple cycle combustion turbine RCCT - Regerative cycle combustion turbine cccT - Combined cycle combustion turbine NG - Natural gas 0 - Distillate oil year 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 Legend: PROJECTED ANNUAL PEAK DEMANDS OF THE NORTHERN RAILBELT SYSTEMS (Megawatts) GVEA FNUS 89 31 96 33 103 34 111 35 119 36 128 38 136 40 145 41 154 42 164 43 174 44 185 45 197 46 209 47 223 49 237 50 GVEA - Golden Valley Electric Association FMUS - Fairbanks Municipal Utility System Total 120 129 137 146 155 166 176 186 196 207 218 230 243 256 272 287 eu tener EXHIBIT A.4 EXISTING PLANTS AND RETIREMENT SCHEDULE NORTHERN RAILBELT SYSTEMS Nameplate Generating Prime Fuel Installation Retirement Capacity Capacity Heat Rate Plant/Unit Mover Type Date Date (MW) @O°F (MW) (Btu/kWH) FAIRBANKS MUNICIPAL UTILITIES SYSTEM (FMUS) Chena Unit 1 ST Coal 1954 1994 5.0 5.5 16,000 Unit 2 ST Coal 1952 1989 2.0 2.2 18,000 Unit 3 ST Coal 1952 1989 1.5 1.8 18,000 Unit 4 SCCT 0 1963 2004 5.3 7.0 24,000 Unit 5 ST Coal 1970 2000 20.0 22.0 10,250 Unit 6 SCCT 0 1976 . 2006 23.1 29.1 17,000 Diesel 1 D 0 1967 1990 2.8 3.0 12,150 Diesel 2 D 0 1968 1990 2.8 3.0 12,150 Diesel 3 D 0 1969 1990 2.8 3.0 12,150 Total FMUS 76.6 GOLDEN VALLEY ELECTRIC ASSOCIATION (GVEA) Healy Coal ST Coal 1967 1997 25.0 25.0 12,700 Healy Diesel D 0 1967 1987 2.8 2.8 11,200 North Pole Unit 1 SCCT 0 1976 2006 64.7 65.0 10,000 Unit 2 SCCT 0 1977 2007 64.7 65.0 10,000 Zendher - Unit 1 SCCT 0 1971 2001 18.4 18.4 14,000 Unit 2 SCCT 0 1972 2002 17.4 17.4 14,000 Unit 3 SCCT 0 1975 leased 2.8 = - Unit 4 SCCT 0 1975 leased 2.8 - - Diesel Unit 1 0 0 1961 1990 2.5 2.5 11,200 Unit 2 0 0 1961 1990 2.5 2.5 11,200 Unit 3 0 0 1964 1990 2.5 2.5 11,200 Unit 5 D 0 1970 1995 2.5 2.5 11,200 Unit 6 OD 0 1970 1995 2.5 2.5 11,200 Unit 7 0 0 1970 1995 2.5 2.5 11,200 Unit 8 O 0 1970 1995 2.5 2.5 11,200 Total GVEA 211.1 Utilities'Total BET7 University of Alaska 13.0 Grand Total 300.7 Legend 0 - Diesel SCCT - Simple Cycle Combustion Turbine ST - Steam Turbine 0 - Distillate oi] APPENDIX B CONCEPTUAL DESIGN DRAWINGS 456/7A3523-7 /D3 10 ’ i ‘ | 1 ‘ | 5 4 3 2 1 sre esi 362 zorsi sea, pom f F : € e Poo 1 j ' 4 ' { : ‘SUBSTATION i ' L------- cooersare oats cyeue water PRE-TREATMENT 7 ‘ L » C74@ }| > : x a : 4 ADMINISTRATION & | ‘SERVICE BUILDING jor U as ont veowine | Ir SSromee om COneTOR L NL That ser = ye gee ar peng Ta : Fides wa} El sess 1 ARSORBERS | ABSORBERS, c to. nad — WAREHOUSE STORAGE ra C ‘ SILOS coma, mou} | | > pare bose {muchos sci Lk p pT al 1.0, FANS, | pa 41.0, FANS Te nme 71 comer ' J As wou ne * ss wou ne \L iS es | a 8 8 put 010 — o 100 200 oo amid EXHIBIT B.1 ar —r axe en | me (| ive pean GILBERT/ COMMOMBEALTH DC, OF MICHIGAN save a a kd OWNER 4 DIAMOND SHAMROCK/VOSS © [s] POWER PLANT A i FEASIBILITY STUDY A 5 5 a} A 10 3 8 1 TI 6 5 4 3 r § | LIME RECEIVING wo UNLOADING wos Be At IMISTRAT JO SERVICE BUILDING LIME STORAGE BUILDING ¥ OFFICE AREA E LO. Faw (peLow te wey ] ‘asa rot \ IPE Uy — fe NSIS Sn i mem ttt | Bb L jee ! woIsTuay 1 1 1 PASSDGER ELEVATOR \ REVERSE AIR rao + X\ 5 morse | DOUBLE J n i t i oe ! uth rofty7—7 mM | i Te oe ae j pe ein eaten ‘alll L aan may Lites toi in r Ae ry ee ay Wt r WHA thr pat! some im ! JEP Hit Jit ae i Writ tiene) ead ~t T Hideo MEY TAT rt Huger Lit - ' Le TH ' ' i - \ OPK JIT 4 mister HI m KA u 8 i ny eS ui ; ! 4 4 \ ———————— J i —— EXHIBIT B.2 " SCALE IN FEET i a Cn C—O a 1 axe riae ] i a OO Te esi l MPO iS le 7 gj eons ' ETT sree come Ea | DIAMOND SHAMROCK VOSS cn 4 POwER PLANT 8 FUSIBILITY stir i i 2 PLANT LAYOUT & GENERAL _ ARRANGEMENT rE] OPERATING FLOOR 4 =r == = = e 64-0751 Sk-003 iis 0 POTLER Room ROOF YONTILATORS STEAM STLO LOADING ‘CONVEYOR 00M. ------—~|-———. DEAERATOR ‘TURBINE AREA DEAERATED l vomiuirn —stiaee Ta pom ute une aa --7 4 TURBINE AEA CRE PURER \f' ‘ VORILATION —— We \/ Lo" OLR FeepuaTer TUCO FED HT ae. MEATS | weatins 9 CM ay ree HANDRAIL __ DOWST cooesen Re-use PME L__ CHOOSER j CMRINTDONEE . Y ASILE — \ PULVERIZERS 10 3 1 ‘ 5 4 3 2 1 et DOTS | A004 1 F CHIMNEY COAL conVEYOR = ABSORBER BUILDING mutta - CFUTIRED asia OPK JT. ~~’ 1 Spe om fl q _ / DAMPER \ /. LIME HOPPER ‘ABSORBER, * Bir : : \ canon j AIR HEATER: ro j 1 EQUIPWENT. } Fb Fan : i — f™ t / a - —— , = ; ‘oN . * C sere 7 r T wILL/SUKER \L SERVICE PLATFORM io wortn peur vorren ane 10 ENCLOSED FOR WEAI pratction wo IMPROVED PERF —e—_ ° 2 CT wo ‘SCALE IW FEET EXHIBIT B.3 a aa ae oe Face o ILO Cou < aeons 6 Com ™ De, OF WICHICAE mess eee, To omen DIAMOND SHAMROCK/ VOSS 4 POWER PLANT g FEASIBILITY STUDY | |a}8 PLANT LAYOUT z GENERAL _ ARRANGEMENT Fi ELEVATION VIEW = A =| 6eors SK-004 6 5 4 3 Rea ver MaKe CHLORINATION STeaw ccnenaton : AL Hn CIRCULATING WATER PUMPS (2-100) RECIRC, Li, HEATER ORAIN x TOS LA MATER Te are eT x 50 3 LP, HEATER ORAIN RECIRC. x OP, MATER 4 LP. MATER wa. 2 x aoe gGgedqgea = & J BOILER FEED PUMPS (1-100 STEAM DRIVEN (1-100 MOTOR DRIVEO EXHIBIT B.4 GILBERT/COMMOMIEALTH INC. OF MICHIGAN = Cee ss ‘Owner DIAMOND SHAMROCK/VOSS POWER PLINT FEASIBILITY STUDY STEAM/ WATER [or OT | hcisass > APPENDIX C LICENSING REQUIREMENTS 456/8A3523-7/D3 . . . ' ' 1 ' ' ‘ a“ « rT) “ « a DIAMOND CHUITNA POWER PLANT EXHIBIT C.1 MAJOR APPROVALS REQUIRED FOR Sheet 1 of 2 150 MW COAL FIRED FACILITY Permit Activity Agency (a) Authority (b) Time (c) Remarks Prevention of Significant New air contaminant DEC/Region X AS 46.03.150 6-12 mos Because of the amount of electricity Deterioration (PSD) New sources - new boilers, coal EPA 18 AAC 50.120 sold to a utility power distribution Source Review handling, ash handling system (over 1/3 of output and over 25 MW) Subpart Da applies to the 150 MW unit. National Pollutant Discharge Water discharges into waters of EPA Clean Water Act, 6-12 mos This activity may involve preparing an Elimination System (NPDES) the U.S. P.L. 92-500, Section 402 environmental report. Permit . Structures in or affecting Intake and discharge structures, COE River and Harbor Act of 1899, 3-12 mos This activity may involve preparing an navigable waters - transmission lines 33 U.S.C. 401-413 environmental report. Permit for dredged or fill Fill or dredging in waters of the COE Clean Water Act 3-12 mos This activity may involve preparing an material U.S. P.L. 92-500, Section 404 environmental report. Certificate of Reasonable Water Quality Certification DEC Clean Water Act 3-6 mos Required for activities affecting waters Assurance P.L. 92-500, Section 401 of Alaska which require federal license or permit. 7 Wastewater Disposal Permit Disposal of wastewater into or onto DEC AS 46.03.100 3-6 mos If NPDES permit is issued, Alaska waives waters or lands of Alaska 18 AAC 72 the procedural requirements and adopts the NPDES permit. Water and Wastewater Water and wastewater treatment DEC AS 46.03.090 6 mos Treatment Works Plan Approval systems 18 AAC 72.060 water Rights Permit Appropriation of waters of Alaska DNR AS 46.15.030-.185 2-3 mos 11 AAC 72 Aircraft Obstruction Notice Chimney, stack, transmission FAA P.L. 85-726 1 mo Notice only, no approval required. towers 14 CFR 77 Cultural Resources Survey Site Survey DNR (Historic Archaeological Resources 3-6 mos Surveys are to be performed during 456/A3425-Tb1/D3 Preservation Protection Act of 1979 Officer) periods with no snow cover. ~ — _ -— — i Permit Activity Agency (a) Solid Waste Disposal Permit Disposal of fly ash, bottom ash, DEC scrubber sludge, construction waste Transmission Line Transmission Line Routing Various To Be Determined Local requirements pertaining to building permits. State and local land use, right-of-way and easement, and access road approvals. (a) Abbreviations DEC - Alaska Department of Environmental Conservation EPA - U.S. Environmental Protection Agency COE - U.S. Army Corps of Engineers ONR - Alaska Department of Natural Resources FAA - Federal Aviation Administration (b) "AS" references to Alaska Statutes "AAC" references to Alaskan Administrative Code (c) Estimated months agency would take to review application and issue permit. Does not include application preparation time. 456/A3425-Tb1/D3 =—3 ~l _ ~~ al Exhibit C.1 Sheet 2 of 2 Authority (b) Time (c) Remarks AS 46.03.100 3-6 mos 18 AAC 60 Var fous 6-12 mos The transmission lines associated with the 150MW facility will require numerous environmental, land use and right-of-way permits and approvals. e 456/9A3523-7/D3 APPENDIX D COST ESTIMATING DETAILS DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA POPE) CCCP CRONE Aenee nena * GENERATORS « eee ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TH) STEAM GENERATOR-150MWe @ 1465 247,500 $19, 800, 000 $9, 900, 000 $29, 700, 000 4,000 PSIG 1000 F/1000 F TURBINE GENERATOR-150MWe 1465 47,000 $11,000, 000 $1, 880, 000 $12, 880, 000 630 PSIG 1000 F/1000 F CeCe COOP ONO NEN ENON NEON PE) « DRY SO2 SYSTEM # Py) ane ITEM DESCRIPTION MAMHOURS MATERIAL LABOR TOTAL WEIGHT(TH) 1SOMW INCL LIME PREP, ABSORBER, 225, 000 $11, 000, 000 69, 000, 000 $20, 000, 000 2,500 BREECHING, WEATHER ENCLOSURE, SLURRY SIDE EQUIPMENT, & ASH HANDLING EQUIPMENT STRUCTURE & EXCAVATION 1,620 57, 300 64, 800 122, 100 77 Sassssasss55 0 ssssassssass 9 sEsscsssseas 0 sussesesesee 06 seesezeussse TOTAL DRY SO2 SYSTEM 226,620 $11,057, 300 $9, 064, 800 $20, 122, 100 2,577 eee PEPE iiiiiiiiiiiiiri iii iiitiiitirilitiiiitiiiiiiiiiiiiiiiiiiiiiiy) COON enone * COAL HANDLING # ACCC ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TM) RECLAIM TUNNEL & HOPPER 1,200 $30, 000 $48, 000 $78, 000 304 CRUSHER/SAMPLE HSE FDN-1600 SF 1,120 14,000 44, 800 58, 800 264 FOUNDATIONS FOR BENDS 600 6, 400 24,000 32, 400 122 COAL HANDLING-QUOTED FROM FHC 42, 857 2, 812, 500 4,714, 280 4,526, 780 oO Sesssassssss oo ssssssssssss 0 sa55555E5E55 SESSEEEESEES sEEEEEEEEess TOTAL COAL HANDLING 45,777 $2, 864, 900 $1,831,080 $4,695, 980 710 L°G LI@IHX4 CONN N REO JECHANICAL EQUIPMENT « CELIO y) DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITWA, ALASKA ITEM DESCRIPTION MAMHOURS MATERIAL LABOR TOTAL WEIGHT(TH) MAKE UP DEMINERALIZER 4,000 $825, 000 $160, 000 $985, 000 40 CONDENSER 6,500 1,045, 000 260, 000 1,305, 000 150 TANKS, DRUMS, & VESSELS 4,790 264, 000 71,600 335, 600 300 HEATERS & EXCHANGERS 4,700 1, 230, 300 188, 000 1, 418, 300 163 PUMPS & DRIVERS 11,740 - 3, 367, 000 469, 600 3, 836, 600 275 CHEMICAL FEED 200 19, 800 8, 000 27, 800 2 MISC. MECHANICAL EQUIPMENT 7,570 4, 468, 000 302, 800 4,770, 800 oO HVAC 7,215 552, 800 288, 600 641, 400 0 WASTE WATER TREATMENT PLANT 12,000 1, 925, 000 480, 000 2, 405, 000 200 COOLING TOWER ACID FEED 500 70, 000 20, 000 90, 000 10 BOTTOM ASH SYSTEH 5,000 500, 000 200, 000 700, 000 oO Seesesssesss oo saasecesssss oss See5s5 0 Saaeccssssss seseesassaas TOTAL MECHANICAL 61,215 $14, 266, 900 $2, 448,600 $16, 715, 500 4,140 COON NEUE U RICAL « eCeCeenenee CONMERON OREO ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TM) TRANSFORMERS 3,924 $1, 228, 000 6156, 960 $1, 384, 960 161 SWITCHGEAR & BUS 8,099 1, 453, 000 323, 960 1,776, 960 138 ELECTRICAL PANELS 1,320 193, 000 52, 800 245, 800 13 ELECTRIC HEAT TRACE 1,040 70, 000 41,600 111,600 2 UPS W/STATION BATTERY 864 120, 000 34,560 154, 560 4s GROUNDING & LIGHTING PROTECT. 4,030 59, 700 161, 200 220, 900 50 480 HCC’S 720 140, 000 28, 800 168, 800 12 ELECTRICAL RACEWAY : 49,940 709, 350 1, 997, 600 2, 706, 950 S71 WIRE & CABLE 47,240 618, 950 * 1, 889, 600 2, 508, SSO 810 LIGHTING, COMMUN. , FIRE DETECT. 22,000 300, 000 880, 000 1, 180, 000 100 SSSSSSSES555 Seescseessss seaezsssssss 0 sessssusscee 0 ssceasescazs TOTAL ELECTRICAL 139, 177 $4, 892, 000 $5, 567,080 $10, 459, 080 1,872 THAUAUUUUACCUANAAHAUOOOUUOAMAUHOROUAUOUMOUUNSOGNUUOOEUUOAUEOROOAUNOOANOMOAENAOUANOOOKUH O A A A O R S O N E R O O N N N R O N N E N E 2°G LIGIHX3 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA eeneneneeee aun SOPUNONNUC RONEN NONE Wenneneenee « SITEWORK # woman ITEM DESCRIPTION MAMHOURS: MATERIAL LABOR TOTAL WEIGHT(TM) SITE ROUGH GRADING 4,000 $160, 000 $160, 000 Qo CLEAR & GRUB 5,000 200, 000 200, 000 o FINE GRADING 2, 400 96, 000 96, 000 0 ON SITE ROADS/PARKING 3,740 $112, 200 149, 600 261, 600 4,676 . STORM DRAINAGE SYSTEM 800 26, 000 32,000 58, 000 0 SITE FEWCE 720 43, 200 28, 800 72,000 2 SITE FIRE PROTECTION LOOP 6,000 76, 000 240, 000 316, 000 60 SAWITARY WASTE SYSTEM 1,300 30, 000 52,000 82,000 10 4° CONCRETE SIDEWALKS 120 3, 000 4,800 7,800 75 WELL & TANK POTABLE WATER 200 10, 000 8,000 18,000 42 (50000 GAL TANK, 1500’ DEEP WELL/400GPH PUMP OIL STORAGE STRUCTURE 1,400 32, 000 56, 000 88, 000 “4 BESEESEESESE oo BEEEEEREEESE | SEEEEESESSSE 0 SEESEEEESESE | SEEEEEEEEEEE TOTAL SITEWORK 25, 680 $332, 400 $1,027, 200 $1, 359, 600 4,923 POPP ® CIVIL/STRUCTURAL & PPP ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TM) ADMINISTRATION BUILDING 19, 883 $920, 800 $795, 320 $1,716,120 a1 MACHINE SHOP 1,548 $72,000 661,920 $133, 920 18 WAREHOUSE 7,395 $341,000 $295, 800 9636, 800 109 150MW BOILER & TURBINE BLDGS. 150, 339 $7, 157, 500 $6, 013, 560 $13, 171,060 4,577 SUPER & SUBSTRUCTURE STRUCTURAL ONLY Saesassscsss 9 euceessesass 96 secsssssssss 0 sEEEsuascsss 0 SESEsaaEEEEE TOTAL CIVIL/STRUCTURAL 179, 165 $8, 491, 300 $7, 166, 600 $15, 657, 900 1,795 « CHIMNEY & FOUNDATION » Ce ITEN DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TW) CHIMNEY & FOUNDATION 19, 350 $581,000 $774,000 $1, 355, 000 2,700 €°d LI@IHX4 ot DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA bbb hhh hhh htt LLL LLL LLLELE LLL iii ii iii ii iititiiiiiiiiiiiiirrii iti r Tritt tit) PEPE y) ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TM) COOLING TOWERS 23, 571 $825, 000 $942, 840 $1, 767, 840 0 CIRCULATING WATER PIPE --72* CONCRETE W/FITTINGS 13,670 432, 000 546, 800 978, 800 0 --OPEN EXCAVATION & BACKFILL 37,594 62, 400 1,503, 760 1,566, 160 0 --PIPE SUPPORT TOWERS AT BASIN 4,720 206, 100 188, 800 394, 900 0 --30° C/S COOLING TOWER RISERS 1,440 30, 400 57,600 88, 000 0 --42° C/S CONDENSER PIPING 900 35, 000 36, 000 71,000 0 --60° BUTTERFLY VALVE 80 27,000 3, 200 30,200 . 0 --42° 4/0 BUTTERFLY VALVE 320 60, 000 12, 800 72,800 0 --30° M/O BUTTERFLY VALVE 320 52,000 12, 800 64, 800 0 --42° EXPANSION JOINT 480 15,000 19, 200 34, 200 o COOLING TOWER BASIN 11,613 117,700 464,520 582, 220 694 WATER WELLS 400 20, 000 16,000 36, 000 30 SUBTOTAL PIPING 71,537 61,057,600 $2, 861, 480 $3, 919, 080 724 FIRE PROTECTION SYSTEM --PIPING, STRUCTURE, & PUMP 2,000 40, 000 80, 000 120, 000 0 SUBTOTAL FPS 71,537 $1,057,600 $2, 861, 480 $3, 919, oao 724 SSssscessses oo ssseescssass oo ssasssssssss 0 sesssssessss 0 ssssssasasc= TOTAL COOLING SYSTEM 166, 645 $6, 665, 800 $9, 606, 000 1,448 $2, 940, 200 vd LIGIHX3 DIAMOND SHANROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA CUOMO * INSTRUMENTATION ‘ONT! CNOA ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TM) MAIN CONTROL PANEL COMPLETE 1,000 $250, 000 $40, 000 $290, 000 5s MAIN & AUX CONTROL BENCH 400 50, 000 16,000 66,000 5 LOGIC/RELAY CABINETS 300 300, 000 12, 000 312,000 5 COMPUTER & DIS. CON. SYSTEM 2,000 1,000, 000 80, 000 1,080, 000 10 STACK GAS MONITORING SYSTEM 4,500 75,000 60, 000 135, 000 6 VALVE CONTROLLERS 2, 400 120, 000 96, 000 216, 000 38 LOCAL CONTROL PAWELS 1,000 250, 000 40, 000 290, 000 13 FLD. MT. PRESSURE INSTRUMENTS 3, 200 240, 000 128, 000 368, 000 10 FLD. MT. FLOW INSTRUMENTS 1,600 90, 000 64,000 154,000 5s FLD. MT. TEMP. INSTRUMENTS 2, 400 160, 000 96, 000 256, 000 10 FLD. MT. LEVEL INSTRUMENTS 800 70, 000 32, 000 102, 000 3 FLD. MT. H20 & CHEM INSTRUMENT 1,200 45,000 48,000 93, 000 2 FLD. MT. THERMOCOUPLES 1,600 100, 000 64,000 164, 000 3 SOLONOID VALVES 4,000 150, 000 160, 000 310, 000 6 THERMOMETER & GAUGES 3, 200 40, 000 128, 000 168, 000 2 1/2° BALL VALVE, BRONZE 4,000 12,500 160, 000 172, 500 2 PRESSURE REGULATOR W/FILTER 800 15, 000 32,000 47,000 3 CU & SS TUBING 12,000 100, 000 480, 000 580, 000 5 INSTRUMENT/VALVE RACKS 600 15, 000 24,000 39, 000 4 MISC. MTGS. & SUPPORTS 4,000 25, 000 160, 000 185, 000 4 Sseeesssssss 0 ssessessssss 9 ssasssszszss 0 seesssssssss 0 senaeeeasscs TOTAL IT&C 48, 000 $3, 107, 500 $1, 920,000 $5, 027, 500 141 G°d LIGIHX43 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA eeenennnne « PIPING « Oeneaneane ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TM) PROCESS ~-LARGE BORE-W/FTGS, VLVS, HNGRS 277, 380 4, 968, 000 $11,095, 200 $16, 063, 200 1, 387 --SMALL BORE-W/FTGS, VLVS, HNGRS 54,650 372, 600 2, 186, 000 2,558,600" ~ 95 PLUMBING - --PIPE 3, 200 48,000 128,000 176, 000 6 ~-FIXTURES 600 45,000 24,000 69, 000 6 FIRE PROTECTION --PIPE & FIXTURES 42, 000 70, 000 1,680, 000 1, 750, 000 18 --AUTOMATIC SPRINKLER SYSTEM 2,857 20, 000 114, 280 134, 280 4 --SHOKE DETECTORS S14 2,000 20, 560 22,560 1 ~-CONVEYOR SPRINKLER SYSTEM 2,657 25, 000 114, 280 139, 280 14 ROOF DRAINS 4,200 21,000 168, 000 189, 000 6 SSSSSS 00 Seeaeeescses oo sassasssssss 0 sessaassssss 0 sasseuesecas TOTAL PIPING 388, 258 $5, 571,600 $15, 530, 320 $21, 101, 920 1,547 MOCCCOR CONCRETE 9° LIGIHX4 DIAMOND SHANROCK/VOSS FEASIBILITY STUDY 150 Ma COAL FIRED PLANT CHUITNA, ALASKA 08 41,000 Py Year 1 Year 2 Year 3 Year 4 Year 5 ITEM DESCRIPTION Ist end ad 4th Ist 2nd aed Ath Ast 2nd ard 4th Ist 2nd aed 4th ist 2nd ard 4th MATERIAL «LABOR = TOTAL STEAM GENERATOR 1,900 3,950 5,90 | 5,340 90 «1,980 4,958 2,978 98 $19,800 $9,900 $29, 700 TURBINE GENERATOR 1,100 2,200 (3,388 3, 300 376 1, 852 564 168 $11,000 $1,088 $12,660 DRY SOe & FABRIC FILTER 5,529 4,423 2,720 «2,728 «2,728 2 $11,057 $9,065 $28, 122 COAL HANDLING 1,146 1,433 HD 103 $2,065 $1,831 $4,696 WECHANICAL EQUIPMENT 713% 5,707,427 988 988 24s as $14,267 $2,449 $16,716 ELECTRICAL EQUIPMENT 978 «= 978,257 2,092) 1,813,133 STB $4,892 $5,567 $10,459 INSTRUMENTATION & CONTROL 621 621 71,085 9 wa aA 384 $3,107 $1,928 $5,027 STTEWORK 68 612 612 68 . $332 $1,027 $1,359 CIVIL/STRUCTURAL-BLDGS. 4,697 = 4,697 3132 3,132 $8,491 $7,167 $15,658 CHIMNEY & FOUNDATION 136 678 He $581 $774 $1,355 COOLING SYSTEM/ TOWERS 1,764 SBR 2,588 2,666 (2,000 $2,940 $6,666 $9,606 PIPING 1,672 1,672 1,672 2118 3,186 4,659 4,659 1,553 $5,572 $15,539 $21, 182 SUBTOTAL 0 6 e 6 68 8,389 12,615 12,504 13,795 6,269 18,528 16,574 7,468 15,118 13,700 11,559 8,414 3,017 62 @ $84,904 $63,776 $148,600 FRI. BSPEC. HNDLNG@$250/TON 4,369 1,349 1,349 1,798 458 899 699 699 $5,871 $3,128 $8,991 CONSTR. INDIRECT COSTS 2,006 4,676 6,681 6,681 «6,681 = 6,681 =, 6B1 5,345 53454008 4,008,388 3,388 1,336 $66,007 $66,007 BOARD & LODGING 292 680 72 a2 972 972 a2 ™m™ ™ 583 583 486 486 194 $9,718 $9,718 ENGR. ENVIR. PERMITALICEN. 700 1,400 1,688 © 2,880 «2,880 2,248 1,680 = 700 ‘ $14,000 $14, 000 CONSTR. MGMT. & OWNERS COST 23 321 45 45 TAS m5 m5 3% 396 447 447 we a 449 $7,446 $7,446 CONTINGENCY @ 25% 175 EN] 420 78 73,624 5,388) 5,738 5,998 93,779 6,956 6, 468 3,771 5,459 4,685 414931531, BO 385, @ $63,911 $63, 911 SUBTOTAL 875 «1,750 2,108) 3,583,517 «9,732 14,287 16,183 16,193 12,625 16,252 15,764 11,388 12,177 TOTAL PROJECT-"85 $ $875 $1,758 $2,108 $3,500 $3,585 $16,121 $26,982 $28,688 $29,988 $10,494 $34,788 $32,338 $18,856 $27,295 eeESS REO OEEOEE aaneneed EERE EO OEE EE: 2£°G LIGIHX4 456/10A3523-7/D3 APPENDIX E DETAILED DEVELOPMENT OF BELUGA POWER COSTS ALASKA POWER PROJECT CAPITALIZATION EQUITY PREFERRED STOCK CONVENTIONAL BONDS ENERGY DEVELOPMENT BONDS OTHER LONG TERM DEBT TOTAL CAPITALIZATION TAX BASIS PROJECT COST EXCLUDING IDC ($000) NON-DEPRECIABLE INVESTMENT (LAND) SALVAGE FACTOR PERSONAL PROPERTY-% REAL PROPERTY-% PERSONAL PROPERTY TAX LIFE CACRS) INVESTMENT TAX CREDIT-%" ENERGY TAX CREDIT-% EQUITY PARTICIPANTS TAX BRACKET-% STATE INCOME TAX RATE-% FEDERAL INCOME TAX RATE-% MISCELLANEOUS DATA PROJECT COST INCLUDING IDC ($000) AVERAGE (BOOK) SERVICE LIFE PROPERTY TAX RATE (PCT OF PLANT) GROSS RECEIPTS TAX RATE BASE YEAR FOR PRESENT WORTH DISCOUNT RATE APPLIED PLANT OUTPUT-GIGANATTHOURS(GWH) —~_ ITEM 1001 1002 1003 1004 1005 1000 ITEM 291 161 306 1038 1039 303 1033 1034 1037 1194 1195 404 299 1094 1095 150 1054 160 OEBT/ EQUITY FUNDING ieivivizizvi-isisizizis) aOOanan BHOONMNSCo (M56 Ul, 85-01-21 09.34) SUMMARY OF ASSUMPTIONS AND OTHER INPUT DATA FOR THIS CASE TOTAL AMOUNT ($000) 135296 399400 0 532600 TOTAL PERCENT OF TOTAL 25.01 0.0 74.99 0.0 100.00 ANNUAL REQUIRED TERM PAYMENT COST COVERAGE CYEARS) PERIODS x 20.00 0.0 0.0 0 0.0 0.0 0.0 0 12.00 1.00 30.0 0 0.0 0.0 0.0 Qo —0.0 oo oo | | oS} o| o r) o} o} o| Page / ALASKA PONER PROJECT ($000) NET PROCEEDS AVAILABLE BEGINNING OF PERIOD CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS ENERGY DEVELOPHENT BONDS OTHER LONG TERN DEBT TOTAL NEW CAPITAL CONSTRUCTION LOANS TOTAL PROCEEDS AVAILABLE UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES START-UP COSTS (CAPITALIZED) PROPERTY TAXES (CAPITALIZED) FUEL STOCK AND OTHER INVENTORY FINANCING COSTS REPAYNENT OF CONSTRUCTION LOANS DEPOSIT-DEBT SERVICE RESERVE FUND PREFERRED STOCK DIVIDENDS TOTAL UTILIZATION BALANCE ON DEPOSIT INTEREST EARNED TOTAL AVAILABLE FOR INTEREST CHARGES INTEREST CHARGES CONSTRUCTION LOANS CONVENTIONAL BONDS ENERGY DEVELOPMENT BONDS OTHER LONG TERN DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD EES EEK TE KEE INTEREST CHARGED TO CONSTRUCTION TOTAL ANOUNT CAPITALIZED CUMULATIVE ANOUNT CAPITALIZED HEH DE HE HE SE DE EE EERE TAX BENEFITS TAX EFFECT OF INTEREST EARNED TAX EFFECT OF INTEREST PAYNENTS (NET OF CAPITALIZED INTEREST ON REAL PROPERTY) INVESTHENT TAX CREDIT ENERGY PROPERTY CREDIT TOTAL : CUMULATIVE TAX BENEFITS CUMULATIVE EQUITY 10 ll 31 12 13 14 15 1 40 61 62 63 64 65 91 92 93 79 80 81 82 83 182 AOOAARAHAA O OH0aMF A AAA A AN AMON OKHOKHO aon E000 Oo DIAMOND SHAMROCK/VOSS INT. CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 85-01-18 15.29) 1986 198, 0 58 19 5 0 10 38 48 92 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000 0 2400 00 0 40 21400 __ 32700 _ 36200 __9470 1000 1958 2419 4105 9400 4410 — 21438 — 32748 36292 — 9471 914 1855 2259 3820 8847 3970 «20361 30671 33187 8818. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 914 1855 2259 3820 8847 3970 20361 30671 33187 8818 86 103 160 285 553 441 1077 2077 3105 652 2 3 4 7 16 ll 27 52 78 16 88 106 164 292 568 452 1104 2129 3183 669 30 87 159 282 558 414 1056 2037 3123 663 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 0 0 0 0 0 0 0 0 0 0 30 87 159 282 558 414 1056 2037 3123 663 58 19 5 10 10 38 LT) 92 60 6 15 46 85: 151 297 221 566 1092 1674 355: 929 1901 2344 3971 9145 4191 20927 31763 34861 9174 929 2830 5174 9145 9145 13336 34263 66026 100887 10088 -1 -1 -2 -3 -7 -5 -12 -26 -36 -7 13 33 70 124 245 182 463 893 1371 290: 69 141 172 290 672 302 1547 2331 2522 670: 0 0 Q 0 0 0 0 0 0 82 178 240 411 910 479 1998 3200 3857 953: 82 260 499 910 1750 1388 3386 6585 10444 2180: RETURN ON EQUITY TO DATE ALASKA POWER PROJECT CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 185 C DIAMOND SHAMROCK/VOSS INT. CONTINUATION ITEM 20 875 1750 2100 3500 C M54 1986 8225 ul, 85-01-18 15.29) 3585 = =18121 26902 28688 PAGE 2A 1987 77296 ALASKA PONER PROJECT ($000) ITEM NET PROCEEDS AVAILABLE BEGINNING OF PE 10 CAPITAL FUNDING: EQUITY ll PREFERRED STOCK 31 CONVENTIONAL BONDS 12 ENERGY DEVELOPMENT BONDS 13 OTHER LONG TERM DEBT 14 TOTAL NEW CAPITAL 15 CONSTRUCTION LOANS 1 TOTAL PROCEEDS AVAILABLE 40 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES 20 START-UP COSTS (CAPITALIZED) 48 PROPERTY TAXES (CAPITALIZED) 53 FUEL STOCK AND OTHER INVENTORY 30 FINANCING COSTS . 21 REPAYiiENT OF CONSTRUCTION LOANS 38 DEPOSIT-DEBT SERVICE RESERVE FUND 52 PREFERRED STOCK DIVIDENDS 70 TOTAL UTILIZATION 50 BALANCE ON DEPOSIT 3 INTEREST EARNED 4 TOTAL AVAILABLE FOR INTEREST CHARGES 5 INTEREST CHARGES CONSTRUCTION LOANS 61 CONVENTIONAL BONDS 62 ENERGY DEVELOPMENT BONDS 63 OTHER LONG TERM DEBT 64 TOTAL INTEREST CHARGES 65 NET P EEDS AVAILABLE END OF PERIOD 7 HEH BEEK RK SE INTEREST CHARGED TO CONSTRUCTION “91 TOTAL AliOUNT CAPITALIZED 92 ““CUMULATIVE AMOUNT CAPITALIZED 93 HX 2E EN IER IER TAX BENEFITS TAX EFFECT OF INTEREST EARNED 79 TAX EFFECT OF INTEREST PAYMENTS (NET OF CAPITALIZED INTEREST ON REAL PROPE 80 INVESTNENT TAX CREDIT 81 ENERGY PROPERTY CREDIT 82 TOTAL 83 CUMULATIVE TAX BENEFITS 182 CUHULATIVE EQUITY 26 DIAMOND SHAMROCK/VOSS INT. CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD AHAAHAAHAOAN OE 85-01-18 15.29) 2099 A AAEAND A AA AAOOOKHOHO aa Anan - 1988 60 2 2 60 38 23 8 38 38 0 0 0 0 Q 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 _ 0 0 0 0 0 0 0 0 0 0 0 0 0 39400 _ 27500 _ 48400 __ 47500 _162800 200 500 _ 41300 _ 39400 _157400 39460 27562 48455 47502 162860 32238 44523 41308 39438 157438 35200 «22503 «= 42031 «39654 «139388 23461 34459 30005 «= 26966 =—-114891 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 4260 7849 23472 8777 10064 11303 12473 42547 107 196 590 219 252 283 312 4367 8045 24062 8996 10316 11585 12784 43612 4305 8007 24024 8973 10308 11547 12729 43557 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4305 8007 24024 8973 10308 11547 — 12729 43557 62 38 38 23 8 38 55 2307 4281 123853 4776 5498 6146 6762 23182 37506 25243 45556 43935 152241 28237 39958 3615] 33728 138073 138393 163636 209192 253127 253127 281365 321322 357473 391200 391200 -49 -90 -271 -101 -116 -130 -143 1892 3529 10582 3977 4558 5119 5655 19309 2675 3014 = 10593 1783 2619 2280 2049 0 0 0 0 0 0 0 0 4518 6453 20904 5659 7061 7269 756) 27551 14962 18877 24894 31347 90081 37007 44068 =52337 «58398 191320 PAGE 2B 4 RETURN ON EQUITY TO DATE 185 C ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS INT. (M54 Ul, 85-01-18 15.29) PAGE 2B CONTINUATION ITEM 1988 1989 CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 20 29988 18894 34780 32338 116000 18856 27295 23423 20746 90320 ALASKA POUIER PROJECT ($000) NET PROCEEDS AVAILABLE BEGINNING OF PERIOD CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS ENERGY DEVELOPMENT BONDS OTHER LONG TERM DEBT TOTAL NEW CAPITAL CONSTRUCTION LOAKS TOTAL PROCEEDS AVAILABLE UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES START-UP COSTS (CAPITALIZED) PROPERTY TAXES (CAPITALIZED) FUEL STOCK AND OTHER INVENTORY FINANCING COSTS REPAYNENT OF CONSTRUCTION LOANS DEPOSIT-DEBT SERVICE RESERVE FUND PREFERRED STOCK DIVIDENDS TOTAL UTILIZATION BALANCE ON DEPOSIT INTEREST EARNED TOTAL AVAILABLE FOR INTEREST CHARGES INTEREST CRARGES CONSTRUCTION LOANS CONVENTIONAL BONDS ENERGY DEVELOPNENT BONDS OTHER LONG TERM DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD HEE IEE EK HED IEEE INTEREST CHARGED TO CONSTRUCTION TOTAL ANOUHT CAPITALIZED CUMULATIVE ANOUNT CAPITALIZED 3X EKG EK TAX BENEFITS TAX EFFECT OF INTEREST EARNED TAX EFFECT OF INTEREST PAYHENTS (NET OF CAPITALIZED INTEREST ON REAL PROPERTY) INVESTNENT TAX CREDIT — ENERGY PROPERTY CREDIT = TOTAL CUMULATIVE TAX BENEFITS CUMULATIVE EQUITY ITEM 10 79 80 81 82 83 182 26 AQOAHAANHAHAHAN AO aOR 29 AHAA00O A AM AANMNNHOKHO on O|A002 2 DIAMOND SHAMROCK/VOSS INT. C M54 CAPITALIZATION SCHEDULE AND UTILIZATION : OF PROCEEDS DURING CONSTRUCTION PERIOD 1990 55 45 88 78 55 0 Q Q 133200 133200 0 0 0 0 0 0 0 0 399400 399400 0 0 0 0 0 io a a as a | vant get rut CL Bt 34255 26345 = 17388 «6549178 §=626955 20792 12069 2617 1378 36856 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 13979 13979 0 0 0 518600 518600 0 0 0 0 0 0 0 0 0 20792 =12069 2617 «533957 569435 13463 14276 14772 15221 57521 337 357 369 381 1443 13800 14632 15141 15602 58964 13755 14544 15063 15558 58920 0 0 0 0 0 0 0 0 0 0 0 0 0 0 13755 14544 15063 15558 58920 45 88 78 44 44 7283° 7650 7817 13017 35767 28075 19720 10433 14394 72623 419276 438995 449429 463823 463823 -155 164 -170 “175 664 6135 6537 6877 7156 26705 1580 917 199 105 2801 0 0 0 0 a 7561 7290 6906 7085 28842 66459 73749 = =80655 87740 308603 133200 133200 ul, 85-01-18 15.29) PAGE 2C RETURN ON EQUITY TO DATE ALASKA PONER PROJECT CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 185 C DIAMOND SHAMROCK/VOSS INT. CONTINUATION ITEM 20 15765 9019 1927 65.9 65.9 C M54 1990 1000 8 27711 Ul, 85-01-18 15.29) PAGE 2c el -. ~, du ALASKA POWER PROJECT ($000) ITEM OPERATING REVENUES PROJECT REVENUE REQUIREMENT 1 SALES OF ELECTRICITY 2 AVOIDED COST OF ELEC. 17 TOTAL 3 OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST 4 OPERATION & MAINTENANCE EXPENSE 6 TOTAL O&M : 8 LEASE EXPENSE 27 DEPRECIATION EXPENSE 9 PROPERTY TAX 94 GROSS RECEIPTS TAX 95 TOTAL OPERATING EXPENSES 10 OPERATING INCOME 90 GQTHER INCOME AND EXPENSES ll INCOME BEFORE INTEREST CHARGES 12 INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS 13 ENERGY DEVELOPMENT BONDS 14 OTHER LONG TERM DEBT 15 SUBTOTAL 16 OTHER INTEREST & EXPENSES ANORTIZED BOND DISCOUNT & EXPENSES 18 SHORT TERM LOANS 19 INTEREST DURING CONSTRUCTION 20 SUBTOTAL 21 TOTAL INTEREST AND OTHER EXPENSES 22 NET INCOME 23 969 HII IK IO IO COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT WORTH DOLLARS 163 LEVELIZED “ANOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUMULATIVE PRESENT WORTH AS = THAT RESULTING FROM THE ACTUAL = ANNUAL AMOUNTS CALCULATED 159 c c c c isisisizioiziziz) ao °o 7 ao HAAN A200 c sag, a —_ —_ i — — _. a 7 s « M56 Ul, 85-01-21 09.34) PAGE 3A FORECASTED STATEMENT OF INCOME 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 112234 95113 101531 112595 =:115751 119111 126744 130565 134639 138986 0 0 0 0 0 0 0 _ 0 8 0 112234 95113 101531 112595 115751 119111 126744 130565 134639 138986 15320 1ees9 17214 td) eH Bet 21732 aoeoe otale 25883 — 2s —332 35213 940 sore #2953 atte Mere zene a LiL 60366 63984 S18e* 0 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 0 : 0 0 0 0 ° : 0 ; 0 55605 58014 60567 63273 66142 69183 72406 75823 79444 83283 56629 37099 40965 49322 49609 49928 54338 54742 55195 55703 “0 0 241 256 271 287 304 322 342 362 56629 37099 41206 49578 49880 50215 54642 55065 55536 56065 47883 47692 47478 47237 46967 46663 46321 45937 45506 45021 Q 0 0 0 0 0 0 , ° 0 47883 47692 47478 47237 46967 46663 46321 45937 45506 45021 466 466 466 466 466 466 466 466 466 466 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 66 6 46 46 46 46 466 466 66 466 48349 48158 497944 47703 47433 47129 46787 46403 45972 45487 8280 -11059 -6738 1875 2447 3087 7855, 8662 9565 10578 113.60 96.27 102.76 113.96 117.16 120.56 128.28 132.15 136.27 140.67 51.75 38.47 36.02 35.04 31.60 28.52 26.62 24.06 21.76 19.71 113.60 105.50 104.70 106.59 108.18 109.63 111.37 112.94 114.39 115.75 i ALASKA POWER PROJECT ($000) ITEM OPERATING REVENUES PROJECT REVENUE REQUIREMENT 1 SALES OF ELECTRICITY 2 AVOIDED COST OF ELEC. 17 TOTAL 3 OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST 4 OPERATION & MAINTENANCE EXPENSE 6 TOTAL O &N 8 LEASE EXPENSE 27 DEPRECIATION EXPENSE 9 PROPERTY TAX 94 GROSS RECEIPTS TAX 95 TOTAL OPERATING EXPENSES 10 OPERATING INCOME 90 QTHER INCOME AND EXPENSES ll INCOME BEFORE INTEREST CHARGES 12 INTEREST AND OTHER EXPENSES LONG TERN DEBT INTEREST CONVENTIONAL BONDS 13 ENERGY DEVELOPMENT BONDS 14 OTHER LONG TERM DEBT 15 SUBTOTAL 16 OTHER INTEREST & EXPENSES AMORTIZED BOND DISCOUNT & EXPENSES 18 SHORT TERM LOANS 19 INTEREST DURING CONSTRUCTION 20 SUBTOTAL 21 TOTAL INTEREST AND OTHER EXPENSES 22 NET INCOME 23 A100 OOK COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT WORTH DOLLARS 163 LEVELIZED ANOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUMULATIVE PRESENT WORTH AS ae THAT RESULTING FROM THE ACTUAL Ps ANNUAL AMOUNTS CALCULATED 159 Qa fF DF AHAMAOOKRQOOO a2 MHAQ0HQO NOAO c DIAMOND SHAMROCK/VOSS (M56 U1, 85-01-21 09.34) PAGE 3B FORECASTED STATEMENT OF INCOME 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 180087 185056 190347 196003 202049 208516 215436 222846 230777 239278 0 a oe | 180087 — 185054 190347 196003 202049 208516 215436 222844 230777 239279 27436 © 29082.~=—- 30827 32676 34637 36715-38918 4125343728 46352 71892 Has 80778 85626 90762 3208 101980 108099 114585 121460 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 0 0 0 0 0 0 0 0 0 0 87353 91666 96259 101085 — 106223 — 111668 — 117441 — 123560 130046 — 136921 92734 93388 94108 94917 95826 96848 97995 99284 100732 102358 384 407 431 457 484 513 544 577 612 648 73118 93794 94539 95374 96311 97361 98539 99861 101343 103007 44477 «43865 = 443178 «= 42405 = 41538 = 40563 = 339467 38236 36853-35299 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 44477 43865 43178 42405 41538 40563 39467 38236 36853 35299 466 466 466 466 466 466 466 466 466 466 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 66 466 466 466 466 66 466 66 466 466 44943 44331 43644 42871 42004 41029 39933 38702 37319 35765 48176 — 49463 — 50895 52503 _ 54307 _ 56333 _ 58606 61159 _ 64025 _ 67242 182.27 187.30 192.66 198.38 204.50 211.05 218.05 225.55 233.58 242.19 22.40 20.19 18.22 16.45 14.88 13.47 12.21 11.08 10.06 9.15 118.64 121,16 123.38 125.38 127.18 128.83 130.34 131.73 133.02 134.22 ALASKA POWER PROJECT ($000) OPERATING REVENUES PROJECT REVENUE REQUIREMENT SALES OF ELECTRICITY AVOIDED COST OF ELEC. TOTAL OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST OPERATION & MAINTENANCE EXPENSE TOTAL O& MN LEASE EXPENSE DEPRECIATION EXPENSE PROPERTY TAX GROSS RECEIPTS TAX TOTAL OPERATING EXPENSES OPERATING INCONE OTHER INCOME AND EXPENSES INCOME BEFORE INTEREST CHARGES INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS ENERGY DEVELOPNENT BONDS OTHER LONG TERM DEBT SUBTOTAL OTHER INTEREST & EXPENSES ANORTIZED BOND DISCOUNT & EXPENSE SHORT TERM LOANS INTEREST DURING CONSTRUCTION SUBTOTAL TOTAL INTEREST AND OTHER EXPENSES NET INCOME TH EK COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 1 IN PRESENT WORTH DOLLARS 1 LEVELIZED ANOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUMULATIVE PRESENT WORTH AS ae THAT RESULTING FROM THE ACTUAL - ANNUAL ANOUNTS CALCULATED i 65 63 59 c c c c Oo fF A AANEOFHAMO 2 AMMEN A000 * . 4 a - a] —_ —~? . - * DIAMOND SHAMROCK/VOSS (M56 «U2, 85-01-21 09.34) PAGE 3C FORECASTED STATEMENT OF INCOME 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 ean79) 258369 269065 LEE ont LELLFY Aa? SEALE S082 LEP 0 0 0 0 0 248791 258569 269063 280334 292446 305469 319481 334567 350820 368343 49133 52081 55206 58519 62030 65751 69697 73878 78311 83010 § 89455 94822 __100511 __106542 __112934 __119710 __ 126893 __134507 128748 TS6472 144661 153348 162541 172293 182651 193589 205204 217516 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 0 0 0 0 0 0 0 0 $ 0 144208 151933 160122 168801 178002 187754 198092 209049 220665 232977 104582 106636 108942 111533 114444 117715 121389 125518 130156 135366 687 729 772 819 868 920 975 1034 1096 1162 105270 107364 109714 112352 115312 118635 122365 126551 131251 136528 33553 31591 29386 26909 24126 20999 17485 13537 9102 4117 0 0 0 0 0 0 0 0 0 0 9 0 9 9 9 9 0 9 9 33553 31591 29386 26909 24126 20999 17485 13537 9102 $ll7 466 466 466 466 466 466 466 466 466 466 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 66 86 466 66 66 46 6 466 6 34019 32057 29852 27375 24592 21465 17951 14003 9568 4583 71251 75308 79862 84977 90720 97170 — 104413 __ 112548 _ 121684 _ 131945 251.81 261.71 272.33 283.74 296.00 309.18 323.36 338.63 355.08 372.82 8.35 7.61 6.95 6.35 5.81 5.32 4.88 4.49 4.13 3.80 135.34 136.39 137.37 138.30 139.16 139.98 140.75 141.47 142.16 142.80 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS C M56 Ul, 85-01-21 09.34) PAGE 4A NET WORKING CAPITAL CFUNDS) AVAILABLE ($000) ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME arapesae REVENUES n 7 112234 95113 101531 seo ae 115751 119111 126744 a oeree ete 138986 OTH CONE ieee, Scsiogcergre ll saeegigee OR, res ask pt a 8? et? sy? SUBTOTAL 37 ¢ 112234 95113 101773 11285 16022 119398 127048 130887 134981 139349 LESS INCONE THAT IS NOT CASH 38 I 0 0 0 0 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME 39 ¢ 112234 95113 101773 112851 116022 119398 127048 130887 134981 139349 LESS FUNDS APPLIED TO OPERATING EXPENSES u TOTAL OPERATING EXPENSES 10 ¢ 55605 58014 60567 63273 66142 69183 72406 75823 79444 83283 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 c 15461 15461 1546] 15461 15461 15461 15461 15461 15461 15461 FUNDS APPLIED TO OPERATING EXPENSE 42 C 40144 42553 45106 47812 50681 53722 56945 60362 63984 67823 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 Cc 72090 52560 56667 65038 65341 65676 70103 70525 70997 71526 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 ENERGY DEVELOPNENT BONDS 45 1 0 0 0 0 0 0 Qo 0 0 0 TEarGek® SN ia) ae ee M G a 8} 0 0 0 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 Cc ~47 2196 131 138 148 157 165 176 187 198 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 c¢ 1.46 1.06 1.15 1.32 1.32 1.33 1.42 1.43 1.44 1.45 CHER Lone ToR WEB 22 c 0.0 a6 g.0 0.0 0 ° 0.0 0.0 0.0 0.0 0.0 Cc 0.0 .0 oO. 0.0 0. 0.0 0.0 0.0 0.0 0.0 TOTAL DEBT 54 ¢ 1.46 1.06 1.15 1.32 1.32 1.33 1.42 1.43 1.44 1.45 ud ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS ¢ M56 Ul, 85-01-21 09.34) PAGE 4B NET WORKING CAPITAL CFUNDS) AVAILABLE ($000) ITEM 2001 2002 © 2003 2004 2005 2006 2007 2008 2009 2010 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES . i € 180087 185054 190347 196083 202049 208516 215436 222844 230777 ree OTHER INCO 407 431 457 484 513 544 577 12648 SUBTOTAL 37 ¢ 180471 185460 90778 196459 202533 209030 215980 223421 231389 239927 LESS INCOME THAT IS NOT CASH 381 Q 0 0 Qo 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME 39.¢ 180471 185460 190778 196459 202533 209030 215980 223421 231389 239927 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 1 87353 91666 96239 101085 106223 111668 117441 123560 130046 136921 oc LESS: SAE ES tay REQUIRING ErEMPT ee ae 545 5 Pr A eae FUNDS APPLIED TO OPERATING EXPENSE 42 C 71892 76205 80778 B3e5t 90762 96208 101980 108099 114585 121460 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43. C 108579 109255 110000 110835 111772 112822 114000 115322 116804 118468 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 49426 49426 §=— 449426 = 49426 = 49426 = 49426 «= 49426 «= 49426 «= 49426 49426 ENERGY DEVELOPMENT BONDS 45 1 0 0 0 0 0 0 0 0 0 0 TEHPORARY BORROWINGS a7 1 0 0 0 0 Q 0 Q H 1 0 : 0 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C 49426 49426 49426 45426 49426 49426 49426 49426 49426 49436 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 ¢ 204 222 236 250 265 280 297 315 334 354 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 ¢ 2.20 2.21 2.23 2.24 2.26 2.28 2.31 2.33 2.36 2.40 ENERGY DEVELOPIIENT BONDS 52 ¢ 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ER LON 0 0:0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 TOTAL DEBT 54 ¢ 2.20 2.21 2.23 2.24 2.26 2.28 2.31 2.33 2.36 2.40 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS C M56 U2, 85-01-21 09.34) PAGE 4C NET WORKING CAPITAL CFUNDS) AVAILABLE ($000) : ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCONE OPERATING REVENUES 3 C 248791 258569 269063 280334 292446 305469 319481 334567 350820 368343 OTHER INCOME llc 687 729 772 819 868 920 975 1934 1096 1162 SUBTOTAL 37 © = 249478 259297 269836 281153 293314 06389 320456 35601 351916 369505 LESS INCOME THAT IS NOT CASH 38 I 0 0 0 0 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME 39 C 9249478 259297 269836 281153 = 293314 306389 320456 335601 351916 369505 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES loc 144208 151933 160122 168801 178002 187754 198092 209049 220665 232977 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 c 15461) ___1546) ___15461 ___15461 ___15461 ___15461 ___15461 ___15461 ___15461 ___15461 FUNDS APPLIED TO OPERATING EXPENS 42 C 128748 © 136472 144661 153340 = 162541 172293 = 182631 193589 =205204 =6217516 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 C 120730 122825 125175 127813 130773 134096 137825 142012 146712 151989 FUNDS APPLIED TO DEBT SERVICE . CONVENTIONAL BONDS 441 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 ENERGY DEVELOPMENT BONDS 45 1 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 46 1. 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 1 0 oO oO 0 0 0 o 0 0 0 TOTAL FUNDS APPLIED TO DEBT SERVI 48 C 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 Cc 375 398 422 447 474 502 532 564 598 634 DEBT SERVICE COVERAGE . CONVENTIONAL BONDS 51 Cc 2.44 2.49 2.53 2.59 2.65 2.71 2.79 2.87 2.97 3.08 ENERGY DEVELOPMENT BONDS 52 C¢ 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 OTHER LONG TERM DEBT 53 c__ 0.0 _ 6.0 _ 0.0 0.0 _ 0,0 0.0 0.0 _ 0.0 0.0 0.0 TOTAL DEBT 54 C¢ 2.44 2.49 2.53 2.59 2.65 2.71 2.79 2.87 2.97 3.08 uf ALASKA POWER PROJECT ($000) BEGINNING CASH BALANCE PLUS FUNDS GENERATED NET INCONE ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS INTEREST & OTHER EXPENSE TOTAL FUNDS GENERATED DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS START-UP COSTS FINANCING COSTS WORKING CAPITAL INCREASES CONSTRUCTION REQUIREMENTS DISTRIBUTION TO PARTNERS TOTAL FUNDS USED PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT TEMPORARY FINANCING BORROWED REPAID CASH RECEIPTS FROM FINANCING NET CASH BEFORE FUNDING DEBT SERVICE RESERVE FUND DEPOSITS DRAWDOWNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRANDOWNS NET ACCRUAL ENDING CASH BALANCE ITEM 60 23 61 22 62 248 56 135 63 64 360 65 66 76 77 78 79 67 68 69 70 71 72 74 aon oO feizvizviziolols) a anon Oo aoe aon c NOTE: OPERATING REVENUES WERE INCREASED BY THESE AMOUNTS SO THAT CASH BALANCES DO NOT ..DROP BELOW 30 DAYS O&M EXPENSE. 75 c DIAMOND SHAMROCK/VOSS (M56 Ul, 85-01-21 09.34) PAGE 5A ANALYSIS OF CASH & ANNUAL CASH BALANCES 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 44 -3 2193 2323 2461 2609 2766 2931 3107 3294 8280 -11059 -6738 1875 2447 3087 7855 8662 9565 10578 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 349 815 47703 0 597 548 72090 52560 56667 65038 65341 65676 70103 70525 70997 71526 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 — 15474 —}irss ——16093 ___20511 ___20923 ___ 21384 ___21902 72137 50364 56536 64900 5193 65519 69938 70349 70811 71328 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8D o_o o_o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 =3 2193 2325 2461 2609 2766 2931 3107 3294 3492 o a a a a o a a a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 0 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0 0 0 ——__=3 ___ 2193 ___2323 ___ 2461 ___ 2609 ____ 2766 ___— 2931 3107 ___ 3294 __ 3492 22663 3134 7240 15612 15914 16250 20677 21099 21571 22100 ALASKA POWER PROJECT ($000) BEGINNING CASH BALANCE PLUS FUNDS GENERATED NET INCOME ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS INTEREST & OTHER EXPENSE TOTAL FUNDS GENERATED DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS START-UP COSTS FINANCING COSTS WORKING CAPITAL INCREASES CONSTRUCTION REQUIRENENTS DISTRIBUTION TO PARTNERS TOTAL FUNDS USED PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT TEMPORARY FINANCING BORROWED REPAID CASH RECEIPTS FROM FINANCING NET CASH BEFORE FUNDING DEBT SERVICE RESERVE FUND DEPOSITS DRAWDOWNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRANDOWNS NET ACCRUAL ENDING CASH BALANCE ITEM 60 66 76 77 78 79 67 68 69 70 71 72 74 Oo [nn A OOOOH aoa aao c c c c NOTE: OPERATING REVENUES WERE INCREASED BY THESE AMOUNTS SO THAT CASH BALANCES DO NOT DROP BELON 30 DAYS O&M EXPENSE. 75 c 1 =, a -9 os — aa a = a a « DIAMOND SHAMROCK/VOSS (M56 Ul, 85-01-21 09.34) PAGE 5B ANALYSIS OF CASH & ANNUAL CASH BALANCES 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 3492 3696 3918 4153 4403 4667 4948 5245 5560 5894 48176 49463 50895 52503 54307 56333 58606 61159 64025 67242 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 9 33 436 2: 00 lo 3993 0 37319 35 108579 ~ 109255 ~-110000 — 110835 — 111772 ~ 112822 ~ 114000 — 115322 116804 118468 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 8 38 9 0 1 63 H 78 80 670 4 63687 8 108375 ~ 109033 — 109764 110585 111507 Tissei 113703 — 115006 116470 — 118114 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3696 3918 4153 4403 4667 4948 5245 5560 5894 6248 g a a a Q a a g a 0 0 0 — 4 0 0 __ 0 0 oo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3696 3918 4153 4403 4667 4948 5245 5560 589 6248 59153 59829 60573 61409 62345 63396 64574 65895 67378 69041 ALASKA POWER PROJECT ($000) BEGINNING CASH BALANCE PLUS FUNDS GENERATED NET INCOME ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS INTEREST & OTHER EXPENSE TOTAL FUNDS GENERATED DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS START-UP COSTS FINANCING COSTS WORKING CAPITAL INCREASES CONSTRUCTION REQUIREMENTS DISTRIBUTION TO PARTNERS TOTAL FUNDS USED PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT TEMPORARY FINANCING BORROWED REPAID CASH RECEIPTS FROM FINANCING NET CASH BEFORE FUNDING DEBT SERVICE RESERVE FUND DEPOSITS DRALDOLWNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRAWDOWNS NET ACCRUAL ENDING CASH BALANCE ITEM 60 23 61 22 62 248 56 135 64 360 67 68 69 70 71 72 74 NOTE: OPERATING REVENUES WERE INCREASED THESE ANOUNTS SO THAT CASH BALANCES DO NOT DROP BELON 30 DAYS O&M EXPENSE. 75 c c c c c OOOOH ao eHAn Oo aoc c c c c BY c a a = 4 a -* al ~*~ -~ = « ‘ DIAMOND SHAMROCK/VOSS © M56 -U2, 85-01-21 09.34) PAGE 5C ANALYSIS OF CASH & ANNUAL CASH BALANCES 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 6248 6624 7021 7443 7890 8363 8865 9398 9962 10559 71251 75308 79862 84977 90720 97170 «104413 112548 121684 131945 15461 15861 1586) 15961 15461 15461 15461 13461 15463 et 120730 35835 i i i i? 409 a3 Ht 146712 — 151989 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q 0 3 3 1 75327 3 0 3 87869 2 6688 101929 120355 122427 — 124753 ~ 127366 ts 133594 ~ 137293 — 141448 — 146114 — 151355 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 serie iuniepcena 9 9 0 0 0 9 0 0 0 0 0 0 0 0 0 0 0 0 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 g a Q a a Q Q a a a 0 0 0 0 0 09 oO. 0. oO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 9 9 9 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ——_-6624 ___7021 ___ 7443 ___ 7890 ___ 8363 ___ 8865 ___—9398 ___— 9962 0559 __ 11193 71304 73399 75749 78386 81347 84669 88399 92586 97286 102562 ALASKA PONER PROJECT ($000) ASSETS PLANT IN SERVICE CONSTRUCTION WORK IN PROGRESS LESS: ACCUMULATED DEPRECIATION NET PLANT CURRENT ASSETS CASH MATERIALS & SUPPLIES OTHER CURRENT ASSETS TOTAL CURRENT ASSETS DEBT SERVICE RESERVE FUND UNAMORTIZED DEBT DISCOUNT & EXPENSE TOTAL ASSETS LIABILITIES EQUITY CAPITAL RETAINED EARNINGS BALANCE, BEGINNING OF PERIOD NET INCOME FOR THE PERIOD DIVIDENDS-PREFERRED STOCK DIVIDENDS-COMMON STOCK BALANCE,END OF PERIOD PREFERRED STOCK LONG TERM DEBT CONVENTIONAL BONDS ENERGY DEVELOPNENT BONDS OTHER LONG TERM DEBT TOTAL LONG TERM DEBT CURRENT LIABILITIES SHORT TERM LOANS CURRENT PORTION OF LONG TERM DEBT OTHER CURRENT LIABILITIES TOTAL CURRENT LIABILITIES DEFERRED CREDITS DEFERRED INCONE TAXES ~=DEFERRED INVESTNENT TAX CREDITS TOTAL DEFERRED CREDITS TOTAL LIABILITIES ITEM 404 398 399 400 74 411 412 413 405 409 410 421 419 23 423 420 ' 427 431 432 433 430 439 441 442 440 443 444 445 450 c I c c 20 8 AHOO o a aHannag aoan a fA OFF OO 7 ~ - -— — ~ “ * a = ~ . DIAMOND SHAMROCK/VOSS (M56 Ul, 85-01-21 09.34) PAGE 6A BALANCE SHEET 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 463825 463825 Agsazs 463825 s6305 s63828 463823 $63825 463823 463823 0 0 0 6 3 2 108225 __123686 __139147 __ 154608 448362 432902 417441 401980 386519 371059 ~~ 355598 ~~ 340137 ~~ 324676 = 3309215 -3 2193 2323 2461 2609 2766 2931 3107 3294 3492 0 0 0 0 0 0 0 0 0 0 ccnticciekietll scone a ee =3 2193 2323 2461 2609 2766 2931 3107 3294 3492 0 0 0 0 0 0 0 0 0 0 13979 13513 047 12581 12115 11649 11183 10717 025 9785 462338 _ 448607 _ 432811 _ 417023 _ 401244 _ 385474 _ 369712 _ 353962 _ 338221 _ 322492 133200 =133200 «133200 133200 133200 133200 133200 133200 133200 133200 -54288 -68719 -80715 -94563 -108163 -121482 -134488 -147144 ~-159406 -171225 8280 -11059 -6738 1875 2447 3087 7855 8662 9565 10578 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -68719 = -80715 === 94563 =-108163 -121482 -134488 -147144 ~-159406 -171225 -182549 0 0 0 0 0 0 0 0 0 0 396123 394174 «6391985 9389525 386762 383656 380167 376247 371842 366892 0 0 . 0 0 0 0 0 0 0 0 sO ae 0 0 0 ie 396123 394174 ~ 391985 389525 386762 ~—«383656 ~=—SBO167 ~=—S3 76247 ~—*371842 (566892 0 0 0 0 0 0 0 0 0 0 1734 1948 2189 2460 2764 3105 3489 3920 4405 4949 0 0 0 0 0 0 0 0 “0 0 1734 1948 2189 2460 2764 3105 3489 3920 4405 4949 0 0 0 0 0 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 462338 _ 448607 _ 432811 417023 401244 — 385474 _ 369712 _ 353962 _ 338221 _ 322492 ALASKA POWER PROJECT ($000) ASSETS PLANT IN SERVICE CONSTRUCTION WORK IN PROGRESS LESS:ACCUMULATED DEPRECIATION NET PLANT CURRENT ASSETS CASH MATERIALS & SUPPLIES OTHER CURRENT ASSETS TOTAL CURRENT ASSETS DEBT SERVICE RESERVE FUND UNAMORTIZED DEBT DISCOUNT & EXPENSE TOTAL ASSETS LIABILITIES EQUITY CAPITAL RETAINED EARNINGS BALANCE, BEGINNING OF PERIOD NET INCONE FOR THE PERIOD DIVIDENDS-PREFERRED STOCK DIVIDENDS-COMNMNON STOCK BALANCE,END OF PERIOD PREFERRED STOCK LONG TERM DEBT CONVENTIONAL BONDS ENERGY DEVELOPMENT BONDS OTHER LONG TERM DEBT TOTAL LONG TERM DEBT CURRENT LIABILITIES SHORT TERN LOANS CURRENT PORTION OF LONG TERM DEBT OTHER CURRENT LIABILITIES TOTAL CURRENT LIABILITIES DEFERRED CREDITS _DEFERRED INCGNE TAXES =DEFERRED INVESTMENT TAX CREDITS TOTAL DEFERRED CREDITS TOTAL LIABILITIES ITEM 404 398 399 400 74 411 412 413 405 409 410 421 419 423 424 420 427 431 432 433 430 439 441 442 440 443 444 445 450 c I c c 202 2 ORO c c c c c c c c c c c Oo 800 OMe OO DIAMOND SHAMROCK/VOSS C M56 Ul, 85-01-21 09.34) PAGE 6B BALANCE SHEET 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 63823 sestes seseaa s63825 Orr ese ser oee ses8es nears se ses Tea 0 5 200990 9 247372 262833 278294 9375 293755 §=278294 262833 89247372 «= 231912 = 2164512 = 200990) )=— 185529 = 170068 = 154608 3696 3918 4153 4403 4667 4948 5245 5560 5894 6248 0 0 0 0 0 0 0 0 0 0 9 9 0 9 9 o 9 3696 918 4153 4403 4667 4948 5245 5560 5894 6248 0 0 0 0 0 0 0 0 0 0 9319 8853 8387 —ateet 7455 6989 6524 6058 5592 5126 —306770 _ 291065 _ 275374 2 — 244035 __ 228388 _ 212759 __197147 __181554 _ 165982 133200 =133200 «6133200 «133200 =6133200 §=6133200 §=6133200 §=6133200 §=6.133200 =. 133200 -182549 ~-193322 -203466 -212908 ~-221565 -229338 ~-236120 ~-241791 ~-246212 ~-249231 48376 S2H65 30899 52808 34307 pees 7eed6 eats onnee oe ee ee ee et .*7 | ._ — -193322 -203466 -212908 ~-221565 ~-229338 ~-236120 ~-241791 ~-246212 ~-249231 ~-250676 0 0 0 0 0 0 0 0 0 0 361331 355082 348061 340173 331309 321349 310159 297586 283458 267584 fe ee 361331 355082 348061 340173 331309 321349 310159 297586 283458 267584 0 0 0 0 0 0 0 0 0 0 a4) $257 2et ea B50 78 11190 — 14128 15874 5561 6249 7021 7889 8864 9959 11190 12573 14128 15874 0 0 0 0 0 0 0 0 0 0 Q 0 0 9 9 9 9 0 0 0 0 Q 0 0 9 9 0 0 0 0 306770 291065 275374 259697 244035 228388 212759 197147 181554 _ 165982 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS (M56 U2, 85-01-21 09.34) PAGE 6C BALANCE SHEET ($000) ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 ASSETS PLANT IN SERVICE 404 C 463823 463823 463823 463823 §=—463823 463823 9=— 463823 463823 = «463823 © 463823 tederaccunivaten oePReetATion $99 _soue7t _sgauat _aspaat aries anand annoal aazeal _ayzou! _capse’ — sesac! SS: ACCUM R NET PLANT 400 C 139147 ~ 123686 — 108225 92765 7730 61843 46382 30922 15461 0 CURRENT ASSETS CASH 74 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 Brien dhtabat ASSETS Ee et OTHER CUR TOTAL CURRENT ASSETS 413 ¢ 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 DEBT SERVICE RESERVE FUND 405 C 0 0 0 0 0 0 0 0 0 0 UNAMORTIZED DEBT DISCOUNT & EXPENS 409 C 4660 4194 3728 3262 2796 2330 1864 1398 ‘932 466 TOTAL ASSETS 410 C __150430 __13490) 119396 103916 _88463 _73038 57644 _ 4228) _ 26952 _ 11659 LIABILITIES EQUITY CAPITAL ; 421 C 133200 «133200 =133200 133200 133200 133200 133200 133200 133200 133200 RETAINED EARNINGS BALANCE, BEGINNING OF PERIOD 419 C -250676 ~-250354 -248047 -243512 ~-236475 -226628 -213625 -197079 -176553 -151557 NET INCOME FOR THE PERIOD 23.C 71251 75308 79862 84977 90720 97170 «104413 112548 121684 131945 DIVIDENDS-PREFERRED STOCK 423 ¢ 0 0 0 0 0 0 0 0 0 0 DIVIDENDS-CONMON STOCK 424 C 0 0 0 0 0 0 0 0 0 0 BALANCE, END OF PERIOD 420 C -250354 248047 -243512 -236475 -226628 -213625 ~-197079 -176553 -151557 -121541 PREFERRED STOCK 427 C 0 0 0 0 0 0 0 0 0 0 LONG TERM DEBT CONVENTIONAL BONDS 431 C 249749 229708 207191 181891 153464 121523 85634 45309 0 0 SINE 1Oie TERM Deptt et et eet ot ep a 2 —_____a 0 9 9 0 TOTAL LONG TERM DEBT 430 C 249749 229708 — 207191 ~ 181891 ~ 153464 ~ 121523 85634 45309 0 0 “ CURRENT LIABILITIES ven SHORT TERM LOANS 439 C 0 0 0 0 0 0 0 0 0 0 CURRENT PORTION OF orice CHERMAY ClAAdi cares at} z 17836 20040 22517 25300 28937 31941 35889 $0328 45309 0 cewenigesiiiadl ‘ciconiiiliaa poe De} TOTAL CURRENT LIABILITIES 440 C 17836 20040 22517 —a300 28427 31941 35889 40325 45309 0 DEFERRED CREDITS __DEFERRED INCOME TAXES 443 C 0 0 0 0 0 0 0 0 0 0 =DEFERRED INVESTMENT TAX CREDITS 444 C 0 0 0 0 0 0 0 0 0 0 TOTAL DEFERRED CREDITS 445 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL LIABILITIES 450 C __150430 — 134901 _ 119396 _ 103916 88463 73038 57644 42281 26952 11659 ‘a ALASKA POWER PROJECT ($000) OPERATING REVENUES OTHER INCOME TOTAL INCOME OPERATING EXPENSES : OPERATION & MAINTENANCE PROPERTY TAXES OTHER TAXES TOTAL HET BEFORE TAX ADJUSTMENTS Ess: INTEREST EXPENSE AMORTIZE BOND DISCOUNT DEPRECIATION PERSONAL PROPERTY REAL PROPERTY ANORTIZE INTEREST CAPITALIZED TOTAL TOTAL DEDUCTIONS TAXABLE INCOME STATE TAX TAXABLE INCOME-FEDERAL FEDERAL INCOME TAX INVESTMENT TAX CREDIT ENERGY PROPERTY CREDIT NET FIT TOTAL TAX EFFECT TO PARTNERS CASH DISTRIBUTIONS _NET RETURN TO PARTNERS CINCLUDING TAX LOSS) IRIE EE HE OEE 3 HE 3 93 HE OE 3 9 HE 3 EE CUMULATIVE RETURN TO DATE EQUITY INVESTMENT __RATE OF RETURN = CURRENT RETURN AS % OF EQUITY CUMULATIVE RETURN AS % OF EQUITY DCF RATE OF RETURN ITEM 3 ll 37 8 94 95 501 502 310 318 319 321 320 340 503 504 505 506 520 331 507 508 360 365 363 300 370 185 385 c c c a 9 2202090 92 A 8 AAA AH A A000 oO aAAN Oo DIAMOND SHAMROCK/VOSS RETURN TO EQUITY PARTICIPANTS 1991 112234 112234 40144 0 40144 72090 47883 466 31054 0 — 380 — 31434 79783 -7693 -723 -6970 -3206 0 -3206 -3929 22711 26640 114380 133200 20.0 85.9 0.0 1992 95113 95113 42553 0 anes | 42553 52560 47692 466 54344 0 8 54 102882 50322 -4730 -45592 -20972 0 Pec ae -20972 -25703 937 26640 141020 133200 20.0 105.9 0.0 1993 101531 101773 45106 0 45106 56667 47478 466 46580 0 38 960 94904 ~38238 -3594 -34643 -15936 -15936 -19530 7110 26640 167660 133200 20.0 125.9 0.0 1994 112595 112851 47812 0 — 8 47812 65038 47237 466 38817 0 380 — 39197 86900 -21862 -2055 -19807 ~91l1 0 ~91ll 11166 15474 26640 194300 133200 20.0 145.9 0.0 © M56 Ul, 85-01-21 09.34) PAGE 7A 1995 1996 1997 1998 1999 2000 115331 tig 126744 130565 #39632 198286 116022 119398 127048 130887 134981 139349 50681 53722 56945 60362 63984 67823 0 0 0 0 0 0 50681 53722 56945 60362 63984 67823 65341 65676 70103 70525 70997 71526 46967 46663 46321 45937 45506 45021 466 466 466 466 466 466 38817 38817 34935 34935 34935 34935 0 0 0 0 0 0 380 380 38 380 380 380 39197 3 5 35315 35315 35315 86630 86326 82102 81718 81287 80803 -21289 -20649 -11999 11193 -10290 -9277 2001 1941 -1128 -1052 -967 -872 -19288 -18708 ~-10871 -10141 -9323 -8405 ~8872 -8606 -5001 -4665 ~4288 —3866 0 0 0 0 0 0 0 0 0 0 0 0 8872 -8606 -5001 4665 -4288 -3866 -10874 -10547 -6129 ~5717 5256 -4738 15766 16093 20511 20923 21384 21902 26640 26640 26640 26640 26640 26640 220940 247580 274220 300860 327500 354140 133200 133200 133200 133200 133200 133200 20.0 20.0 20.0 20.0 20.0 20.0 165.9 185.9 205.9 225.9 245.9 265.9 0.0 0.0 0.0 0.0 0.0 0.0 4a ALASKA POWER PROJECT ($000) OPERATING REVENUES OTHER INCOME TOTAL INCOME OPERATING EXPENSES OPERATION & NAINTENANCE PROPERTY TAXES OTHER TAXES TOTAL Tey BEFORE TAX ADJUSTMENTS S$: INTEREST EXPENSE AMORTIZE BOND DISCOUNT DEPRECIATION PERSONAL PROPERTY REAL PROPERTY AORTICE INTEREST CAPITALIZED OTAL TOTAL DEDUCTIONS TAXABLE INCOME STATE TAX TAXABLE INCOME-FEDERAL FEDERAL INCOME TAX INVESTMENT TAX CREDIT ENERGY PROPERTY CREDIT NET FIT TOTAL TAX EFFECT TO PARTNERS CASH DISTRIBUTIONS NET RETURN TO PARTNERS CINCLUDING TAX LOSS) HEHEHE HIE HEHE HK HEH HE 9 EE 5 HE 9 0 DEE IE IEE CUMULATIVE RETURN TO DATE EQUITY INVESTMENT _RATE OF RETURN = CURRENT RETURN AS % OF EQUITY CUMULATIVE RETURN AS % OF EQUITY DCF RATE OF RETURN ITEM 3 ll 37 8 94 95 501 502 310 18 318 319 321 320 340 503 504 505 506 520 331 507 508 360 365 363 300 370 185 385 c c c a 9 A229 29 8 M8 A292 EON 2 ERE00 oa eA 2 0 DIAMOND SHAMROCK/VOSS RETURN TO EQUITY PARTICIPANTS 2001 2002 2003 180087 185054 190347 180471 185460 190778 71892 76205 80778 0 0 0 71892 T6208 80778 108579 109255 110000 44477 43865 43178 466 466 466 0 0 0 0 0 0 ——380 ____380 ____380 80 380 38 45323 44711 44024 63256 64544 65976 5946 6067 6202 57310 58477 59774 26363 26899 27496 26363 2087? e7836 26363 26899 27496 32309 32966 33698 58949 59606 60338 26640 26640 26640 380780 407420 434060 133200 133200 133200 20.0 20.0 20.0 285.9 305.9 325.9 0.0 0.0 0.0 2004 196003 196459 85624 Qo 85624 110835 42405 466 ——__380 —384 43251 67584 6353 61231 28166 28166 28166 34519 61159 26640 460700 133200 20.0 345.9 0.0 ¢ M56 2005 2006 202049 208516 zazest 209030 90762 96208 0 0 90762 96208 111772 112822 41538 40563 466 466 0 0 0 : 0 380 80 380 380 42384 41408 69388 71413 6522 6713 62866 64701 28918 29762 5100 8 28918 29762 35441 36475 62081 63115 26640 26640 487340 513980 133200 133200 20.0 20.0 365.9 385.9 0.0 0.0 Ul, 85-01-21 09.34) 2007 215436 215980 101980 0 ee 101980 114000 39467 466 380 aOsis 73687 6927 66761 30710 0 30710 37636 64276 26640 540620 133200 20.0 405.9 0.0 2008 222844 223421 108099 0 ean 108099 115322 38236 466 0 0 8 8 39082 76240 7167 69073 31774 31774 38940 65580 26640 567260 133200 20.0 425.9 0.0 2009 230777 6 231389 114585 0 apie 114585 116804 36853 466 380 80 37699 79105 7436 71669 32968 32968 40404 67044 26640 593900 133200 20.0 445.9 0.0 PAGE 7B 2010 oo eeaa 239927 121460 0 aah 121460 118468 35299 466 380 380 36145 82323 7738 74584 34309 Ee 34309 42047 68687 26640 620540 133200 20.0 465.9 0.0 au ALASKA POWER PROJECT ($000) OPERATING REVENUES OTHER INCOME TOTAL INCOME OPERATING EXPENSES OPERATION & MAINTENANCE PROPERTY TAXES OTHER TAXES TOTAL NEY PEFORE TAX ADJUSTMENTS INTEREST EXPENSE ANORTIZE BOND DISCOUNT DEPRECIATION PERSONAL PROPERTY REAL PROPERTY ANCRTIZE INTEREST CAPITALIZED - TOTAL TOTAL DEDUCTIONS TAXABLE INCOME STATE TAX TAXABLE INCOME-FEDERAL FEDERAL INCOME TAX INVESTMENT TAX CREDIT ENERGY PROPERTY CREDIT NET FIT TOTAL TAX EFFECT TO PARTNERS CASH DISTRIBUTIONS NET RETURN TO PARTNERS (INCLUDING TAX LOSS) PoE SESS SS ESTES ES TS STE SSS SS CUMULATIVE RETURN TO DATE EQUITY INVESTMENT RATE OF RETURN ~- CURRENT RETURN AS % OF EQUITY CUMULATIVE RETURN AS % OF EQUITY DCF RATE OF RETURN ITEM ll 37 94 95 501 502 310 318 319 321 320 340 503 504 505 506 520 331 507 508 360 365 363 300 370 185 385 aan oa 9 AM0209 2A A A AARON 20 A A200 o Onn oO 7 DIAMOND SHAMROCK/VOSS © M56 U2, 85-01-21 09.34) PAGE 7C¢ RETURN TO EQUITY PARTICIPANTS 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 248791 258569 269063 280334 292446 305469 319481 334567 350820 368343 249478 259297 269836 281153 293314 306389 320456 335601 351916 369505 128748 136472 144662 153348 162541 172293 182631 193589 zeszee 217516 rg ce 8 128748 136472 ~ 144661 153340 162541 172293 182631 ~—«193589 205204 217516 120730 «122825125175 127813130773 = 134096) §=.:137825 142012 = 146712 151989 33553 31591 29386 26909 24126 20999 17485 13537. 9102 4117 466 466 466 466 466 466 466 466 466 466 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 eee Be Be ge 9 9 o 9 0 RS ee ee ——..2 — 2 8 34019 32057 29852 27375 24592 21465 17951 14003 9568 4583 86712 90768 95323 100438 106181 112631 119874 128009 137145 147405 8151 8532 8960 9441 9981 10587 11268 12033 12892 13856 78561 82236 86363 90996 96200 102043. 108606 115976 124253 133549 36138 37829 39727 41858 44252 46940 49959 53349 57156 61433 0 0 0 0 0 0 0 0 0 0 amenghihig lh winner 0 9 0 0 0 _ 36138 37829 39727 41858 44252 46940 ° 49959 53349 57156 61433 44289 46361 48687 51299 54233 57527 61227 65382 70048 75289 70929 73001 75327 77939 80873 84167 87867 92022 96688 101929 26640 26640 26640 26640 26640 26640 26640 26640 26640 26640 647180 673820 700460 727100 753740 780380 807020 833660 860300 836940 133200 =133200 =6.133200 §=- 133200 )=—:133200 §= 133200 §=— 133200 §=:33200 §= 133200 =: 133200 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 485.9 505.9 525.9 545.9 565.9 585.9 605.9 625.9 645.9 665.9 0.0 0.0 9.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS INT. ¢ M55 Ul, 85-01-18 15.31) PAGE 9A DEBT SERVICE SCHEDULE ($000) : ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 CONVENTIONAL BONDS BALANCE,START OF PERIOD 1ST SERIES 301 0 399400 397857 396123 394174 391985 389525 386762 383656 380167 376247 2ND SERIES 302 C 0 0 0 0 0 0 0 0 0 0 3RD SERIES 303 C 9_ ss oe 8 : 9 gph weer eee rr TOTAL OUTSTANDING 201 ¢ 399400 397857 396123 394174 391985 389525 386762 383656 380167 376247 INTEREST CHARGES 202 ¢ 47883 47692 47478 47237 46967 46663 46321 45937 45506 45021 PRINCIPAL REPAYMENT 203 ¢ 1543 1734 1948 2189 2460 2764 3105 3489 3920 4405 TOTAL DEBT SERVICE 204 ¢ 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 ENERGY DEVELOPMENT BONDS BALANCE, START OF PERIOD 1ST SERIES 311 ¢ 0 0 0 0 0 . 0 0 0 0 0 2ND SERIES 312 € 0 0 0 0 0 0 0 0 0 0 3RD SERIES 313 C 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 205 C 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 206 C ' 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYNENT 207 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL DEBT SERVICE 208 C 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT BALANCE, START OF PERIOD 1ST SERIES 321 ¢ 0 0 0 0 0 0 0 0 0 0 2ND SERIES 322 € 0 0 0 0 0 0 0 0 0 0 3RD SERIES 323 C 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 209 ¢ 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 210 C 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 211 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL DEBT SERVICE 212 ¢ 0 0 0 0 0 0 0 0 0 0 TOTALS ALL DEBT BALANCE-START OF PERIOD 213 C 399400 397857 396123 394174 391985 389525 386762 383656 380167 376247 INTEREST CHARGES 214 C 47883 47692 47478 47237 46967 46663 46321 45937 45506 45021 PRINCIPAL REPAYMENT 215 ¢ 1543 1734 1948 2189 2460 2764 3105 3489 3920 4405 TOTAL DEBT SERVICE 216 C 49426 $9426 49426 49426 49426 49426 49426 49426 49426 49426 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS INT. © M55 Ul, 85-01-18 15.31) PAGE 9B DEBT SERVICE SCHEDULE ($000) ITEM 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 CONVENTIONAL BONDS BALANCE, START OF PERIOD 1ST SERIES sol Cc 371842 366892 361331 355082 348061 340173 331309 321349 310159 297586 2ND SERIES 302 C 0 Q 0 0 0 0 0 0 0 0 3RD SERIES 303 Cc OD 8 a 8 8 LD TOTAL OGUTSTANDING 201 c¢ 371842 366892 361331 355082 348061 340173 331309 321349 310159 297586 INTEREST CHARGES 202 ¢ 44477 43865 43178 42405 41538 40563 39467 38236 36853 35299 PRINCIPAL REPAYMENT 203 Cc 4949 5561 6249 7021 7889 8864 9959 11190 12573 14128 TOTAL DEBT SERVICE 204 C¢ 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 ENERGY DEVELOPMENT BONDS BALANCE, START OF PERIOD 1ST SERIES sll c 0 0 0 0 0 0 0 0 0 0 2ND SERIES 312 ¢ 0 0 0 0 Qo 0 0 0 0 0 SRD SERIES 313 C__ 0 0 o_ sb 0 0 o 0 o TOTAL OUTSTANDING 205 ¢ 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 206 C Q 0 0 0 0 0 Q 0 0 0 PRINCIPAL REPAYMENT 207 C 0 0 0 _ 0 0 0 0 0 0 TOTAL DEBT SERVICE 208 Cc 0 0 0 0 0 Qo 0 0 0 0 OTHER LONG TERM DEBT BALANCE,START OF PERIOD 1ST SERIES 321 € 0 0 0 0 0 0 0 0 0 0 2ND SERIES 322 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 323 C€ 9 0 0 0 0 o 0 oO 0 0 TOTAL OUTSTANDING 209 ¢ 0 0 0 0 Q 0 0 0 0 0 INTEREST CHARGES 210 Cc 0 0 0 0 Q 0 0 0 0 0 PRINCIPAL REPAYMENT _ 211¢ 0 0 0 0 0 0 0 0 0 0 TOTAL DEBT SERVICE 212 C 0 0 0 0 0 0 0 0 0 0 TOTALS ALL DEBT BALANCE-START OF PERIOD 213 € 371842 366892 361331 355082 348061 340173 331309 321349 310159 297586 INTEREST CHARGES 214 C 44477 43865 43178 42405 41538 40563 39467 38236 36853 35299 PRINCIPAL REPAYMENT 215 ¢ 4949 5561 6249 7021 7889 8364 9959 11190 12573 14128 TOTAL DEBT SERVICE 216 C 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 e ALASKA PONER PROJECT ($000) CONVENTIONAL BONDS BALANCE, START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE ENERGY DEVELOPMENT BONDS BALANCE, START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE OTHER LONG TERM DEBT BALANCE,START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE TOTALS ALL DEBT BALANCE-START OF PERIOD INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE ITEM 301 302 303 201 202 203 204 311 312 313 205 206 207 208 321 322 323 209 210 211 212 213 214 215 216 a | fF ANAND a 90 9 fAAQN0 ao 9a 98 ANN c DIAMOND SHAMROCK/VOSS INT. C M55 Ul, 85-01-18 15.31) PAGE 9C DEBT SERVICE SCHEDULE 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 253458 267966 259783 eeazes 207291 181891 153468 ee 85634 45309 0 ee 8 8 ee os 283458 267584 249749 229708 207191 181891 153464 121523 85634 45309 33553 31591 29386 26909 24126 20999 17485 13537 9102 4117 15874 17836 20040 22517 25300 28427 31941 35889 40325 45309 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 0 Qo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 t } 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Qo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 283458 267584 249749 229708 207191 181891 153464 121523 85634 45309 33553 31591 29386 26909 24126 20999 17485 13537 9102 4117 15874 17836 20040 22517 25300 28427 31941 35889 40325 45309 49426 49426 $9426 49426 49426 49426 49426 49426 49426 49426 BASE -R.E.A. CAPITALIZATION EQUITY PREFERRED STOCK CONVENTIONAL BONDS REA GUARANTED BONDS OTHER LONG TERM DEBT TOTAL CAPITALIZATION TAX BASIS PROJECT COST EXCLUDING IDC ($000) NON-DEPRECIABLE INVESTMENT (LAND) SALVAGE FACTOR PERSONAL PROPERTY-% REAL PROPERTY-% PERSONAL PROPERTY TAX LIFE (ACRS) INVESTNENT TAX CREDIT-% ENERGY TAX CREDIT-% EQUITY PARTICIPANTS TAX BRACKET-% STATE INCOME TAX RATE-% FEDERAL INCOME TAX RATE-% MISCELLANEOUS DATA PROJECT COST INCLUDING IDC ($000) AVERAGE (BOOK) SERVICE LIFE PROPERTY TAX RATE (PCT OF PLANT) GROSS RECEIPTS TAX RATE BASE YEAR FOR PRESENT WORTH DISCOUNT RATE APPLIED PLANT OUTPUT-GIGALWATTHOURS (GNH) ta tt tt ITEM ooooo ooooo uSune AAANAD 000 ITEM 291 161 306 1038 1039 303 1033 1034 1037 1194 1195 404 299 1094 1095 150 1054 160 QAAMHANSGHAAAND HOOONSOO REA FUNOING BELUGA POWER PROJECT SUMMARY OF ASSUMPTIONS AND OTHER INPUT DATA FOR THIS CASE TOTAL PERCENT AMOUNT ($000) 493500 493500 TOTAL 388170 ~ o aL0ooe® coe oe 6 e ee ofooolooooeo OF TOTAL 100.00 100.00 C M56 Ul, 85-01-22 13.34) ANNUAL REQUIRED TERM PAYMENT COST COVERAGE CYEARS) PERIODS % 0.0 0.0 0.0 0 0.0 0.0 0.0 0 0.0 0.0 0.0 0 11.61 1.00 34.0 0 —o.2 __0.0___ 11.61 0.0 0.0 0 Page! BASE-R.E.A. BELUGA POWER PROJECT C M54 Ul, 85-01-22 13.32) PAGE 2A CAPITALIZATION SCHEDULE AND UTILIZATION ($000) OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 1986 1987, NET PROCEEDS AVAILABLE BEGINNING OF PERIOD 10 C 0 63 38 52 0 5 4 94 87 5 CAPITAL FUNDING: EQUITY llc 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK 31 c¢ 0 0 0 0 0 Q 0 0 0 0 CONVENTIONAL BONDS 12 ¢ 0 0 0 0 0 0 0 0 0 0 R.E.A. GUARANTEED BONDS 3c 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 14.) 8 Ln OO TOTAL NEW CAPITAL 15 c 0 0 a 0 0 0 0 0 0 0 CONSTRUCTION LOANS ic ——1900 __2400 __4000 ___9300 _____ 4300 __ 21300 __ 32300 __ 35700 __ 93600 TOTAL PROCEEDS AVAILABLE “ 40 ¢ 1000 1963 2438 4052 9300 4305 21304 32394 35787 93605 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS : CONSTRUCTION EXPENDITURES 20 Cc 914 1855 2259 3820 8847 3970 20361 30671 33187 88188 START-UP COSTS (CAPITALIZED) 48 I 0 0 0 0 0 0 0 0 0 0 PROPERTY TAXES (CAPITALIZED) 53C 0 0 0 0 0 0 0 0 0 0 FUEL STOCK AND OTHER INVENTORY 361 0 0 0 8 0 0 0 0 0 0 FINANCING COSTS 21 Cc 0 0 0 0 0 0 0 0 0 0 REPAYMENT OF CONSTRUCTION LOANS 38 C 0 0 0 0 0 0 0 0 0 0 DEPOSIT-DEBT SERVICE RESERVE FUND 52 C 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK DIVIDENDS 70 C 0 0 TOTAL UTILIZATION 50 C 914 1855 2259 3820 8847 3970 20361 30671 33187 88188 BALANCE ON DEPOSIT 3c 86 108 180 232 453 335 943 1723 2600 5417 INTEREST EARNED 4c 2 3 4 6 15 8 24 43 65 140 TOTAL AVAILABLE FOR INTEREST CHARGES 5c 88 lll 184 238 468 344 967 1767 2665 5557 INTEREST CHARGES CONSTRUCTION LOANS 61 Cc 25 72 132 232 462 340 872 1680 2572 5465 CONVENTIONAL BONDS 62 C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPNENT BONDS 63 C 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERN DEBT 64C 0 0 0 0 0 0 0 0 0 TOTAL INTEREST CHARGES 65 C 25 72 132 232 462 340 872 1680 2572 5465 NET PROCEEDS AVAILABLE END OF PERIOD 7¢ 63 38 52 5 5 4 94 87 92 92 DE OEE HO OK INTEREST CHARGED TO CONSTRUCTION 91c 23 70 128 227 447 332 849 1637 2508 5325 TOTAL AMOUNT CAPITALIZED 92 ¢ 937 1925 2387 4046 9295 4301 21210 32308 35694 93513 CUMULATIVE AMOUNT CAPITALIZED 93 Cc 937 2862 5248 9295 9295 13596 34806 67113 102808 102808 3 DEH HEH SE SEH HHI CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 20 875 1750 2100 3500 8225 3585 18121 26902 28688 77296 al Ul, 85-01-22 13.32) BASE-R.E.A. BELUGA POWER PROJECT C M54 PAGE 2B CAPITALIZATION SCHEDULE AND UTILIZATION ($000) OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 1988 1989 NET PROCEEDS AVAILABLE BEGINNING OF PE 10C . 92 42 40 57 92 28 46 27 7 28 CAPITAL FUNDING: EQUITY llc 0 0 0 Q 0 0 Q 0 0 0 PREFERRED STOCK 31 c 0 0 Q Qo 0 0 0 0 0 0 CONVENTIONAL BONDS 12 ¢ 0 0 0 0 0 0 0 0 0 0 R.E.A. GUARANTEED BONDS 3c 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 1G: Oe ee 8 DD 0 0 TOTAL NEW CAPITAL isc 0 0 0 0 0 0 0 0 CONSTRUCTION LOANS 1c 00 __26600 __47300 __46000 _158500 ____30600 __42600 __39100 __37000 _149300 TOTAL PROCEEDS AVAILABLE 40 Cc 38692 26642 47340 46057 158592 30628 42646 39127 37007 149328 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES 20 Cc 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 START-UP COSTS CCAPITALIZED) 48 1 0 0 0 0 0 0 0 0 0 0 PROPERTY TAXES (CAPITALIZED) 53 ¢ 0 0 0 0 0 0 0 0 0 0 FUEL STOCK AND OTHER INVENTORY 30 1 0 0 0 Q 0 0 0 0 0 0 FINANCING COSTS 21c 0 0 0 0 0 0 0 0 0 0 REPAYNENT OF CONSTRUCTION LOANS 38 C 0 0 0 0 0 Qo 0 0 0 0 DEPOSIT-DEBT SERVICE RESERVE FUND 52 C 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK DIVIDENDS 70 C 0 0 0 0 0 0 0 0 0 TOTAL UTILIZATION 50 C 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 BALANCE ON DEPOSIT 3c 3493 4139 5309 6403 19204 7167 8187 9122 10042 34437 INTEREST EARNED 4c 87 103 133 160 484 179 205 228 251 863 TOTAL AVAILABLE FOR INTEREST CHARGES 5c 3580 4243 5442 6563 19688 7346 8392 9350 10293 35300 INTEREST CHARGES CONSTRUCTION LOANS 61 c 3537 4202 5385 6535 19660 7300 8365 9342 10267 35275 CONVENTIONAL BONDS 62 C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS 63 C 0 0 0 0 0 Qo 0 0 0 0 OTHER LOWG TERM DEBT 64 C 0 0 0 0 0 0 0 0 0 0 TOTAL INTEREST CHARGES 65 Cc 3537 4202 5385 6535 19660 7300 8365 9342 10267 35275 NET PROCEEDS AVAILABLE END OF PERIOD 7¢ 42 40 57 28 28 46 27 ‘ZL 25 25 HSE IESE DEE INTEREST. CHARGED TO CONSTRUCTION g1c 3450 4099 5252 6375 19176 7121 8160 9114 10016 34412 TOTAL AMOUNT CAPITALIZED 92 C 38650 26602 47284 46029 158564 30582 42620 39119 36982 149303 CUMULATIVE ANOUNT CAPITALIZED 93 C 141458 168060 215343 261372 261372 291954 334573 373693 410675 410675 3 HE DEH HED HE 2S DE DEBE DEE CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION : 20 29988 18894 34780 32338 116000 18856 27295 23423 20746 90320 BASE-R.E.A. BELUGA POWER PROJECT © M54 Ul, 85-01-22 13.32) PAGE 2C CAPITALIZATION SCHEDULE AND UTILIZATION ($000) OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 1990 NET PROCEEDS AVAILABLE BEGINNING OF PERIOD 10 C 25 46 19 95 25 CAPITAL FUNDING: EQUITY llc 0 0 0 0 0 PREFERRED STOCK 31¢ 0 0 0 0 0 CONVENTIONAL BONDS 12 ¢ 0 0 0 0 0 R.E.A. GUARANTEED BONDS 13 c 8 at ies _Svaneg capone OTHER LONG TERM DE TOTAL NEW CAPITAL 15 ¢ 0 0 0 ~493500 493500 CONSTRUCTION LOANS 1 C __31600 _ 23400 _ 14400 _ 13400 _ 82800 TOTAL PROCEEDS AVAILABLE 40 C 31625 23446 — 14419 ~506995 576325 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES 20C 20792 12069 2617 1378 36856 START-UP COSTS (CAPITALIZED) 48 I 0 0 0 0 0 PROPERTY TAXES (CAPITALIZED) 53.C 0 0 0 0 0 FUEL STOCK AND OTHER INVENTORY 30 I 0 0 0 0 0 FINANCING COSTS 21¢ 0 0 0 0 0 REPAYHNENT OF CONSTRUCTION LOANS 38 C 0 0 0 493500 493500 DEPOSIT-DEBT SERVICE RESERVE FUND 52 ¢ 0 0 0 0 0 PREFERRED STOCK DIVIDENDS 70 ¢ 0 0 0 0 0 TOTAL UTILIZATION 50 C 20792 12069 2617 494878 530356 BALANCE ON DEPOSIT 3.¢ 10833 11377. 11802 ~ 12117 ~ 45969 INTEREST EARNED 4c 271 284 295 303 1153 TOTAL AVAILABLE FOR INTEREST CHARGES 5 C 11104 ~ 11661 ~ 12097 — 12420 — 47122 INTEREST CHARGES CONSTRUCTION LOANS 61 C 11057 11642 12002 12337 47040 CONVENTIONAL BONDS 62 C 0 0 0 0 0 ENERGY DEVELOPHENT BONDS 63 C 0 0 0 0 0 OTHER LONG TERN DEBT 64 C 0 Q 0 0 TOTAL INTEREST CHARGES 65 C 11057 ~ 11642 ~ 12002 — 12337 — 47040 NET PROCEEDS AVAILABLE END OF PERIOD 7¢ 46 19 95 82 82 DEDEDE DE SE DE DE HE EK OS EE IEE . INTEREST CHARGED TO CONSTRUCTION 91 C 10787 11358 11707 12035 45887 __TOTAL AMOUNT CAPITALIZED 92 © 31579 23428 14324 «=13412 = 82743 CUMULATIVE AMOUNT CAPITALIZED . 93 C 442254 465681 480005 493418 493418 DEDEDE NEE OE EEE CONSTRUCTION EXPENDITURES : i EXCLUDING ESCALATION 20 15765 9019 1927 1000 827711 LEVELIZED AMOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUMULATIVE PRESENT WORTH AS sf THAT RESULTING FROM THE ACTUAL - ANNUAL AMOUNTS CALCULATED au BASE -R.E.A. ($000) ITEM OPERATING REVENUES PROJECT REVENUE REQUIREMEN 1 SALES OF ELECTRICITY : 2 AVOIDED COST OF ELEC. 17 TOTAL 3 OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST 4 OPERATION & MAINTENANCE EXPENSE 6 TOTAL O&M 8 LEASE EXPENSE 27 DEPRECIATION EXPENSE 9 PROPERTY TAX 94 GROSS RECEIPTS TAX 95 TOTAL OPERATING EXPENSES 10 OPERATING INCOME 90 OTHER INCOME AND EXPENSES ll INCOME BEFORE INTEREST CHARGES 12 INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS 13 REA GUARANTED BONDS 14 OTHER LONG TERM DEBT 15 SUBTOTAL 16 OTHER INTEREST & EXPENSES ANORTIZED BOND DISCOUNT & EXPENSES 18 SHORT TERM LOANS 19 INTEREST DURING CONSTRUCTION 20 SUBTOTAL 21 TOTAL INTEREST AND OTHER EXPENSES 22 NET INCOME 23 HD DE I HI COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT HORTH DOLLARS 163 159 BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 3/ FORECASTED STATEMENT OF INCOME 1991 1992 1993 1994 1995 1996 1997 1998 1999 200 € 96702 103212 103554 1eg22 199113 te} 115368 ~~ teesee see Q 0 c 0 o 0 0 c 98702 103212 103554 10625 109115 112149 115364 118773 122386 126215 c 15320 16239 17214 18246 19341 20502 21732 23036 24418 2588: c 8 78 56 3 37326 39566 1 c 40144 42553 45106 47812 50681 53722 56945 60362 63984 6782: I 0 9 0 0 Q 9 9 0 0 ( c 16447 16447 16447 16447 16447 16447 16447 16447 16447 1644] c 0 0 0 0 0 0 0 0 0 ( c 0 0 0 c 56591 59000 61553 64260 67128 70169 73392 76809 80431 84270 c 42110 44212 42001 41994 41987 41980 41972 41964 41955 4194E 0 9 241 256 271 287 305 323 342 36: c 42110 44221 42242 42250 42258 42267 42276 42286 42297 42308 c 0 0 0 0 0 0 0 0 0 ( : $7283 37205 56930 56735 eis 56274 56001 35698 22398 5497] eine { c 57259 57104 56930 56735 56518 56274 56001 55696 55354 5497] c 0 0 0 0 0 0 0 0 0 ( c 0 0 0 0 0 0 0 0 0 ( c 0 oO 0 0 0 0 0 0 9 ( c 0 0 0 0 0 9 0 0 0 ( c 57259 57104 56930 56735 56518 56274 56001 55696 55354 5497) C _-15148 -12883 _ -14688 = 85 -14259 -14007 13725 __-13409 13057 -1266: c 99.90 104.47 104.81 107.54 110.44 113.52 116.77 120.22 123.87 127.75 c 51.68 48.42 43.53 40.02 36.82 33.91 31.25 28.83 26.62 24.55 c 99.90 102.06 102.88 103.86 104.90 105.97 107.06 108.14 109.22 110.36 ba BASE -R.E.A. ($000) ITEM OPERATING REVENUES PROJECT REVENUE REQUIREMENT 1 SALES OF ELECTRICITY 2 AVOIDED COST OF ELEC. 17 TOTAL 3 OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST 4 OPERATION & MAINTENANCE EXPENSE 6 TOTAL O&M 8 LEASE EXPENSE 27 DEPRECIATION EXPENSE 9 PROPERTY TAX 94 GROSS RECEIPTS TAX 95 TOTAL OPERATING EXPENSES 10 OPERATING INCOME 90 OTHER INCOME AND EXPENSES ll INCOME BEFORE INTEREST CHARGES 12 INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS 13 REA GUARANTED BONDS 14 OTHER LONG TERM DEBT 15 SUBTOTAL 16 OTHER INTEREST & EXPENSES AMORTIZED BOND DISCOUNT & EXPENSES 18 SHORT TERM LOANS 19 INTEREST DURING CONSTRUCTION 20 SUBTOTAL 21 TOTAL INTEREST AND OTHER EXPENSES 22 NET INCOME 23 TOK COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT WORTH DOLLARS 163 LEVELIZED ANOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUMULATIVE PRESENT WORTH AS es THAT RESULTING FROM THE ACTUAL - ANNUAL AMOUNTS CALCULATED 159 c c c c AAOOOBOOO a Cc BELUGA POWER PROJECT (M56 = UL, 85-01-22 13.34) PAGE 3B FORECASTED STATEMENT OF INCOME 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 130679 135033 Lyatse 144551 149747 155258 161167 167311 173892 180876 0 mapiieil 9 0 130679 ~ 135033 ~ 139652 — 144551 ~ 149747 ~ 155259 — 161107 — 167311 173892 — 180876 a7936 egese 30827 32676 39637 36715 35918 91253 43726 46352 i882 7203 B0r78 55638 verse 96208 TOLSEE 168099 Tis383 T2i466 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 0 0 0 0 ° 0 9 0 6 ¢ ee —.___9 88339 92653 97225 102072 ~—-107209 ~—«*2112655 ~—«21:18427 ~ 124546 ~ 131032 — 137907 42340 42381 42427 42479 42538 42604 42679 42764 42860 42968 384 408 432 458 485 514 545 578 613 650 42725 42788 «42859 42937 43023 43119 43225 43343 43473 43618 0 0 0 0 0 0 0 0 0 0 54542 54063 53526 52925 52252 51498 50655 49711 Anns 47470 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q 0 0 0 0 0 Gg eg 0 0 0 0 0 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 —=11818 __=11274 __=10667 ___-9988 __=9228 _=8379 =7430 = 6368 =5181 ___-3852 132.27) 136.67 9141.35 146.31 «151.57 157.14 = 163.06 ©= 169.34 9176.00 «183.07 22.81 21.12 19.57 18.15 16.85 15.65 14.55 13.54 12.61 11.75 WWN.39 112.46 123.52 124.56 125.58 126.59. 117.58 118.54 9119.49 9120.41 a8 BASE -R.E.A. ($000) ITEM OPERATING REVENUES PROJECT REVENUE REQUIREMENT 1 SALES OF ELECTRICITY 2 AVOIDED COST OF ELEC. 17 TOTAL 3 OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST 4 OPERATION & MAINTENANCE EXPENSE 6 TOTAL O aN 8 LEASE EXPENSE 27 DEPRECIATION EXPENSE 9 PROPERTY TAX 94 GROSS RECEIPTS TAX 95 TOTAL OPERATING EXPENSES 10 OPERATING INCOME 90 OTHER INCOME AND EXPENSES ll INCOME BEFORE INTEREST CHARGES 12 INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS 13 REA GUARANTED BONDS 14 OTHER LONG TERM DEBT 15 SUBTOTAL 16 OTHER INTEREST & EXPENSES ANORTIZED BOND DISCOUNT & EXPENSE 18 SHORT TERM LOANS 19 INTEREST DURING CONSTRUCTION 20 SUBTOTAL 21 TOTAL INTEREST AND OTHER EXPENSES 22 NET INCOME 23 TITHE HK HS DEE WDE ODEN COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS : 16 IN PRESENT WORTH DOLLARS 16 LEVELIZED AMOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SANE CUMULATIVE PRESENT WORTH AS THAT RESULTING FROM THE ACTUAL - ANNUAL AMOUNTS CALCULATED 159 5 3 c c c c OOOOKHOON a AMAA O00 c c DIAMOND SHAMROCK/VOSS © M56 U2, 85-01-22 13.34) PAGE 3¢ FORECASTED STATEMENT OF INCOME 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 188519 19618} 204528 215378 222775 252748 e133 t 254572 #0620" 27916? 0 o o 0 0 0 0 0 0 188319 196181 204524 213378 = =222775 232748 243334 254572 266501 279167 49133 52081 zoeee 33313 62030 tee $3637 yeatp aecnee Srere 128748 $9646 199861 159898 teastt 11ze7* Bie pposes ar 217516 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 : . 0 0 0 0 0 3 7 0 145195 152920 161108 169788 178988 188741 199078 210036 221651 233964 43124 43262 43416 43591 43787 44008 44256 44536 44850 45203 688 730 774 820 869 921 977 1035 1097 1163 43813 43991 44190 44411 44656 44929 45233 45571 45947 46367 0 0 . 0 0 0 0 0 0 0 0 46146 #3883 “3885 $1143 $7066 36735 ottee easy 73 24285 0 46146 449663 43003 41145 39064 36735 34128 31210 27943 24285 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 8 8 0 46146. 44663 43003 41145 39064 36735 34128 31210 27943 24285 2333 672 1187 3266 5592 8194 11105 14361 18005 22082 190.61 198.56 207.01 215.97 225.48 235.58 246.29 257.66 269.74 282.56 10.96 10.23 9.56 8.93 8.36 7.82 7.33 6.87 6.44 6.05 121.31 122.19 123.05 123.88 124.69 125.47 126.23 126.97 127.69 128.38 BASE -R.E.A. ($000) ITEM FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES 3c OTHER INCOME 1c SUBTOTAL 37 ¢ LESS INCOME THAT IS NOT CASH 38 I FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME 39.c LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 Cc LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS - 41 c FUNDS APPLIED TO OPERATING EXPENSE 42 C INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 c FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BOKRDS 441 REA GUARANTED BONDS 45 1 OTHER LONG TERN DEBT 46 I TEMPORARY BORROWIKGS 47 1 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 C¢ DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 Cc ENERGY DEVELOPMENT BONDS 52 C¢ OTHER LONG TERM DEBT 53¢ TOTAL DEBT 54 C BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 4A NET WORKING CAPITAL (FUNDS) AVAILABLE 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 98702 103212 103554 106254 109115 112149 115364 118773 122386 126215 g 9 241 256 305 342 36 9870 103221 103795 106509 109386 112436 115669 119096 122728 126578 0 0 0 0 0 0 0 0 0 0 98702 103221 103795 106509 109386 112436 115669 119096 122728 126578 56591 59000 61553 64260 67128 70169 73392 76809 80431 84270 16447 16447 16447 6 16447 16447 16447 644 40144 42553 45106 47812 50681 53722 56945 60362 63984 67823 58558 60668 58689 58697 58705 58714 58724 58734 58744 58755 0 0 0 Q 0 0 0 0 0 0 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 0 2110 132 139 148 157 166 176 187 198 1.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.00 1.04 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.00 1.04 1.00 1.00 1.00 1.090 1.00 1.00 1.00 1.00 BASE -R.E.A. ($000) * ITEM FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES 3 OTHER INCOME ll SUBTOTAL 37 LESS INCOME THAT IS NOT CASH 38 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME 39 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 LESS: EXPENSES NOT REQUIRING EXPENDITUR OF FUNDS 41 FUNDS APPLIED TO OPERATING EXPENSE 42 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 44 REA GUARANTED BONDS 45 OTHER LONG TERM DEBT 46 TEMPORARY BORROWINGS 47 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 ENERGY DEVELOPNENT BONDS 52 OTHER LOWG TERM DEBT 53 TOTAL DEBT 54 c c c I c c E c c c OO One aQnoan BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 4B NET WORKING CAPITAL (FUNDS) AVAILABLE 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 130679 135033 199632 144551 499787 155259 161107 167311 eae tne te 131064 135441 140084 145008 150232 155774 161652 167889 174505 181525 0 0 0 0 0 0 0 0 0 0 131064 135441 140084 145008 150232 155774 161652 167889 174505 181525 88339 92653 97225 102072 107209 112655 118427 124546 131032 137907 16447 16447 16447 16447 ___16447 ___16447 ___16447 6 71892 76205 80778 85624 90762 96208 101980 108099 114585 121460 59172 59236 59306 59384 59470 59566 59672 59790 59920 60065 0 0 0 0 0 Q 0 0 0 0 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 0 0 0 0 , 0 0 0 7 7 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 210 222 236 250 265 281 297 315 334 354 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.01 1.01 1.01 1.01 1.02 1.02 1.02 1.02 1.02 1.03 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.01 1.01 1.01 1.01 1.02 1.02 1.02 1.02 1.02 1.03 BASE -R.E.A. DIAMOND SHAMROCK/VOSS C M56 U2, 85-01-22 13.34) PAGE 4C NET WORKING CAPITAL (FUNDS) AVAILABLE ($000) ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 FUNDS PROVIDED BY OPERATING REVENUE * AND OTHER INCOME OPERATING REVENUES 3c 188319 196181 204524 213378 222775 «=6.232748 = 243334 =. 254572 266501 279167 OTHER IKCONE 1c 688 730 ___774 820 869 921 977 1035 1097 1163 SUBTOTAL 37 ¢ 189007 196911 205298 214198 223644 233670 244311 255607 267599 280330 LESS INCOME THAT IS NOT CASH 381 0 0 0 0 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE a ete SSS MN Ee ec AND OTHER INCOME 39 ¢ 189007 196911 205298 214198 223644 233670 244311 255607 267599 280330 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 Cc 145195 152920 161108 169788 178988 188741 199078 210036 221651 233964 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 c 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 FUNDS APPLIED TO OPERATING EXPENS 42 C 128748 136472 144661 153340 162541 172293 182631 93589 205204 217516 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 c 60260 60439 60637 60858 61103 61376 61680 62018 62395 62814 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS 45 1 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT 46 I 0 0 0 0 Q- Q 0 0 6 0 TEMPORARY BORROWINGS 47 1 o 0 0 0 9 0 0 0 0 TOTAL FUNDS APPLIED TO DEBT SERVI 48 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 Cc 376 398 422 447 474 503 533 565 599 634 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 Cc 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 REA GUARANTED BONDS 52 C¢ 1.03 1.03 1.04 1.04 1.04 1.05 1.05 1.06 1.07 1.07 OTHER LONG TERM DEBT 53.C 0.0 0.0 0.0 0.0 0.0. 0.0 0.0 9.0 0.0 0.0 TOTAL DEBT 54 C 1.03 1.03 1.04 1.04 1.04 1.05 1.05 1.06 1.07 1.07 BASE -R.E.A. ($000) BEGINNING CASH BALANCE PLUS FUNDS GENERATED NET INCONE ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS INTEREST & OTHER EXPENSE TOTAL FUNDS GENERATED DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS START-UP COSTS FINANCING COSTS WORKING CAPITAL INCREASES CONSTRUCTION REQUIREMENTS DISTRIBUTION TO PARTNERS TOTAL FUNDS USED PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT TEMPORARY FINANCING BORROWED REPAID CASH RECEIPTS FROM FINANCING NET CASH BEFORE FUNDING DEBT SERVICE RESERVE FUND DEPOSITS DRANDOMNS NET ACCRUAL REPLACENENT RESERVE FUND DEPOSITS DRANDOLNS NET ACCRUAL ENDING CASH BALANCE ITEM 60 66 76 77 78 79 74 a ann Oo aac NOTE: OPERATING REVENUES WERE INCREASED BY THESE AMOUNTS SO THAT CASH BALANCES DO NOT DROP BELOW 30 DAYS O&M EXPENSE. 75 c BELUGA POWER PROJECT (M56 Ul, 85-01-22 13.34) PAGE 5A ANALYSIS OF CASH & ANNUAL CASH BALANCES 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 82 82 2193 2324 2464 2612 2768 2934 3111 3297 -15148 -12883 -14688 -14485 -14259 -14007 -13725 -13409 -13057 -12663 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 5 57104 3 6 56001 69 55354 54971 58558 60668 58689 58697 58705 58714 58724 58734 58744 58755 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ——neiel wail sampdie —_____o 0 0 0 0 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 _o 0 Oe 0 o_O 0 0 0 0 0 0 0 0 0 0 0 0 82 2193 2324 2464 2612 2768 2934 31 3297 3495 a 4 a g a a o a 9 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 82 2193 2324 _ 2464 2612 2768 2934 Sli} 329 3495 0 2110 132 139 148 157 166 176 187 198 aa BASE -R.E.A. BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 5B ANALYSIS OF CASH & ANNUAL CASH BALANCES ($000) ITEM 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 BEGINNING CASH BALANCE 60 Cc 3495 3705 3927 4163 4412 4677 4958 5255 5570 5905 PLUS FUNDS GENERATED ; : NET INCOME 23 CC -11818 -11274 10667 -9988 -9228 -8379 -7430 -6368 -5181 -3852 ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS 61 ¢ 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 INTEREST & OTHER EXPENSE 22c¢ 542 __ 54063 53526 52925 ___52252 51498 50655 $9711 48654 47470 TOTAL FUNDS GENERATED 62c 59172 59236 59306 59384 59470 59566 59672 59790 59920 60065 DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS 248 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 START-UP COSTS 56 I 0 0 0 0 0 0 0 0 0 0 FINANCING COSTS 135 I 0 0 0 0 0 0 0 0 0 0 WORKING CAPITAL INCREASES 63 Cc 0 0 0 0 0 0 0 0 0 0 CONSTRUCTION REQUIREMENTS 64 Cc 0 Q 0 0 0 0 0 0 0 0 DISTRIBUTION TO PARTNERS 360 C 0 56 57 648 28 8 17 1028 1153 TOTAL FUNDS USED 65 ¢ 58962 59013 59070 59134 59206 59285 59375 59474 59586 59711 PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEN CAPITAL-EQUITY/DEBT 66 C 0 0 0 0 0 0 0 0 0 0 TEMPORARY FINANCING BORROWED 76 C Q 0 0 0 0 0 0 0 0 0 REPAID 77 9 oO 9 0 0 0 0 0 0 0 CASH RECEIPTS FROM FINANCING 78 C 0 0 0 0 0 0 0 0 0 NET CASH BEFORE FUNDING 79 ¢ . 3705 3927 4163 4412 4677 4958 5255 5570 5905 6259 oe pret ee RESERVE FUND 0 EPOS 67 0 Q g Q g Q a a DRAWCOWUNS 68 C Q 0 0 0 0 0 t 0 8 0 NET ACCRUAL 69 C 0 0 0 0 0 0 0 0 0 0 REPLACEMENT RESERVE FUND a DEPOSITS 70 C 0 0 0 0 0 0 0 0 0 0 DRANDOWNS 7c 9 0 0 0 0 0 0 0 0 0 NET ACCRUAL 72C 0 0 0 0 0 0 0 0 0 0 ENDING CASH BALANCE 74 C¢ 3705 3927 4163 4412 4677 4958 5255 5570 5905 6259 NOTE: OPERATING REVENUES WERE INCREASED BY THESE AMOUNTS SO THAT CASH BALANCES DO NOT DROP BELOW 30 DAYS O&M EXPENSE. 75 ¢ 614 678 748 826 913 1008 1114 1232 1363 1508 BASE -R.E.A. ($000) ITEM BEGINNING CASH BALANCE 60 PLUS FUNDS GENERATED NET INCOME 23 ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS 61 INTEREST & OTHER EXPENSE 22 TOTAL FUNDS GENERATED 62 DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS 248 START-UP COSTS 56 FINANCING COSTS 135 WORKING CAPITAL INCREASES 63 CONSTRUCTION REQUIREMENTS 64 DISTRIBUTION TO PARTNERS 360 TOTAL FUNDS USED 65 PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT 66 TEMPORARY FINANCING BORROWED 76 REPAID 77 CASH RECEIPTS FROM FINANCING 78 NET CASH BEFORE FUNDING 79 DEBT SERVICE RESERVE FUND DEPOSITS 67 DRANDCHUS 68 NET ACCRUAL 69 REPLACEMENT RESERVE FUND _ DEPOSITS 70 DRANDONNS 71 NET ACCRUAL 72 ENDING CASH BALANCE 74 NOTE: OPERATING REVENUES WERE INCREASED THESE ANOUNTS SO THAT CASH BALANCES DO NOT DROP BELOW 30 DAYS O&M EXPENSE. 75 DIAMOND SHAMROCK/VOSS C M56 U2, 85-01-22 13.34) PAGE 5C ANALYSIS OF CASH & ANNUAL CASH BALANCES 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 c 6259 6635 7033 7455 7902 8376 8878 9411 9976 10574 c -2333 -672 1187 3266 5592 8194 11105 14361 18005 22082 c 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 c 6 0 0 8 2 24285 c 60260 60439 60637 60858 61103 61376 61680 62018 62395 62814 c 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 I 0 0 0 0 0 0 0 0 0 0 I 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 32 8 0 2316 2590 896 3238 3622 c 59884 60041 60215 60411 60629 60874 61148 61454 61796 62179 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 C a oe LD c 0 0 0 0 0 0 0 0 0 0 c 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 0 a Q g g g Q g g g a c 9 0 0 9 0 0 0 9 9 o Cc 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 9 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 BY . : c 1702 1881 2080 2300 2546 2819 3123 3461 3837 4256 4e BASE -R.E.A. BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 6A BALANCE SHEET ($000) ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 ASSETS PLANT IN SERVICE "404 C 493418 =. 4493418 = 493418 = 4493418 = 493418 = 493418 = 4.93418 = 4493418 = 4.93418 =. 493418 teasteccUiutaten DERECIATEON 399 € asa sang anual _s7a anal oneal uasasl _isnart —esned _icard LESS: ACCUMULATED DEPRE! NET PLANT 400 C 476970 = 460523 444076 ~— 427629 ~~ 411181 394734 ~ 378287 ~ 361840 345392 328945 CURRENT ASSETS CASH 74 82 2193 2324 2464 2612 2768 2934 3111 3297 3495 MATERIALS g SUEEL IES 4u ¢ ‘ 0 0 0 0 $ 0 $ 0 8 OTHER CURR A $s cecil 9. ~-2 —___# —____@_. _ o_O CUCU TOTAL CURRENT ASSETS 413 C 82 2193 2324 2464 2612 2768 2934 S1iy 3297 3495 DEBT SERVICE RESERVE FUND 405 c 0 0 0 0 0 0 0 0 0 0 UNAMORTIZED DEBT DISCOUNT & EXPENSE 409 C +O CCC ll TOTAL ASSETS 410 C __477053 __ 462716 _ 446400 __ 430092 __413793 __397502 381221 _ 364950 — 348689 _ 332440 LIABILITIES EQUITY CAPITAL 421 ¢ 0 0 0 0 0 0 0 0 0 0 RETAINED EARNINGS BALANCE,BEGINNING OF PERIOD 419 C 0 15148 ~-28031 -42719 -57204 -71464 -85471 -99195 -112604 -125661 NET INCOME FOR THE PERIOD 23 © -15148 -12883 -14688 =-14485 = - 14259-14007 = --13725 «= -13409 = -13057. _ - 12663 DIVIDENDS-PREFERRED STOCK 423 ¢ 0 0 o 0 0 0 0 0 0 0 DIVIDENDS-CONNON STOCK 424 C 0 0 0 o_o 0 0 0 se BALANCE, END OF PERIOD 420 C =-15148 = =28031 — -42719 — -57204 ~ -71464 ~ -85471 ~— -99195 ~-112604 -125661 -138324 PREFERRED STOCK 427 C 0 0 0 0 0 0 0 0 0 0 LONG TERM DEBT CONVENTIONAL BONDS 431 C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPNENT BONDS 432 C 490747 = 489119 §=487297 485257 «482973 480416 = 4477554 «= 474350 §=— «4.70764 «= 466.748 OTHER LONG TERM DEBT 433. C 0 0 0 0 0 0 0 0 0 TOTAL LONG TERM DEBT 430 C = 490747 489119 487297 ~ 485257 482973 ~ 480416 477554 ~ 474350 470764 466748 CURRENT LIABILITIES SHORT TERN LOANS 439 C 0 0 0 0 0 0 0 0 0 0 CURRENT PORTION OF LONG TERN DEBT 441 I 1454 1628 1822 2040 2284 2557 2862 3204 3587 4015 OTHER CURRENT LIABILITIES 442 I 0 0 0 0 0 0 0 0 0 0 TOTAL CURRENT LIABILITIES 440 C 1454 1628 1822 2040 2284 2557 2862 3204 3587 4015 DEFERRED CREDITS __DEFERRED INCOME TAXES 443 C 0 0 0 0 0 0 0 0 0 0 =DEFERRED INVESTMENT TAX CREDITS 444 C 0 0 0 0 0 0 0 0 0 0 TOTAL DEFERRED CREDITS 445 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL LIABILITIES 450 C __477053 __462716 _ 446400 _ 430092 "413793 __ 397502 _ 381221 _ 364950 _ 348689 _ 332440 + a “ ua BASE -R.E.A. ($000) ITEM ASSETS PLANT IN SERVICE 404 CONSTRUCTION WORK IN PROGRESS 398 LESS: ACCUMULATED DEPRECIATION 399 NET PLANT 400 CURRENT ASSETS CASH 74 MATERIALS & SUPPLIES 411 OTHER CURRENT ASSETS 412 TOTAL CURRENT ASSETS 413 DEBT SERVICE RESERVE FUND 405 UNAMORTIZED DEBT DISCOUNT & EXPENSE 409 TOTAL ASSETS 410 IABILITIES EQUITY CAPITAL 421: RETAINED EARNINGS BALANCE,BEGINNING OF PERIOD 419 NET INCONE FOR THE PERIOD 23 DIVIDENDS-PREFERRED STOCK 423 DIVIDENDS-COMMON STOCK 424 BALANCE,END OF PERIOD 420 PREFERRED STOCK 427 LONG TERM DEBT CONVENTIONAL BONDS : 431 ENERGY DEVELOPMENT BONDS 432 OTHER LONG TERM DEBT 433 TOTAL LONG TERM DEBT 430 “ CURRENT LIABILITIES SHORT TERM LOANS 439 CURRENT PORTION OF LONG TERM DEBT 441 OTHER CURRENT LIABILITIES 442 TOTAL CURRENT LIABILITIES 440 DEFERRED CREDITS DEFERRED INCOME TAXES 443 =DEFERRED INVESTMENT TAX CREDITS 444 TOTAL DEFERRED CREDITS 445 TOTAL LIABILITIES 450 QOH ao OF AHOO a a anaan aaan a 800 One OO BELUGA POWER PROJECT (M56 Ul, 85-01-22 13.34) PAGE 6B BALANCE SHEET 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 493418 493618 493418 493418 493418 495418 493418 493618 495418 493418 130920 6 8 230262 _ 246709 _ 263156 _ 279603 _ 296051 __312498 __ 328945 312498 296051 279603 263156 246709 230262 213814 197367 180920 164473 3705 3927 4163 4412 4677 4958 5255 5570 5905 6259 0 0 0 0 0 0 ‘ 0 0 0 3705 3927 4163 4412 4677 4958 5255 — 5570 5905 6259 0 0 0 0 0 0 0 0 0 0 eg 8 —._2 —___2 ____§__o 0 316202 —2ITITT —2B37E6 —26756R — 251386 — D352 219069 — 202937 _1868 T0731 0 0 0 0 0 0 0 0 0 0 “138324 -150546 -162276 -173456 -184020 -193896 -203004 -211250 -218535 -224744 “11818-11276 -10667, 9988-9228 8379-7430 6368-5181 ~3852 Oe ee DG =150546 ~-162276 ~-173456 -184020 ~-193896 —-203004 —-211250 ~-218535 —-224744 ~-229750 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 462253 457221 451588 445282 438223 430320 421473 411569 400481 388070 a ee 8 0 0 0 ‘es 462253 457221 451588 445282 438223 430320 421473 411569 400481 388070 0 0 0 0 0 0 0 0 0 0 4495 5032 5633 6306 7060 7903 8847 9904 11087 ~=—:1242 0 9 0 9 5 9 9 9 9 9 Ly 4495 5032 5633 6306 7060 7903 3847 9904 11087 — 12412 0 0 0 0 0 0 0 0 0 0 Q 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 316202 — 299977 283766 — 267555 —P513H6 — 235215 — 219069 — 202937 _ 186824 — 170731 ta BASE -R.E.A. ($000) ASSETS PLANT IN SERVICE CONSTRUCTION WORK IN PROGRESS LESS:ACCUNULATED DEPRECIATION NET PLANT CURRENT ASSETS CASH MATERIALS & SUPPLIES OTHER CURRENT ASSETS TOTAL CURRENT ASSETS DEBT SERVICE RESERVE FUND UNAMORTIZED DEBT DISCOUNT & EXPENS TOTAL ASSETS LIABILITIES EQUITY CAPITAL RETAINED EARNINGS BALANCE, BEGINNING OF PERIOD NET INCOME FOR THE PERIOD DIVIDENDS-PREFERRED STOCK DIVIDENDS-CONMON STOCK BALANCE, END OF PERIOD PREFERRED STOCK LONG TERM DEBT CONVENTIONAL BONDS REA GUARANTED BONDS OTHER LORG TERM DEBT TOTAL LONG TERM DEBT “~ CURRENT LIABILITIES SHORT TERM LOANS CURRENT PORTION OF LONG TERM DEBT OTHER CURRENT LIABILITIES TOTAL CURRENT LIABILITIES DEFERRED CREDITS _.DEFERRED INCOME TAXES “DEFERRED INVESTMENT TAX CREDITS TOTAL DEFERRED CREDITS TOTAL LIABILITIES ITEM 404 398 399 400 74 411 412 413 405 409 410 421 419 23 423 424 420 427 431 432 433 430 439 441 442 440 443 444 445 450 c I c c 20 8 OFOO a A0000 aQaaoo a2 8200 Oe Oo DIAMOND SHAMROCK/VOSS C M56 U2, 85-01-22 13.34) PAGE 6C BALANCE SHEET 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 $95918 493838 493518 993448 95qus 495618 A958 meer #935638 noite 5 8 828 8 2 444076 460523 0 _ 493418 148025 131578 115131 98684 82236 65789 49342 3289 16447 0 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 0 0 0 0 0 0 Q 0 0 0 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 0 0 0 0 0 0 0 0 0 0 at ae 8 — ed 154660 138611 122585 106585 906)2 74667 58753 42870 27022 11209 0 0 0 0 0 0 0 0 0 0 -229750 ~-233410 ~-235564 -236035 -234622 -231102 -225224 -216710 -205244 -190478 -2333 -672 1187 3266 5592 8194 11105 14361 18005 22082 0 0 0 0 0 0 0 0 0 0 ee cg —__0__o -233410 -235564 -236035 -234622 -231102 -225224 ~-216710 -205244 -190478 -172018 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 S18473 338629 591207 s21718 £29898 275463 298113 otia0t 183227 eee BREE TE eG RPA TR ee eS eg) 374175 358620 341207 321714 299892 275463 248115 217500 183227 144860 0 0 0 0 O- 0 0 0 0 0 13895 15555 17413 19493 21822 24429 27348 30615 34273 38367 0 0 0 0 0 0 Q 0 o 0 13895 15555 17413 19493 21822 24429 27348 30615 34273 38367 0 0 0 0 0 0 o 0 0 0 0 0 9 0 0 0 0 0 Q 0 0 0 0 0 0 0 0 0 0 0 154660 138611 122585 106585 90612 74667 58753 42870 27022 11209 BASE- R.E.A. ($000) CONVENTIONAL BONDS BALANCE,START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE ENERGY DEVELOPMENT BONDS BALANCE,START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE OTHER LONG TERM DEBT BALANCE, START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE TOTALS ALL DEBT BALANCE-START OF PERIOD INTEREST CHARGES PRINCIPAL REPAYNENT TOTAL DEBT SERVICE ITEM 301 302 303 201 202 203 204 NUwe Onn e unde 207 208 321 322 323 209 210 211 212 213 214 215 216 BELUGA POWER PROJECT (M55 Ul, 85-01-22 13.33) PAGE 9A DEBT SERVICE SCHEDULE 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 eTTTTITTBI TEAL RTRRETTITS . . . SMTA TIITTTTHI c wrt 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 Cee WOU reel ete: fates] Ol) eee OUI AT SHiinininn® 0 O 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 c 0 0 0 0 0 0 0 0 0 0 c 9 9 9 9 Lela detale tsi olathe c 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 c 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 c 1299 1454 1628 1822 2040 2284 2557 2862 3204 3587 c 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 9 9 9 0 9 0 0 9 0 9 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 C 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 c 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 c 1299 1454 1628 1822 2040 2284 2557 2862 3204 3587 c ‘58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 BASE- R.E.A. ($000) CONVENTIONAL BONDS BALANCE, START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE ENERGY DEVELOPNENT BONDS BALANCE,START OF PERIOD 1ST SERIES 2D SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYMENT TOTAL DEBT SERVICE OTHER LONG TERM DEBT BALANCE,START OF PERIOD 1ST SERIES 2ND SERIES 3RD SERIES TOTAL OUTSTANDING INTEREST CHARGES PRINCIPAL REPAYNENT TOTAL DEBT SERVICE TOTALS ALL DEBT BALANCE-START OF PERIOD INTEREST CHARGES PRINCIPAL REPAYNENT TOTAL DEBT SERVICE ITEM 301 302 303 201 202 203 204 311 312 313 205 206 207 208 321 322 323 209 210 211 212 213 214 215 216 BELUGA POWER PROJECT (M55 Ul, 85-01-22 13.33) PAGE 9B DEBT SERVICE SCHEDULE 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 ¢ 0 0 0 0 0 0 t t 3 $ c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 Ch) fC) ees Cot ee 6 0 0) ee 0 c 470766 946748 462253 457221 452588 445282 438223 a30sze 421473 411569 c ee OB: ee eee te Le c 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 c 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 c 4015 4495 5032 5633 6306 7060 7903 8847 9904 11087 c 58558 58558 58558 58558 58558 58558 58558 58558 «58558 58558 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 9 ate 9 Oe 8 9 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 c 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 c 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 c 4015 4495 5032 5633 6306 7060 7903 8847 9904 11087 c 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 BASE- R.E.A. BELUGA POWER PROJECT C M55 Ul, 85-01-22 13.33) PAGE 9C DEBT SERVICE SCHEDULE ($000) ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 CONVENTIONAL BONDS BALANCE, START OF PERIOD 1ST SERIES 301 Cc 0 0 0 0 0 0 0 0 0 0 2ND SERIES 302 C 0 0 0 0 0 0 0 0 0 0 3RD SERIES 305 ¢ ____g ___g ___@ ___9 ____ _____# _____# ___# nO ee TOTAL OUTSTANDING 201 C 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 202 Cc 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 203 C 0 0 0 0 0 0 0 0 0 0 TOTAL DEBT SERVICE 204 C¢ 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS BALANCE, START OF PERIOD 1ST SERIES 311 ¢c 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 2tuD SERIES 312 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 313 ¢ ee 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 205 Cc 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 INTEREST CHARGES 206 C 46146 44663 43003 41145 39064 36735 34128 31210 27943 24285 PRINCIPAL REPAYMENT 207 ¢ 12412 13895 15555 17413 19493 21822 24429 27348 30615 34273 TOTAL DEBT SERVICE 208 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT BALANCE,START OF PERIOD 1ST SERIES 321 ¢ 0 0 0 0 0 0 0 0 0 Q 2ND SERIES 322 € 0 0 0 0 0 0 0 0 0 0 3RD SERIES 323 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 209 C 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 210 ¢ 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 211 c 0 0 0 0 0 0 0 0 0 0 TOTAL DEBT SERVICE 212 ¢ 0 0 0 0 0 0 0 0 0 0 TOTALS ALL DEBT BALANCE-START OF PERIOD 213 C 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 INTEREST CHARGES 214 ¢ 46146 44663 43003 41145 39064 36735 34128 31210 27943 24285 PRIKCIPAL REPAYMENT 215 Cc 12412 13895 15555 17413 19493 21822 24429 27348 30615 34273 TOTAL DEBT SERVICE 216 ¢ 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558