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Home My WebLink AboutBeluga Coal Fired Power Plant Project revised 3-1985BELUGA COAL FIRED POWER PLANT PROJECT FEASIBILITY STUDY FOR DIAMOND ALASKA COAL COMPANY VOSS INTERNATIONAL CORPORATION JANUARY 1985 REVISED MARCH, 1985 E, Gilbert/Commonwealth Gilbert/Commonwealth Inc. of Michigan engineers and consultants PENTRU nOIERERERRTeR TTR - eee. RECEIVED Mar 2 0 1985 ALASKA POWER AUTHORITY, Diamond Shamrock Diamond Alaska Coal Company March 15, 1985 John Stafford Alaska Power Authority 334 W. 5th Avenue Anchorage, AK 99501 Subject: Beluga Coal Fired Power Plant Project- Feasibility Study Dear Mr. Stafford: We are looking forward to meeting with you on March 20, 1985 at the briefing on the Beluga Coal Fired Power Project. Enclosed please find a copy of the feasibility study report. We hope you will have an opportunity to review the report before the meeting. Sincerely, RtB. Stiles Vice President Operations & Development RBS:rgr Enclosure Diamond Alaska Coal Company A Subsidiary of Diamond Shamrock S 550 West Seventh Avenue, Suite 1900, Anchorage, Alaska 99501 Phone: 907 276-6868 YO a7 the iS 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 REVISED MARCH, 1985 Prepared By: Approved By: Gilbert/Commonwealth Inc. ve 209 East Washington Avenue ven Jackson, Michigan 49201 SL. CALLS <R. Calvert, P.E. Vice President and General Manager ower & Industrial Systems Division TABLE OF CONTENTS Chapter 1. Introduction 2. Market Potential 3. Design Concepts 4. Costs and Cash Flow 5. Cost of Product 6. Conclusions A. Load Forecasts and Existing Generation of the Railbelt Utilities B. Conceptual Design Drawings C. Licensing Requirements 0. Cost Estimating Details E. Detailed Development of Beluga Power Cost 456/A3523-1/D3 18 23 27 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/D3 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. 456/2A3523-1/03 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. 3. 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, Beluga 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 Generating Capacit Year Added 1984 / 1985 39 (b) 1986 1987 i 1988 7 1989 90 (c) 1990 1 1991 i 1992 W 1993 4 1994 1995 . 1996 7 1997 W 1998 . 1999 ul 2000 129 Retired 72 36 19 38 148 1 2 56 143 1 516 FUTURE GENERATION NEEDS OF THE SOUTHERN RAILBELT SYSTEMS ASSUMING ON-TIME RETIREMENTS Total 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) Soldotna Unit 1. (c) Bradley Lake Hydro Plant. 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 (aay (303) (322) (342) (363) (441) (618) (647) T°2 LIGIHX4 Generating Capacit Year Added 1984 - 1985 39 (b) 1986 - 1987 : 1988 . 1989 90 (c) 1990 7 1991 - 1992 7 1993 7 1994 7 1995 - 1996 - 1997 : 1998 - 1999 - 2000 - 129 Retired 148 1 2 316 Total 826 865 865 849 841 931 883 883 883 847 847 828 790 642 642 641 639 FUTURE GENERATION NEEDS OF THE SOUTHERN RAILBELT SYSTEMS ASSUMING 5-YEAR DEFERMENT OF RETIREMENTS (Megawatts) Requirement Demand Reserve(a) Total 597 90 687 633 95 728 661 99 760 690 104 794 719 108 827 752 113 865 772 116 888 790 119 909 805 121 926 821 123 944 836 125 961 853 128 981 871 131 1002 890 134 1024 920 138 1058 944 142 1086 (a) Assuming 15 percent minimum reserve requirement. (b) Soldotna Unit 1. (c) Bradley Lake Hydro Plant. 456/4A3523-2/D3 Long (Short) 178 137 89 47 104 18 (5) (26 (79) (97) (133) (191) (360) (382) (417) (447) 2°e LIGIHX4 Generating Capacit FUTURE GENERATION NEEDS OF THE NORTHERN RAILBELT SYSTEMS ASSUMING ON-TIME RETIREMENTS (Megawatts) Requirement Demand Reserve(a) Total Year Added Retired Total 1984 - - 301 1985 - - 301 1986 - - 301 1987 - 3 298 1988 - - 298 1989 - 4 294 1990 - 17 277 1991 - - 277 1992 - - 277 1993 - - 277 1994 - - 272 1995 - 10 262 1996 - - 262 1997 - 25 237 1998 - - 237 1999 - - 237 2000 - 22 215 86 120 129 137 146 155 166 176 186 196 207 218 230 243 256 272 287 (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 ASSUMING 5-YEAR DEFERMENT OF THE RETIREMENT OF CERTAIN UNITS (a) Generating Capacit Year Added 1984 - 1985 - 1986 - 1987 - 1988 - 1989 - 1990 - 1991 - 1992 - 1993 - 1994 - 1995 - 1996 - 1997 - 1998 - 1999 - 2000 - Retired 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 b°2 LIGIHX3 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: L. 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, C09 and SO. 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 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. . 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- lutant Discharge Elimination System will be conditioned such that water quality standards are not violated. Stream and/or groundwater sampling jin 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/D3 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/D3 [STACKER /RECLaIMER ral [YARD Conve YOR 1,200,200 Ton) Se we STACKER /RECLAINER/S 2 _ _\\2.4300 To TRANSFER STATION NOG TYONEK NATIVE CoRP ( sugrace) COOK INLET REGION (MC. ($u8 SURFACED G9 KY FRANSAISS/ON LINE 1 2565125 N. 2552508. LEGEND QO): seevice Bunowe A ADMINISTRATION. B -MANTENANCE SHOP C~ WaARsHOUSE D- BARGE UNLOADING WAREHOUSE a | | | ale . | Q@>- Teansree station wo 4 a “ys Ie | | > OVERLAND Conv. uo Z DRIVE House ' \ : | @)>- TRANSFER STATION No.8 § SURGE BAL r ~ EX H I B I T 3 e | @- mam ELECTRICAL ¢ CONTROL BuUKONG gestae $ {OB \ | — SAMPLING BUKOING | @0@ — ELECTRICAL SUBSTATION \ POWER PLANT FEASIBILITY STUDY OS , | PLANT LAYOUT Mise. O1L § COOLANT STORAGE TANKS iH SK-005 | — FURL DISTRIBUTION STATION © fae {amenuoce sein DIAMOND/ SHAMROCK T w 2 & R 2 & eg z o x * Y 2 v ~ DIESEL C1 STORAGE TANKS — WATER STORAGE ¢ TREATMENT PLANT STORM DRANAGE POND > “LOCATION MAP” — SEWAGE TREATMENT PLANT GRANITE POINT COAL PORT - HELIPORT EB EFFLUENT DISCHARGE PIPE KENA! PENINSULA BOROUGH, ALASKA Location MAP QOOQOQOOOO! A co mote UGUST 10, 1984 Topo qe apne ot 7 trom - - £ - sear ncteweren Mtiect vor 10° orem 1980 ° 7 sv E : Checked By: __ [Approved ay: [Dete:8/ 10784 Comrat intermonon supplied by Sow! Engineers Aieade Stole Pine Coorginate Spriem ond geodetic sevetion ‘ 7 Drawing No. GRANITE POINT COAL PORT, Inc. Pameres Oy MORTH PACING AERIAL MUAVENE UNC, AWCRORAGE, ALAS Page 1 of 1 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 Dry FGD system with fabric filter DIAMOND SHAMROCK 150 MW BELUGA COAL FIRED UNIT CONCEPTUAL PROJECT SCHEDULE DESCRIPTION MILESTONES ENVIRONMENT/LICENSING Data Collection ER Review and Draft Els Final El D N/PRO REMEN gineering [Fluid System Descriptions Geotech Investigation Cooling Water Optimization bine e Op atio team Gen. Optimization or Equipment Sp O f d Desig Major Equipment Procurement | CONSTRUCTIO Mob ite Work tation Excav andFnd 9 o : cD Pressure Parts Ereciton | ea / oO [_1-GPedestal ection Boiler Feed Pumps Aux Equipment Installation Insulation and Lagging DISIs 3 610 witchyard Tnstruments and Controls Coal Handling Finds Qal Handling Structures oal Handling Equip Ash Handling and Disposal Equipment Bit Quality Control Equipment Flues and D Stack Adminisatration Facilities TEST AND START-UP Preop Testing and Insrtument Calb tart-up Commercial Operation A3331/G EXHIBIT 3.3 1985 1986 1987 1988 a es en a [e{ ml al mals J}A{S}O}N]D]s]F{ MP Aj Mis sals o[n]ofs Fi Mj) A|M Als on] ofa [e[m alms [s[a]s]oln[o}s |r| mal ms [s[a]s[oln[o]s [| mals [s [a|slo[n]o | BID 756 Vee | ce | weenie: cea | learcren | | yeseue nae | Ca + Yr | | 7 7 | 7 PEL TT ne 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 D.1 through 0.6 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 D0, 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/D3 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/D3 TZ DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA TITLE ii iii) PrETEriiiiiiiiyy) (eae AERC * TOTAL PROJECT * eee ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TN) 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, 864, 900 1, 831,080 4,695, 980 710 MECHANICAL EQUIPMENT 61,215 14, 266, 900 2, 448, 600 16, 715, 500 1,140 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 $148,680, 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 & LICEN. 14, 000, 000 14, 000, 000 CONSTR. MGMT. & 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 TOTAL PROJECT-1985 DOLLARS 1,672,387 $185,850,295 $133,702,480 $319,552,775 23, 483 JUUUIUIGIIIRIOUIGOGIUIIIUIOIOIOUGIIEIIGIIUIOGOIUGTIOFIDIODIIITIGIEOUIGITGIUIGGI BG ETIOO GEE JUUUUGOUIUUOUOOOOUUGOOUOOUUGHOUOGUOOG JUIUIUIGIUIIIOIGIGIIO OIE JUOUOGUGGUUOIEGHEE T°t LIGIHX3 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 2°y LIGIHX3 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. One case was run on the basis of 12 percent interest on construc- tion loans, 12 percent interest on long term debt, and 15 percent yield on equity, with a capitalization ratio of 75 percent debt and 25 percent equity. 2. A second case was run on the basis of 100 percent debt at 11.61 percent 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 inflation 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 Total Total Less: Total Less: Total TOTAL CAPITAL REQUIREMENTS (Thousands of Dollars) direct cost interest charges financing cost Interest earned capitalization Financing costs Tax effect of interest 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 ANNUAL ENERGY COST (Cents per Kilowatthour) Year 75/25 Capitalization 1991 11.36 1992 9.63 1993 10.28 1994 11.96 1995 11.72 1996 12.06 1997 12.83 1998 13.22 1999 13.63 2000 14.07 2001 18.23 2002 18.73 2003 19.27 2004 19.84 2005 20.45 2006 21.11 2007 21.81 2008 22.56 2009 23.36 2010 24.22 2011 25.18 2012 26.17 2013 27.23 2014 28.37 2015 29.60 2016 30.92 2017 32.34 2018 33.86 2019 35.51 2020 37.28 25 456/3A3523-5/D3 EXHIBIT 5.2 R.E.A. Financing 9.99 10.45 10.48 10.75 11.04 11.35 11.68 12.02 12.39 12.78 13.23 13.67 14.14 14.63 15.16 15.71 16.31 16.93 17.60 18.31 19.06 19.86 20.70 21.60 22.55 23.56 24.63 25.77 26.97 28.26 EXHIBIT 5.2.1 BELUGA COAL-FIRED POWER PLANT PROJECT ANNUAL ENERGY COST (Cents Per kWh) REA REA Year 80% Capacity Factor 70% Capacity Factor 1991 9.99 10.73 1992 10.45 11.21 1993 10.48 11.21 1964 10.75 11.47 1995 11.04 11.75 1996 11.35 12.05 1997 11.68 12.37 1998 . 12.02 12.71 1999 : 12.39 13.06 2000 12.78 13.44 2001 13.23 13.89 2002 13.67 14.26 2003 14.14 14.71 2004 14.63 15.19 2005 15.16 15.70 2006 15.71 16.23 2007 16.31 . 16.80 2008 16.93 17.40 2009 17.60 18.04 2010 18.31 . 18.72 2011 19.06 19.44 2012 : 19.86 20.19 2013 20.70 21.00 2014 21.60 21.85 2015 22.55 22.76 2016 23.56 23.71 2017 24.63 24.73 2018 r 25.77 25.81 2019 = 26.97 26.95 2020 28.26 28.16 26 REVISED 3/85 gt CHAPTER 6 CONCLUSIONS AND RECOMMENDATIONS From the results of this investigation, Gilbert/Commonwealth concludes as follows: 1. 3. 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: 1. 2. 3. 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. 27 456/1A3523-6a/D3 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. 28 456/2A3523-6a/D3 APPENDIX A LOAD FORECASTS AND EXISTING GENERATION OF THE RAILBELT UTILITIES 456/6A3523-7/D3 PROJECTED ANNUAL PEAK DEMANDS OF THE SOUTHERN RAILBELT SYSTEMS (Megawatts) Year CEA NEA HEA SES Subtotal AMLP Total 1985 165 139 85 10 399 198 597 1986 166 154 92 re 423 210 633 1987 166 168 99 11 444 217 661 1988 164 184 107 12 467 223 690 1989 162 201 116 12 491 228 719 1990 160 220 125 14 519 233 752 1991 173 216 130 15 534 238 772 1992 187 210 134 15 546 - 2nd 790 1993 196 205 138 _ 16 555 250 805 1994 205 200 143 16 564 257 821 1995 213 195 148 16 572 264 836 1996 221 190 153 16 580 273 853 1997 230 185 158 16 589 282 871 1998 225 192 165 16 598 292 (a) 890 1999 230 (a) 198 173 17 618 302 (a) 920 2000 230 (a) 205 180 17 632 312 (a) 944 (a) Extrapolated. Legend: CEA - Chugach Electric Association MEA - Matanuska Electric Association HEA - Homer Electric Association SES - Seward Electric System AMLP- Anchorage Municipal Light and Power T°V LI@IHX3 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 Mover Type Date Date (HW) @O°F (HW) (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 a 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 ad -- 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 D 0 1952 1990 0.3 0.3 15,000 Unit 2 D 0 1964 1994 0.6 0.6 15,000 Unit 3 D 0 1970 (used) 2000 0.6 0.6 15,000 Unit 4 D 0 1982 (used) 2012 0.6 0.6 15,000 Total HEA 2.1 SEWARD ELECTRIC SYSTEM (SES) Unit 1 D 0 1965 1990 1.5 1.5 15,000 Unit 2 D 0 1965 1990 1.5 1.5 15,000 Unit 3 D 0 1965 1995 2.5 2.5 15,000 Unit 4 D 0 1984 2004 2.5 2.5 15,000 Unit 5 D 0 1985 2005 2.5 2.5 15,000 Total SES 10.5 ANCHORAGE MUNICIPAL LIGHT AND POWER (ANLP) 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 D 0 1962 -- 1.1 a 10,500 Diesel 2. D 0 1962 -- 1.1 -- 10,500 Station 2 Unit 5&6 CCCT NG 1979 1999 -- 48.0 8,500 Unit 7&6 CCCT NG 1979 1999 ca 95.0 8,500 Unit 8 SCCT NG/O 1984 2004 77.6 94.8 12,000 Total AMLP 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 CCET || j= Combined cycle combustion turbine NG - Natural gas Distillate oi] 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 FMUS 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 €°V LIGIHX] 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 ron -- Diesel Unit 1 D 0 1961 1990 2.5 2.5 11,200 Unit 2 D 0 1961 1990 2.5 2.5 11,200 Unit 3 D 0 1964 1990 2.5 2.5 11,200 Unit 5 D 0 1970 1995 2.5 2.5 11,200 Unit 6 D 0 1970 1995 2.5 2.5 11,200 Unit 7 D 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 287.7 University of Alaska 13.0 Grand Total 300.7 Legend D fa Diesel SCCT - Simple Cycle Combustion Turbine ST - Steam Turbine 0 - Distillate oi] APPENDIX B CONCEPTUAL DESIGN DRAWINGS 456/7A3523-7/D3 Cn Co PLANT WASTE TREATMENT AREA -9| 2 pocseene 1 SUBSTATION Lo------ CONDENSATE ‘STORAGE CYCLE MAKE-UP ‘\ PRE-TREATMENT ‘ |_— ADWINISTRATION & _———— ‘SERVICE BUILDING TURBINE/ GENERATOR AREA f— OIL UNLOADING a & STORAGE COAL CONVEYOR x£ Je, Lime SLURRY =4 > VC ay £ iain fsa E] usage: | ABSORBERS | ABSORBERS " L--L-4 - \ r & storace _ u . SILOS CONTROL ROOM tat ' | —conrro. Roow | BAcHouse Bacws Lod - aT oO. om La. ows Aut ro ~ entuney—7 1 1 1 \— cntuner ASH HANOL ING EQUIPMENT AREA J XL ASH HANDLING EQUIPMENT AREA PLANT ROAD WAREHOUSE 0 700 SCALE IN FEET REVISIONS rev oave| oF Te] O0,] 0 Ty akc 12/10/84} GS = 64-0751 EXHIBIT B.1 ra poreation.nanisTion GILBERT/COMMOMNEALTH. INC. OF MICHIGAN Sec eaieron Ae ‘OWNER DIAMOND SHAMROCK/VOSS ~ POWER PLANT FEASIBILITY STUY PLOT PLAN ‘SK-002 1.0, FAM (BELOW) L.D. FAM (BELOW) ABSORBER BUILDING LIME STORAGE BUILDING LIME RECEIVING AND UNLOADING BUILDING \ s \ 1 / LIME SLURRY ROOM | Foo eaurpwenr }-~ t ' Le. | CsSSse=55 CIIIIEsSS=SaS ‘y FS E 8 Fa==o q " ADMINISTRATION SERVICE BUILOING OFFICE AREA GS5556 2207] 2522317224 10 EXHIBIT B.2 Tee uc 12/12/04} faadeone a Sse enckece renal GTLBERT/COMMONNEALTH INC. OF MICHIGAM ‘OWNER DIAMOND SHAMROCK/VOSS on Cesmaperton Ae POWER PLANT FEASIBILITY STUY PLANT LAYOUT GENERAL ARRANGEMENT OPERATING FLOOR ‘SK-003 SMOISIASY 10 10 3 8 1 ‘ | 5 4 3 2 | \ osu ! 1 BOILER ROOM ROOF VENTILATORS SILO LoMDING con. coeever ~ ABSORBER BUILDING CONVEYOR | sieeie (FUTURE) ii PK Tt. SON SN : DEAERATOR iin — TURBINE AREA DEAERATED / i \ vemrivaror stout arrer \ AN po LIME HOPPER ABSORBER Une oa Sg j TURBINE AREA cue NAA ‘ ; i waste Low maar BOILER = Y = t [Meta Se | tte | | — sa en HEATERS \ BOIL : i : H fe + HANDRAIL 4 fic | OUST 4 / = | CONDENSER RE-TuBING ~~~} 1 Me SPACE ee Conmenser| ' ' ! Access — + + * J TC WAINTENANCE CASH HOPPER ASILE ne \ PLvenizens \ wiuu/suaner <a 0 20 0 60 ‘SCALE IN FEET ‘ EXHIBIT B.3 mune lca er | csnem | srowisas oxnem auc 17/12/84} S ———==——=—— GILBERY/COMMOMTEALTH INC. OF MICHIGAN, 20 Ceampeton Ave DIAMOND SHAMROCK/ VOSS POMER PLANT FEASIBILITY STUDY PLANT LAYOUT GENERAL ARRANGEMENT ELEVATION VIEW REVISIONS. rev. oave| ore] omo.] 10 9 8 7 | 6 5 4 3 WOT RENEAT nea LP, WEATER DRAIN HP. HEATER NOL 4 Loe thee —__ BOILER FEED PUMPS LP, HEATER NO, 3 DEAERATOR (1-100 STEAM DRIVEN) (1-100 MOTOR DRIVEN) 4 LeP. TURBINE CONDENSATE PUMPS (21000) CONDENSER LP. HEATER NO, 1 GENERATOR MAKE-UP ATER FROM. TREATMENT SYSTEM (CHLORINATION LiP. HEATER ORAIN — LP, HEATER NO. 2 CIRCULATING WATER PUMPS (2-100 (COOLING TOWER EXHIBIT B.4 at nae orvices oF GILBERT/COMMONNEALTH INC. OF MICHIGAN. a SHAMROCK VOSS rosie Stuy een FLOW DIAGRAM een WATER APPENDIX C LICENSING REQUIREMENTS 456/8A3523-7/D3 Permit Activity DIAMOND CHUITNA POWER PLANT MAJOR APPROVALS REQUIRED FOR 150 MW COAL FIRED FACILITY EXHIBIT C.1 Sheet 1 of 2 Prevention of Significant Deterioration (PSD) New Source Review National Pollutant Discharge Elimination System (NPDES) Permit Structures in or affecting navigable waters Permit for dredged or fill material Certificate of Reasonable Assurance Wastewater Disposal Permit Water and Wastewater Treatment Works Plan Approval Water Rights Permit Aircraft Obstruction Notice Cultural Resources Survey 456/A3425-Tb 1/03 New air contaminant sources - new boilers, coal handling, ash handling water discharges into waters of the U.S. Intake and discharge structures, transmission lines Fill or dredging in waters of the U.S. Water Quality Certification Disposal of wastewater into or onto waters or lands of Alaska Water and wastewater treatment systems Appropriation of waters of Alaska Chimney, stack, transmission towers Site Survey Agency (a) Authority (b) Time (c) Remarks DEC/Region X AS 46.03.150 6-12 mos Because of the amount of electricity EPA 18 AAC 50.120 sold to a utility power distribution system (over 1/3 of output and over 25 MW) Subpart Da applies to the 150 MW unit. EPA Clean Water Act, 6-12 mos This activity may involve preparing an P.L. 92-500, Section 402 environmental report. COE River and Harbor Act of 1899, 3-12 ms This activity may involve preparing an 33 U.S.C. 401-413 environmental report. COE Clean water Act 3-12 mos This activity may involve preparing an P.L. 92-500, Section 404 environmental report. DEC Clean Water Act 3-6 mos Required for activities affecting waters P.L. 92-500, Section 401 of Alaska which require federal license . or permit. DEC AS 46.03.100 3-6 mos If NPDES permit is issued, Alaska waives 18 AAC 72 the procedural requirements and adopts the NPDES permit. DEC AS 46.03.090 6 mos 18 AAC 72.060 DNR AS 46.15.030-.185 2-3 mos 11 AAC 72 FAA P.L. 85-726 1 mo Notice only, no approval required. 14 CFR 77 ONR (Historic Archaeological Resources 3-6 mos Surveys are to be performed during Preservation Protection Act of 1979 Of ficer) periods with no snow cover. Exhibit C.1 Sheet 2 of 2 Permit Activity Agency (a) Authority (b) Time (c) Remarks Solid Waste Disposal Permit Disposal of fly ash, bottom ash, DEC AS 46.03.100 3-6 mos scrubber sludge, construction 18 AAC 60 waste Transmission Line Transmission Line Routing Various Various 6-12 mos The transmission lines associated 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 DNR - 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. 456/A3425-Tb1/D3 Does not include application preparation time. with the 150MW facility will require numerous environmental, land use and right-of-way permits and approvals. APPENDIX D COST ESTIMATING DETAILS 456/9A3523-7/D3 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA JURUUUOUINIUIBOIUGIGGUIGIUIUIUIUBIOIIOIUIIOBEINGBBUUBEBOEBOOGBEOGOIOGOIOGOINOGOIOBEBOEIIGOIIIGGGIIGGGIGUEIIGUUIIUEE UGH OEM OE MIE eee * GENERATORS * JOUUGOGOOGGE ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TN) 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 (UUURGUIEEUEBUUOUORIEGUOGBUUUUNEGGUUUOUEGOUEBOUGGBHOGUUOUUOOGUUGUIUUGIUGGIOOUOGEGE Cece one eee * DRY SO2 SYSTEM « Ue ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TN) 1SOMW INCL LIME PREP, ABSORBER, 225, 000 $11, 000, 000 $9, 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 SSesesesssss oo Sessesssssss 9 sassssssssas 0 sssscassssss 0 sesceseassss TOTAL DRY SO2 SYSTEM 226, 620 $11,057, 300 $9, 064, 800 $20, 122, 100 2,577 JUG UGGUOOGGGUUOUOIOIGUOUGOGUIGUIIUGIGEIUIGIITIUIGIIITGDIUIGIOGIEIOIGGOMEIEGIIGGIIEITITIIGIGIIEIGIGIIEIGIGITIGIGCITUIGI GIGI ee * COAL HANDLING « JOGO ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TN) 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, 800 284 FOUNDATIONS FOR BENDS 600 8, 400 24,000 32, 400 122 COAL HANDLING-QUOTED FROM FHC 42, 857 2,812,500 1,714, 280 4,526,780 0 SSsscscsas55 0 ssssssesssss oo sssssssssses 0 sssseseessss 9 ssesscsssse5 TOTAL COAL HANDLING 45,777 $2, 864, 900 $1, 831,080 $4,695, 980 710 JOCURI GGGOGUUGGURGGUIOGGHIOGUEIOGOUIOGUEUOUUUGOUOGUIOGEIIOUIUIEIOHEIUUGOUGEIIEIIUE GID OUGIEOOIG GOTO U'G LIGIHX3 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA * MECHANICAL EQUIPMENT «* (GUO ITEM DESCRIPTION MANHOURS 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 1,790 264, 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 MISC. MECHANICAL EQUIPMENT 7,570 4, 468, 000 302, 800 4,770, 800 HVAC 7,215 552, 800 288, 600 841,400 WASTE WATER TREATMENT PLANT 12, 000 1,925, 000 480, 000 2, 405, 000 COOLING TOWER ACID FEED 500 70,000 20, 000 90, 000 BOTTOM ASH SYSTEM 5,000 500, 000 200, 000 700, 000 SSSseesaee5 0 saesescsssss 4 ssescccsssss sescsessssss 2 sases TOTAL MECHANICAL 61,215 $14, 266, 900 $2, 448, 600 $16, 715, 500 (CCID JCC CUCU CUO 0000000000000 00000000 UG UU UNG G00 IOOOOOO OGG OUOOGGGGG ae OC * ELECTRICAL « COU ITEM DESCRIPTION MAHHOURS MATERIAL LABOR TOTAL WEIGHT(TN) TRANSFORMERS 3,924 $1, 228, 000 $156, 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 iS GROUNDING & LIGHTING PROTECT. 4,030 59, 700 161, 200 220, 900 i) 480 MCC’S 720 140, 000 28, 800 168, 800 12 ELECTRICAL RACEWAY . 49, 940 709, 350 1,997,600 2,706, 950 571 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 SSSSSS5enEES SEeseetsssss 4 saseassssess 4 oo sassssessazs 20 sssueesezsss TOTAL ELECTRICAL 139, 177 $4, 892, 000 $5, 567, 080 $10, 459, 080 1,872 SHAE CCC 00 00000 C0000 OOOO CoO oe eee @°G LIGIHX4 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA JG2UOUOUGOUEEOONEOOOOOGOOUUEOOOUOr inl JCUUGGGUBGOUGOOUGGOOUOUOOOOOiennme CO * SITEWORK # eee ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TH) SITE ROUGH GRADING 4,000 $160, 000 $160, 000 0 CLEAR & GRUB 5,000 200, 000 200, 000 0 FINE GRADING 2,400 96, 000 96, 000 0 ON SITE ROADS/PARKING 3,740 $112, 200 149, 600 261, 800 4,678 . STORM DRAINAGE SYSTEM 800 26, 000 32,000 58, 000 oO SITE FENCE 720 43, 200 28, 800 72,000 2 SITE FIRE PROTECTION LOOP 6,000 76, 000 240, 000 316, 000 60 SANITARY 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/400GPM PUMP OIL STORAGE STRUCTURE 32, 000 56, 000 88, 000 Seeeesssesss oo sesacsssssse 0 sssssssss555 TOTAL SITEWORK $332, 400 $1,027, 200 $1,359, 600 * CIVIL/STRUCTURAL # JSOUUOOUUUOOOUOGOGoGE ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TH) ADMINISTRATION BUILDING 19, 683 $920, 800 $795, 320 $1,716,120 a1 MACHINE SHOP 1,548 $72, 000 $61,920 $133, 920 18 WAREHOUSE 7,395 $341,000 $295, 800 $636, 800 109 150MW BOILER & TURBINE BLDGS. 150, 339 $7,157,500 $6, 013, 560 $13, 171,060 1,577 SUPER & SUBSTRUCTURE STRUCTURAL ONLY wessasesssss oo saseessesess oo sesssssssssz 0 = Beeses 9 seesses = TOTAL CIVIL/STRUCTURAL 179, 165 $8, 491, 300 $7, 166, 600 $15, 657, 900 1,795 JOU GUISIUIIUIOIGIOUIIUISIUIOIOIUIGQU UIQ ITIOUIGI II UIDITIGIGUITIGIGQUIDIDIIIDITIOUIOI DIGG U DIGIT IDOE * CHIMNEY & FOUNDATION « JOROUUNGOOUOHOOOOOOOOGiEE ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TH) CHIMNEY & FOUNDATION 19,350 $581, 000 $774, 000 61,355, 000 2,700 €°d LIGIHX3 DIAMOND SHAMROCK. FEASIBILITY ST 150 MW COAL FIRED CHUITNA, ALAS /VOSS 'UDY PLANT KA JUDOUGOOGOUUUUOOOUOUUOUUOOOUGOBEIUGOUUUOGOEEIEEOEEUUOOOOOOUOIIIIBIIUEEUGOGHUIGEIE UIE UTEOGOOOGIIIEIE OE UUUO IEEE AE JOU * COOLING SYSTEM « (OQ UIQUOIOGGGOGOE ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TN) 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 o --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 o --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° M/O BUTTERFLY VALVE 320 60, 000 12, 800 72,800 o --30° M/O BUTTERFLY VALVE 320 52,000 12, 800 64, 800 0 --42° EXPANSION JOINT 480 15, 000 19, 200 34, 200 0 COOLING TOWER BASIN 11,613 117,700 464,520 582, 220 694 WATER WELLS 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, 000 120, 000 0 SUBTOTAL FPS 71,537 $1,057,600 $3, 919, 080 724 SSeeeessssss 0 sesessssssss Sssesscssss 0 seseesesesss TOTAL COOLING SYSTEM 166,645 $2,9: $6, 665, 800 $9, 606, 000 1,448 40, 200 v°d LIGIHX4 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA * INSTRUMENTATION & CONTROL * JOUUUOUUUUUSUOOOUHUUHEGGGHOOE ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TH) MAIN CONTROL PANEL COMPLETE 1,000 $250, 000 - $40, 000 $290, 000 5 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 1,500 75, 000 60, 000 135, 000 6 VALVE CONTROLLERS 2,400 120, 000 96, 000 216,000 38 LOCAL CONTROL PANELS 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 5 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 SSESEEESaSSS seseseccsses osssssesccass oo seessacssssz 2 seeueesssess TOTAL I&EC 48, 000 $3, 107, 500 $1, 920, 000 $5, 027, 500 141 S$°d LIGIHX3 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 150 MW COAL FIRED PLANT CHUITNA, ALASKA JUEOIGROSGOOGOOOUUGEIOOUOOUEOOUSOOOGUEUEOGOGOOUOOOUOOUOOUOOOODOHEIGO EGO UO U TOUT BTU IGE EEE EEE JOU * PIPING » ee ITEM DESCRIPTION MANHOURS MATERIAL LABOR TOTAL WEIGHT(TN) 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 14 --SMOKE DETECTORS 514 2,000 20, 560 22,560 1 --CONVEYOR SPRINKLER SYSTEM 2,857 25, 000 114, 280 139, 280 14 ROOF DRAINS 4,200 21, 000 168, 000 189, 000 6 SSESESESSS55 seescsesssss sessessscsss oo sanesscsssss 09 saacesssesss TOTAL PIPING 388, 258 $5,571,600 $15, 530, 320 $21, 101,920 1,547 JUGUUUOUGUUOUOOOUUGUUGHOGUGOBOUEOUUOUUUGGUUUBIEUOOUOOOUOGUOETEUUOOOEE 9° LIGIHX3 DIAMOND SHAMROCK/VOSS FEASIBILITY STUDY 198 Mw COAL FIRED PLANT CHUITNA, ALASKA eee EEE EE EDD OEE EASE EEE: # CASHFLOW # #$ 1,000 # UE Year 1 Year 2 Year 3 Year 4 Year 5 ITEM DESCRIPTION Ist 2nd avd 4th Ist 2nd 3rd 4th Ist 2nd ard 4th ist end and Ath Ist end ard 4th MATERIAL §=LABOR = TOTAL STEAM GENERATOR 1,980 3,968 5,948 5,948 990 1,988 4,958 2,978 998 i $19,808 $9,908 $29, 708 TURBINE GENERATOR 1,108 2,208 3,388 3,320 376 «1,852 564 198 $11,008 $1,880 $12,688 DRY SO2 & FABRIC FILTER 5,529 4,423 2,728 2,720 2,728 2, 812 $11,057 $9,065 $28, 122 COAL HANDLING 1,146 1,433 836 49 9 183 $2,865 $1,831 $4,696 MECHANICAL EQUIPMENT i 7,134 (5,707 1,427 988 988 245 245 $14,267 $2,449 $16,716 ELECTRICAL EQUIPMENT 978 978 «1,257 «2,092 18131113 MM 835 278 $4,892 $5,567 $10,459 INSTRUMENTATION & CONTROL 621 621 717 1,085 909 34 cy 364 $3,107 $1,928 $5,827 ‘STTEWORK 68 612 612 68 $332 $1,027 $1,359 CIVIL/STRUCTURAL~BLDES. 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 SAB 2,588 2,666 «2,000 $2,948 $6,666 $9,686 PIPING 1,672 1,672 1,672 2,118 3,106 4,659 4,659 1,553 $5,572 $15,538 $21, 182 ‘SUBTOTAL e e e a 68 «8,389 12,615 12,584 13,795 6,269 16,528 16,574 7,468 15,118 13,708 11,559 8,414 3,017 662 © $84,904 $63,776 $148,688 FRT. BSPEC. HNDLNG@$250/TON 1,349 1,349 1,349 1,798 450 899 899 899 $5,871 $3,120 $8,991 CONSTR. INDIRECT COSTS 2,004 4,676 6,681 6,681 6,681 6,681 6,681 5,345 5,345 4,008 4,008 3,340 3,340 1,336 $66,807 $66,807 BOARD & LODGING 292 680 ae a2 972 972 72 ™ ™ 583 583 486 486 19% $9,718 $9,718 ENGR. ,ENVIR.PERNITALICEN. 700 1,400» 1,688 © 2,808» 2,888 2,248 1,688 = 700 $14, 000 $14,008 CONSTR. MGMT. & OWNERS COST 223 set TAS 745 TAS m5 TAS 596 596 4a7 447 we we 149 $7,446 $7,446 CONTINGENCY @ 25% 1753582788 173,624 5,388 5,738 «5,998 3,779 6,956 6,468 «3,771 «5,459 4,685) 41493153 1,804 585 @ $63,911 $63,911 SUBTOTAL 875 1,758) 2,108) 3,500 3,517 9,732 14,287 16,183 16,193 12,625 16,252 15,764 11,388 12,177 9,723 9,188 = 7,352 6,082,265 @ $100,946 $69,927 $178,873 TOTAL PROJECT-"85 $ «$875 $1,752 $2,108 $3,500 $3,585 $18,121 $26,982 $28,688 $29,988 $18,894 $34,780 $32,338 $18,856 $27,295 $23,423 $20,746 $15,765 $9,019 $2,927 $0 $185,858 $133, 783 $319, 553 4 HEREEEEEEEEEE: Pei) ei URC R OCS EEE EEEEEEEEEE PERERA EERE EEE EEE EATS Oe JCAHO CUCU EE, UH JHU eee Z£°Q LI@IHX3 APPENDIX E DETAILED DEVELOPMENT OF BELUGA POWER COSTS 456/10A3523-7/D3 R.E.A.-70% CAPACITY FACTOR DETAILED BELUGA POWER COST 3/85 BASE -R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT © M56 Ul, 85-02-07 16.04) SUMMARY OF ASSUMPTIONS AND OTHER INPUT DATA FOR THIS CASE ITEM TOTAL PERCENT ANNUAL REQUIRED TERM PAYMENT AMOUNT OF COST COVERAGE (YEARS) PERIODS ($000) = TOTAL % CAPITALIZATION EQUITY 1001 ¢ 0 0.0 0.0 0.0 0.0 0 PREFERRED STOCK 1002 ¢ 0 0.0 0.0 0.0 0.0 0 CONVENTIONAL BONDS 1003 ¢ 0 0:0 0:0 0:0 0:0 0 OTHER LONG TERN DEBT faye eM re Wier te en ll Wezel linge 0 0 ot RN Sig 0 0 TOTAL CAPITALIZATION 1000 C 493500 — 100.00 11.61 0.0 0.0 0 ITEM TOTAL TAX BASIS PROJECT COST EXCLUDING IDC ($000) 291 C 388170 NON-DEPRECIABLE INVESTMENT (LAND) 161 C 0 SALVAGE FACTOR 306 C 0.0 PERSONAL PROPERTY-% 1038 C = -:100.0 REAL PROPERTY-% 1039 ¢ 0.0 PERSONAL PROPERTY TAX LIFE CACRS) 303 0 10 INVESTMENT TAX CREDIT-% 1033 C 8.0 ENERGY TAX CREDIT-% 1034 ¢ 0.0 EQUITY PARTICIPANTS TAX BRACKET-% 1037 C 0.0 STATE INCOME TAX RATE-% 1194 ¢ 9.4 FEDERAL INCONE TAX RATE-% 1195 ¢ 46.0 MISCELLANEOUS DATA PROJECT COST INCLUDING IDC ($000) 404 493418 AVERAGE (BOOK) SERVICE LIFE 299 0 30 PROPERTY TAX RATE (PCT OF PLANT) 1094 C 0.0 GROSS RECEIPTS TAX RATE 1095 C 0.0 BASE YEAR FOR PRESENT WORTH 150 0 1985 DISCOUNT RATE APPLIED 1054 C= .11..61 PLANT OUTPUT-GIGANATTHOURS(GWH) 160 I = 865.0 3/85 BASE-R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT © M54 Ul, 85-02-07 16.02) 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 Q 0 0 0 0 0 0 0 0 0 PREFERRED STOCK 31¢ 0 0 0 0 0 0 0 0 0 0 CONVENTIONAL BONDS 12 ¢ 0 0 0 0 0 0 0 0 0 0 R.E.A. GUARANTEED BONDS 13.¢ 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 14 C¢ 0 0 _0 oO o __ oO oO oO 6G 0 STRUCTION LOANS yf ¢ oo 0 24 0 4 00 9300 4 00 1300 32300 357 0 _9 ob CONSTRUCTION LOANS 0 0 000 ___9300 300 _2 0 36 TOTAL PROCEEDS AVAILABLE 40 ¢ 1000 1963 2438 4052 9300 4305 — 21304 32394 35787 — 93605 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS. CONSTRUCTION EXPENDITURES 20 ¢ 914 1855 2259-3820. 8847 3970 20361 += 30671 += 33187 = 88188 START-UP COSTS (CAPITALIZED) 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 I 0 0 0 0 0 0 0 0 0 0 FINANCING COSTS 21¢ 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 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK DIVIDENDS 70C __0 0 0 0 0 ___o 0 0 TOTAL UTILIZATION 50 ¢ 914 1855 2259 3820 8847 3970 — 20361 30671 33187 ~ 88188 BALANCE ON DEPOSIT 3¢ 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 Til 184 238 468 344 967 1767 2665 5557 INTEREST CHARGES CONSTRUCTION LOANS 61 25 72 132 232 462 340 872 1680 2572 5465 CONVENTIONAL BONDS 62C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPHENT BONDS 63C 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 64 C 0 0 0 0 0 0 0 0 Q 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 q 74 87 92 92 VEE EE EEE EOE INTEREST CHARGED TO CONSTRUCTION 91 23 70 128 227 447 332 849 1637 2508 5325 TOTAL ANOUNT CAPITALIZED 92. 937 1925 2387 4046 9295 4301 21210 = 32308 §=— 35694 ~=—-93513 CUMULATIVE AMOUNT CAPITALIZED 93C 937 2862 5248 9295 9295 13596 34806 67113 102808 102808 DEBE SEE EE EO CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 20 875 1750 2100 3500 8225 3585 18121 26902 28688 77296 BASE-R.E.A.- 70% PLANT FACTOR ($000) ITEM NET PROCEEDS AVAILABLE BEGINNING OF PE 10 CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS R.E.A. GUARANTEED BONDS OTHER LONG TERM 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 CEPOSIT-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 TERM DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD HHI KEN IO INTEREST CHARGED TO CONSTRUCTION TOTAL AMOUNT CAPITALIZED CUNULATIVE ANOUNT CAPITALIZED 32K CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION ll Po eee orusune 20 53 30 21 38 52 70 50 61 63 64 65 91 92 93 AQEQNRNMAN A ag99 9 A29092 9 AN AAEM OHOHO BELUGA POWER PROJECT C M54 Ul, 85-02-07 16.02) PAGE 2B CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD 1988 1989 92 42 40 57 92 28 46 27 7 28 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 0 0 0 0 9 0 0 0 0 0 3 0 0 0 0 0 0 0 38600 26600 47300 46000 _158500 0600 42600 39100 37000 _149300 38692 26642 47340 46057 158592 30628 42646 39127 37007 =149328 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 0 0 0 0 0 0 0 0 0 0 0 0 2 0 0 0 0 0 0 0 0 0 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 3493 4139 5309 6403 19204 7167 8187 9122 10042 34437 87 103 133 160 484 179 205 228 251 863 3580 4243 5442 6563 19688 7346 8392 9350 10293 35300 3537 4202 5385 6535 19660 7300 8365 9342 10267 35275 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 3537 4202 5385 6535 19660 7300 8365 9342 10267 35275 42 40 57 28 28 46 27 Z 25 25 3450 4099 5252 6375 19176 7121 8160 9114 10016 34412 38650 26602 47284 46029 158564 30582 42620 39119 36982 149303 141458 168060 215343 261372 261372 291954 334573 373693 410675 410675 29988 18894 34780 32338 116000 18856 27295 23423 20746 90320 BASE-R.E.A.- 70% PLANT FACTOR ($000) NET PROCEEDS AVAILABLE BEGINNING OF PERIOD CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS R.E.A. GUARANTEED 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 REPAYMENT 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 DEVELOPNENT BONDS OTHER LONG TERN DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD HON NEE EK INTEREST CHARGED TO CONSTRUCTION TOTAL ANOUNT CAPITALIZED “CUMULATIVE AMOUNT CAPITALIZED YEN HK CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 10 61 62 64 65 91 92 93 QQQOANNNANAN OC 2299 9 2229299 9 20 ANAM KMOROHO 0 BELUGA POWER PROJECT CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM C M54 1990 25 46 19 95 25 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 493500 493500 0 0 0 oO o 0 0 0 493500 493500 31600 _ 23400 _ 14400 __ 13400 _ 82800 31625 — 23446 14419 —506995 576325 20792 12069 = 2617 1378 36856 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 493500 493500 0 0 0 0 0 0 0 0 0 0 20792 ~ 12069 2617 ~494878 530356 10833 — 11377 — 11802 — 1217 45969 271 284 295 303-1153 T1104 ~1V66l 12097 12420 47122 11057. 11642 +=: 12002)»: 12337 47040 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 11057 — 11642 — 12002 12337 — 47040 46 15 5 82 82 10787-11358 =611707. 12035 45887 31579 23428 «=: 14324 = 13412-82743 442254 465681 480005 493418 493418 15765 9019 1927 1000 27712 Ul, 85-02-07 16.02) PAGE 2c 4a BASE -R.E.A.~- 70% PLANT FACTOR ; BELUGA POWER PROJECT C M56 Ul, 85-02-07 16.04) PAGE 3A FORECASTED STATEMENT OF INCOME ($000) ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 OPERATING REVENUES PROJECT REVENUE REQUIREMENT 1c 92802 96958 96925 99227 101667 104253 106995 109901 112982 116247 SALES OF ELECTRICITY 2c 0 0 0 S ° HK c ; e ; AVOIDED COST OF ELEC. 17c¢ 0 0 0 TOTAL 3c 92802 96958 96925 59257 To1ee7 104353 100355 TOss01 112582 Treza7 OPERATING EXPENSES OPERATION & MAINTENANCE OPERATION £ MAINTENANCE EXPENSE 6 G __2anna __zeste 2785p 29868 S300 __ 33020 __gsstg __Soshe $3gde 29828 oP MAINTENA 3 73 9566 1940 TOTAL O&M 8C 34244 36299 38477 40785 43232 45826 48576 51490 54580 57855 LEASE EXPENSE 271 0 0 0 0 0 0 0 0 0 0 DEPRECIATION EXPENSE 9c 16447 16447 16447 16447 sonar pened 16447 16447 16447 16557 PROPERTY TAX 94 C 0 0 0 0 0 0 0 GROSS RECEIPTS TAX 95 C 0 0 0 0 0 0 0 H _ TOTAL OPERATING EXPENSES loc 50691 52746 54924 57233 59680 32378 65023 67938 71027 74302 OPERATING INCOME go c 42110 44212 42001 41994 41987 41980 41972 491964 41955 41946 OTHER INCOME AND EXPENSES llc 0 9 241 256 271 287 305 323 342 363 INCOME BEFORE INTEREST CHARGES 12c¢ 42110 44221 42242 42250 42258 42267 42276 42286 42297 42308 INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS 13. Cc 0 0 0 0 0 0 0 0 0 0 REA GUARANTED BONDS 144 C¢ 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 OTHER LONG TERM DEBT 15 Cc 0 0 0 0 0 0 0 0 0 SUBTOTAL 16 ¢C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 OTHER INTEREST & EXPENSES ANORTIZED BOND DISCOUNT & EXPENSES 18 C 0 0 0 0 0 0 0 0 0 0 SHORT TERM LOANS 19 Cc 0 0 0 0 0 0 0 0 0 0 INTEREST DURING CONSTRUCTION 20 C A 0 0 0 0 0 0 0 0 0 SUBTOTAL 21 c 0 0 0 0 0 0 0 0 0 TOTAL INTEREST AND OTHER EXPENSES 22 C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 NET INCOME 23.Cc -15148 12883 -14688 -14485 -14259 -14007 -13725 -13409 -13057 -12663 HHH IIE COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 C = 107.29 112.09 122.05 124.72) 117.53) 120.52 123.69 =:127.05 = 130.62 134.39 IN PRESENT WORTH DOLLARS 163 ¢ 55.50 51.96 46.54 42.69 39.19 36.00 33.11 30.47 28.06 25.87 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 107.29 109.56 110.30 111.23 112.23 113.26 114.31 115.36 116.41 117.45 BASE -R.E.A.- 70% PLANT FACTOR ($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 INCONE 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 M7700 305000000008 COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT WORTH DOLLARS 163 LEVELIZED AMOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SANE CUMULATIVE PRESENT WORTH AS 7 THAT RESULTING FROM THE ACTUAL = ANNUAL AMOUNTS CALCULATED 159 c c c c a 29 fF AAMAOFKAAO Oo AAAAA AANn0O ao BELUGA POWER PROJECT C M56 Ul, 85-02-07 16.04) PAGE 3B FORECASTED STATEMENT OF INCOME 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 alee 123343 nea 131596 a7s6 asset 145310 ate aera aa 0 0 ssa t eet sas? oes — ! — YD I 9 120113 123343 127278 131396 135767 140400 145310 150516 156033 161882 16870 17882 18955 20092 21298 22576 23930 25366 26888 28501 $4456 47124 49 2 6125 59492 63062 6684 70856 75108 ice Papas 68906 oo es arte 86992 Pts Rate Pie 0 0 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 0 0 0 0 0 0 0 0 0 0 oe le TT ee ie io 77773 81453 85353 89487 93870 98515 103439 108659 114191 120056 42340 41890 41925 41909 41897 41884 41871 41857 41842 41826 384 452 477 510 543 580 619 660 705 753 42725 42342 42402 $2418 42440 42464 42490 42517 42547 42579 0 0 0 0 0 0 0 0 0 0 5 eau pares aes oeeee 51498 50655 49711 men 47470 — 2? — 2 —-! — 2 — 2 —-2 —~-2 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 -11818 -11721 ~11124 _ =10506 ~9811 -9034 -8165 -7194 -6107 -4891 138.86 142.59 147.14 151.90 156.96 162.31 167.99 174.01 180.39 187.15 23.95 22.04 20.37 18.85 17.45 16.17 14.99 13.91 12.92 12.01 118.51 119.53 120.54 121.54 122.52 123.48 124.43 125.35 126.26 127.14 BASE -R.E.A.- 70% PLANT FACTOR ($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 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 TE KK COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT NORTH 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 c c c I c c c c c c eo AAANRD A200 oO oo BELUGA POWER PROJECT C M56 U2, 85-02-07 16.04) PAGE 33¢ FORECASTED STATEMENT OF INCOME 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 168116 ala 181617 ahh aiid’ 205125 etsset aa 233126 7200s 0 0 0 0 0 0 0 0 0 168116 174646 181617 189001 196828 205125 213920 223243 233126 243601 30211 seat 33383 33982 38141 60429 42855 AH soups aeeee 2 8 4822 005 0 93 9 12 134507 ELE 116415 125400 aa8BUe 138652 aah = aeatet £72082 185548 0 0 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 0 6 0 0 ° 0 0 $ 0 0 0 0 0 126273 132862 139847 147251 155099 163418 172237 181584 191492 201995 41843 41784 41770 41750 41729 41707 41684 41659 41634 41606 805 864 923 987 1056 1130 1210 1296 1389 1489 42648 42648 42693 42736 42785 42837 42894 42955 43022 43096 0 0 0 0 0 0 0 0 0 0 oe 44663 behest as 39064 36735 34128 31210 Bh 24285 0 0 0 0 46146 44663 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 46146 44663 43003 41145 39064 36735 34128 31210 27943 24285 -3498 -2015 -310 1592 3720 6101 8765 11745 15080 18811 194.35 201.90 209.96 218.50 227.55 237.14 247.31 258.08 269.51 281.62 11.18 10.40 9.69 9.04 8.43 7.87 7.36 6.88 6.44 6.03 128.00 128.85 129.66 130.46 131.23 131.98 132.71 133.41 134.10 134.76 a BASE -R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT ( M56 Ul, 85-02-07 16.04) PAGE 4A NET WORKING CAPITAL (FUNDS) AVAILABLE ($000) ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES i c a 96958 inees 99227 tees 104253 Tene Paes tneeae atnske OTHER INCONE ee EC 256 271 287 SUBTOTAL 37: ¢ 92802 96967 97166 99482 01938 104541 107300 110224 113324 116610 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 ¢ 92802 96967 97166 99482 101938 104541 107300 110224 113324 116610 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 Cc 50691 52746 54924 57233 59680 62274 65023 67938 71027 74302 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 Cc 16447 16447 16447 6447 164 64 6 16447 16447 16447 FUNDS APPLIED TO OPERATING EXPENSE 42 C 34244 36299 38477 40785 43232 45826 48576 51490 54580 57855 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43C 58558 60668 58689 58697 58705 58714 58724 58734 58744 58755 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 0 0 0 0 0 0 0 0 0 0 REA GUARANTED BONDS 45 1 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERN DEBT 46 1 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 1 0 0 0 0 0 0 0 0 0 9 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 C¢ 0 2110 132 139 148 157 166 176 187 198 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 C 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ENERGY one eer De en He c 1-00 ate 1.00 1.00 1.00 aiet 1.00 1.00 1.00 1.00 OTHER LONG TERM DEB c .0 20 0.0 0.0 0.0 Q. 0.0 0.0 0.0 0.0 TOTAL DEBT 54 C 1.00 1.04 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 BASE -R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT ( M56 Ul, 85-02-07 16.04) PAGE 4B NET WORKING CAPITAL (FUNDS) AVAILABLE ($000) ITEM 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES OTHER INCOME 1 SUBTOTAL 3 LESS INCOME THAT IS NOT CASH 3 FUNDS PROVIDED BY OPERATING REVENUE € et +4 mar tts acini aeeie CEE 140400 ae2ete ett TE qeaee 4 2 7 5 543 5 9 70 : 120498 123795 127755 131906 136310 140979 145929 151176 156738 162635 c One 0 0 0 0 0 0 0 0 0 0 AND OTHER INCOME 39 120498 123795 127755 131906 136310 140979 145929 151176 156738 162635 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES loc 77773 81453 85353 89487 93870 98515 103439 108659 114191 120056 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 Cc 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 FUNDS APPLIED TO OPERATING EXPENSE 42 C 61326 65005 68906 73040 77423 82068 86992 92212 97744 103609 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 C 59172 58789 58849 58865 58888 58911 58937 58964 58994 59026 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 0 0 0 0 0 0 0 0 0 0 REA GUARANTED BONDS 45 I 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT 46 I 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 I 0 0 0 0 0 0 0 0 0 0 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C 58558 — 58558 58558 58558 58558 58558 58558 ——5a558 ——58553 55558 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 ¢ 614 231 292 308 330 354 379 407 436 469 DEBT SERVICE COVERAGE ; CONVENTIONAL BONDS 51 ¢ 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ENERGY DEVELOPTIENT BONDS 32 ¢ 1.01 1-00 1.00 1.01 1-01 1.01 1.01 1.01 1:01 1.01 THER LONG TER T a: : 0: ; lo 0: lo 0.0 0.0 0.0 TOTAL DEBT 54 ¢ 1.01 1.00 1.00 1.01 1.01 — 1.01 1.01 1.01 1.01 1.01 BASE -R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT C M56 U2, 85-02-07 16.04) PAGE 34C NET WORKING CAPITAL (FUNDS) AVAILABLE ($000) ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCONE OPERATING REVENUES 3c 168116 174646 181617 189001 196828 205125 213920 223243 233126 243601 OTHER INCOME llc 805 86 92 98 05 30 12 1296 1389 1489 SUBTOTAL 37. ¢ 168920 175510 182540 189988 197884 206255 215130 224539 234515 245091 LESS INCOME THAT IS NOT CASH 38 1 0 0 0 0 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE a wa ee | careers eerie || eet ee | ee AND OTHER INCOME 39 ¢ 168920 175510 182540 189988 197884 206255 215130 224539 234515 245091 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES loc 126273 132862 139847 147251 155099 163418 172237 181584 191492 201995 LESS: aaah NOT REQUIRING FTA Ten Eas? a re a beat : 7 , 7 OF DS 1 164 6 4 447 44 16447 6447 FUNDS APPLIED TO OPERATING EXPENS 42 C 109825 116415 123400 130804 138652 146971 155789 165137 175045 185548 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43C 59095 59095 59140 59184 59232 59284 59341 59402 59470 59543 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPNENT BONDS 451 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT 46 I 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 1 0 0 0 0 0 0 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 C¢ 537 537 582. 626 674 726 783 845 912 985 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 OTHER LONG TERM DEBT Sn eee ee eg ee OTHER RM 7 7 . . TOTAL DEBT 54 C 1.01 1.01 1.01 1.01 1.01 1.01 1.01 1.01 1.02 1.02 BASE -R.E.A.- 70% PLANT FACTOR ($000) BEGINNING CASH BALANCE PLUS FUNDS GENERATED NET INCOME ITENS 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 NEN CAPITAL-EQUITY/DEBT TEMPORARY FINANCING BORROWED REPAID CASH RECEIPTS FROM FINANCING NET CASH BEFORE FUNDING DEBT SERVICE RESERVE FUND DEPOSITS DRANDONNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRAUDOWNS NET ACCRUAL ENDING CASH BALANCE ITEM 60 66 76 77 78 79 74 o QOOOKRRO ano oO a a00 9 aoo0 e200 c NOTE: OPERATING REVENUES WERE INCREASED BY THESE ANOUNTS SO THAT CASH BALANCES DO NOT —DROP BELOW 30 DAYS O&M EXPENSE. 75 c BELUGA POWER PROJECT C M56 Ul, 85-02-07 16.04) 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 31ll 3297 ~15148 -12883 -14688 -14485 -14259 -14007 -13725 -13409 -13057 -12663 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 57259 710 56930 73 6518 627 600 5569 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 0 0 0 0 0 4 0 e ° 0 8 0 0 0 0 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 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 sll) 3297 3495 o a a o o g 0 o g a 0 0. 0 0 0 9 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 0 0 0 0 0 0 0 0 0 0 0 82 2193 2324 2464 2612 2768 2934 311) 3297 3495 0 2110 132 139 148 157 166 176 187 198 ti BASE -R.E.A.- 70% PLANT FACTOR ($000) BEGINNING CASH BALANCE PLUS FUNDS GENERATED NET INCOME ITENS 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 NORKING 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 DRANDOWUNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRANDONNS NET ACCRUAL ENDING CASH BALANCE ITEM 60 66 76 77 78 79 74 Qoa QOOOKHO ao anon oo ooo 200 c 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 C M56 Ul, 85-02-07 16.04) PAGE 5B ANALYSIS OF CASH & ANNUAL CASH BALANCES 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 3495 4109 4341 4632 4940 5270 5624 6003 6410 6846 -11818 -11721 -11124 -10506 -9811 -9034 -8165 -7194 -6107 -4891 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 5454 540 3 925 52252 51498 50655 4971 48654 47470 59172 58789 58849 58865 58888 58911 58937 58964 58994 59026 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q° 9 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 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 4109 4341 4632 4940 5270 5624 6003 6410 6846 7315 o a a g a g a g a 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4109 4341 4632 4940 5270 5624 6003 6410 6846 £315 614 231 292 308 330 354 379 407 436 469 BASE -R.E.A.- 70% PLANT FACTOR ($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 DRAMDOUNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRANDONNS NET ACCRUAL ENDING CASH BALANCE NOTE: OPERATING REVENUES WERE INCREASED BY THESE AMOUNTS SO THAT CASH BALANCES DO NOT —DROP BELOW 30 DAYS O&M EXPENSE. BELUGA POWER PROJECT C M56 U2, 85-02-07 16.04) PAGE 35C ANALYSIS OF CASH & ANNUAL CASH BALANCES ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 60 Cc 7315 7852 8389 8971 9597 10272 10998 11781 12626 13538 23c -3498 ~2015 -310 1592 3720 6101 8765 11745 15080 18811 61 Cc 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 22 C 46146 44663 430 41145 906 36735 3412 31210 27943 24285 62 C 59095 59095 59140 59184 59232 59284 59341 59402 59470 59543 248 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 56 1 0 0 0 0 0 0 0 0 0 0 135 1 0 0 0 0 0 0 0 0 0 0 63 C 0 0 0 0 0 0 0 0 0 0 64 C 0 0 0 0 0 0 0 0 0 0 360 C 0 0 0 0 0 0 0 0 65 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 66 C 0 0 0 0 0 0 0 0 0 0 76 C 0 0 0 0 0 0 0 0 0 0 77C¢ 0 0 9 0 0 0 0 0 0 0 78 C 0 0 0 0 0 0 0 0 0 0 79 ¢ 7852 8389 8971 9597 10272 10998 11781 12626 13538 14523 67 0 o o o a o a o a a 0 68 C 0 0 9 0 0 0 0 0 0 0 69 C 0 0 0 0 0 0 0 0 0 0 70 Cc 0 0 0 0 0 0 0 0 0 0 71C 0 9 0 0 0 0 0 0 0 0 72 C¢ 0 0 0 0 0 0 0 0 0 0 74 C 7852 8389 8971 9597 10272 099. 11781 12626 13538 14523 75 C 537 537 582 626 674 726 783 845 912 985 BASE -R.E.A.- 70% PLANT FACTOR ($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 & EXPENSE 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 ENERGY DEVELOPNENT 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 IKCONE TAXES “IDEFERRED 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 E20 2 OHO oO Qa AnAna00 aang c I I c c c c c BELUGA POWER PROJECT BALANCE SHEET C M56 Ul, 85-02-07 16.04) PAGE 6A 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 _ oa vanie vote qe 318 a2saae ate ee Vato aa 16447 32895 49342 65789 82236 98684 115131 131578 148025 164473 476970 460523 444076 427629 411181 394734 378287 361840 345392 328945 82 2193 2324 2464 2612 2768 2934 3111 3297 3495 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 9 _0 82 2193 2324 2464 2612 2768 2934 311i 3297 3495 0 0 0 0 0 0 0 0 0 0 Co ee ee eg Te I i Beh late 1 26 47705 462716 __446400 __430092 __413793 __397502 __381 —364950 _ 348689 _ 332440 0 0 0 0 0 0 0 0 0 0 0 -15148 28031 -42719 -57204 -71464 85471 -99195 -112604 ~-125661 -15148 -12883 = =-14688 -14485 -14259 -14007 -13725 -13409 -13057 -12663 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 ~15148 28031 -42719 -57204 71464 -85471 -99195 -112604 ~-125661 ~-138324 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 BaA Li aot, nenaia seen peers wie a1o35 474350 tetee neers I ee er IT oe Ter oa) 490747 489119 487297 485257 482973 480416 477554 474350 470764 466748 0 0 0 0 0 0 0 0 0 0 1454 1628 1822 2040 2284 2557 2862 3204 3587 4015 0 0 0 0 0 0 0 0 9 0 1454 1628 1822 2040 2284 2557 2862 3204 3587 4015 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0 0 0 0 0 0 477053 462716 446400 430092 413793 397502 381221 364950 348689 332440 it BASE -R.E.A.- 70% PLANT FACTOR ($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 & 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 DEVELOPMENT BONDS OTHER LONG TERN 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 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 a a|an0Nn o Qaagn0 a O00 OF OO BELUGA POWER PROJECT C M56 Ul, 85-02-07 16.04) PAGE 6B BALANCE SHEET 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 493418 493418 tt 493418 493418 493418 aaseis 493418 ide oosts 0 0 092 367 3 26 4670 263 279603 _ 296051 2498 328945 312498 296051 279603 263156 246709 230262 213814 197367 180920- 164473 4109 4341 4632 4940 5270 5624 6003 6410 6846 7315 0 0 0 0 0 0 0 0 0 0 9 0 9 9 0 oO 0 _0 0 0 4109 4341 4632 4940 5270 5624 6003 6410 6846 7315 0 0 0 0 0 0 0 0 0 0 a a ee en | 316607 380 284236 6809 251979 _ 235885 __ 2198 203777 187766 171787 0 0 0 0 0 0 0 0 0 0 -138324 -150141 -161862 -172986 ~-183492 -193303 -202337 -210503 -217696 -223803 -11818 11721 -11124 -10506 -9811 -9034 -8165 -7194 -6107 ~4891 0 0 0 0 0 0 0 0 0 0 = Se 2 S|: YE SS SD I “150141 -161862 ~172986 -183492 “-193303 ~-202337 ~-210503 ~-217696 ~-223803 -228694 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ta nereet 451588 445282 aagees 430320 421473 411569 400481 388070 —~;! —.! —~_ 1 —_? -._2 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 12412 0 0 0 0 0 0 9 0 0 0 4495 5032 5633 6306 7060 7903 8847 9904 11087 12412 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 516607 __300391 _ 284236 _ 268096 251979 235885 _ 219817 _ 203777 __187766 _ 171787 BASE -R.E.A.- 70% PLANT FACTOR ($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-COrNON STOCK BALANCE, END OF PERIOD PREFERRED STOCK LONG TERM DEBT CONVENTIONAL BONDS REA GUARANTED BONDS OTHER LONG TERN 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 INCOME TAXES “IDEFERRED 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 ea 8 ORO BELUGA PONER PROJECT C M56 U2, 85-02-07 16.04) PAGE 36C BALANCE SHEET 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 ioe hr ne rT ie caer ae on 77 46 he Tire ane 345392 840 8 394734 _ 411181 76 076 460523 476970 $93418 148025 131578 115131 98684 82236 65789 49342 32895 16447 0 7852 8389 8971 9597 10272 10998 11781 12626 13538 14523 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 7852 83389 8971 9597 10272 10998 11781 12626 13538 14523 0 0 0 0 0 0 0 0 0 0 ee eee Seer — oe et SS et 155877 139967 124102 _ 108281 92508 26787 61123 45520 29985 1452 0 0 0 0 0 0 0 0 0 0 ~228694 -232193 -234208 -234518 ~-232926 -229206 -223105 -214340 -202594 -187514 -3498 -2015 -310 1592 3720 6101 8765 11745 15080 18811 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 ~232193 -234208 -234518 -232926 ~-229206 ~-223105 ~-214340 ~-202594 ~-187514 ~-168704 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 oS jae paren petite ate ei tee titer etteee 183227 144860 sso eee Oe 2 SL 2 0 0 374175 358620 341207 321714 299892 275463 248115 217500 183227 144860 0 0 0 0 0 0 0 0 0 0 asee eH aoe 19493 21822 24429 27348 30615 34273 38367 0 0 0 0 0 0 0 13895 15555 17413 19493 21822 24429 27348 30615 34273 38367 0 0 0 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 0 155877 139967 124102 10828) 92508 16787 61123 45520 299385 14523 BASE-R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT © M55 Ul, 85-02-07 16.03) 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 sol c 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 303 Cc 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 201c¢ 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 202 ¢ 0 0 0 0 Qo 0 0 0 0 0 PRINCIPAL REPAYMENT 203 ¢ 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 0 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 2ND SERIES 312 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 313 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 205 ¢ 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 INTEREST CHARGES 206 C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 PRINCIPAL REPAYMENT 207 C 1299 1454 1628 1822 2040 2284 2557 2862 3204 3587 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 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 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 2llc 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 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 INTEREST CHARGES 214 ¢ 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 PRINCIPAL REPAYMENT 215 C 1299 1454 1628 1822 2040 2284 2557 2862 3204 3587 TOTAL DEBT SERVICE 216 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 BASE-R.E.A.- 70% PLANT FACTOR BELUGA POWER PROJECT C M55 Ul, 85-02-07 16.03) 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 c 0 0 0 0 0 0 0 0 0 0 2ND SERIES 302 ¢ 0 0 0 0 0 0 Qo 0 0 0 3RD SERIES 303. ¢c 0 0 0 0 __0 0 0 0 0 0 TOTAL OUTSTANDING 201 Cc 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 202 ¢ 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 203 Cc 0 0 0 0 0 0 0 0 0 0 TOTAL DEBT SERVICE 204 ¢ 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS BALANCE,START OF PERIOD 1ST SERIES sll c 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 2ND SERIES 312 € . ; H ° 0 0 7 ° 7 0 3RD SERIES ee en a ae ee | TOTAL OUTSTANDING 205 ¢ 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 INTEREST CHARGES 206 C 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 PRINCIPAL REPAYMENT 207 ¢ 4015 4495 5032 5633 6306 7060 7903 8847 9904 11087 TOTAL DEBT SERVICE 208 ¢ 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 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 Cc 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 2llc 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 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 INTEREST CHARGES 214 C 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 PRINCIPAL REPAYMENT 215 ¢ 4015 4495 5032 5633 6306 7060 7903 8847 9904 11087 TOTAL DEBT SERVICE 216 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 BASE-R.E.A.- 70% PLANT FACTOR ($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 oa 8 |0n00 BELUGA POWER PROJECT (M55 Ul, 85-02-07 16.03) DEBT SERVICE SCHEDULE 2015 2016 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 9 EO 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 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 0 0 0 0 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 46146 44663 43003 41145 39064 36735 34128 31210 27943 24285 12412 13895 15555 17413 19493 21822 24429 27348 30615 34273 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 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 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 46146 49663 43003 41145 39064 36735 34128 31210 27943 24285 12412 13895 15555 17413 19493 21822 24429 27348 30615 34273 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 R.E.A.-80% CAPACITY FACTOR ‘DETAILED BELUGA POWER COST ec 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 306 1038 1039 303 1033 1034 1037 1194 1195 404 299 1094 1095 150 1054 160 OEBT/EQUITY FUNDING isisivisiel—-isieisieis) AHAANaD FOOONOND SUMMARY OF ASSUMPTIONS AND OTHER INPUT DATA FOR THIS CASE TOTAL AMOUNT ($000) 133200 0 399400 532600 TOTAL 388170 PERCENT OF TOTAL 25.01 0.0 74.99 0.0 0.0 100.00 ANNUAL REQUIRED TERM COST COVERAGE CYEARS) 0.0 0.0 0.0 0.0 1.00 30.0 0.0 0.0 0.0 0.0 0.0 0.0 C M56 Ul, 85-01-21 09.34) PAYMENT PERIODS Page ! ALASKA PONER PROJECT DIAMOND SHAMROCK/VOSS INT. © M54 Ul, 85-01-18 15.29) PAGE 2A CAPITALIZATION SCHEDULE AND UTILIZATION ($000) OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 1986 1987 NET PROCEEDS AVAILABLE BEGINNING OF PERIOD 10 C 0 58 19 5 0 10 38 48 92 10 CAPITAL FUNDING: , EQUITY llc 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK 31 ¢ 0 0 0 0 0 0 0 0 0 0 CONVENTIONAL BONDS 12 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPHENT BONDS 3c 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 14 C 0 0 0 0 0 0 0 0 0 0 TOTAL NEW CAPITAL 15 C 0 0 0 0 0 0 0 0 0 0 CONSTRUCTION LOANS 1c 1000 1900 ___2400 __4100 __ 9400 ___—— 400 __ 21400 __ 32700 _ 36200 __ 94700 TOTAL PROCEEDS AVAILABLE 40 Cc 1000 1958 2419 4105 9400 4410 ~ 21438 — 32748 — 36292 94710 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES 20 ¢ 914 1855 2259 3820 8847 3970 §= 20361 += 30671 = 333187 = 88188 START-UP COSTS (CAPITALIZED) 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 I 0 0 0 0 0 0 0 0 O. 0 FINANCING COSTS 21 ¢ 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.¢ 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK DIVIDENDS 70 C 0 0 0 0 0 0 0 0 0 0 TOTAL UTILIZATION 50 ¢ 914 1855 2259 3820 8847 3970 — 20361 30671 33187 ~ 88188 BALANCE ON DEPOSIT 3¢ 86 103 160 285 553 441 1077 2077 3105 6522 INTEREST EARNED 4c 2 3 4 7 16 ll 27 52 78 167 TOTAL AVAILABLE FOR INTEREST CHARGES 5¢ 88 106 164 292 568 452 1104 2129 3183 6690 INTEREST CHARGES CONSTRUCTION LOANS 61 Cc 30 87 159 282 558 414 1056 2037 3123 6630 CONVENTIONAL BONDS 62 C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS 63 C 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERN DEBT 64 C 0 0 0 0 0 0 0 0 0 0 TOTAL INTEREST CHARGES 65 ¢ 30 87 159 282 558 414 1056 2037 3123 6630 NET PROCEEDS AVAILABLE END OF PERIOD 7¢ 58 19 5 10 10 38 a8 92 60 60 DEES IE EK ETEK EEE INTEREST CHARGED TO CONSTRUCTION 91 ¢ 15 46 85 151 297 221 566 1092 1674 3554 TOTAL AMOUNT CAPITALIZED 92 ¢ 929 1901 2344 3971 9145 4191 20927 31763 34861 ~=—-91742 CUMULATIVE ANOUNT CAPITALIZED 93 ¢ 929 2830 5174 9145 9145 13336 34263 66026 100887 100887 KKM KIMI He TAX BENEFITS TAX EFFECT OF INTEREST EARNED 79¢ -1 -1 -2 -3 -7 -5 -12 -26 -36 -77 TAX EFFECT OF INTEREST PAYMENTS (NET OF CAPITALIZED INTEREST ON REAL PROPERTY) 80 C 13 33 70 124 245 182 463 893 1371 2909 INVESTMENT TAX CREDIT gl c 69 141 172 290 672 302 1547 2331 2522 6702 ENERGY PROPERTY CREDIT 82 C 0 0 0 0 0 0 0 0 0 0 TOTAL : 83 C 82 178 240 411 910 479 1998 3200 3857 9534 CUMULATIVE TAX BENEFITS 182 ¢ 82 260 499 910 1750 1388 3386 6585 10444 21804 CUMULATIVE EQUITY 26 ¢ ad 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 DIAMOND SHAMROCK/VOSS INT. © M54 Ul, 85-01-18 15.29) PAGE 2B CAPITALIZATION SCHEDULE AND UTILIZATION ($000) OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 1988 1989 NET PROCEEDS AVAILABLE BEGINNING OF PE 10 C 60 62 55 2 60 38 23 8 38 38 CAPITAL FUNDING: EQUITY llc 0 0 0 0 0 0 0 0 0 0 PREFERRED STOCK 31 ¢ 0 0 0 0 0 0 0 0 0 0 CONVENTIONAL BONDS 12.C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS 13.¢ 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 14.¢ Oo. 0. 0 TOTAL NEW CAPITAL 15 C 0 0 0 0 0 0 0 0 0 0 CONSTRUCTION LOANS 1¢ 39400 _ 27500 _ 48400 _ 47500 _162800 32200 _ 44500 _ 41300 __39400 157400 TOTAL PROCEEDS AVAILABLE 40 ¢ 39460 27562 48455 47502 162860 32238 44523 41308 39438 157438 UTILIZATION OF PROCEEDS CONSTRUCTION MORK IN PROGRESS CONSTRUCTION EXPENDITURES 20 ¢ 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 START-UP COSTS (CAPITALIZED) 48 I 0 0 0 0 0 0 0 0 0 0 PROPERTY TAXES (CAPITALIZED) 53.C 0 0 0 0 0 0 0 0 0 0 FUEL STOCK AND OTHER INVENTORY 30 I 0 0 0 0 0 0 0 0 0 0 FINANCING COSTS : 21¢ 0 0 0 0 0 0 0 0 0 0 REPAYiiENT 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 0 0 0 0 0 0 0 0 TOTAL UTILIZATION 50 ¢ 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 BALANCE ON DEPOSIT 3¢ 4260 5059 6424 7849 — 23472 8777 10064 ~ 11303 12473 — 42547 INTEREST EARNED 4c 107 126 161 196 590 219 252 283 312 1065 TOTAL AVAILABLE FOR INTEREST CHARGES 5 ¢ 4367 5185 6584 8045 24062 8996 10316 11585 12784 43612 INTEREST CHARGES CONSTRUCTION LOANS 61 C 4305 5130 6582 8007 24024 8973 10308 11547 12729 43557 CONVENTIONAL BONDS 62 C 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS 63 C 0 0 0 0 0 0 0 0 0 0 OTHER LONG TERM DEBT 64 C 0 0 0 0 0 0 0 0 0 0 TOTAL INTEREST CHARGES 65 C 4305 5150 6582 8007 — 24024 8973 10308 11547 ~ 12729 43557 NET P AVAILABLE END OF PERIOD 7c 62 55 2 38 38 23 8 38 55 55 INTEREST CHARGED TO CONSTRUCTION 91 2307 2740 3525 4281 12853 4776 5498 6146 6762 23182 __TOTAL AMOUNT CAPITALIZED 92 ¢ 37506 25243 45556 «= 43935-15224 28237 39958 36151 33728 138073 CUMULATIVE AMOUNT CAPITALIZED 93 ¢ 138393 163636 209192 253127 253127 281365 321322 357473 391200 391200 MUX KE MMRKNKKK RRR TAX BENEFITS TAX EFFECT OF INTEREST EARNED 79 ¢ -49 -58 -74 -90 -271 -101 -116 -130 -143 -490 TAX EFFECT OF INTEREST PAYMENTS (NET OF CAPITALIZED INTEREST ON REAL PROPE 80 C 1892 2263 2896 3529 10581 3977 4558 5119 5655 19309 INVESTNENT TAX CREDIT 81 2675 1710 3194 3014 10593 1783 2619 2280 2049 8732 __ ENERGY PROPERTY CREDIT 82 C 0 0 0 0 0 0 0 0 0 0 = TOTAL a3 c 4518 3916 6017 6453 20904 5659 7061 7269 7561 27551 CUMULATIVE TAX BENEFITS 182 ¢ 14962 18877 24894 31347 90081 37007 44068 51337 58898 191310 CUMULATIVE EQUITY 26 C RETURN ON EQUITY TO DATE ALASKA POWER PROJECT CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 185 C DIAMOND SHAMROCK/VOSS INT. CONTINUATION ITEM 20 29988 18894 34780 C M54 1988 32338 116000 ul, 85-01-18 15.29) 18856 27295 23423 20746 PAGE 2B 1989 90320 ALASKA POVER PROJECT DIAMOND SHAMROCK/VOSS INT. ( M54 CAPITALIZATION SCHEDULE AND UTILIZATION ($000) OF PROCEEDS DURING CONSTRUCTION PERIOD ITEM 1990 NET PROCEEDS AVAILABLE BEGINNING OF PERIOD 10 C 55 45 88 78 55 CAPITAL FUNDING: EQUITY llc 0 0 0 133200 133200 PREFERRED STOCK 31 C¢ 0 0 0 0 0 CONVENTIONAL BONDS 12 ¢ 0 0 0 399400 399400 ENERGY DEVELOPMENT BONDS 13C 0 0 0 0 0 OTHER LONG TERM DEBT 14 C 0 0 0 o_o TOTAL NEW CAPITAL 15 Cc 0 0 0 532600 532600 CONSTRUCTION LOANS 1c 34200 26300 17300 16500 94300 TOTAL PROCEEDS AVAILABLE 40 C 34255 26345 17388 549178 626955 UTILIZATION OF PROCEEDS CONSTRUCTION WORK IN PROGRESS CONSTRUCTION EXPENDITURES 20 ¢ 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 13979 13979 REPAYNENT OF CONSTRUCTION LOANS 38 C 0 0 0 518600 518600 DEPOSIT-DEBT SERVICE RESERVE FUND 52 ¢ 0 0 0 0 0 PREFERRED STOCK DIVIDENDS 70 C 0 0 0 0 TOTAL UTILIZATION 50 € 20792 12069 2617 533957 569435 BALANCE ON DEPOSIT 3.¢ 13463 14276 14772 — 15221 ~ 57521 INTEREST EARNED 4c 337 357 369 381 1443 TOTAL AVAILABLE FOR INTEREST CHARGES 5 C 13800 14632 — 15141 15602 58964 INTEREST CHARGES CONSTRUCTION LOANS 61 C 13755 14544 15063 15558 58920 CONVENTIONAL BONDS 62 C 0 0 0 0 0 ENERGY DEVELOPNENT BONDS 63 C 0 0 0 0 0 OTHER LONG TERM DEBT 64 C 0 0 0 0 0 TOTAL INTEREST CHARGES 65 C 13755 14544 ~ 15063 15558 58920 NET PROCEEDS AVAILABLE END OF PERIOD 7c 45 83 78 44 a4 BEDE IE EE DEE DEE DE EK EE INTEREST CHARGED TO CONSTRUCTION 91 ¢ 7283’ 7650 7817 13017 35767 TOTAL ANOUMT CAPITALIZED 92 C 28075 19720 10433 14394 72623 CUMULATIVE ANOUNT CAPITALIZED 93 C 419276 438995 449429 463823 463823 DE EE DE ESE EH EK KE TAX BENEFITS TAX EFFECT OF INTEREST EARNED 79°C -155 -164 -170 -175 -664 TAX EFFECT OF INTEREST PAYMENTS (NET OF CAPITALIZED INTEREST ON REAL PROPERTY) 80 C 6135 6537 6877 7156 26705 INVESTMENT TAX CREDIT gl c 1580 917 199 105 2801 ENERGY PROPERTY CREDIT 82 C 0 0 0 0 0 TOTAL Bsc 7561 7290 6906 7085 28842 CUMULATIVE TAX BENEFITS 182 C 66459 73749 80655 87740 308603 CUMULATIVE EQUITY 26 C 133200 133200 Ul, 85-01-18 15.29) PAGE 2C RETURN ON EQUITY TO DATE ALASKA POWER PROJECT CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION 185 ¢ 65.9 65.9 DIAMOND SHAMROCK/VOSS INT. © M54 CONTINUATION ITEM 1990 20 15765 9019 1927 1000 827711 ul, 85-01-18 15.29) PAGE 2c Wu 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&M : LEASE EXPENSE DEPRECIATION EXPENSE PROPERTY TAX GROSS RECEIPTS TAX TOTAL OPERATING EXPENSES OPERATING INCOME OTHER INCOME AND EXPENSES INCOME BEFORE INTEREST CHARGES INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS ENERGY DEVELOPMENT BONDS OTHER LONG TERM DEBT SUBTOTAL OTHER INTEREST & EXPENSES AMORTIZED BOND DISCOUNT & EXPENSES SHORT TERM LOANS INTEREST DURING CONSTRUCTION SUBTOTAL TOTAL INTEREST AND OTHER EXPENSES NET INCOME 96 3 COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS IN PRESENT WORTH DOLLARS LEVELIZED* AMOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUMULATIVE PRESENT WORTH A THAT RESULTING FROM THE ACTUAL ANNUAL AMOUNTS CALCULATED ITEM ~ UNne Nn PONOan Mow ou ~ we Nn KY S&S 13 14 15 16 18 19 20 21 22 23 165 163 Ss 159 a 9°99 fF AHAAQOR|OAO a aaangq aann ao ( 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 9 0 0 0 0 0 0 0 0 0 0 0 0 0 112234 95113 101531 112595 115751 119111 126744 130565 134639 138986 15320 16239 17214 18246 19341 20502 21732 23036 24418 25883 24824 26314 27892 956 31340 33220 35213 37326 39566 41940 40144 oe bat a7ete roe eyes se is 63984 67823 0 0 0 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 55605 58014 60567 63273 66142 69183 72406 75823 79444 83283 56629 37099 40965 49322 45609 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 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 0 466 466 46 466 466 466 466 466 466 466 48349 48158 47944 47703 47433 47129 46787 46403 45972 45487 8280 -11059 -6738 1875 2447 3087 7855 866 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 ui 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 TERM 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 9 93 HOHE 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 P0000 Qa 9 fF ANMANOKH|DAO a AAAMNAD O20 ao DIAMOND SHAMROCK/VOSS C M56 Ul, 85-01-21 09.34) PAGE 3B FORECASTED STATEMENT OF INCOME 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 180087 185054 190347 196003 202049 208516 215436 222844 230777 239279 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 180087 185054 190347 196003 202049 208516 215436 222844 230777 239279 27436 29082 30827 32676 34637 36715 38918 41253 43728 46352 44456 $7124 $9951 529 56125 59492 63062 66846 70856 75108 71892 76205 80778 85624 90762 96208 101980 108099 114585 121460 0 0 0 0 0 0 0 0 0 9 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 87353 91666 96239 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 93118 93794 94539 95374 96311 97361 98539 99861 101343 103007 44477 43865 43178 42405 41538 40563 39467 38236 36853 35299 0 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 0 466 466 466 466 466 466 466 466 466 466 44943 44331 43644 42871 42004 41029 39933 38702 37319 35765 48176 49463 50895 52503 54307 56333 58606 61153 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 se 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 OTHER 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 AMORTIZED BOND DISCOUNT & EXPENSE 18 SHORT TERM LOANS 19 INTEREST DURING CONSTRUCTION 20 SUBTOTAL 21 TOTAL INTEREST AND OTHER EXPENSES 22 NET INCOME 23 56 HDI COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT LIORTH DOLLARS 163 LEVELIZED ANOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SAME CUNULATIVE PRESENT WORTH AS = THAT RESULTING FROM THE ACTUAL - ANNUAL AMOUNTS CALCULATED 159 Qo OF fF AAMOKHQNQAOO a AA009Q 2000 ao DIAMOND SHAMROCK/VOSS C M56 U2, 85-01-21 09.34) PAGE "3C FORECASTED STATEMENT OF INCOME 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 248791 258569 269063 280334 292446 305469 319481 334567 350820 368343 0 0 0 0 0 0 0 0 0 0 Se ee ee eee a ee ee eee ae ee 248791 258569 269063 280334 292446 305469 319481 334567 350820 368343 49133 52081 55206 58519 62030 65751 69697 73878 78311 83010 796 84391 89455 948 0 106542 112934 710 126893 134507 128748 is i 153340 bears 172298 182631 paeees See 217516 0 0 0 0 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 0 0 0 0 0 0 0 0 0 0 a lg et TO ee vile stipe 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 0 0 0 0 0 0 0 0 0 Qo. 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 0 466 466 466 466 66 466 466 466 466 66 34019 32057 29852 27375 24592 21465 17951 14003 9568 4583 71251 15308 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 ($000) ITEM FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES 3c OTHER INCOME llc SUBTOTAL 37 ¢ LESS INCOME THAT IS NOT CASH 38 I FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME 39 ¢ LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 C LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 Cc FUNDS APPLIED TO OPERATING EXPENSE 42 C INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43 Cc FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 ENERGY DEVELOPNENT BONDS 45 1 OTHER LONG TERM DEBT 46 I TEMPORARY BORRONINGS 47 1 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 ¢ DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 C¢ ENERGY DEVELOPMENT BONDS 52 C OTHER LONG TERM DEBT 53 ¢ TOTAL DEBT 54 C DIAMOND SHAMROCK/VOSS C M56 Ul, 85-01-21 09.34) PAGE 4A NET WORKING CAPITAL (FUNDS) AVAILABLE 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 112234 95113 101531 112595 115751 119111 126744 130565 134639 138986 0 0 241 5 71 28 304 2 342 362 112234 95113 101773 112851 116022 119398 127048 130887 134981 139349 0 0 0 0 0 0 0 0 0 0 112234 95113 101773 112851 116022 119398 127048 130887 134981 139349 55605 58014 60567 63273 66142 69183 72406 75823 79444 83283 546 15461 15461 15461 46 15461 15461 546 15461 15461 40144 42553 45106 47812 50681 53722 56945 60362 63984 67823 72090 52560 56667 65038 65341 65676 70103 70525 70997 71526 49426 49426 49426 $9426 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 9 0 0 0 0 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 -47 2196 131 138 148 157 165 176 187 198 1.46 1.06 1.15 1.32 1.32 1.33 1.42 1.43 1.44 1.45 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 1.46 1.06 1.15 1.32 1.32 1.33 1.42 1.43 1.44 1.45 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS ¢ M56 Ul, 85-01-21 09.34) PAGE 4B NET WORKING CAPITAL (FUNDS) AVAILABLE ($000) ITEM 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES 3c 180087 185054 190347 196003 202049 208516 215436 222844 230777 239279 OTHER INCOME llc 384 0 43 45 48 1 54 5 12 648 SUBTOTAL 37 ¢ 180471 185460 190778 196459 202533 209030 215980 223421 231389 239927 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 ¢ 180471 185460 190778 196459 202533 209030 215980 223421 231389 239927 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 ¢ 87353 91666 96239 101085 106223 111668 117441 123560 130046 136921 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 Cc 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 FUNDS APPLIED TO OPERATING EXPENSE 42 C 71892 76205 80778 85624 90762 96208 101980 108099 114585 121460 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43C 108579 109255 110000 110835 111772 112822 114000 115322 116804 118468 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 I 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORRONINGS 47 1 0 0 0 0 0 0 0 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 ¢ 204 222 236 250 265 280 297 315 334 354 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 Cc 2.20 2.21 2.23 2.24 2.26 2.28 2.31 2.33 2.36 2.40 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 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 TOTAL DEBT 54 C¢ 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 INCONE llc 687 729 772 819 868 920 975 1034 1096 1162 SUBTOTAL 37 C ~ 249478 — 259297 — 269836 281153 293314 306389 320456 335601 351916 369505 LESS INCOME THAT IS NOT CASH 38 1 0 0 0 0 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE _ _ _— AND OTHER INCOME 39 C 249478 — 259297 — 269836 281153 293314 306389 320456 335601 351916 369505 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 C_ 144208 151933 160122 168801 178002 187754 198092 209049 220665 232977 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 ¢ 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 FUNDS APPLIED TO OPERATING EXPENS 42 C 128748 136472 144661 153340 162541 172293 182631 193589 205204 217516 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 0 0 0 0 0 0 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 C 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 0.0 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 ud 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 DRANDOLWNS NET ACCRUAL REPLACEMENT RESERVE FUND DEPOSITS DRANDOWNS NET ACCRUAL ENDING CASH BALANCE ITEM 66 76 77 78 79 67 68 69 70 71 72 74 So a Onn Oo QOKOOKRHO aaa oo aQaoo Qa ann 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 C 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 48349 48158 47944 47703 47433 47129 46787 46403 45972 45487 72090 52560 56667 65038 65341 65676 70103 70525 70997 71526 49426 49426 49426 49426 $9426 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 22711 937 7110 15474 15766 16093 20511 20923 21384 21902 72137 50364 56536 64900 65193 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -3 2193 2323 2461 2609 2766 2931 3107 3294 3492 Q a a a a a a g 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 0 0 0 0 0 0 0 0 0 0 0 0 0 9 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) ITEM BEGINNING CASH BALANCE 60 Cc PLUS FUNDS GENERATED NET INCOME 23.c¢ ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS 61 Cc INTEREST & OTHER EXPENSE 22 C¢ TOTAL FUNDS GENERATED 62 C DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS 248 C START-UP COSTS 56 1 FINANCING COSTS 135 I WORKING CAPITAL INCREASES 63 C CONSTRUCTION REQUIRENENTS 64 C DISTRIBUTION TO PARTNERS 360 C TOTAL FUNDS USED 65 ¢ PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT 66 C TEMPORARY FINANCING BORROWED 76 C REPAID 77¢ CASH RECEIPTS FROM FINANCING 78 C NET CASH BEFORE FUNDING 79 ¢ DEBT SERVICE RESERVE FUND DEPOSITS 67 0 DRANDOWNS 68 C NET ACCRUAL 69 C REPLACEMENT RESERVE FUND DEPOSITS 70 Cc DRANDOLWNS 71¢ NET ACCRUAL 72 ¢ ENDING CASH BALANCE 74 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 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 4943 $433 $3644 287 42004 410 39933 870 37319 35765 108579 109255 110000 110835 111772 112822 114000 115322 116804 118468 49426 49426 $9426 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 58949 9606 60338 61159 62081 631 4276 65580 67044 68687 108375 109033 109764 110585 111507 112541 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 o o g g a g o Q g a 0 0 0 0 0 0 9 0 9 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 3696 3918 4153 4403 4667 4948 5245 5560 5894 6248 59153 59829 60573 61409 62345 63396 64574 65895 67378 69041 ALASKA POWER PROJECT ($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 BORRONED 76 REPAID 77 CASH RECEIPTS FROM FINANCING 78 NET CASH BEFORE FUNDING 79 DEBT SERVICE RESERVE FUND DEPOSITS 67 DRALIDOLINS 68 NET ACCRUAL 69 REPLACEMENT RESERVE FUND DEPOSITS 70 DRAWDOLINS 71 NET ACCRUAL 72 ENDING CASH BALANCE 74 NOTE: OPERATING REVENUES WERE INCREASED THESE ANOUNTS SO THAT CASH BALANCES DO NOT DROP BELON 30 DAYS O&M EXPENSE. 75 DIAMOND SHAMROCK/VOSS C 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 c 6248 6624 7021 7443 7890 8363 8865 9398 9962 10559 c 71251 75308 79862 84977 90720 97170 104413 112548 121684 131945 c 15461 15461 15461 15461 15461 15461 15461 15461 15461 15461 c 34019 32057 29852 37 459 1 17951 00 9568 4583 c 120730 122825 125175 127813 130773 134096 137825 142012 146712 151989 c 49426 49426 49426 49426 49426 49426 49426 49426 49426 49426 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 0929 73001 5327 779 80873 4167 87867 920 6688 101929 c 120355 122427 124753 127366 130299 133594 137293 141448 146114 151355 c 0 0 0 0 0 0 0 0 0 0 Cc 0 0 O° 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 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 0 a g a a a Q a 4 a a 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 Cc 0 0 0 0 0 0 0 0 0 0 c 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 BY c 71304 73399 75749 78386 81347 84669 88399 92586 97286 102562 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 INCOME FOR THE PERIOD DIVIDENDS-PREFERRED STOCK DIVIDENDS-COMMON STOCK BALANCE,END OF PERIOD PREFERRED STOCK LONG TERM DEBT CONVENTIONAL BONDS ENERGY DEVELOPMENT BONDS OTHER LONG TERN 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 Of OHA oO Qo eannna aang a O00 OHH OO DIAMOND SHAMROCK/VOSS C M56 Ul, 85-01-21 09.34) PAGE 6A BALANCE SHEET 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 463823 —. eaeee fosees aes seoeea aesnes ees 463823 a 0 0 46 30922 $6382 61843 304 92765 108225 123686 139147 154608 448362 432902 417441 401980 386519 371059 355598 340137 324676 309215 -3 2193 2323 2461 2609 2766 2931 3107 3294 3492 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 -3 2193 2323 2461 2609 2766 2931 3107 3294 3492 0 0 0 0 0 0 0 0 0 0 13979 13513 13047 12581 12115 11649 11183 10717 10251 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 391985 389525 386762 383656 380167 376247 371842 366892 0 0 0 0 0 0 0 0 0 0 a eg tO fT OD CEE DRT TE ra Teer 396123 394174 391985 389525 386762 383656 380167 376247 371842 366892 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 INCOME FOR THE PERIOD DIVIDENDS-PREFERRED STOCK DIVIDENDS-COMMON 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 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 QOH e202 2 OHO o Qa annagn anon Qa A090 OHH Oo DIAMOND SHAMROCK/VOSS (M56 Ul, 85-01-21 09.34) PAGE 6B BALANCE SHEET 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 463823 463823 463823 463825 465825 463825 465825 463825 465825 463825 0 0 170068 __185529 _ 200990 __216451 __2319 372 __ 262833 _ 278294 __ 293755 __ 309215 293755 278294 262833 247372 231912 216451 200990 185529 170068 154608 3696 3918 4153 4403 4667 4948 5245 5560 5894 6248 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 0 0 0 0 0 0 0 0 0 0 9319 8853 8387 7921 7455, 6989 6524 6058 5592 5126 306770 — 291065 _ 275374 _ 259697 _ 244035 _ 228388 — 212759 197147 181554 _ 165982 133200 133200 133200 133200 133200 133200 133200 133200 133200 133200 -182549 -193322 -203466 -212908 -221565 -229338 -236120 -241791 -246212 -249231 48176 49463 50895 52503 54307 56333 58606 61159 64025 67242 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 =1933522 ~-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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 361331 355082 ~ 348061 — 340173 — 331309 321349 — 310159 297586 283458 — 267584 0 0 0 0 0 0 0 0 0 0 5561 6249 7021 7889 8864 9959 11190-12573, «4128 = «15874 0 0 0 0 0 0 0 0 0 0 5561 6249 7021 7889 8864 9959 — 11190 12573 14128 — 15874 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 306770 _ 291065 _ 275374 _ 259697 _ 244035 _ 228388 _ 212759 _197147 — 181554 — 165982 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 & EXPENS TOTAL ASSETS TABILITIE 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 ENERGY DEVELOPNENT 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 INCOME TAXES =DEFERRED INVESTMENT TAX CREDITS TOTAL DEFERRED CREDITS TOTAL LIABILITIES ITEM 404 398 399 400 74 411 412 413 405 409 410 421 419 423 424 420 427 431 432 433 430 439 441 442 440 443 444 445 450 QO °o 20 2 OHA QOH oO aQaa0 ao E00 OFF OO DIAMOND SHAMROCK/VOSS (M56 -U2, 85-01-21 09.34) PAGE 6C BALANCE SHEET 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 463823 463823 465823 463825 463BZ2S_ 463823 463825 463823 463825 463825 0 0 0 0 324676 __ 340137 __355598 __ 371059 __ 386519 __ 401980 432902 _ 448362 __ 463823 139147 123686 108225 92765 77304 61843 46382 30922 15461 0 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6624 7021 7443 7890 8363 8865 9398 9962 10559 11193 0 0 0 0 0 0 0 0 0 0 4660 4194 3728 3262 2796 2330 1864 1398 932 466 150430 134901 _119396 —103916 88463 _ 73038 _ 57644 _ 4228] 26952 11659 133200 133200 133200 133200 133200 133200 133200 133200 133200 133200 -250676 -250354 ~-248047 -243512 ~-236475 -226628 -213625 -197079 -176553 -151557 71251 75308 79862 84977 90720 97170 104413 112548 121684 131945 0 0 0 0 0 0 0 0 0 0 — | ee ee Se =250354 -248047 243512 -236475 -226628 -213625 -197079 —-176553 —-151557 ~-121541 0 0 0 0 0 0 0 0 0 0 249749 229708 207191 181891 153464 121523 85634 45309 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 249749 — 229708 207191 181891 153464 121523 85634 45309 0 0 0 0 0 0 0 0 0 0 0 0 17836 20040 22517 25300 =. 28427 31941 35889 = 40325. 45309 0 0 0 0 0 0 0 0 0 0 0 17836 20040 22517 25300 28427 31941 35889 40325 45309 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 150430 _ 134901 _119396 — 103916 88463 _ 73038 57644 42281 26952 11659 ALASKA POWER PROJECT ($000) OPERATING REVENUES OTHER INCOME TOTAL INCOME OPERATING EXPENSES OPERATION & MAINTENANCE PROPERTY TAXES OTHER TAXES TOTAL NET 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) HE 33 HED HE 9 IE 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 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 ao oa mF 7220090 92 28 82 AAAAM AN A AAA oO Qno0 fO 4 DIAMOND SHANROCK/VOSS © M56 Ul, 85-01-21 09.34) PAGE 7A RETURN TO EQUITY PARTICIPANTS 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 112234 95113 101531 112595 115751 119111 126744 130565 134639 138986 0 0 24 256 7 287 304 32 342 362 112234 95113 101773 112851 116022 119398 127048 — 130887 — 134981 139349 401446 42553 45106 47812 50681 53722 56945 60362 63984 67823 0 0 0 0 0 0 0 0 0 0 ——_2 —__? i —— ee ee te Sea 40144 42553 45106 47812 50681 53722 56945 60362 63984 67823 72090 52560 56667 65038 65341 65676 70103 70525 70997 71526 47883 47692 47478 47237 46967 46663 46321 45937 45506 45021 466 466 466 466 466 466 466 466 466 466 31054 54344 46580 38817 38817 38817 34935 34935 34935 34935 0 0 0 0 0 0 0 0 0 0 380 380 380 380 380 380 380 380 380 380 31434 54724 46960 39197 719 39197 35315 35315 35315 35315 79783 102882 94904 86900 86630 86326 82102 81718 81287 80803 -7693 -50322 ~-38238 -21862 -21289 -20649 -11999 -11193 -10290 -9277 -723 -4730 -3594 -2055 -2001 -1941 -1128 -1052 -967 -872 -6970 -45592 -34643 -19807 -19288 -18708 -10871 -10141 -9323 -8405 -3206 -20972 -15936 -9111 -8872 -8606 -5001 -4665 -4288 -3866 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 =3206 — -20972 — -15936 =9111 =B872 =8606 =5001 =4665 =4288 =3866 -3929 -25703 -19530 -11166 -10874 ~-10547 -6129 -5717 -5256 -4738 22711 937 7110 15474 15766 16093 20511 20923 21384 21902 26640 26640 26640 26640 26640 26640 26640 26640 26640 26640 114380 141020 167660 194300 220940 247580 274220 300860 327500 354140 133200 133200 ©=.133200 ©=133200 ©=-:133200 =«:133200 ©=—-133200 ©=:133200 ©=133200 «133200 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 85.9 105.9 125.9 145.9 165.9 185.9 205.9 225.9 245.9 265.9 0.0 0.0 0.0 0.0 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 Nee BEFORE TAX ADJUSTMENTS LESS: INTEREST EXPENSE AMORTIZE BOND DISCOUNT DEPRECIATION PERSONAL PROPERTY REAL PROPERTY AMORTIZE 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) JOB OBO GG BORO EK CUMULATIVE RETURN TO DATE EQUITY INVESTMENT RATE OF RETURN = CURRENT RETURN AS % OF EQUITY CUMULATIVE RETURN AS % OF EQUITY DCF RATE OF RETURN ITEM 11 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 Qa 9 20902909 2 09 9 292009 4290 9 49000 oO ean a 2007 215436 54 215980 101980 0 0 ~~TO1980 114000 39467 466 85-01-21 09.34) 2008 222844 7 223421 108099 0 0 ~T08099 115322 38236 466 2009 230777 612 231389 114585 0 0 114585 116804 36853 466 PAGE 7B 2010 239279 648 239927 121460 0 121460 118468 35299 466 DIAMOND SHAMROCK/VOSS (M56 Ul, RETURN TO EQUITY PARTICIPANTS 2001 2002 2003 2004 2005 2006 180087 185054 190347 196003 202049 208516 38 7 43 57 484 51 180471 185460 — 190778 — 196459 202533 209030 71892-76205 «= 80778 «= 85624 «= (90762 = 96208 0 0 0 0 0 0 Ce ee ee eee eM alee ee 71892 ~ 76205 80778 85624 90762 — 96208 108579 109255 110000 110835 111772 112822 44477 43865 = 43178 = 42405 41538 «= 40563 466 466 466 466 466 466 0 0 0 0 0 0 0 0 0 0 0 0 380 380 380 380 380 380 380 380 380 380 380 380 45323 44711 44024 43251 42384 41408 63256 64544 65976 67584 69388 71413 5946 6067 6202 6353 6522 6713 57310 58477 59774 61231 62866 64701 26363 26899 27496 28166 28918 29762 26363 26899 27496 28166 5100 0 0 0 0 0 0 0 26363 26899 27496 28166 28918 29762 32309 32966 33698 34519 35441 36475 58949 59606 60338 61159 62081 63115 26640 26640 26640 26640 26640 26640 380780 407420 434060 460700 487340 513980 133200 133200 133200 133200 133200 133200 20.0 20.0 20.0 20.0 20.0 20.0 285.9 305.9 325.9 345.9 365.9 385.9 0.0 0.0 0.0 0.0 0.0 0.0 540620 133200 20.0 405.9 0.0 567260 133200 20.0 425.9 0.0 593900 1332006 20.0 445.9 0.0 620540 133200 20.0 465.9 0.0 dd ALASKA POWER PROJECT ($000) ITEM OPERATING REVENUES 3 OTHER INCOME ll TOTAL INCOME 37 OPERATING EXPENSES OPERATION & MAINTENANCE 8 PROPERTY TAXES 94 OTHER TAXES 95 TOTAL 501 NET BEFORE TAX ADJUSTMENTS 502 LESS: INTEREST EXPENSE 310 AMORTIZE BOND DISCOUNT 18 DEPRECIATION PERSOWAL PROPERTY 318 REAL PROPERTY 319 AMGRTIZE INTEREST CAPITALIZED 321 TOTAL 320 TOTAL DEDUCTIONS 340 TAXABLE INCOME 503 STATE TAX 504 TAXABLE INCOME-FEDERAL 505 FEDERAL INCOME TAX 506 INVESTMENT TAX CREDIT 520 ENERGY PROPERTY CREDIT 331 NET FIT 507 TOTAL TAX EFFECT TO PARTNERS 508 CASH DISTRIBUTIONS 360 NET RETURN TO PARTNERS CINCLUDING TAX LOSS) 365 3 EE EE DE 3 OE 3 OE DE OE 3 3 3 3 3 3 3 DE 3 EE CUMULATIVE RETURN TO DATE 363 EQUITY INVESTMENT 300 RATE OF RETURN = CURRENT RETURN AS % OF EQUITY 370 CUMULATIVE RETURN AS % OF EQUITY 185 DCF RATE OF RETURN 385 c oOo a 9a 92fM09090 2 8 8 HHA0290 429 2 A200 oO eQ00 OO UF 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 687 7 1 868 920 1 1096 1162 249478 259297 269836 281153 293314 306389 320456 335601 351916 — 369505 128748 136472 144661 153340 «162541 =«-:172293 182631 ©=—«193589 =. 205204 = 217516 0 0 Q 0 0 0 0 0 Q 0 128748 — 136472 144661 — 153340 — 162541 — 172293 — 182631 — 193589 — 205204 — 217516 120730 122825 «125175 127813. 130773 «134096 §=:137825 142012 «146712151989 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 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 0 0 0 0 0 0 0 0 0 0 36138 37829 39727 41858 44252 46940 49959 — 53349 57156 61433 44289 46361 «= «448687, 51299 54233-57527 «= 61227-65382 = 70048 = 75289 70929 73001 «= 75327-77939 = 80873 = 84167 = 887867 = 92022-96688 ~=—-:101929 26640 26640 26640 26640 26640 26640 26640 26640 26640 26640 647180 673820 700460 727100 753740 780380 807020 833660 860300 886940 133200 133200 133200 133200 133200 133200 133200 133200 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 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS INT. C 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 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 303 C 0 eee) 0 0 0 0 0 0 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 $9426 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 ¢ 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 ¢ 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 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 ¢ 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 REPAYNENT 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 49426 49426 49426 49426 49426 49426 $9426 49426 49426 ALASKA POWER PROJECT DIAMOND SHAMROCK/VOSS INT. C 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 c 371842 366892 361331 355082 348061 340173 331309 321349 310159 297586 2ND SERIES 302 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 303 ¢ Oe 0 ee ee Oe Oe ee 9 TOTAL OUTSTANDING 201c 371842 366892 361331 355082 348061 340173 331309 321349 310159 297586 INTEREST CHARGES 202 C 44477 43865 43178 42405 41538 40563 39467 38236 36853 35299 PRINCIPAL REPAYMENT 203 C 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 c¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 31l3.c 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 205 ¢ 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 REPAYMENT 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 C 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 ¢ 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT _21lre¢ 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 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 2isc 4949 5561 6249 7021 7889 8364 9959 11190 12573 14128 TOTAL DEBT SERVICE 216 C 49426 49426 49426 49426 49426 49426 49426 49426 49426 $9426 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 a 9 A200 oa 9 8 |AAN0 Qo fF fF 20900 DIAMOND SHAMROCK/VOSS INT. ¢ M55 Ul, 85-01-18 15.31) PAGE 9C DEBT SERVICE SCHEDULE 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 283458 267584 249749 229708 207191 181891 153464 121523 85634 45309 0 0 0 0 0 0 0 0 0 0 9 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 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 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 Go 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 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 49426 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 CACRS) INVESTHENT 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 OQUTPUT-GIGAWATTHOURS(GNH) 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 QANgAGANAAAD QaaagN9NgD HOONANCN REA FUNOING BELUGA POWER PROJECT SUMMARY OF ASSUMPTIONS AND OTHER INPUT DATA FOR THIS CASE TOTAL AMOUNT ($000) 0 0 0 493500 =i 493500 TOTAL 388170 PERCENT TOTAL OF ANNUAL REQUIRED COST COVERAGE % clorooo clooocoeo C M56 Ul, 85-01-22 13.34) TERM CYEARS) w sclopooo PAYMENT PERIODS Hl Page! BASE-R.E.A. ($000) NET PROCEEDS AVAILABLE BEGINNING OF PERIOD CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS R.E.A. GUARANTEED BONDS OTHER LONG TERM 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 REPAYMENT 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 TERM DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD DEK DEDEDE DE HE DE IEE EK INTEREST CHARGED TO CONSTRUCTION TOTAL AMOUNT CAPITALIZED “CUMULATIVE AMOUNT CAPITALIZED BOE HH HE HE IESE HH IKK CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION ITEM 10 ll 31 12 13 14 15 1 40 20 48 53 30 21 38 52 70 50 61 62 63 64 65 91 92 93 E0929 9 O2A99O 9 OM AMOMOHOHOD BELUGA POWER PROJECT C M54 Ul, 85-01-22 13.32) PAGE 2A CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD 1986 1987 0 63 38 52 0 5 4 94 8&7 5 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 00 900 ___2400 __4000 __9300 ____4300 __21300 __32300 __35700 __93600 1000 1963 2438 4052 9300 4305 21304 32394 35787 93605 914 1855 2259 3820 8847 3970 20361 30671 33187 88188 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 0 0 0 0 0 0 0 0 914 1855 2259 3820 8847 3970 20361 30671 33187 88188 86 108 180 232 453 335 943 1723 2600 5417 2 3 4 6 15 8 24 43 65 140 88 lll 184 238 468 344 967 1767 2665 5557 25 72 132 232 462 340 872 1680 2572 5465 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 25 72 132 232 462 340 872 1680 2572 5465 63 38 52 5 5 4 94 87 92 92 23 70 128 227 447 332 849 1637 2508 5325 937 1925 2387 4046 9295 4301 21210 32308 35694 93513 937 2862 5248 9295 9295 13596 34806 67113 102808 102808 875 1750 2100 3500 8225 3585 18121 26902 28688 77296 BASE-R.E.A. ($000) NET PROCEEDS AVAILABLE BEGINNING OF PE CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS R.E.A. GUARANTEED BONDS OTHER LONG TERM 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 TERM DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD HSE HEHEHE DE IE BE KEE INTEREST. CHARGED TO CONSTRUCTION TOTAL AMOUNT CAPITALIZED CUMULATIVE AMOUNT CAPITALIZED SEE DEI HEHE DEE DEE HE HEE CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION ITEM 10 ll 31 12 13 14 15 1 40 20 48 53 30 21 38 52 70 50 61 62 63 64 65 91 92 93 QOHNANAENAON OC a090Q0 29 29099 28 A209 ANAAMAMOKOHO joo eooooo BELUGA POWER PROJECT © M54 U1, 85-01-22 13.32) PAGE 2B CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD 1988 1989 92 42 40 57 92 28 46 27 7 28 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 Oreo 0 0 0 0 8600 _ 26600 300 _ 46000 _158500 30600 _ 42600 __39100 __ 37000 _149300 38692 26642 47340 46057 158592 30628 42646 39127 37007 149328 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 35200 22503 42031 39654 139388 23461 34459 30005 26966 114891 3493 4139 5309 6403 19204 7167 $187 9122 — 10042 — 34437 87 103 133 160 484 179 205 228 251 863 3580 4243 5442 6563 19688 7346 8392 9350 10293 — 35300 3537 4202 5385 6535 19660 7300 8365 9342 10267 35275 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 3537 4202 5385 6535 19660 7300 8365 9342 10267 35275 42 40 57 28 28 46 27 7 25 25 3450 4099 5252 6375 19176 7121 8160 9114 10016 34412 38650 26602 47284 46029 158564 30532 42620 39119 36982 149303 141458 168060 215343 261372 261372 291954 334573 373693 410675 410675 29988 18894 34780 32338 116000 18856 27295 23423 20746 90320 BASE-R.E.A. ($000) NET PROCEEDS AVAILABLE BEGINNING OF PERIOD CAPITAL FUNDING: EQUITY PREFERRED STOCK CONVENTIONAL BONDS R.E.A. GUARANTEED BONDS OTHER LONG TERM 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 REPAYHNENT 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 DEVELOPHENT BONDS OTHER LONG TERN DEBT TOTAL INTEREST CHARGES NET PROCEEDS AVAILABLE END OF PERIOD EOE SE HE 5 DEE EEK DE HIE INTEREST CHARGED TO CONSTRUCTION TOTAL AMOUNT CAPITALIZED “CUMULATIVE AMOUNT CAPITALIZED BENCH EEK IEE CONSTRUCTION EXPENDITURES EXCLUDING ESCALATION ITEM 10 ll 31 12 13 14 15 1 40 20 48 53 30 21 38 52 70 50 61 62 63 64 65 91 92 93 AMAAANRAAA A e200 929 220209290 28 AH AAAOOHOHO BELUGA POWER PROJECT © M54 CAPITALIZATION SCHEDULE AND UTILIZATION OF PROCEEDS DURING CONSTRUCTION PERIOD 1990 25 46 19 95 25 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 493500 493500 2 8 ss 8 0 0 0 ~493500 ~493500 31600 _ 23400 _ 14400 _ 13400 _ 82800 31625 ~ 23446 14419 506995 576325 20792 12069 2617 1378 36856 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 493500 493500 0 0 0 0 0 0 0 0 0 20792 12069 2617 494878 530356 10833 11377 11802 12117 ~ 45969 271 284 295 303 1153 11104 11661 12097 12420 — 47122 11057 11642 += 12002) «12337-47040 0 0 0 0 0 0 0 0 0 0 0 0 8 0 0 11057 11642 12002 — 12337 ~ 47040 46 19 5 82 82 10787 11358 =11707 «12035 = 45887 31579 23428 14324 13412 82743 442254 465681 480005 493418 493418 15765 9019 1927 1000 = 27711 Ul, 85-01-22 13.32) PAGE 2C BASE -R.E.A. BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 3A FORECASTED STATEMENT OF INCOME ($000) ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 OPERATING REVENUES PROJECT REVENUE REQUIREMENT 1c 98702 103212 103554 106254 109115 112149 saab a 122386 126215 SALES OF ELECTRICITY 2c 0 0 0 0 0 0 0 AVOIDED COST OF ELEC. we 9 0 9 0 9 0 0 0 TOTAL 3c 98702 103212 103554 106254 109115 112149 Tr53e8 T1e773 122386 126215 OPERATING EXPENSES OPERATION & MAINTENANCE FUEL COST 4c 15320 16239 17214 18246 19341 20502 21732 23036 24418 25883 OPERATION & MAINTENANCE EXPENSE 6c 24824 26314 27892 29566 31340 33220 35213 37326 39566 $1940 TOTAL O&M 8c 40144 42553 45106 47812 50681 53722 56945 60362 63984 67823 LEASE EXPENSE 271 0 9 9 0 0 0 9 0 0 0 DEPRECIATION EXPENSE 9C¢ 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 PROPERTY TAX 94 C 0 0 0 0 0 0 0 0 0 0 GROSS RECEIPTS TAX 95 C 0 0 0 0 9 0 0 0 0 0 TOTAL OPERATING EXPENSES loc 56591 59000 61553 64260 67128 70169 73392 76809 80431 84270 OPERATING INCOME 90 Cc 42110 44212 42001 41994 41987 41980 41972 41964 41955 41946 OTHER INCOME AND EXPENSES llc 0 9 241 256 271 287 305 323 342 363 INCOME BEFORE INTEREST CHARGES 12 ¢ 42110 44221 42242 42250 42258 42267 42276 42286 42297 42308 INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS 13.c 0 0 0 0 0 0 0 0 0 0 REA GUARANTED BONDS 14 C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 OTHER LONG TERM DEBT 15 Cc 0 0 0 0 0 0 0 0 0 0 SUBTOTAL 16 C¢ 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 OTHER INTEREST & EXPENSES AMORTIZED BOND DISCOUNT & EXPENSES 18 C 0 0 0 0 0 0 0 0 0 0 SHORT TERM LOANS 19 ¢ 0 0 0 0 0 0 0 0 0 0 INTEREST DURING CONSTRUCTION 20 C 0 9 0 0 0 0 0 0 0 0 SUBTOTAL 21 Cc 0 9 0 0 0 0 0 9 0 0 TOTAL INTEREST AND OTHER EXPENSES 22 C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 NET INCOME 23.¢ -15148 12883 -14688 -14485 14259 -14007 13725 -13409 -13057 -12663 TT KH HE HO HE COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 ¢ 99.90 104.47 104.81 107.54 110.44 113.51 116.77 120.22 123.87 127.75 IN PRESENT WORTH DOLLARS 163 C 51.68 48.42 43.53 40.02 36.82 33.91 31.25 28.83 26.62 24.59 LEVELIZED ANOUNT WHICH IF APPLIED EACH YEAR TO DATE NOULD HAVE THE SAME CUMULATIVE PRESENT WORTH AS aE THAT RESULTING FROM THE ACTUAL - ANNUAL AMOUNTS CALCULATED 159 ¢ 99.90 102.06 102.88 103.86 104.90 105.97 107.06 108.14 109.22 110.30 ba BASE -R.E.A. ($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&M LEASE EXPENSE DEPRECIATION EXPENSE PROPERTY TAX GROSS RECEIPTS TAX TOTAL OPERATING EXPENSES OPERATING INCOME OTHER INCOME AND EXPENSES INCOME BEFORE INTEREST CHARGES INTEREST AND OTHER EXPENSES LONG TERM DEBT INTEREST CONVENTIONAL BONDS REA GUARANTED BONDS OTHER LONG TERM DEBT SUBTOTAL OTHER INTEREST & EXPENSES AMORTIZED BOND DISCOUNT & EXPENSES SHORT TERM LOANS INTEREST DURING CONSTRUCTION SUBTOTAL TOTAL INTEREST AND OTHER EXPENSES NET INCOME TH HE NH KIKI COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS IN PRESENT WORTH DOLLARS LEVELIZED ANOUNT WHICH IF APPLIED EACH YEAR TO DATE WOULD HAVE THE SANE CUMULATIVE PRESENT WORTH A os THAT RESULTING FROM THE ACTUAL - ANNUAL ANOUNTS CALCULATED ITEM UNE aaag 13 14 15 16 18 193 20 21 22 23 165 163 S 159 a AF FF AARAROOO a AAAANN A900 ao BELUGA POWER PROJECT C 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 139652 144551 149747 155259 161107 167311 173892 180876 0 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 130679 135033 139652 144551 149747 155259 161107 167311 173892 180876 27436 29082 30827 32676 34637 36715 38918 41253 43728 46352 44456 7124 49951 52948 56125 59492 63062 66846 70856 75108 71892 76205 80778 a a 96208 zorea EE 114585 121460 0 0 0 0 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 88339 92653 97225 102072 107209 112655 118427 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 48654 47470 0 0 0 0 0 0 0 0 0 0 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 0 0 0 0 0 0 0 0 0 0 0 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 132.27 136.67 141.35 146.31 151.57 157.14 163.06 169.34 176.00 183.07 22.81 21.12 19.57 18.15 16.85 15.65 14.55 13.54 12.61 11.75 111.39 112.46 113.52 114.56 115.58 116.59 117.58 118.54 119.49 120.41 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 CPERATION & 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 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 TH HEHEHE IED HE OIE COST OF ELECTRICITY- MILLS/KWH IN CURRENT DOLLARS 165 IN PRESENT WORTH DOLLARS 163 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 c c Cc c QNAKDNAD a AAANNM AOAO00 ano DIAMOND SHAMROCK/VOSS ( M56 U2, 85-01-22 13.34) PAGE 3C FORECASTED STATEMENT OF INCOME 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 188319 196181 204524 213378 222775 232748 243334 254572 266501 279167 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 188319 196181 204524 213378 222775 232748 243334 254572 266501 279167 49133 52081 55206 58519 62030 65751 69697 73878 78311 83010 79614 84391 89455 94822 100511 106542 112934 119710 126893 134507 128748 ase 144661 153340 tt G 172293 182631 Bree e 205204 217516 0 0 0 0 0 0 0 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 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 9 0 0 0 0 0 0 0 46146 nates 43003 41145 39066 36735 34128 Bhan 27943 24285 9 0 0 0 0 0 0 46146 44663 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 9 0 9 0 0 0 0 0 0 0 0 0 Q 0 0 0 0 0 0 0 46146. 44663 43003 41145 39064 36735 341238 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. BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) 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 OPERATING REVENUES 3c¢ 98702 103212 103554 106254 109115 112149 115364 118773 122386 126215 OTHER INCOME DO ra a ere iS? 385 325 34 363 SUBTOTAL 37 ¢ 98702 103221 103795 106509 109386 112436 115669 119096 122728 126578 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 ¢ 98702 103221 103795 106509 109386 112436 115669 119096 122728 126578 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 ¢ 56591 59000 61553 64260 67128 70169 73392 76809 80431 84270 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS - 41 C¢ 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 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 C 58558 60668 58689 58697 58705 58714 58724 58734 58744 58755 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BOKDS 441 0 0 0 0 0 0 0 0 0 0 REA GUARANTED BONDS 45 1 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT 46 I 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 1 0 0 0 Q 0 0 0 0 0 0 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 € 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 C¢ 0 2110 132 139 148 157 166 176 187 198 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 c¢ 1.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ENERGY DEVELOPMENT BONDS 52 ¢ 1.00 1.04 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 OTHER LONG TERM DEBT 53 ¢ 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 TOTAL DEBT 54 C 1.00 1.04 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 BASE -R.E.A. BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 4B NET WORKING CAPITAL (FUNDS) AVAILABLE ($000) ITEM 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 FUNDS PROVIDED BY OPERATING REVENUE AND OTHER INCOME OPERATING REVENUES 3.C 130679 135033 139652 144551 149747 155259 161107 167311 173892 180876 OTHER INCOME llc 384 408 «432 458 485 514 545 578 613 650 SUBTOTAL 37 GC — 131064 — 135441 140084 — 145008 150232 155774 161652 167889 174505 181525 LESS INCOME THAT IS NOT CASH 38 I 0 0 0 0 0 0 0 0 0 0 FUNDS PROVIDED BY OPERATING REVENUE ee AND OTHER INCOME 39 C 131064 ~ 135441 140084 145008 — 150252 155774 161652 167889 174505 181525 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES 10 Cc 88339 92653 97225 102072 107209 112655 118427 124546 131032 137907 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 Cc 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 FUNDS APPLIED TO OPERATING EXPENSE 42 C 71892 76205 80778 85624 90762 96208 101980 108099 114585 121460 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43.C 59172 59236 59306 59384 59470 59566 59672 59790 59920 60065 FUNDS APPLIED TO DEBT SERVICE CONVENTIONAL BONDS 441 0 0 0 0 0 0 0 0 0 0 REA GUARANTED BONDS 45 1 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT 46 I 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 I 0 0 0 o_o 0 0 0 0 0 TOTAL FUNDS APPLIED TO DEBT SERVIC 48 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 INTERNALLY GENERATED FUNDS AVAILABLE FOR OTHER APPLICATIONS 50 ¢ 210 222 236 250 265 281 297 315 334 354 DEBT SERVICE COVERAGE CONVENTIONAL BONDS 51 ¢ 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ENERGY DEVELOPNENT BONDS 52 C 1.01 1.01 1.01 1.01 1.02 1.02 1.02 1.02 1.02 1.03 OTHER LONG TERN DEBT 53 C 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 TOTAL DEBT 54 C 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 232748 243334 254572 266501 279167 OTHER INCONE 1c 688 730 7 820 86 921 977 1035 1097 1163 SUBTOTAL 37 ¢ 189007 196911 205298 214198 223644 233670 244311 255607 267599 280330 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 ¢ 189007 196911 205298 214198 223644 233670 244311 255607 267599 280330 LESS FUNDS APPLIED TO OPERATING EXPENSES TOTAL OPERATING EXPENSES lo Cc 145195 152920 161108 169788 178988 188741 199078 210036 221651 233964 LESS: EXPENSES NOT REQUIRING EXPENDITURE OF FUNDS 41 Cc 16447 16447 447 16447 644 16447 16447 16447 16447 16447 FUNDS APPLIED TO OPERATING EXPENS 42 C 128748 136472 144661 153340 162541 172293 182631 193589 205204 217516 INTERNALLY GENERATED FUNDS AVAILABLE TO COVER DEBT SERVICE 43C 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 1 0 0 0 0 0 0 0 0 0 0 TEMPORARY BORROWINGS 47 1 0 0 8 0 0 0 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 C¢ 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 0.0 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. BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 5A ANALYSIS OF CASH & ANNUAL CASH BALANCES ($000) ITEM 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 BEGINNING CASH BALANCE 60 0 82 82 2193 2324 2464 2612 2768 2934 3111 3297 PLUS FUNDS GENERATED NET INCOME 23 © -15148 -12883 -14688 -14485 -14259 -14007 -13725 -13409 -13057 -12663 ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS 61 ¢ 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 INTEREST & OTHER EXPENSE 22 57259 57104 5693 56735 6518 56274 56001 55696 55354 54971 TOTAL FUNDS GENERATED 62 C 58558 60668 58689 58697 58705 58714 58724 58734 58744 58755 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 63C 0 0 0 0 0 0 0 0 0 0 CONSTRUCTION REQUIREMENTS 64 C 0 0 0 0 0 0 0 0 0 0 DISTRIBUTION TO PARTNERS 360 C 0 0 0 0 0 0 0 0 0 0 TOTAL FUNDS USED 65 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT 66 C 0 0 0 0 0 0 0 0 0 0 TEMPORARY FINANCING BORROWED 76 C 0 0 0 0 0 0 0 0 0 0 REPAID 77.¢ 0 0 0 0 0 0 0 0 0 0 CASH RECEIPTS FROM FINANCING 78 C 0 0 0 0 0 0 0 0 0 0 NET CASH BEFORE FUNDING 79.¢ 82 2193 2324 2464 2612 2768 2934 S1il 3297 3495 DEBT SERVICE RESERVE FUND DEPOSITS 67 0 0 0 o 0 0 0 0 o 0 0 DRANDO!!NS 68 C 0 0 0 0 0 0 0 0 0 0 NET ACCRUAL 69 C 0 0 0 0 0 0 0 0 0 0 REPLACEMENT RESERVE FUND DEPOSITS 70 ¢C 0 0 0 0 0 0 0 0 0 0 DRAMIDO!NN 71 0 0 0 0 0 0 0 0 0 0 NET ACCRUAL = 72-6 0 0 0 0 0 0 0 0 0 0 ENDING CASH BALANCE 74 ¢ B2 2193 2324 2464 2612 2768 2934 31il 3297 3495 NOTE: OPERATING REVENUES WERE INCREASED BY THESE AMOUNTS SO THAT CASH BALANCES DO NOT _DROP BELOW 30 DAYS O&M EXPENSE. 75 ¢ 0 2110 132 139 148 157 166 176 187 198 au BASE -R.E.A. ($000) ITEM BEGINNING CASH BALANCE 60 Cc PLUS FUNDS GENERATED NET INCOME 23c ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS 61 Cc INTEREST & OTHER EXPENSE 22 ¢ TOTAL FUNDS GENERATED 62 C DEDUCT USES OF FUNDS DEBT SERVICE PAYNENTS 248 C START-UP COSTS 56 1 FINANCING COSTS 135 2 WORKING CAPITAL INCREASES 63 C CONSTRUCTION REQUIREMENTS 64 C DISTRIBUTION TO PARTNERS 360 C TOTAL FUNDS USED 65 Cc PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT 66 C TEMPORARY FINANCING BORROWED 76 C REPAID 77C CASH RECEIPTS FROM FINANCING 78 C NET CASH BEFORE FUNDING 79 ¢ DEBT SERVICE RESERVE FUND DEPOSITS 67 0 DRAWDOWNS 68 C NET ACCRUAL 69 C REPLACEMENT RESERVE FUND DEPOSITS 70 Cc DRAMDOWNS 71C¢ NET ACCRUAL 72 C ENDING CASH BALANCE 74 C 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 5B ANALYSIS OF CASH & ANNUAL CASH BALANCES 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 3495 3705 3927 4163 4412 4677 4958 5255 5570 5905 -11818 -11274 -10667 -9988 -9228 -8379 -7430 6368 -5181 -3852 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 54542 54063 53526 52925 52252 1498 0655 49711 48654 47470 59172 59236 59306 59384 59470 59566 59672 59790 59920 60065 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 405 456 51 577 648 728 817 917 1028 153 58962 59013 59070 59134 59206 59285 59375 59474 59586 59711 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 3705 3927 4163 4412 4677 4958 5255 5570 5905 6259 a a a 9 a a g Q 4 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 3705 3927 4163 4412 4677 4958 5255 5570 5905 6259 614 678 748 826 913 1008 1114 1232 1363 1508 BASE -R.E.A. DIAMOND SHAMROCK/VOSS C M56 U2, 85-01-22 13.34) PAGE 5C ANALYSIS OF CASH & ANNUAL CASH BALANCES ($000) ITEM 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 BEGINNING CASH BALANCE 60 Cc 6259 6635 7033 7455 7902 8376 8878 9411 9976 10574 PLUS FUNDS GENERATED NET INCOME 23.c 2333 672 1187 3266 5592 8194 11105 14361 18005 22082 ITEMS INCLUDED IN NET INCOME NOT REQUIRING EXPENDITURE OF FUNDS 61 Cc 16447 16447 16447 16447 16447 16447 16447 16447 16447 16447 INTEREST & OTHER EXPENSE 22 C¢ 46146 44663 $3003 41145 39064 36735 34128 31210 27943 24285 TOTAL FUNDS GENERATED 62 C 60260 60439 60637 60858 61103 61376 61680 62018 62395 62814 DEDUCT USES OF FUNDS DEBT SERVICE PAYMENTS 248 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 START-UP COSTS 56 1 0 0 0 0 0 0 0 0 0 0 FINANCING COSTS 135 1 0 0 0 0 0 0 0 0 0 0 WORKING CAPITAL INCREASES 63 C¢ 0 0 0 0 0 0 0 0 0 0 CONSTRUCTION REQUIREMENTS 64 C 0 0 0 0 0 0 0 0 0 0 DISTRIBUTION TO PARTNERS 360 C 1327 1483 1658 1853 2072 2316 2590 2896 3238 3622 TOTAL FUNDS USED 65 C 59884 60041 60215 60411 60629 60874 61148 61454 61796 62179 PLUS CASH RECEIPTS FROM FINANCING CAPITAL CASH RECEIPTS NEW CAPITAL-EQUITY/DEBT 66 C 0 0 0 0 0 0 0 0 0 0 TEMPORARY FINANCING BORROWED 76 C 0 0 0 0 0 0 0 0 0 0 REPAID 7C¢ 0 0 0 0 0 0 0 0 0 0 CASH RECEIPTS FROM FINANCING 78 C 0 0 0 0 0 0 0 0 0 0 NET CASH BEFORE FUNDING 79 C 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 DEBT SERVICE RESERVE FUND DEPOSITS 67 0 a a a a a a a a a a DRANDGRNS 68 C 0 0 0 0 0 0 0 0 9 0 NET ACCRUAL 69 C 0 0 0 0 0 0 0 0 0 0 REPLACEMENT RESERVE FUND i DEPOSITS 70 Cc 0 0 0 0 0 0 0 0 0 0 DRANDONHS 71c 0 0 0 0 0 0 0 0 0 0 NET ACCRUAL 72 C¢ 0 0 0 0 Q 6 0 0 0 0 ENDING CASH BALANCE 74 C 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 NOTE: OPERATING REVENUES WERE INCREASED BY THESE ANOUNTS SO THAT CASH BALANCES DO NOT __DROP BELOW 30 DAYS O&M EXPENSE. 75¢ 1702 1881 2080 2300 2546 2819 3123 3461 3837 4256 BASE -R.E.A. BELUGA PONER PROJECT ( 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 493418 493418 493418 493418 493418 493418 493418 493418 493418 CONSTRUCTION WORK IN PROGRESS 398 I 0 0 0 0 0 0 0 0 0 0 LESS:ACCUMULATED DEPRECIATION 399 C 16447 32895 ___49342 __ 65789 ___82236 ___ 98684 1513 315738 148025 164473 NET PLANT 400 C 476970 460523 444076 427629 411181 394734 378287 361840 345392 328945 CURRENT ASSETS CASH 74 C¢ 82 2193 2324 2464 2612 2768 2934 3111 3297 3495 MATERIALS & SUPPLIES 411 C 0 0 0 0 0 0 0 0 0 0 OTHER CURRENT ASSETS 412 1 0 0 0 0 0 0 0 0 0 0 TOTAL CURRENT ASSETS 413 Cc 82 2193 2324 2464 2612 2768 2934 3111 3297 3495 DEBT SERVICE RESERVE FUND 405 C 0 0 0 0 0 0 0 0 0 0 UNAMORTIZED DEBT DISCOUNT & EXPENSE 409 C 0 0 0 0 0 0 0 0 0 0 TOTAL ASSETS 410 C 477053 462716 446400 430092 _ 413793 39750 38122 364950 348689 332440 LIABILITIES EQUITY CAPITAL 421 c¢ 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 23Cc -15148 ~12883 -14688 -14485 -14259 -14007 -13725 -13409 -13057 -12663 DIVIDENDS-PREFERRED STOCK 423 C 0 0 0 0 0 0 0 0 0 0 DIVIDENDS-COMMON STOCK 424 C 0 0 0 0 0 0 0 0 0 0 BALANCE,END OF PERIOD 420 C -15148 ~28031 42719 -57204 -71464 -85471 —99195 -112604 ~-125661 ~-138324 PREFERRED STOCK 427 ¢ 0 0 0 0 0 0 0 0 0 0 LONG TERN DEBT CONVENTIONAL BONDS 431 ¢ 0 0 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS 432 C 490747 489119 487297 485257 482973 480416 477554 474350 470764 466748 OTHER LONG TERM DEBT 433 C 0 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 TERM LOANS 439 C 0 0 0 0 0 0 0 0 0 0 CURRENT PORTION OF LONG TERM DEBT 441 1 1454 1628 1822 2040 2284 2557 2862 3204 3587 4015 OTHER CURRENT LIABILITIES 442 I 0 0 0 0 0 0 9 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 C 0 0 0 0 0 0 0 0 0 0 TOTAL LIABILITIES 450 C 477053 462716 446400 430092 413793 397502 381221 364950 348689 332440 ta 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 LIABILITIES EQUITY CAPITAL 421 RETAINED EARNINGS BALANCE, BEGINNING OF PERIOD 419 NET INCOME 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 INCOWE TAXES 443 =DEFERRED INVESTMENT TAX CREDITS 444 TOTAL DEFERRED CREDITS 445 TOTAL LIABILITIES 450 QOnD 20 2 OHOO oO foleiels) ao a|naagn QO E200 OF OO BELUGA POWER PROJECT C M56 Ul, 85-01-22 13.34) PAGE 6B BALANCE SHEET 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 493418 493418 aes 493418 493418 493418 “aes nee anaes 493418 0 180920 197367 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 0 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 2 —____8 —____d _ LLU Ll 316202 299977 283766 267568 251386 235219 _ 219069 202937 186824 170731 0 0 0 0 0 0 0 0 0 0 -138324 -150546 -162276 ~-173456 ~-184020 ~-193896 ~-203004 ~-211250 ~-218535 ~-224744 11818 -11274 -10667 -9988 —9228 -8379 -7430 -6368 -5181 -3852 0 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 -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 nbee?s as722i 451588 445282 438223 430320 421473 411569 400481 388070 0 0 0 0 0 0 0 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 12412 0 0 0 0 0 G 0 0 0 0 4495 5032 5633 6306 7060 7903 8847 9904 11087 12412 0 0 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 0 0 316202 299977 233766 267568 251386 235219 219069 202937 186824 170731 fa 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-CONMNON STOCK BALANCE, END OF PERIOD PREFERRED STOCK LONG TERM DEBT CONVENTIONAL BONDS REA GUARANTED BONDS OTHER LONG TERM DEBT TOTAL LONG TERM DEBT “ CURRENT LIABILITIES SHORT TERI1 LOANS CURRENT PORTION OF LONG TERM DEBT OTHER CURRENT LIABILITIES TOTAL CURRENT LIABILITIES DEFERRED CREDITS DEFERRED INCOME TAXES “IDEFERRED 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 ao fF ORO QO ananan oO isieieie) a 2090 OFF 2 DIAMOND SHAMROCK/VOSS (M56 U2, 85-01-22 13.34) PAGE 6C BALANCE SHEET 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 493418 493418 493418 493418 493418 493418 493418 493618 493418 493418 0 0 0 0 0 345392 _ 361840 __378287 __394734 __411181 __ 427629 __ 444076 60523 _ 476970 __ 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6635 7033 7455 7902 8376 8878 9411 9976 10574 11209 0 0 0 0 0 0 0 0 0 0 ——_2 —. 2 — 2 —___8 —__io_ LUC 154660 __138611 __122585 6585 W612 — 74667 5875 42870 7022 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 0 0 0 0 0 0 0 0 0 0 =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 0 0 0 0 0 374175 358620 341207 321714 299892 275463 = 248115 217500 183227 144860 0 0 0 0 0 0 Q 374175 358620 341207 ~ 321714 299892 — 275463 248115 217500 — 183227 144860 0 0 0 0 0 0 0 0 0 0 13895 15555 17413 19493 21822 24429 27348 30615 34273 38367 0 0 0 0 0 0 0 0 0 0 13895 15555 17413 19493 21822 24429 27348 30615 34273 38367 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 154660 __138611 __ 122585 — 106585 0612 74667 58753 42870 27022 11209 BASE- R.E.A. BELUGA POWER PROJECT C M55 Ul, 85-01-22 13.33) 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 C 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 303 C __s—i 0 0 o_o o_o 0 0 0 TOTAL OUTSTANDING 201 C 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 202 ¢ 0 0 0 0 0 0 0 0 0 0 PRINCIPAL REPAYMENT 203 ¢ 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 0 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 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 . 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 INTEREST CHARGES 206 C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 PRINCIPAL REPAYMENT 207 ¢ 1299 1454 1628 1822 2040 2284 2557 2862 3204 3537 TOTAL DEBT SERVICE 208 Cc 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 OTHER LONG TERM DEBT BALANCE, START OF PERIOD 1ST SERIES 321 C 0 0 0 0 0 0 0 0 0 0 2ND SERIES 322 C 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 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 ¢ 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 493500 492201 490747 489119 487297 485257 482973 480416 477554 474350 INTEREST CHARGES 214 C 57259 57104 56930 56735 56518 56274 56001 55696 55354 54971 PRINCIPAL REPAYMENT 215 C¢ 1299 1454 1628 1822 2040 2284 2557 2862 3204 3587 TOTAL DEBT SERVICE 216 C 58558 58553 58558 58558 58558 58558 58558 58558 58558 58558 BASE- R.E.A. BELUGA POWER PROJECT © M55 Ul, 85-01-22 13.33) PAGE 9B 7 DEBT SERVICE SCHEDULE ($000) ITEM 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 CONVENTIONAL BONDS BALANCE,START OF PERIOD 1ST SERIES 301 C 0 0 0 0 0 9 0 0 0 0 2ND SERIES 302 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 303 C 9 0 0 0 0 oO 0 0 0 0 TOTAL OUTSTANDING 201 Cc 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 202 C 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 6 0 0 0 0 0 0 0 0 ENERGY DEVELOPMENT BONDS BALANCE,START OF PERIOD 1ST SERIES sll c 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 2D SERIES 312 ¢ 0 0 0 0 0 0 0 0 0 0 3RD SERIES 313 ¢ 0 0 0 0 0 0 0 0 0 0 TOTAL OUTSTANDING 205 C 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 INTEREST CHARGES 206 C 54542 54063 53526 52925 52252 51498 50655 49711 $8654 47470 PRINCIPAL REPAYMENT 207 C 4015 4495 5032 5633 6306 7060 7903 8847 9904 11087 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 0 2ND SERIES 322 C 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 Cc 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 C 0 0 0 0 0 0 0 0 0 0 TOTALS ALL DEBT BALANCE-START OF PERIOD 213 C 470764 466748 462253 457221 451588 445282 438223 430320 421473 411569 INTEREST CHARGES 214 C . 54542 54063 53526 52925 52252 51498 50655 49711 48654 47470 PRINCIPAL REPAYMENT 215 C 4015 4495 5032 5633 6306 7060 7903 8847 9904 11087 TOTAL DEBT SERVICE 216 ¢ 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558 BASE- R.E.A. BELUGA POWER PROJECT ¢ 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 903-0 Se amet 0 o_O 0 o_O 0 0 TOTAL OUTSTANDING 201 C 0 0 0 0 0 0 0 0 0 0 INTEREST CHARGES 202 C 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 sll c 400481 388070 374175 358620 341207 321714 299892 275463 248115 217500 2ND SERIES 312 ¢ 0 0 0 0 0 0 0 0 0 0 SRD SERIES 313.¢ 0 0 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 C 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 0 2ND SERIES 322 € 0 0 0 0 0 0 0 0 0 0 3RD SERIES 323 C 0 0 0 9 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 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 C 46146 44663 43003 41145 39064 36735 34128 31210 27943 24285 PRINCIPAL REPAYMENT 215 ¢ 12412 13895 15555 17413 19493 21822 24429 27348 30615 34273 TOTAL DEBT SERVICE 216 C 58558 58558 58558 58558 58558 58558 58558 58558 58558 58558