CONTENTS. I. TEPCO Outline. II. Power Demand. III. Electricity Supply Facilities

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3 CONTENTS I. TEPCO Outline 1. TEPCO Service Area Company Highlights... 2 (1) Company Highlights... 2 (2) Business Scale Developments... 3 (3) Business Scale by Area... 4 (4) Comparison of TEPCO with 1 Japanese Electric Power Companies (total) and World Major Power Companies... 5 a. Position of TEPCO in Japanese Electric Power Industry... 5 b. Major Electric Power Companies in the World... 5 c. Business Highlights for All Japanese Electric Power Companies Organization Chart... 8 II. Power Demand 1. Changes in Japan's GDP and TEPCO's Power Demand... 1 (1) Changes in Japan's GDP and TEPCO's Power Demand... 1 (2) Average Rates of Increase in GDP, Final Energy Consumption, Electricity Sales, and Peak Demand (3) Recent Changes in GDP Elasticity (4) Electric Curve of Large Industrial Power as Diffusion Index (5) Electrification Rate (primary energy supply base) Electricity Sales (1) Changes in Electricity Sales and Number of Customers (FY 25 29) (2) Changes in Electricity Sales and Number of Customers (FY 2 24) (3) Changes in Electricity Sales and Number of Customers (until FY 1999) (4) Changes in Percentage Composition of Large Industrial Power Customers by Industry Type (5) Residential Customer Power Demand Changes in Energy Consumption and Contract Power per Household Peak Demand... 2 (1) Changes in Peak Demand (daily peak at generation end)... 2 <Reference> Recent Changes in Peak Demand <Reference> Peak Demand in Major Countries (2) Trend of Monthly Peak Demand (daily peak at generation end) (3) Pattern of Daily Electricity Usage (dates of annual peak demand recorded) (4) Peak Demand and Annual Load Factor (5) Estimated Ratio of Air Conditioning and Other Summer Demands During Peak Load (at transmission end) III. Electricity Supply Facilities 1. Power Generation Facilities (1) Power Generation (authorized capacity) <Reference> Special Note on Power Generation Facility (2) Power Generation Capacity by Primary Energy Source... 3 (3) Generation Capacity by Energy Source a. TEPCO (a) Generation Capacity by Energy Source (TEPCO only) i

4 (b) Generation Capacity by Energy Source (including purchased power) <Reference> Combining of Energy Sources to Meet Changing Demand b. 1 Electric Power Companies (a) Generation Capacity by Energy Source (1 electric power companies) (b) Generation Capacity by Energy Source (1 electric power companies: including purchased power) c. Power Source Shares by Country d. Development Status of Overseas Business <Reference> Characteristics of Each Energy Source (i) Supply Stability (ii) Economic Considerations (iii) Environmental Considerations... 4 <Reference> FuelRelated Conversion Formulas (4) Major Power Generation Facilities a. Hydroelectric Power (with a capacity of more than 5MW) b. Thermal Power c. Nuclear Power d. New Energy (5) Electricity Generated and Purchased (6) Changes in Power Output Composition by Energy Sources (including purchased power) a. TEPCO b. 1 Electric Power Companies (7) Electric Power Development Program a. Major Electric Power Development Projects b. Demand Outlook c. Peak Demand Outlook (8) Reserve Capacity <Reference> Summary of Power Plant Siting Procedure (example of nuclear power station)... 5 (9) Wide Area Coordination System Operation a. Purpose b. Recent Situations <Reference> Classification of Power Exchange c. History of Wide Area Coordination System Operation at TEPCO d. Current Situation of Interconnection for WideArea Operation (1) Summary of Bid System for Wholesale Supply of Electric Power a. Screening Results b. List of Successful Bidders c. IPP Power Supply Procurement (procurement amount: total and by fiscal year) Transmission and Distribution Facilities (1) Transmission / Underground Transmission a. Transmission Facilities by Voltage b. Underground Transmission Line Installation Rate <Reference> 1MV Designed Power Transmission Lines (UHV: Ultra High Voltage lines) (2) Substation Facilities (3) Distribution Facilities a. Number of Supports and Transformers for Distribution Facilities b. Underground Distribution Line Installation Rate ii

5 3. Forced Outages... 6 <Reference> SinglePhase ThreeWire Facility Installation Rate for Lighting Service... 6 IV. Fuels 1. Fuel Consumption (Thermal power) Crude Oil / Heavy Oil (1) Crude Oil Purchase and Consumption a. TEPCO's Crude Oil Purchase and Consumption b. Total Crude Oil Purchase and Consumption for 1 Electric Power Companies (2) Heavy Oil Purchase and Consumption a. TEPCO's Heavy Oil Purchase and Consumption b. Total Heavy Oil Purchase and Consumption for 1 Electric Power Companies (3) Yearly Changes in Crude Oil CIF Pricing <Reference> Monthly Changes in Crude Oil Pricing LNG (1) LNG Purchase and Consumption a. TEPCO's LNG Purchase and Consumption b. Total LNG Purchase and Consumption for Electric Power Suppliers (2) TEPCO's LNG Contract Summary (longterm contracts only) Coal (1) TEPCO's Coal Purchase and Consumption (2) Total Coal Purchase and Consumption for 1 Electric Power Companies V. Nuclear Power 1. Nuclear Power Generation... 7 (1) General Data on Nuclear Power Plants in Operation... 7 (2) Nuclear Power Plant Capacity Factor Trend (3) Nuclear Power Plant Performance (4) Problem Occurrence Problems to be Reported in Accordance with the Electricity Utilities Industry Law and the Law on the Regulation of Nuclear Source Material, Nuclear Fuel Material and Reactors (5) Annual Production of Solid Radioactive Wastes <Reference> Units of Radioactivity and Radiation <Reference> Radiation Doses and Their Physical Effects Nuclear Fuel Cycle (1) Outline of Nuclear Fuel Cycle Facilities (2) Japan's Procurement of Uranium (3) Outline Plan for Plutonium Utilization in Light Water Reactors (MOX utilization) (4) Amount of Spent Fuel Storage... 8 a. Amount of Spent Fuel Storage... 8 b. Outline of Common Spent Fuel Storage Facility at Fukushima Daiichi Nuclear Power Station... 8 c. Outline of Spent Fuel Storage Cask at Fukushima Daiichi Nuclear Power Station... 8 (5) Overview of Recycled Fuel Storage Center (6) Current Status of Nuclear Fuel Reprocessing Contracts (7) HighLevel Radioactive Waste Storage Conditions <Reference> Schedule of Geological Disposal Project <Reference> Nuclear Fuel Cycle Concept iii

6 VI. VII. Accounting 1. Profit and Financial Structure Improvement Targets a. Changes in Standard Profits b. Changes in ROA/ROE c. Changes in Outstanding Amount of InterestBearing Liabilities d. Changes in Shareholders' Equity Ratio <Reference> Numerical Targets of "Management Vision 21" Targets to be achieved by FY Balance Sheet (1) NonConsolidated (2) Consolidated Statement of Income... 9 (1) NonConsolidated... 9 (2) Consolidated Summary of NonConsolidated Financial Results Consolidated Statements of Cash Flow Changes in Ordinary Income (1) NonConsolidated (2) Consolidated Changes in Capital Changes in Number of Shareholders and Shares (including shareholders and shares less than one unit) <Reference> Comparison with Other Industries as Ratio of Individual Shareholders and Ratio of Individual Stock Ownership (per unit) <Reference> Current Distribution of Shares (per unit) by Owners <Reference> Major Shareholders (top 1 shareholders) Changes in Shareholders' Equity Ratio <Reference> Shareholders' Equity Ratio, by Industry (FY 28) Changes in Ratio of Recurring Profit to Capital Stock Changes in Costs of Supplying Electricity <Reference> Changes in Equipment Expenses and Fuel Costs per kwh of Electricity Sales <Reference> Changes in Exchange Rate (Interbank Monthly Average)... 1 <Reference> Annual Exchange Rate (Interbank)... 1 Electricity Rates and Rate Systems 1. Electricity Rates...11 (1) Overall Electricity Rates for Residential and Power Services (2) Electricity Rates Revision History (3) Unit Price of Electricity (become effective on April 1, 21) (4) Formulas for Calculating Electricity Charges (Monthly Bills) under Major Contract Categories (5) Fuel Cost Adjustment System (6) Introduction of a Solar Surcharge in Conjunction with the Introduction of the "New System for the Purchase of Surplus Electric Power from Solar Power Plants" (7) Ratios of Electricity Bills to Household Expenses and Production Amount a. Ratio of Electricity Bills to Household Expenses (all households nationwide) b. Ratio of Electricity Bills to Production Amount (total for manufacturing industry sector) c. Ratio of Electricity Bills to Production Amount (by industry) <Reference> Comparison of Rate Increases for Electric Power and Other Public Services (in Tokyo Metropolitan 23 wards) iv

7 (8) Household Electrical Appliances Usage Cost Reference Chart (9) Calculation Process of Electricity Rates Electricity Rate Systems (1) Number of Customers Served and Contract Power by Use (2) Number of Customers Using Electric Water Heaters under NightOnly Service (3) Summary of Major Optional Tariffs (4) New System for the Purchase of Surplus Electric Power from Solar Power Plants a. Electric Power That Can Be Purchased b. Unit Price for the Purchase of Surplus Electric Power c. Purchase Period and Revisions of Unit Purchase Price (5) Wheeling Service VIII. Capital Investment and Financing 1. Changes in Capital Investment and Plans Changes (Net Increase) in Plans for Raising Equipment Funds (1) TEPCO <Reference> Changes (net increase) in Plans for Raising Equipment Funds (2) 1 Electric Power Companies <Reference> Changes (1 electric power companies) in Plans for Raising Equipment Funds <Reference> Changes in Private Sector Capital Investment <Reference> Comparison of Investment by Industry (FY 28) Changes in Amount of Corporate Bonds Issued Balance of Corporate Bonds and Loans Payable Changes in Materials Procurement Cost IX. Rationalization and Streamlining 1. Changes in Electric Power Sales per Employee Thermal Power Generation Efficiency (LHV: Lower Heating Value) <Reference> International Comparison of Thermal Power Generation Efficiency Transmission and Distribution Loss Rate Changes in Automatization Rate of Hydroelectric Power Stations and Substations X. Technology Development and Renewable Energy 1. Research and Development (1) Main Themes of FY 21 Research and Development Plan (2) Changes in Research and Development Expenditure (3) Ratio of Research and Development Expenditure to Sales (4) Changes in the Number of Patent Applications Electric Vehicles Number of Electric Vehicles in Fleet at TEPCO Offices <Reference> Annual CO 2 Emissions per Vehicle (after 1,km run) Renewable Energy (1) Sites Where TEPCO Has Introduced New Energy (as of the end of March 21) (2) Business Use Facilities (as of the end of March 21) <Reference> International Comparison of Solar Amounts and Wind Power Generation Installations in Major Countries (3) Issues and TEPCO R&D Milestones v

8 (4) Purchase of Surplus Power from Solar, Wind and Waste Power Plants <Reference> Purchase of Electricity from Solar and Wind Power XI. Environmental Protection Measures 1. Changes in SOx and NOx Emissions Intensity per Power Output from Thermal Power Stations <Reference> CO 2 Emissions per kwh of Electricity Usage (for each electric source in Japan) Changes in TEPCO's CO 2 Emissions and Emissions Intensity <Reference> List of CO 2 Emission Factor for Each Company (FY 28) Active Implementation of Green Procurement and Purchasing Internal Environmental Costs (for TEPCO alone in FY 29) TEPCO's Efforts Toward Industrial Waste Recycling Overview of PCB Treatment Facilities XII. Energy Conservation and Recycling 1. Total Energy Efficiency of District Heating and Cooling (DHC) Services (within the TEPCO service area) CO 2 Emission per Amount of Heat Unit Sold in District Heating and Cooling (DHC) Services (within the TEPCO service area) EnergyIIP Intensity by Industry Energy Conservation for Major Household Electrical Appliance <Reference> Power Consumption Comparison for Household Appliances <Reference> Comparison of Environmental Performance of Heating Appliance Major Electrical Appliances and Systems TEPCO is Recommending <Reference> Increase of Heat Storage Air Conditioning Systems (cumulative) XIII. Related Businesses 1. Affiliated Companies New Businesses <Reference> Outline of TEPCO Gas Business XIV. Other Data 1. Energy Dependency of Major Countries (27) Composition of Primary Energy Sources in Major Countries (27) <Reference> Japan's Energy SelfSufficiency Rate <Reference> SelfSufficiency Rate by Energy Source (27) <Reference> Import and Export of Electricity Related to France (27) Japan Energy Supply and Demand Outlook (1) Final Energy Consumption (2) Primary Energy Supply Long Term Supply and Demand Outlook for Electric Power (1) End of Fiscal Year Equipment Capacity (electric companies) (2) Power Generation (electric companies) Security Index of Various Countries (27) Changes in Japan's Crude Oil Imports and Security Index Power Generation Costs for Each Power Source <Reference> Items Used for Trial Calculations by Advisory Committee on Energy and Natural Resources, Electricity Industry Committee of Advisory Committee for Natural Resources and Energy vi

9 I. TEPCO Outline 1. TEPCO Service Area Gunma Branch Office Tochigi Branch Office Maebashi Utsunomiya Ibaraki Branch Office Saitama Branch Office Mito Yamanashi Branch Office Tama Branch Office Saitama Kofu Hachioji Tokyo Branch Office Head Office Shinjuku Numazu Branch Office Numazu Kanagawa Branch Office Yokohama Chiba Chiba Branch Office (Service Areas of the 1 Electric Power Companies in Japan) Hokkaido Electric Power Sapporo Okinawa Electric Power Urasoe Kyushu Electric Power Fukuoka Chugoku Electric Power Hiroshima Osaka Takamatsu Shikoku Electric Power Hokuriku Electric Power Toyama Nagoya Chubu Electric Power Kansai Electric Power Tohoku Electric Power Sendai Tokyo Tokyo Electric Power 1

10 2. Company Highlights (1) Company Highlights Capital stock: 676,434,197,5 yen (as of the end of March 21) Total number of shares issued: 1,352,867,531 (as of the end of March 21) Number of shareholders: 794,653 (as of the end of March 21) Electricity sales: (FY 29) For lighting: 96,89 GWh For power: 184,78 GWh Total: 28,167 GWh Peak demand: 64.3 GW (as of July 24, 21) Number of customers (Period ended March 31, 21 exc. specifiedscale demand) For lighting: million GW For power: 2.19 million 15.2 GW Total: million 18.7 GW Revenue from electricity sales: 4,54.5 billion yen (as of FY 29) Number of power stations and generation capacity (as of the end of March 21) Hydro: GW Thermal: GW Oil 1.83 GW Coal 1.6 GW LN(P)G GW Nuclear: GW New Energy, etc. 2.4 GW Total: GW Number of employees: 38,227 (as of the end of March 21) 2

11 (2) Business Scale Developments Capital Stock (billion yen) At the End of FY Total of 1 EP Co. 29 2,655.9 Revenue from Electricity Sales (billion yen) , ,32.3 4,9.6 4, ,682. 4,74.6 4, , , ,749.6 Capital Investment (billion yen) ,14.3 1, ,34.4 Utility Fixed Assets (billion yen) , ,36.4 9, ,31.9 9, ,77.5 8,416. 8, , (118.9) (113.9) (19.3) (16.) (12.2) 24,773.6 Electricity Sales (TWh) Generation Capacity (GW) Number of Customers (million) Number of Employees 29,274 29,453 37,724 38,341 39,58 43,448 38,51 38,235 38,18 38,234 38,3 38, ,42 Notes: 1. Numerical data (Revenue from electricity sales and Electricity sales) for FY 1951 include those of Kanto Haiden Kabushiki Kaisha for April Figures in parentheses are a multiplication unit with the reference value for FY 1951 or the end of FY 1951 being one. 3. Figures for capital stock, revenue from electricity sales, capital investment, and utility fixed assets are obtained by omitting fractions smaller than.1 billion yen. Those for other items are obtained by are rounding. 4. The number of employees is that of persons at work. The number of employees of TEPCO includes employees on loan to other companies and agencies. 5. The number of customers of 1 electric power companies excludes those in the specificscale demand and is based on electric service contracts. 3

12 (3) Business Scale by Area (as of the end of FY 29) 6, , , , ,135 2,445 4, ,631 2, , (1) (35) * (33) (34) (26) (31) (37) (1) (32) 377, Notes: 1. New energy etc. consist of wind, solar, waste, geothermal and biomass power generation (facilities with expected supply capacity and TEPCO's approved facilities). 2. Numazu refers to a part of TEPCO's service area on the east of the Fuji River in Shizuoka Prefecture. Th e data for TEPCO's two branch offices in Tokyo are based on the total of the Tokyo and Tama branch offices. 3. Figures in parentheses represent the ratio (%) to the total for the entire nation (total for 1 electric power companies). 4. The figures for TEPCO's area represent the total of the areas that its branch offices cover. The figure for total for the entire nation (total of the 1 electric power companies) is as of October 1, 29. Source: "Land Areas of the Individual Prefectures, Cities, Wards, Towns and Villages of Japan," Ministry of Land, Infrastructure, Transport and Tourism. 5. Figures for peak demand represent peak demand recorded at the consumption end in the area that each branch office covers. * The figure 54.5 does not agree with that for the total of peak demand recorded by each branch office because it represents the peak load registered by TEPCO as a whole (at the generation end). 6. The number of customers of 1 electric power companies exclude those in the specificscale demand and is based on electric service contracts. 7. Totals in the table may not agree with the sums of each column because of being rounded off. 8. Figures for service centers are as of March 31, The nationwide population figure is as of January 1, 21. (Source: Ministry of Internal Affairs and Communications, "Monthly Report on Current Population Estimates") 4

13 (4) Comparison of TEPCO with 1 Japanese Electric Power Companies (total) and World Major Power Companies a. Position of TEPCO in Japanese Electric Power Industry opulation (million) Area (km 2 ) Population Density (persons/km 2 ) Electricity Sales (TWh) Peak Demand (GW) Capital Stock (billion yen) Total Assets (billion yen) Gross Income (billion yen) Number of Customers (million) TEPCO Service Area (a) Total Service Area of 1 EP Co. (b) (as of the end of FY 29) (a) / (b) * * Notes: *1 TEPCO's peak demand so far is 64.3 GW recorded on July 24, 21. *2 The number of customers exclude those in the specificscale demand and is based on electric service contracts. *3 The nationwide population is as of January 1, 21. (Source: Ministry of Internal Affairs and Communications, "Monthly Report on Current Population Estimates") b. Major Electric Power Companies in the World (29, or as of the end of 29) Country Electricity Sales GWh Total Assets (billion Yen) (1) U. S. A. Exelon Southern Company (2) Duke Energy (2) Germany E. ON RWE Italy ENEL Canada HydroQuébec U. K. Centrica Scottish and Southern Energy France EDF GDF Suez (3) (2), (4) Sweden Vattenfall (5) Japan TEPCO Kansai Electric Power Co. Chubu Electric Power Co. Notes: Source: Figures for electricity sales (excluding wholesale and trading) include those sold to other countries. Total assets are consolidated figures for companies that incorporate a holding company system (other than for Japan). (1) Converted at the rates of US$1 = yen; 1 euro = yen; UK 1 = yen; Canada 1$ = yen (Cabinet office 'foreign economic data', 29 values). Sweden 1 krona = yen (calculated based on "Vattenfall 29 Annual Report"). (2) Figures include the electricity sales for wholesale and trading. (3) Domestic figures only. (4) Subsidiaries in foreign countries such as Electrabel of Belgium make up most of the electricity sales. (5) Subsidiaries in foreign countries such as Vattenfall Europe AG of Germany account for approximately half of the electricity sales. Annual Reports of the world's major electric power companies, etc. 5

14 c. Business Highlights for All Japanese Electric Power Companies Notes: Sources: 1. Figures in parentheses in the thermal power column are those for geothermal power. 2. Fractions smaller than one MW were rounded to the nearest whole number for maximum outputs. 3. Electricity generated and purchased = power generated by their own + power purchased from other utilities + electricity exchanged (deducted) power for pumped storage. 4. Figures for electricity sales include those for business operations and construction work but exclude those for intercompany power sales and for power sales to other utilities (with fractions smaller than one GWh when rounded). 5. Figures given for revenue from electricity sales exclude intercompany power sales and power sales to other utilities. Fractions smaller than a million yen are rounded down. 6. The number of employees is that of persons at work. The number of employees of TEPCO includes employees on loan to other companies and agencies. 7. in the above table indicates the item under which the utility holds first place among the ten electric power companies in Japan. 8. Totals in the table may not agree with the sums of each column because of being rounded off. 9. The number of customers is based on electric service contracts excluding those in the specifiedscale demand. "Electric Power Statistics" (from the website of the Federation of Electric Power Companies of Japan) "Annual Securities Report" 6

15 (FY 29 or as of the end of March 21) <Peak demand: as of the end of June 21> 7

16 3. Organization Chart 8

17 (As of July 1, 21) 9

18 II. Power Demand 1. Changes in Japan's GDP and TEPCO's Power Demand (times) 4 (1) Changes in Japan's GDP and TEPCO's Power Demand 35 (Sales) 3 (Peak) (GDP) 1 Electricity sales Peak demand 5 FY 1952=1 GDP '52 '55 '6 '65 '7 '75 '8 '85 '9 ' ' '6'7'8'9 (FY) Note: Real GDP is based on the 2 price standard (continuity system). However, years before 1954 are estimated based on the 1985 price standard, and years before 1979 are estimated on the 199 price standard (in each case based on fixed benchmark year). 1

19 (2) Average Rates of Increase in GDP, Final Energy Consumption, Electricity Sales, and Peak Demand (%) Notes: 1. FY 1973 was the year when the first oil crisis occurred. 2. FY 1979 was the year when the second oil crisis occurred. 3. FY 1985 was the year when the economic recession caused by "strong yen" occurred. 4. FY 199 was the year when the "bubble" economy collapsed. 5. FY 27 and 28 were the years when the worldwide recession occurred. 6. The final energy consumption is quoted from Agency for Natural Resources and Energy, "General energy statistics." (3) Recent Changes in GDP Elasticity (%) Note: Peak demand: Daily peak at generation end 11

20 t Q3 (4) Electric Curve of Large Industrial Power as Diffusion Index (%) 15. Electric Curve of Large Industrial Power as Diffusion Index (Monthly) 1. Total electric power, sales + independently generated Contracted power Shaded areas show the recession periods (this time is provisional). 25. '83/4 '84/4 '85/4 '86/4 '87/4 '88/4 '89/4 '9/4 '91/4 '92/4 '93/4 '94/4 '95/4 '96/4 '97/4 '98/4 '99/4 '/4 '1/4 '2/4 '3/4 '4/4 '5/4 '6/4 '7/4 '8/4 '9/4 '1/4 Growth (a) Rate (%) Total electric power, sales + independently generated (b) Contracted power (a)(b) Gap of the growth rates above FY 21 FY 22 FY 23 FY 24 FY 25 FY 26 FY 27 FY 28 FY 29 Q1 Q 2 Q 3 Q4 Q 1 Q2 Q3 Q 4 Q1 Q2 Q3 Q 4 Q 1 Q2 Q 3 Q4 Q1 Q 2 Q 3 Q4 Q1 Q 2 Q3 Q 4 Q 1 Q2 Q 3 Q Q 1 Q2 Q4 Q1 Q2 Q3 Q N ote: The electric curve of large industrial power is an indicator for assessing the current state of the economy from the powe r dema nd side. I shows the yeartoyear growth of the volume of large industrial power (including independent power generation) and largesc a le contracted power. 12

21 (5) Electrification Rate (primary energy supply base) [Electrification rate (%)] (1 15 J) Gross primary energy supply 25, Energy input for electric power generation Electrification rate (%) 4 2, ,1 22,761 22,473 22,352 22,888 22,751 22,699 22,813 21, , , ,627 16, ,33 1, 13,383 9,4 9,441 9,317 9,22 9,51 9,65 9,678 9,969 9, , ,232 5,416 5, 7,71 4,473 3, ,943 5 '65 '7 '75 '8 '85 '9 '95 ' '2 '3 '4 '5 '6 '7 '8 FY Source: Agency for Natural Resources and Energy, "General Energy Statistics 28" 13

22 2. Electricity Sales (1) Changes in Electricity Sales and Number of Customers (FY 25 29) TWh FY Electricity Sales Other than Specified Scale Demand Total Lighting Power Total SpecifiedScale Demand SpecifiedScale Demand Number of Customers Lighting Total Power Total Lighting and Power Total Power Total Lighting Composition Ratio Residential Purposes Industrial Purposes Notes: 1. Units of electricity sales: 1 TWh 2. Customer subscriptions at the end of fiscal year, in units of one million. Does not include specifiedscale demand. 3. The scope of specifiedscale demand users after FY 25 is in principle customers with a contract of more than 5 kw. 14

23 (2) Changes in Electricity Sales and Number of Customers (FY 2 24) FY Notes: 1. Units of electricity sales: 1 TWh 2. Customer subscriptions at the end of fiscal year, in units of million. Does not include specificscale demand. 3. For the years FY 2 23, the specifiedscale demand as a rule includes customers with a contract of at least 2MW. For FY 24, the specifiedscale demand as a rule includes customers with a contract of at least 5 kw. 4. The composition ratio represents the ratio to electricity sales (%): residential purposes indicates public and other uses (railways, etc.) under Lighting, Night only power service, Commercial power, Lowvoltage power; and the remainder is for industrial purposes. 5. Figures in table may not exactly match the total shown because of rounding. * The format was modified since year 2 when extra high voltage power sector was newly set due to deregulation of electricity. 15

24 (3) Changes in Electricity Sales and Number of Customers (until FY 1999) Notes: 1. Units of electricity sales: 1 TWh 2. Customer subscriptions at the end of fiscal year, in units of one million. 3. The composition ratio represents the ratio to electricity sales (%): residential purposes indicates public and other uses (railways, etc.) under Lighting, Night only Power, Commercial Power, LowVoltage Power; and the remainder is for industrial purposes. 16

25 TWh) 17

26 (4) Changes in Percentage Composition of Large Industrial Power Customers by Industry Type Note: Others include railways, foodstuffs, metals, oil and coal, plastics, printing, publishing, water service, and other. 18

27 (5) Residential Customer Power Demand Changes in Energy Consumption and Contract Power per Household (Monthly average in TEPCO's service area) (kwh) (Ampere) '51'55'6'65'7'71'72'73'74'75'76'77'78'79'8'81'82'83'84'85'86'87'88'89'9'91'92'93 '94'95'96'97'98'99''1'2'3'4'5'6'7'8'9FY 19

28 3. Peak Demand (1) Changes in Peak Demand (daily peak at generation end) Note: Peak demand has shifted from winter to summer since FY in the above table indicates the highest figure historically. 2

29 <Reference> Recent Changes in Peak Demand (GW) <Jul.24> 51.9 <Aug.23> <Sep.4> 54.1 <Aug.24> <Jul.18> <Aug.25> 59.4 <Aug.4> <Jul.4> <Jul.3> <Sep.1> <Aug.3> <Jul. 24> <Aug.1> <Jul. 2> <Aug.5> <Aug. 22> <Aug. 8> <Jul. 14> <Sep.11> <Jul. 3> '89 '9 '91 '92 '93 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 (FY) Note: in the above table represents an increase over the previous year. 21

30 <Reference> Peak Demand in Major Countries (GW) TEPCO U.S.A. Japan Canada France Germany U.K. Italy Note: FY 27 results. The figure for Japan shows the peak daily output for the 1 major electric power companies (July 24, 21) together with the peak daily output for TEPCO (July 24, 21). The figure for U.S.A. is a total of peak demands in the summer of 26. Sources: Japan Electric Power Information Center, Inc., "Overseas Electric Power Industry Statistics (29)" 22

31 (2) Trend of Monthly Peak Demand (daily peak at generation end) (GW) FY FY FY 1968 Apr. May Jun. Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Month Note: Peak demand has shifted from winter to summer since FY

32 (3) Pattern of Daily Electricity Usage (dates of annual peak demand recorded) (GW) 7 (1%) FY 21 (Jul) 6 5 (1%) FY 199 (Aug) 4 3 (47%) (1%) FY 198 (Jul) 2 (44%) (1%) (45%) FY 197 (Sep) 1 (45%) (1%) (44%) FY 196 (Jan. 1961) (o'clock) 24

33 (4) Peak Demand and Annual Load Factor (GW) () 7 (Planned) (Actual) Peak Demand Peak Demand Annual Load Factor (Actual) (Planned) Annual Load Factor '73 '74 '75 '76 '77 '78 '79 '8 '81 '82 '83 '84 '85 '86 '87 '88 '89 '9 '91 '92 '93 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 '1 '19 (FY) Notes: 1. "Peak demand" here represents the maximum threeday average peak load at transmission end. 2. Planned values are based on the management plan for FY 21 (peak demand for FY 21 is the planned value). 25

34 (5) Estimated Ratio of Air Conditioning and Other Summer Demands During Peak Load (at transmission end) (GW) '7 '75 '77 '79 '81 '83 '85 '87 '89 '91 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 '1 '19 (FY) (Actual) (Planned) (Planned) Notes: 1. Above figures represent maximum threeday average peak demand, indicate the portion of August, at the transmission end. (However, FY 1979, FY 1981, FY 1987, FY 1991, FY 1996 to FY 1998, FY 21, FY 24 and FY 29 indicate the portion of July, FY 1985, FY 1992 and FY 23 indicate the portion of September.) 2. Shaded areas represent the percentage (%) of air conditioning and other summer loads during peak demand. 26

35 MEMO 27

36 III. Electricity Supply Facilities 1. Power Generation Facilities (1) Power Generation (authorized capacity) (Unit: GW) Notes: 1. The figures in brackets in the upper rows represent the number of locations or sites. Figures in parentheses in the lower rows show the percentage composition (%) of authorized capacity. 2. The figures before FY 28 for thermal power include geothermal power. 3. Totals in the table may not agree with the sums of each column because of being rounded off. 4. The figures for new energy etc. consist of wind, solar and waste power generation before FY 28 (facilities with expected supply capacity and TEPCO's approved facilities). The figures in FY 29 added geothermal and biomass power generation (facilities with expected supply capacity and TEPCO's approved facilities). <Reference> Special Note on Power Generation Facility August 18, 1959 Thermal power becomes primary power source, with hydroelectric next December 1, 1965 Yagisawa Power Station begins operations (TEPCO's first pumped storage plant) March 3, 1968 Generation capacity surpasses 1GW April 24, 197 Minami Yokohama Thermal Power Station begins operations (world's first LNGonly thermal power) March 26, 1971 Fukushima Daiichi Nuclear Power Station Unit 1 (46MW) begins operations June 16, 1973 End of coalonly thermal power in Japan (ShinTokyo Thermal Power Station was the last) July 18, 1974 Generation capacity surpasses 2GW September 28, 1974 Kashima Thermal Power Station Unit 5 begins operations (first 1,MW capacity from single unit in Japan) October 12, 1978 Fukushima Daiichi Nuclear Power Station Unit 4 begins operations (nuclear power surpasses hydroelectric power) October 24, 1979 Fukushima Daiichi Nuclear Power Station Unit 6 (1,1MW) begins operations (Total power station output 4,696MW) October 26, 1979 Generation capacity surpasses 3GW September 11, 1981 Shintakasegawa Power Station completed (maximum output 1,28MW, singleunit output 32MW) April 2, 1982 Fukushima Daini Nuclear Power Station Unit 1 (1,1MW) begins operations December 17, 1982 Tanbara Power Station Units 1, 4 (3MW each) begin operations June 3, 1984 Tsurumi Thermal Power Station (445MW) ceases operations February 28, 1985 Yokosuka Thermal Power Station Unit 1 (265MW) begins operations with COM fuel 28

37 September 18, 1985 December 2, 1985 July 4, 1986 November 6, 1986 August 25, 1987 September 18, 1987 July 8, 1988 June 23, 1989 March 12, 1991 August 29, 1991 December 2, 1991 January 22, 1993 June 24, 1994 July 7, 1994 June 16, 1995 July 2, 1997 January 21, 1998 January 22, 1998 March 25, 1999 March 29, 1999 December 3, 1999 March 27, 2 March 31, 2 April 7, 2 June 8, 2 June 15, 2 August 2, 23 November 13, 23 December 12, 23 July 12, 24 December 2, 24 December 2, 24 December 22, 25 March 27, 26 March 27, 26 July 29, 28 February 5, 29 November 1, 29 KashiwazakiKariwa Nuclear Power Station Unit 1 (1,1MW) begins operations Futtsu Thermal Power Station Group 1 Unit 1 (165MW) begins operations Tanbara Power Station Units 2, 3 (3MW x 2) begin operations All units of Futtsu Thermal Power Station Group 1 (1,MW) begin operations Fukushima Daini Nuclear Power Station Unit 4 (1,1MW) begins operations Fukushima Daini Nuclear Power Station completed (total output 4,4MW, capacity of nuclear power facilities surpasses 1,MW) Higashi Ohgishima Thermal Power Station Unit 1 (1,MW) begins operations Imaichi Power Station Unit 1 (35MW) begins operations Hirono Thermal Power Station Unit 3 (1,MW) begins operations Higashi Ohgishima Thermal Power Station Unit 2 (1,MW) begins operations ShinTokyo Thermal Power Station (35MW) ceases operations Imaichi Power Station Units 2, 3 (35MW x 2) begin operations Imaichi Power Station completed (maximum output 1,5MW, singleunit output 35MW) Hirono Thermal Power Station Unit 4 (1,MW) begins operations Shiobara Power Station Units 1, 2 (3MW x 2) begin operations Goi Thermal Power Station No. 6 Gas Turbine (126MW) begins operations Shiobara Power Station Unit 3 (3MW) begins operations KashiwazakiKariwa Nuclear Power Station Unit 7 (1,356MW) begins operations KashiwazakiKariwa Nuclear Power Station completed (the world's largest nuclear power station with total output of 8,212MW) All units of Yokohama Thermal Power Station Group 7 (1,4MW) begin operations All units of Yokohama Thermal Power Station Group 8 (1,4MW) begin operations Hachijojima Geothermal Power Station (3.3MW) begins operations (TEPCO's first geothermal power station) Chiba Thermal Power Station Units 1 4 (6MW) ceases operations Kazunogawa Power Station Unit 1 (4MW) begins operations Yokohama Thermal Power Station Units 1 3 (525MW) cease operations Hachijojima Wind Power Station (5kW) begins operations (first commercial wind power plant for a power company) All units of Chiba Thermal Power Station Group 1 (1,44MW) begin operations Kazunogawa Power Station Unit 2 (4MW) begins operations All units of Chiba Thermal Power Station Group 2 (1,44MW) begin operations All units of Shinagawa Thermal Power Station Group 1 (1,14MW) begin operations All units of Futtsu Thermal Power Station Group 3 (1,52MW) begin operations Hitachinaka Thermal Power Station Unit 1 (1,MW) begins operations Hirono Thermal Power Station Unit 5 (6MW) begins operations Yokosuka Thermal Power Station Unit 1 (265MW) ceases operations Yokohama Thermal Power Station Unit 4 (175MW) ceases operations Kannagawa Power Station Unit 1 (47MW) begins operations Kawasaki Thermal Power Station Units 16 (1,5MW) cease operations Yokosuka Thermal Power Station Unit 2 (265MW) ceases operations Futtsu Thermal Power Station Group 4 Unit 1 (57MW) begins operations All units of Kawasaki Thermal Power Station Group 1 (15MW) begin operations Futtsu Thermal Power Station Group 4 Unit 2 (57MW) begins operations 29

38 (2) Power Generation Capacity by Primary Energy Source (unit: MW, %) Thermal Hydro At fy the end End of FY Conventional Pumped Storage Subtotal Oil Coal LNG/LPG Other Gases Subtotal Nuclear New Energy, etc. Total TEPCO Capacity Output 2,179 ( 3) 6,88 ( 11) 8,987 ( 14) 1,83 ( 17) 1,6 ( 2) 25,759 ( 4) ( ) 38,189 ( 59) 17,38 ( 27) 4 ( ) 64,487 ( 1) 29 Including Purchased Power Output 4,15 ( 5) 1,533 ( 14) 14,638 ( 19) 12,12 ( 16) 4,774 ( 6) 26,463 ( 34) 1,613 ( 2) 44,862 ( 58) 18,188 ( 23) 4 ( ) 77,692 ( 1) 21 (planned) TEPCO Capacity Output 2,181 ( 3) 6,88 ( 11) 8,989 ( 14) 1,831 ( 17) 1,6 ( 2) 26,265 ( 4) ( ) 38,696 ( 59) 17,38 ( 27) 4 ( ) 64,996 ( 1) Including Purchased Power Output 4,112 ( 5) 1,533 ( 14) 14,645 ( 19) 11,946 ( 15) 4,774 ( 6) 26,936 ( 35) 1,613 ( 2) 45,269 ( 58) 18,188 ( 23) 4 ( ) 78,16 ( 1) 219 (planned) TEPCO Capacity Output 2,183 ( 3) 7,278 ( 1) 9,461 ( 13) 1,831 ( 15) 3,2 ( 5) 26,299 ( 37) ( ) 4,33 ( 57) 21,453 ( 3) 52 ( ) 71,296 ( 1) Including Purchased Power Output 4,119 ( 5) 11,3 ( 13) 15,122 ( 18) 11,946 ( 14) 6,4 ( 8) 26,97 ( 31) 1,314 ( 2) 46,631 ( 55) 22,795 ( 27) 52 ( ) 84,6 ( 1) Notes: 1. The figures in parentheses represent the percentage to the total capacity. 2. Planned values are based on the management plan for FY Purchased power by bid, which is already decided for FY 21 and FY 219, is divided into each energy source. 4. Totals in the table may not agree with the sums of each column because of being rounded off. 5. New energy etc. consist of wind, solar, waste, geothermal and biomass power generation (facilities with expected supply capacity and TEPCO's approved facilities). 3

39 (3) Generation Capacity by Energy Source a. TEPCO (a) Generation Capacity by Energy Source (TEPCO only) 1.82GW % (.36) 8% (1.46) End of FY (.81) 67 (1.64) '55 41 (3.36) 33 (2.64) 26 (2.1) '65 2(.46) 72 (14.1) 9(1.75) 17 (3.2) '73 8(2.3) 63 (15.42) 16 (3.95) 13 (3.19) '75 24 (9.1) 1(.53) 26 (9.58) 35 (13.32) 14 (5.7) '85 28 (14.6) 1(.53) 17 (8.83) 1(.35) 38 (19.26) 15 (7.63) '95 3 (17.31) () 15 (8.76) 41 (23.67) 14 (8.1) '99 29 (17.31) () 15 (8.76) 41 (24.27) 15 (8.51) ' 29 (17.31) () 14 (8.76) 43 (25.79) 14 (8.52) '1 29 (17.31) () 14 (8.76) 43 (25.79) 14 (8.52) '2 28 (17.31) 2(1.) 14 (8.76) 43 (27.7) 13 (8.52) 28 (17.31) 3(1.6) 13 (8.5) 43 (26.9) () () () () () () 13 (8.52) 28 (17.31) 3(1.6) 13 (8.23) 42 (25.7) 14 (8.99) '3 '4 '5 28 (17.31) 3(1.6) 13 (8.23) 42 (25.7) () () 14 (8.99) '6 28 (17.31) 3(1.6) 17 (1.83) 38 (23.75) () 14 (8.99) 27 (17.31) 3(1.6) 17 (1.83) 39 (25.25) () 14 (8.99) '7 '8 ' (17.31) 2(1.6) 17 (1.83) 4 (25.76) () 14 (8.99) 27 (17.31) 2(1.6) 17 (1.83) 4 (26.27) () 14 (8.99) 3 (21.45) 5(3.2) 15 (1.83) 37 (26.3) (5) 13 (9.46) '1 '19 (planned) (planned) Nuclear Coal Oil Other Gasses LNG LPG Geothermal (199828) () New Energy etc. (After 1999) Hydro Notes: 1. Figures at the top and in parentheses are authorized output (GW). 2. Planned values are based on the management plan for FY Total capacity for the year may not agree with the sum of each energy source because of being rounded off. 4. City gas is classified into LNG/LPG after The figures for new energy etc. consist of wind, solar and waste power generation before FY 28 (facilities with expected supply capacity and TEPCO's approved facilities). The figures added geothermal and biomass power generation after FY 29 (facilities with expected supply capacity and TEPCO's approved facilities). 9.96GW % (3.51) 29% (2.87) 36% (3.58) End of FY1965 Notes: 3(.63) 3(.67) 6 (14.44) 3(.83) 7 (1.75) 24 (5.91) '73 (b) 8(2.19) 2(.67) 54 (15.85) 3(.83) 13 (3.95) 2 (5.94) '75 Generation Capacity by Energy Source (including purchased power) 22 (1.14) 4(1.77) 22 (9.8) 3(1.53) 29 (13.32) 2 (9.1) '85 25 (15.64) 4 (2.65) 16 (9.59) 4(2.26) 31 (19.29) 2 (12.53) '95 26 (18.19) 3(2.12) 14 (9.77) 2(1.53) 35 (24.17) () 2 (13.51) '99 26 (18.19) 3(2.12) 14 (9.99) 2(1.53) 35 (24.62) () 2 (13.92) ' 25 (18.19) 2(1.73) 14 (1.1) 2(1.53) 37 (26.11) () 2 (13.93) '1 25 (18.19) 3(2.23) 14 (1.4) 2(1.53) 37 (26.46) () 19 (13.93) '2 24 (18.19) 4(3.23) 14 (1.34) 2(1.64) 37 (27.74) () 19 (14.15) 24 (18.19) 5(3.83) 13 (1.8) 2(1.79) 37 (27.57) () 19 (14.15) 24 (18.19) 5(3.8) 13 (9.82) 2(1.79) 36 (26.37) () 2 (14.63) '3 '4 '5 24 (18.19) 5(3.8) 13 (9.96) 2(1.79) 36 (26.57) () 2 (14.63) '6 24 (18.19) 6(4.27) 16 (12.34) 2(1.61) 33 (24.62) () 19 (14.6) 24 (18.19) 6(4.27) 16 (12.7) 2(1.61) 33 (25.97) () 19 (14.64) '7 '8 '9 '1 '19 (planned) (planned) Nuclear Coal Oil Other Gasses LNG LPG Geothermal (199828) () New Energy etc. (After 1999) 1. Figures at the top and in parentheses are authorized output (GW). 2. Planned values are based on the management plan for FY Purchased power by bid, which is already decided for the years 21 and 219, is divided into each energy source. 4. Total capacity for the year may not agree with the sum of each energy source because of being rounded off. 5. City gas is classified into LNG/LPG after The figures for new energy etc. consist of wind, solar and waste power generation before FY 28 (facilities with expected supply capacity and TEPCO's approved facilities). The figures added geothermal and biomass power generation after FY 29 (facilities with expected supply capacity and TEPCO's approved facilities) (18.19) 6(4.77) 16 (12.1) 2(1.61) 34 (26.46) () 19 (14.64) (18.19) 6(4.77) 15 (11.95) 2(1.61) 35 (26.94) () 19 (14.65) (22.8) 8(6.4) 14 (11.95) 2(1.31) 31 (26.97) (5) 18 (15.12) Hydro 31

40 <Reference> Combining of Energy Sources to Meet Changing Demand Conventional hydroelectric power (Pondage type) Pumped storage hydroelectric power Daily load curve Electricity for pumped storage hydroelectric power generation Oil Peak load supply LNG, LPG, and other gases Middle load supply Coal Nuclear power Base load supply Conventional hydroelectric ( Runoffriver type ) (hours) Nuclear power: Coal thermal power: LNG thermal power: Oil thermal power: Pumped storage hydroelectric power: TEPCO promotes its development as a base load supply due to its greater stability, economical fuel supply situation and its environmental preservation advantage while keeping safety as the first target. TEPCO promotes its long term development as a base load supply considering its environmental impact from the viewpoint of diversification of electric power sources and due to its higher stability and economical fuel supply situation. TEPCO promotes its development as an urban type electric power source near demand areas for middle and base load supplies with aiming the highefficiency power generation due to its excellent environmental adaptability and operability as compared with other fossil fuels. TEPCO ensures proper capacity for peak load supply by extending the service life of present facilities due to its quick operational response to variations in demand and its flexible fuel supply buffer function. TEPCO properly promotes its development as an economic and reliable peak load supply due to its excellent load traceability and a power storageoperations function. Conventional hydroelectric power: TEPCO promotes its development as an environment friendly and low economic impact due to its advantages as a purely domestic renewable energy source and its lower environmental impact. 32

41 b. 1 Electric Power Companies (a) Generation Capacity by Energy Source (1 electric power companies) 8.48GW 33% (2.81) % () 67% (5.67) Notes: (b) (3.98) 1 (.11) 65 (7.49) GW 3(2.28) 7(5.31) 32% (11.61) 24% (8.45) 2% (.65) 42% (15.18) 57 (45.94) (1) 6(4.98) 27 (21.4) (1.95) 27 (8.15) 2 (.5) 35 (1.78) (6.8) 4 (2.89) 62 (5.26) (1) 6 (4.93) 2 (16.38) (22.9) 4 (4.69) 36 (46.66) (17) 23 (3.5) 19 (24.13) (42.3) 24 (46.7) (48) 29 (56.8) (51) 17 (33.77) (43.13) 9 (17.28) 22 (43.45) (48) 3 (58.41) (51) 17 (33.75) (43.13) 1 (18.98) 22 (42.8) (48) 29 (58.41) (51) 17 (33.77) (43.13) 1 (2.57) 21 (4.4) (48) 3 (59.5) (35) 17 (33.77) Figures at the top and in parentheses are authorized output (GW). 2. Total capacity for the year may not agree with the sum of each energy source because of being rounded off. (The sum of the values in each bar is adjusted to 1%.) 3. Figures given are for a total of 9 power companies (except Okinawa Electric Power Company) before The figures for new energy etc. consist of wind, solar and waste power generation before FY 28 (facilities with expected supply capacity and TEPCO's approved facilities). The figures in FY 29 added geothermal and biomass power generation (facilities with expected supply capacity and TEPCO's approved facilities). Generation Capacity by Energy Source (1 electric power companies: including purchased power) (6.6) 5(4.87) 55 (52.4) (2) 8(7.25) 25 (23.67) (1.76) 5 (3.33) 67 (44.62) (1) 4 (2.73) 21 (14.21) (24.52) 7(9.94) 32 (48.31) (18) 22 (33.19) 22 (33.6) (41.19) 1 (2.14) 25 (49.53) (49) 24 (47.83) (16) 21 (41.99) (38.41) 6 (1.79) 28 (48.1) (46) 26 (44.27) (16) 18 (31.68) (44.92) 11 (24.88) 22 (48.6) (52) 27 (6.35) (51) 2 (44.33) (42.3) 8 (14.5) 24 (46.56) (48) 29 (56.21) (51) 17 (33.32) (44.92) 13 (29.22) 21 (48.39) (52) 26 (6.8) (51) 2 (44.78) 8 (15.7) (45.74) 13 (3.5) 2 (45.79) (52) 27 (62.38) (51) 2 (44.86) (45.74) 14 (33.77) 2 (45.16) (52) 27 (62.87) (51) 19 (44.9) (45.74) 15 (35.75) 19 (43.19) (52) 27 (63.97) (35) 2 (45.2) (47.12) 16 (37.84) 18 (43.33) (52) 27 (63.13) (35) 19 (45.26) 22 (44.51) 11 (22.42) 2 (4.36) (48) 3 (58.51) (35) 17 (33.79) 23 (46.96) 11 (22.33) 2 (4.43) (48) 29 (57.32) () 17 (34.27) (49.58) 16 (37.67) 18 (43.42) (52) 26 (61.94) () 19 (45.74) (46.85) 11 (22.33) 2 (38.93) (49) 29 (58.44) () 17 (34.29) (49.47) 16 (37.36) 18 (42.6) (52) 26 (63.26) () 19 (45.76) (46.85) 11 (21.98) 21 (41.16) (49) 28 (55.79) () 17 (34.58) (49.47) 16 (37.47) 19 (44.9) (52) 25 (6.44) () 19 (46.4) (45.32) 11 (21.98) 21 (41.17) (49) 29 (58.33) () 17 (34.89) 23 (46.23) 11 (21.86) 2 (41.81) 29 (59.67) () 17 (34.9) (47.94) 16 (37.45) 18 (43.83) (52) 26 (62.78) () 2 (46.38) 2 (48.85) 16 (37.95) 18 (43.45) 27 (64.32) () 19 (46.38) End of FY1965 '73 '75 '85 '95 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 Notes: 1. Figures at the top and in parentheses are authorized output (GW). 2. Total capacity for the year may not agree with the sum of each energy source because of being rounded off. (The sum of the values in each bar is adjusted to 1%.) 3. Figures given are for a total of 9 power companies (except Okinawa Electric Power Company) before The figures for new energy etc. consist of wind, solar and waste power generation before FY 28 (facilities with expected supply capacity and TEPCO's approved facilities). The figures in FY 29 added geothermal and biomass power generation (facilities with expected supply capacity and TEPCO's approved facilities). 33