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

CONTENTS I. TEPCO Outline 1. TEPCO Service Area... 1 2. 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... 6 3. 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... 11 (3) Recent Changes in GDP Elasticity... 11 (4) Electric Curve of Large Industrial Power as Diffusion Index... 12 (5) Electrification Rate (primary energy supply base)... 13 2. Electricity Sales... 14 (1) Changes in Electricity Sales and Number of Customers (FY 25 29)... 14 (2) Changes in Electricity Sales and Number of Customers (FY 2 24)... 15 (3) Changes in Electricity Sales and Number of Customers (until FY 1999)... 16 (4) Changes in Percentage Composition of Large Industrial Power Customers by Industry Type... 18 (5) Residential Customer Power Demand... 19 Changes in Energy Consumption and Contract Power per Household... 19 3. Peak Demand... 2 (1) Changes in Peak Demand (daily peak at generation end)... 2 <Reference> Recent Changes in Peak Demand... 21 <Reference> Peak Demand in Major Countries... 22 (2) Trend of Monthly Peak Demand (daily peak at generation end)... 23 (3) Pattern of Daily Electricity Usage (dates of annual peak demand recorded)... 24 (4) Peak Demand and Annual Load Factor... 25 (5) Estimated Ratio of Air Conditioning and Other Summer Demands During Peak Load (at transmission end)... 26 III. Electricity Supply Facilities 1. Power Generation Facilities... 28 (1) Power Generation (authorized capacity)... 28 <Reference> Special Note on Power Generation Facility... 28 (2) Power Generation Capacity by Primary Energy Source... 3 (3) Generation Capacity by Energy Source... 31 a. TEPCO... 31 (a) Generation Capacity by Energy Source (TEPCO only)... 31 i

(b) Generation Capacity by Energy Source (including purchased power)... 31 <Reference> Combining of Energy Sources to Meet Changing Demand... 32 b. 1 Electric Power Companies... 33 (a) Generation Capacity by Energy Source (1 electric power companies)... 33 (b) Generation Capacity by Energy Source (1 electric power companies: including purchased power)... 33 c. Power Source Shares by Country... 34 d. Development Status of Overseas Business... 36 <Reference> Characteristics of Each Energy Source... 38 (i) Supply Stability... 38 (ii) Economic Considerations... 39 (iii) Environmental Considerations... 4 <Reference> FuelRelated Conversion Formulas... 41 (4) Major Power Generation Facilities... 42 a. Hydroelectric Power (with a capacity of more than 5MW)... 42 b. Thermal Power... 43 c. Nuclear Power... 44 d. New Energy... 44 (5) Electricity Generated and Purchased... 45 (6) Changes in Power Output Composition by Energy Sources (including purchased power)... 46 a. TEPCO... 46 b. 1 Electric Power Companies... 47 (7) Electric Power Development Program... 48 a. Major Electric Power Development Projects... 48 b. Demand Outlook... 48 c. Peak Demand Outlook... 49 (8) Reserve Capacity... 49 <Reference> Summary of Power Plant Siting Procedure (example of nuclear power station)... 5 (9) Wide Area Coordination System Operation... 51 a. Purpose... 51 b. Recent Situations... 51 <Reference> Classification of Power Exchange... 51 c. History of Wide Area Coordination System Operation at TEPCO... 52 d. Current Situation of Interconnection for WideArea Operation... 53 (1) Summary of Bid System for Wholesale Supply of Electric Power... 54 a. Screening Results... 54 b. List of Successful Bidders... 54 c. IPP Power Supply Procurement (procurement amount: total and by fiscal year)... 55 2. Transmission and Distribution Facilities... 56 (1) Transmission / Underground Transmission... 56 a. Transmission Facilities by Voltage... 56 b. Underground Transmission Line Installation Rate... 56 <Reference> 1MV Designed Power Transmission Lines (UHV: Ultra High Voltage lines)... 57 (2) Substation Facilities... 58 (3) Distribution Facilities... 59 a. Number of Supports and Transformers for Distribution Facilities... 59 b. Underground Distribution Line Installation Rate... 59 ii

3. Forced Outages... 6 <Reference> SinglePhase ThreeWire Facility Installation Rate for Lighting Service... 6 IV. Fuels 1. Fuel Consumption (Thermal power)... 62 2. Crude Oil / Heavy Oil... 63 (1) Crude Oil Purchase and Consumption... 63 a. TEPCO's Crude Oil Purchase and Consumption... 63 b. Total Crude Oil Purchase and Consumption for 1 Electric Power Companies... 63 (2) Heavy Oil Purchase and Consumption... 63 a. TEPCO's Heavy Oil Purchase and Consumption... 63 b. Total Heavy Oil Purchase and Consumption for 1 Electric Power Companies... 63 (3) Yearly Changes in Crude Oil CIF Pricing... 64 <Reference> Monthly Changes in Crude Oil Pricing... 64 3. LNG... 65 (1) LNG Purchase and Consumption... 65 a. TEPCO's LNG Purchase and Consumption... 65 b. Total LNG Purchase and Consumption for Electric Power Suppliers... 65 (2) TEPCO's LNG Contract Summary (longterm contracts only)... 66 4. Coal... 68 (1) TEPCO's Coal Purchase and Consumption... 68 (2) Total Coal Purchase and Consumption for 1 Electric Power Companies... 68 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... 72 (3) Nuclear Power Plant Performance... 73 (4) Problem Occurrence... 74 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... 74 (5) Annual Production of Solid Radioactive Wastes... 75 <Reference> Units of Radioactivity and Radiation... 76 <Reference> Radiation Doses and Their Physical Effects... 77 2. Nuclear Fuel Cycle... 78 (1) Outline of Nuclear Fuel Cycle Facilities... 78 (2) Japan's Procurement of Uranium... 79 (3) Outline Plan for Plutonium Utilization in Light Water Reactors (MOX utilization)... 79 (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... 81 (6) Current Status of Nuclear Fuel Reprocessing Contracts... 82 (7) HighLevel Radioactive Waste Storage Conditions... 83 <Reference> Schedule of Geological Disposal Project... 83 <Reference> Nuclear Fuel Cycle Concept... 84 iii

VI. VII. Accounting 1. Profit and Financial Structure Improvement Targets... 86 a. Changes in Standard Profits... 86 b. Changes in ROA/ROE... 86 c. Changes in Outstanding Amount of InterestBearing Liabilities... 86 d. Changes in Shareholders' Equity Ratio... 86 <Reference> Numerical Targets of "Management Vision 21" Targets to be achieved by FY 21... 87 2. Balance Sheet... 88 (1) NonConsolidated... 88 (2) Consolidated... 89 3. Statement of Income... 9 (1) NonConsolidated... 9 (2) Consolidated... 91 4. Summary of NonConsolidated Financial Results... 92 5. Consolidated Statements of Cash Flow... 93 6. Changes in Ordinary Income... 94 (1) NonConsolidated... 94 (2) Consolidated... 94 7. Changes in Capital... 95 8. Changes in Number of Shareholders and Shares (including shareholders and shares less than one unit)... 96 <Reference> Comparison with Other Industries as Ratio of Individual Shareholders and Ratio of Individual Stock Ownership (per unit)... 96 <Reference> Current Distribution of Shares (per unit) by Owners... 96 <Reference> Major Shareholders (top 1 shareholders)... 97 9. Changes in Shareholders' Equity Ratio... 98 <Reference> Shareholders' Equity Ratio, by Industry (FY 28)... 98 1. Changes in Ratio of Recurring Profit to Capital Stock... 98 11. Changes in Costs of Supplying Electricity... 99 <Reference> Changes in Equipment Expenses and Fuel Costs per kwh of Electricity Sales... 99 <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... 11 (2) Electricity Rates Revision History... 12 (3) Unit Price of Electricity (become effective on April 1, 21)... 14 (4) Formulas for Calculating Electricity Charges (Monthly Bills) under Major Contract Categories... 18 (5) Fuel Cost Adjustment System... 19 (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"... 111 (7) Ratios of Electricity Bills to Household Expenses and Production Amount... 113 a. Ratio of Electricity Bills to Household Expenses (all households nationwide)... 113 b. Ratio of Electricity Bills to Production Amount (total for manufacturing industry sector)... 113 c. Ratio of Electricity Bills to Production Amount (by industry)... 113 <Reference> Comparison of Rate Increases for Electric Power and Other Public Services (in Tokyo Metropolitan 23 wards)... 114 iv

(8) Household Electrical Appliances Usage Cost Reference Chart... 115 (9) Calculation Process of Electricity Rates... 116 2. Electricity Rate Systems... 117 (1) Number of Customers Served and Contract Power by Use... 117 (2) Number of Customers Using Electric Water Heaters under NightOnly Service... 118 (3) Summary of Major Optional Tariffs... 118 (4) New System for the Purchase of Surplus Electric Power from Solar Power Plants... 119 a. Electric Power That Can Be Purchased... 119 b. Unit Price for the Purchase of Surplus Electric Power... 119 c. Purchase Period and Revisions of Unit Purchase Price... 119 (5) Wheeling Service... 12 VIII. Capital Investment and Financing 1. Changes in Capital Investment and Plans... 121 2. Changes (Net Increase) in Plans for Raising Equipment Funds... 122 (1) TEPCO... 122 <Reference> Changes (net increase) in Plans for Raising Equipment Funds... 122 (2) 1 Electric Power Companies... 123 <Reference> Changes (1 electric power companies) in Plans for Raising Equipment Funds... 123 <Reference> Changes in Private Sector Capital Investment... 124 <Reference> Comparison of Investment by Industry (FY 28)... 124 3. Changes in Amount of Corporate Bonds Issued... 125 4. Balance of Corporate Bonds and Loans Payable... 126 5. Changes in Materials Procurement Cost... 126 IX. Rationalization and Streamlining 1. Changes in Electric Power Sales per Employee... 127 2. Thermal Power Generation Efficiency (LHV: Lower Heating Value)... 128 <Reference> International Comparison of Thermal Power Generation Efficiency... 128 3. Transmission and Distribution Loss Rate... 129 4. Changes in Automatization Rate of Hydroelectric Power Stations and Substations... 129 X. Technology Development and Renewable Energy 1. Research and Development... 13 (1) Main Themes of FY 21 Research and Development Plan... 13 (2) Changes in Research and Development Expenditure... 131 (3) Ratio of Research and Development Expenditure to Sales... 131 (4) Changes in the Number of Patent Applications... 131 2. Electric Vehicles... 132 Number of Electric Vehicles in Fleet at TEPCO Offices... 132 <Reference> Annual CO 2 Emissions per Vehicle (after 1,km run)... 132 3. Renewable Energy... 133 (1) Sites Where TEPCO Has Introduced New Energy (as of the end of March 21)... 133 (2) Business Use Facilities (as of the end of March 21)... 134 <Reference> International Comparison of Solar Amounts and Wind Power Generation Installations in Major Countries... 134 (3) Issues and TEPCO R&D Milestones... 135 v

(4) Purchase of Surplus Power from Solar, Wind and Waste Power Plants... 136 <Reference> Purchase of Electricity from Solar and Wind Power... 136 XI. Environmental Protection Measures 1. Changes in SOx and NOx Emissions Intensity per Power Output from Thermal Power Stations...138 <Reference> CO 2 Emissions per kwh of Electricity Usage (for each electric source in Japan)... 139 2. Changes in TEPCO's CO 2 Emissions and Emissions Intensity... 14 <Reference> List of CO 2 Emission Factor for Each Company (FY 28)... 14 3. Active Implementation of Green Procurement and Purchasing... 141 4. Internal Environmental Costs (for TEPCO alone in FY 29)... 142 5. TEPCO's Efforts Toward Industrial Waste Recycling... 143 6. Overview of PCB Treatment Facilities... 145 XII. Energy Conservation and Recycling 1. Total Energy Efficiency of District Heating and Cooling (DHC) Services (within the TEPCO service area)... 146 2. CO 2 Emission per Amount of Heat Unit Sold in District Heating and Cooling (DHC) Services (within the TEPCO service area)... 147 3. EnergyIIP Intensity by Industry... 147 4. Energy Conservation for Major Household Electrical Appliance... 148 <Reference> Power Consumption Comparison for Household Appliances... 149 <Reference> Comparison of Environmental Performance of Heating Appliance... 15 5. Major Electrical Appliances and Systems TEPCO is Recommending... 151 <Reference> Increase of Heat Storage Air Conditioning Systems (cumulative)... 155 XIII. Related Businesses 1. Affiliated Companies... 156 2. New Businesses... 162 <Reference> Outline of TEPCO Gas Business... 163 XIV. Other Data 1. Energy Dependency of Major Countries (27)... 164 2. Composition of Primary Energy Sources in Major Countries (27)... 164 <Reference> Japan's Energy SelfSufficiency Rate... 165 <Reference> SelfSufficiency Rate by Energy Source (27)... 165 <Reference> Import and Export of Electricity Related to France (27)... 165 3. Japan Energy Supply and Demand Outlook... 166 (1) Final Energy Consumption... 166 (2) Primary Energy Supply... 166 4. Long Term Supply and Demand Outlook for Electric Power... 167 (1) End of Fiscal Year Equipment Capacity (electric companies)... 167 (2) Power Generation (electric companies)... 167 5. Security Index of Various Countries (27)... 168 6. Changes in Japan's Crude Oil Imports and Security Index... 168 7. Power Generation Costs for Each Power Source... 169 <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... 169 vi

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

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: 26.42 million 93.67 GW For power: 2.19 million 15.2 GW Total: 28.62 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: 16 8.987 GW Thermal: 25 38.189 GW Oil 1.83 GW Coal 1.6 GW LN(P)G 25.759 GW Nuclear: 3 17.38 GW New Energy, etc. 2.4 GW Total: 19 64.487 GW Number of employees: 38,227 (as of the end of March 21) 2

(2) Business Scale Developments Capital Stock (billion yen) At the End of FY 1951 1955 1965 1975 1985 1995 24 25 26 27 28 29 1.4 13.1 12. 4.9 65. 676.4 676.4 676.4 676.4 676.4 676.4 676.4 9.4 85.7286.4464.3483.1483.1483.1483.1483.1483.1 483.1 Total of 1 EP Co. 29 2,655.9 Revenue from Electricity Sales (billion yen) 25.8 57.6 274.7 1,249.6 4,32.3 4,9.6 4,637.2 4,682. 4,74.6 4,914.7 5,295.9 4,54.5 2.2 1.6 48.4156.3189.9179.7181.5182.319.525.3 174.6 13,749.6 Capital Investment (billion yen) 8.6 28.5 124.6 383.2 1,14.3 1,399.2 464.2 55. 496.3 568.8 59.2 592.1 3.3 14.5 44.6127.9162.7 54. 58.7 57.7 66.1 68.6 68.8 2,34.4 Utility Fixed Assets (billion yen) 77. 165.3 643.4 1,778.8 6,36.4 9,654.5 9,31.9 9,154.9 8,77.5 8,416. 8,159.5 7,871.7 2.1 8.4 23.1 82.6125.412.9 (118.9) (113.9) (19.3) (16.) (12.2) 24,773.6 Electricity Sales (TWh) 7.3 1.9 41. 12.2 165.3 254.4 286.7 288.7 287.6 297.4 289. 28.2 1.5 5.6 14. 22.6 34.8 39.3 39.5 39.4 4.7 39.6 38.4 858.5 Generation Capacity (GW) 1.82 2.44 8.1 24.59 37.59 51.21 62.82 61.84 61.83 62.47 63.98 64.49 1.3 4.5 13.5 2.7 28.1 34.5 34. 34. 34.3 35.2 35.4 23.96 Number of Customers (million) 3.97 4.52 8.22 15.5 19.95 24.83 27.74 27.8 28.9 28.34 28.51 28.62 1.1 2.1 3.8 5. 6.3 6.9 7. 7.1 7.1 7.2 7.2 83.51 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 38,227 1. 1.1 1.3 1.3 1.5 1.3 1.3 1.3 1.3 1.3 1.3 125,42 Notes: 1. Numerical data (Revenue from electricity sales and Electricity sales) for FY 1951 include those of Kanto Haiden Kabushiki Kaisha for April 1951. 2. 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

(3) Business Scale by Area (as of the end of FY 29) 6,413 2.2 1.31 17. 3.12 8.5 3 2.26 2.26 6,393 2.6 1.33 15.9 3.1 7.16 4 2.438 2.438 6,117 3.3 1.94 25.4 4.29 7.3 4 5.4 5.4 3,79 7.16 4.23 37.9 7.48 7.16 6 5,135 2,445 4,323 6.24 9.7.85 3.87 5.37.66 37. 5.2 6.2 6.49 9.21 1.18 7.3 8.9 7.16 5 7 2.46 1.54 16.5 1.249 16.5 1.295 1.54 2,631 2,263 1.23 12.92.86 9.5 1.6 8. 1.85 16.16 8.4 7.3 3 11.18 2.24.4.18 2.243 3.224 3.8 17.38 24.332 39,51 44.57 28.62 (1) (35) 28.2 54.5 * 7.3 45 8.987 38.189 17.38.4 64.487 (33) (34) (26) (31) (37) (1) (32) 377,947 127.48 83.51 858.5 159.13 8.7 34.898 122.345 46.23.487 23.96 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, 21. 9. The nationwide population figure is as of January 1, 21. (Source: Ministry of Internal Affairs and Communications, "Monthly Report on Current Population Estimates") 4

(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$1 = 93.57 yen; 1 euro = 13.19 yen; UK 1 = 146.26 yen; Canada 1$ = 82.12 yen (Cabinet office 'foreign economic data', 29 values). Sweden 1 krona = 12.24 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

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

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

3. Organization Chart 8

(As of July 1, 21) 9

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) 25 2 15 (GDP) 1 Electricity sales Peak demand 5 FY 1952=1 GDP '52 '55 '6 '65 '7 '75 '8 '85 '9 '958 9 1 ' '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

(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

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 5.. 5. Contracted power 1. 15. 2. 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.1.8.7 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 Q4 2.3.8 3.1 3.1.4 3.5 2.8. 2.8.9 1..1 1.4 1.5 2.9 2.9 1.2 4.1 3.5 1.2 4.7 2.8.9 3.7 1.6 1.3.3.1 1.4 1.5 2.2 1.4 3.6 1. 1.2 2.2 5.3.8 6.1 1.5 1. 2.5.4.9.5.4 1. 1.4 1.1.5.6 1..3 1.3.1.1.2.5.3.8.6.3.3 1.3 1.7.4 1.5 2..5 3. 2.2.8 1.8 2.1.3 1.3 1.1.2 1.8 1..8 Q 1 Q2 Q4 Q1 Q2 Q3 Q4.4 1.3 1.7.3 1.1 1.4 6.3 1.1 7.4 18.5.3 18.8 15. 3.1 11.9 11.3 3.6 7.7 4.4 3.8.6 1.6 3.6 14.2 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

(5) Electrification Rate (primary energy supply base) [Electrification rate (%)] (1 15 J) Gross primary energy supply 25, Energy input for electric power generation 45 41.5 41.2 4.9 41.5 41.5 42.4 42.6 43.7 43.8 Electrification rate (%) 4 2, 4.1 32.6 36.7 22,1 22,761 22,473 22,352 22,888 22,751 22,699 22,813 21,552 35 15, 29.2 27.5 19,657 3 25.8 16,627 16,967 25 15,33 1, 13,383 9,4 9,441 9,317 9,22 9,51 9,65 9,678 9,969 9,441 2 7,88 15 6,232 5,416 5, 7,71 4,473 3,455 1 1,943 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

2. Electricity Sales (1) Changes in Electricity Sales and Number of Customers (FY 25 29) TWh FY 25 26 27 28 29 3 288.7 287.6 297.4 289. 28.2 Electricity Sales Other than Specified Scale Demand Total Lighting Power Total SpecifiedScale Demand 95.2 13.5 18. 288.7 93.2 12.6 181.8 287.6 97.6 12.8 187. 297.4 96.1 11.9 181. 289. 96.1 11.4 172.7 28.2 25 2 15 18. 181.8 187. 181. 172.7 SpecifiedScale Demand Number of Customers Lighting Total Power Total Lighting and Power Total 25.43 2.36 27.8 25.76 2.32 28.9 26.5 2.28 28.34 26.27 2.24 28.51 26.42 2.19 28.62 1 5 13.5 95.2 12.6 93.2 12.8 97.6 11.9 96.1 11.4 96.1 Power Total Lighting Composition Ratio Residential Purposes Industrial Purposes 7 3 7 3 7 3 71 29 73 27 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

(2) Changes in Electricity Sales and Number of Customers (FY 2 24) FY 2 21 22 23 24 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

(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

TWh) 17

(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

(5) Residential Customer Power Demand Changes in Energy Consumption and Contract Power per Household (Monthly average in TEPCO's service area) (kwh) 3 28.4 286.7 294.7 287.5 284.3 28.4 297.5 288.9 297.1 282.3 31.8 297. 298.3 288.2 286.4 282.7 25 2 171.3 254.6 259.6 27.8 259.5 28.45 (Ampere) 34.13 34.48 33.63 33.7 32.38 34.32 34.6 32.1 32.75 33.36 33.9 31.15 31.61 29.91 29.17 3.58 35 3 15 27.5 25 21.28 2 1 99.1 16.35 15 1 5 48.8 6.3 5 '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

3. Peak Demand (1) Changes in Peak Demand (daily peak at generation end) Note: Peak demand has shifted from winter to summer since FY 1969. in the above table indicates the highest figure historically. 2

<Reference> Recent Changes in Peak Demand (GW) 7 6 5 <Jul.24> 51.9 <Aug.23> 49.3 2.6 <Sep.4> 54.1 <Aug.24> 2.2 3.9 5.2 <Jul.18> <Aug.25> 59.4 <Aug.4> 58.65.75 57.6 1.5 7.4 3.5 <Jul.4> 57.96 1.44 <Jul.3> 59.2 1.24 <Sep.1> 59.25.5 <Aug.3> 59.24.1 <Jul. 24> <Aug.1> 64.3 63.2 1.1 <Jul. 2> <Aug.5> <Aug. 22> <Aug. 8> 5.6 5.84 <Jul. 14> 61.5 6.12 61.47 6.89 58.6 <Sep.11> 3.41.58 4.14 1.38 57.36 2.6 <Jul. 3> 54.49 6.39 43.7 1.68 5.6 4 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

<Reference> Peak Demand in Major Countries (GW) 8 789.48 7 6 5 4 3 2 182.69 1 64.3 TEPCO 92.77 89. 78.5 61.53 56.82 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

(2) Trend of Monthly Peak Demand (daily peak at generation end) (GW) 7 6 5 4 3 FY 1988 2 FY 1978 1 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 1969. 23

(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) 1 2 3 4 5 6 7 8 9 1 11 12 13 14 15 16 17 18 19 2 21 22 23 24 (o'clock) 24

(4) Peak Demand and Annual Load Factor (GW) () 7 (Planned) 6 5 57.12 55.99 56.6 56.88 56.63 57.2 51.66 5.5 47.85 48.8 61.43 6.53 59.16 58.96 58.91 57.45 57.83 55.31 55.27 52.54 (Actual) 56.65 61.5 42.45 Peak Demand 4 3 2 1 32.38 29.56 27.38 29.52 24.8 27.43 27.28 24.81 21.33 2.41 22.1 58.3 58.2 57.1 57.3 56.6 56.6 56.2 55.5 55.5 35.34 36.13 33.95 56.6 55.9 55.9 56.4 56.4 38.55 4.53 57.2 56.8 58.2 55.6 Peak Demand Annual Load Factor 55. 57.5 56.6 53.9 53.8 54.3 53.8 58.3 56.9 57.5 53.8 62.5 64.1 (Actual) 59.8 6.2 6.6 6.4 59. 58.2 56.2 (Planned) 62.8 66 64 62 6 58 56 54 52 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

(5) Estimated Ratio of Air Conditioning and Other Summer Demands During Peak Load (at transmission end) (GW) 7 6 5 4 61.43 6.53 55.99 56.88 57.12 56.63 56.6 57.2 57.83 5.5 39 38 39 33 37 35 36 35 4 42.45 38 38.55 59.16 58.96 58.91 57.45 56.65 55.31 55.27 52.54 37 31 35 35 36 33 31 35 61.5 34 3 2 35.34 32.38 29.56 34 27.43 34 24.71 34 22.1 31 32 32 14.82 2 37 34 1 '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

MEMO 27

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

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

(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 21. 3. 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

(3) Generation Capacity by Energy Source a. TEPCO (a) Generation Capacity by Energy Source (TEPCO only) 1.82GW 2.44 8.1 19.42 24.59 37.59 51.21 57.85 58.84 6.38 6.38 62.66 62.82 61.84 61.83 62.47 63.98 2% (.36) 8% (1.46) End of FY1951 33 (.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 '9 64.49 65. 71.3 27 (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 21. 3. 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 1996. 5. 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 24.21 29.43 45.55 61.95 69.28 7.36 71.5 72.37 75.29 75.61 74.59 74.93 75.63 76.76 35% (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 21. 3. 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 1996. 6. 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). 77.69 23 (18.19) 6(4.77) 16 (12.1) 2(1.61) 34 (26.46) () 19 (14.64) 78.11 23 (18.19) 6(4.77) 15 (11.95) 2(1.61) 35 (26.94) () 19 (14.65) 84.6 27 (22.8) 8(6.4) 14 (11.95) 2(1.31) 31 (26.97) (5) 18 (15.12) Hydro 31

<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 ) 3 6 9 12 15 18 21 24 (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

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) 11.58 34 (3.98) 1 (.11) 65 (7.49) 79.91 35.89GW 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) 3.38 36 (1.95) 27 (8.15) 2 (.5) 35 (1.78) 8.56 8 (6.8) 4 (2.89) 62 (5.26) (1) 6 (4.93) 2 (16.38) 128.58 18 (22.9) 4 (4.69) 36 (46.66) (17) 23 (3.5) 19 (24.13) 195.62 22 (42.3) 24 (46.7) (48) 29 (56.8) (51) 17 (33.77) 197. 22 (43.13) 9 (17.28) 22 (43.45) (48) 3 (58.41) (51) 17 (33.75) 198.7 22 (43.13) 1 (18.98) 22 (42.8) (48) 29 (58.41) (51) 17 (33.77) 198.21 22 (43.13) 1 (2.57) 21 (4.4) (48) 3 (59.5) (35) 17 (33.77) 2.42 21.8 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 1985. 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). Generation Capacity by Energy Source (1 electric power companies: including purchased power) 94.82 7(6.6) 5(4.87) 55 (52.4) (2) 8(7.25) 25 (23.67) 66.66 3(1.76) 5 (3.33) 67 (44.62) (1) 4 (2.73) 21 (14.21) 149.21 17 (24.52) 7(9.94) 32 (48.31) (18) 22 (33.19) 22 (33.6) 21.34 2 (41.19) 1 (2.14) 25 (49.53) (49) 24 (47.83) (16) 21 (41.99) 173.76 22 (38.41) 6 (1.79) 28 (48.1) (46) 26 (44.27) (16) 18 (31.68) 224.1 2 (44.92) 11 (24.88) 22 (48.6) (52) 27 (6.35) (51) 2 (44.33) 193.42 22 (42.3) 8 (14.5) 24 (46.56) (48) 29 (56.21) (51) 17 (33.32) 229.13 2 (44.92) 13 (29.22) 21 (48.39) (52) 26 (6.8) (51) 2 (44.78) 8 (15.7) 23.3 2 (45.74) 13 (3.5) 2 (45.79) (52) 27 (62.38) (51) 2 (44.86) 233.47 2 (45.74) 14 (33.77) 2 (45.16) (52) 27 (62.87) (51) 19 (44.9) 234.72 19 (45.74) 15 (35.75) 19 (43.19) (52) 27 (63.97) (35) 2 (45.2) 237.55 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) 238.87 21 (49.58) 16 (37.67) 18 (43.42) (52) 26 (61.94) () 19 (45.74) 21.33 23 (46.85) 11 (22.33) 2 (38.93) (49) 29 (58.44) () 17 (34.29) 238.43 21 (49.47) 16 (37.36) 18 (42.6) (52) 26 (63.26) () 19 (45.76) 2.86 23 (46.85) 11 (21.98) 21 (41.16) (49) 28 (55.79) () 17 (34.58) 238.3 21 (49.47) 16 (37.47) 19 (44.9) (52) 25 (6.44) () 19 (46.4) 22.18 23.96 22 (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) 238.9 241.47 2 (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 1985. 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). 33

c. Power Source Shares by Country Japan 572.5 Energy Source Power Output Composition by Country (Part 1) 198 1,123.5 Others.9.2% Hydro74.6.6% 27 Others28.72.6% (Unit: TWh) Hydro 88.3 15.4% Nuclear 82.6 14.4% Gas 81.1 14.2% Coal 5. 8.7% Oil 269.6 47.1% Nuclear 263.8 23.5% Gas 289.9 25.7% Coal 31.8 27.7% Oil 156.3 13.9% France 256.9 Hydro 69.1 26.9% Others1.2.5% Coal 69.9 27.2% 564.4 Others1.11.8% Hydro 58.2 1.3% Coal28.25.% Oil6.21.1% Gas22. 3.9% Nuclear 61.3 23.8% Oil 48.4 18.9% Nuclear 439.7 77.9% U.S.A. 2,427.3 Others5.8.2% Gas7.2.7% 4,322.9 Hydro249.65.8% Others124.92.9% Nuclear 266.2 11.% Hydro 278.8 11.5% Gas 37.4 15.3% Oil 263.2 1.8% Coal 1,242.9 51.2% Nuclear 836.6 19.4% Gas 915.2 21.2% Coal 2,118.5 49.% U.K. 284.1 Hydro 4. 1.4% Oil78.11.8% 392.3 Hydro5.11.3% Others16.74.3% Gas2.1.7% Nuclear 37. 13.% Oil 33.1 11.7% Coal 27.9 73.2% Nuclear 63. 16.1% Gas 164.5 41.9% Coal 138.3 35.3% Oil4.71.2% Source: IEA, "Energy Balances of OECD Countries 29 edition" 34

Germany 367.5 Energy Source Power Output Composition by Country (Part 2) Hydro 17.44.7% 198 Others5.41.5% 629.6 Hydro 2.9 3.3% 27 Others73.611.7% (Unit: TWh) Nuclear 43.7 11.9% Gas 61.1 16.6% Coal 214.2 58.3% Nuclear 14.5 22.3% Coal 31.6 49.3% Oil 25.77.% Gas 72.9 11.6% Italy 183.5 38.2 Oil 11.1 1.8% Nuclear 2.2 1.2% Others4.2.2% Gas9.2 5.% Hydro 45.2 24.7% Coal 18.3 9.9% Oil 14.6 57.% Hydro 32.8 1.6% Gas 172.7 56.% Others17.65.7% Coal 49.7 16.1% Oil 35.4 11.5% Australia 95.2 254.6 Others.4.4% Hydro 14.4 5.7% Others4.71.8% Gas7. Oil5.2 7.3% 5.4% Hydro 12.9 13.6% Coal 69.7 73.3% Oil 2.2.9% Gas 39.2 15.4% Coal 194.2 76.3% Canada 373.3 639.7 Others1.3.3% Others11.51.8% Coal 59.8 16.% Oil 13.8 3.7% Gas9.22.5% Coal 115.8 18.1% Oil9.91.5% Gas4.76.4% Hydro 251.2 67.3% Nuclear38.1.2% Hydro 368.4 57.6% Nuclear 93.5 14.6% Note: Germany : Figures given for 198 are for the former West Germany Source: IEA, "Energy Balances of OECD Countries 29 edition" 35

d. Development Status of Overseas Business [Major Overseas Investment Activities (Power Generation)] Countries and Regions Taiwan q Chang Bin, Fong Der and Star Buck Project Vietnam Phu My 22 Project 715MW Australia e Loy Yang A Project 2,2MW U.A.E. r Umm Al Nar Power and Water Project 2,2MW Indonesia Philippines U.S.A., Europe, Asia t Paiton I Project Projects etc. y TeaM Energy Project u Eurus Energy Chang Bin 49MW, Fong Der 98MW Star Buck 49MW 1,23MW (Paiton II 815MW, under construction) 3,24MW Installed Capacity 1,93MW (wind power generation etc.) Notes: 1. As of the end of March 21. 2. Installed Capacity means the sum of power output of power generating facilities. Changes in Total Generation Capacity of Overseas Projects MW 4, 3,5 3, 2,5 2, 1,5 1, 5 86 1,75 1,96 2,7 3,32 3,48 3,53 23 24 25 26 27 28 29 FY Notes: 1. Figures include that of Eurus Energy Holdings. 2. The sum of the power output of each power generation company multiplied by TEPCO's shareholding ratio in the respective company. 3. As of the end of March of every fiscal year. 36

[Recent Major Overseas Consulting Services] * Consulting services shown here are selected from those already conducted and those underway Countries and Regions Projects etc. Ordering Parties/ Companies Supported by TEPCO, etc. China q UHV Transmission System Design STATE GRID CORPORATION of CHINA Philippines w Renewable Energy Development Department of Energy (JICA) Singapole e Power Facilities Maintenance in Power Grid Singapore Power Grid U.A.E. r The Master Plan Study of Transmission Abu Dhabi Transmission & Dispatch System Company (TRANSCO) Saudi Arabia t The Master Plan Study for Energy Conservation Ministry of Water and Electricity (JICA) Zambia y Rural Electrification Master Plan Study Ministry of Energy and Water Development (JICA) Denmark u Study on the 4kV Cable Line Energinet.dk U.S.A. i Study on ABWR Design and Construction South Texas Power Nuclear Operating Company Jamaica & Bahamas o Study on Power Transmission and Jamaica Public Service Company Limited (JPS), Distribution Facilities Grand Bahama Power Company (GBPC) Fiji! Renewable Energy Power Development Department of Energy (JBIC) Turkey Bangladesh The Study on Optimal Power Generation For Peak Demand in Turkey The Study for Master Plan on Coal Power Development in the People's Republic of Bangladesh JICA JICA Changes in Order Volume and Award Volume of Overseas Consulting Services (billion yen) 2.5 2. 1.5 1..5.24 (4) '96.3 (2) '97.17 (8).24 (7).4 (16).53 (18) 1. (35) '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 ODA, development finance Organization, etc. 1.35 (4) Electric power company, private business, IPP, etc. * Figures in parentheses are number of cases. 1.71 (45) 1.34 (48) 1.28 (37) 1.97 (49) 1.83 (46) 1.81 (41) (FY) 37

i N uclear Power (ur a nium ) Hydroelectric Power T his is renewable energ y, and the reserves of the resource are vast. However, there are limits t o the available volume in a year. A bout 6 3* years of harvestable reserves. The resource has not been much developed, so further re serves are expected to be f ound. The time frame will ex pand as the nuclear fuel cycle is established. W idely existin g throughout the world. The weight is heavy in Cana da, Australia, other industrial ized nations, and the supply is stable. U ranium is 1% dep e ndent from on import ; purchasing politicallystable countries uch as Canada and Australia, e tc. under long ter m agree ments. The uranium used for electric p ower station for 2 to 3 years i s stocked including that is un der the processes such as concentration and molding and that is stored in electric power s tation as completed fuel as semblies. s C ompared to othe r power s ources, however, pumped s torage hydropower is excel l ent for keeping up with sys tem load and an appropriate a mount will be develope d fo r p roviding peak power. < Reference> Characteristics of Each Energy Sourc e (i) Supply Stability Items Evaluated 1.Resource Reserves Amount of resource is rel a tively small, with 46* years h arvestable reserv es. O il Coa l Natural Gas of Approximately 57% of total is concentrated in the Middle East. 1 19* years of harvestable r e serves, which is the biggest a mong the fosil fue ls. Widely existing throughout th e world. 6 3* years of harvestable r e serves. Exploration for new deposits is not as advanced as oil. Exploration for and development of nontraditional natural gas resources such as shale gas resources has been attracting attention in recent years, and the amounts of exploitable resources could increase in the future. Approximately 7% is n the former Soviet Union and Middle East, so the regional distri bu tion is somewhat overconcen trated, though not as bad as oil. 2. Supply In the future, the world coul d become more dependent on the Middle East and there c ould be more risk of instabili ty because production in other p laces will reach its limit. Major producing countries are China, U.S.A., Australia, India, Indonesia, etc. Supply is stable. Over 4% is produced in U.S.A. and the former Soviet Union. Shale gas production has been increasing in U.S.A., and the production of nontraditional natural gases could increase in the future. 3. Supply Japan Stability of supply will increase when the nuclear fuel cycle is established. This is domestically produced energy, but is affected by nature to some degree. to Japan depends on imports n early 1% of its supply. J apan depends on the Midd l East for about 9% of its crude oil imports. for e Imported in the form of LNG. Dependence on Southeast Asian countries and Australia is high, with imports from them accounting for 66% of the total. Japan gets about 65% of it s imports from Australia, but im ports from regions around the world. Stable because the main s tream is long term agree ments, but this obliges con tracting companies to take contracted amount. *Sources: "BP Statistics (21) " OECD NEA & IAEA, "Uranium 27," etc. 38

i i j i N uclear Power Hydroelectric Power P resently, LNG p rices are linked to crude oil prices. Prices are on a rising trend n the mediumand longterm because the demand is in c reasing on a global scale. W ith the global acti vation of n uclear energy development, t he demand of uranium in c reased and the pr ice was on t he upward trend f or several y e ars. However, the demand and price of uranium have re m ained stable recently. However, the ratio of fuel cos t is low, and the effect of fluctu a tion of uranium pr ice against g enerating cost is relatively small. Natural energy and creates n o price fluctuation problems. I t is a little more expensive than other power sources. Operating costs are low, an d long term costs ar e highly sta ble. (ii) Construction cost is high, but the power generation cost is comparable to the power generation costs for other power sources, because operation costs including the fuel cost are low. Economic Considerations 1. Items Ev aluate d Price Stability O il C oa l Natural Gas Prices are on a rising trend n the medium and longterm, b ecause the demand s rising due to economic growth in India and China, and there is little spare supply capacity in t he oilproducing nations. I n addition, the price range flucturates more widely, be c ause the situation in the Mid d le East is unstable and spec ulative money is flowing into a nd out of the oil mark et. Prices are inexpensive an d compared sources. T he implementatio n of new technology is expected to im p rove usage efficiency, and ad va nces in distribution arrange m ents should reduce costs. 2. Implementation and Costs Usage There is no particular problem with using existing infr astruc ture, facilities, etc. s table compared to other ma or energy sources, but they h ave been rising in the medi umand longterm because of economic growth and increas i ng demand in China and In dia. Even so, the costcom petitiveness still remains to other energy Because it is imported a s L NG, liquefaction facilities, special ships and receiving fa c ilities are necessa ry, which makes initial costs high. 39

N uclear Power Hydroelectric Power P roduces no air pol lutants. P roduces no air pol lutants. N o C O2 emissions during pow er generation. N o C O2 e missions during p o w er generation. ife cycle C O L 2.22kgCO 2 /kw h emissions L 2 ife cycle C O.11kgCO 2 /kw h emissions Radioactive waste is process ed ately. and disposed appropriof C onsideration is gi v natural environment, scenery. en to the including (iii) Environmental Considerations 1. Items Ev aluate d Air Pollution O il C oa l Natural Gas C ombustion causes SOx, N Ox and soot emissions. Countermeasures being take n such as using low sulphur heavy crude oil, denitration and precipitation equipment. C ombustion causes SOx, N Ox and soot emissions. Countermeasures being take n i nclude using desulphuriza tion, denitration and pr ecipita tion equipment. Combustion does not caus e emissions of SOx or soot, and emissions of NOx are small compared to coal and oil. 2. Global Warming* C O2 e missions during p o wer g eneration (sending end) ar e.74kgco 2 /kwh (or a value o f.794 when the value f or coal is set at 1) C O2 e missions during p o g eneration (sending end).887kgco 2 /kw h wer ar e C O2 e missions during p o w er g eneration (sendin g end) are.478kgco 2 /kwh (or a value of.539 when the value for coal is set at 1) ife cycle C O L 2.742kgCO 2 /kw h emissions are ife cycle C O L 2.975kgCO 2 /kw h emissions are ife cycle C O L 2.68kgCO 2 /kw h emissions are Remarks Pow er generation efficiency is high. Integrated Gasification C ombined Cycle (IGCC) tech n ology is being de v e loped to h elp suppress CO 2 emissions. C O2 e mission reduction e f fo rts by improving thermal ef f iciency of thermal po wer generation are underway, such as implementing 1,5 C class combined c y cle (MACC) power generating equipment. *Source: "Report of Central Research Institute of Electric Power Industry" 4

<Reference> FuelRelated Conversion Formulas Oil 1 barrel = 159 liters 1 kiloliter = 6.29 barrels 1 barrel per day = 58 kiloliters per year Calorie Equivalence (based on TEPCO's actual data) Crude oil 1.4 kr LNG.75 tons Heavy oil 1 kr Coal 1.52 tons Unit Calorie (Calorific Value) of Fuels Heavy oil: 1 liter = 4,87 kj (9,76 kcal) Crude oil: 1 liter = 39,34 kj Coal: 1 kg = 26,89 kj <imported steam coal> LNG: 1 kg = 54,56 kj City gas: 1 m 3 = 43,7 kj Comparison of Various Fuels Required to Operate 1 GW Scale Power Plant LNG: Approx. 1 million ton (per year) Heavy oil: Approx. 1.4 million kl (per year) C oal: Approx. 2 million tons (per year) Nuclear power (nuclear fuel): 21 tons (per year) Notes: 1. LNG, heavy oil and coal are those used for the operation of thermal power plants and nuclear power (nuclear fuel) is that used for the operation of nuclear power plants. 2. Calculation is based on the assumption that the capacity factor of LNG, heavy oil and coal is 7% and that of nuclear power (nuclear fuel) is 8%. 41

(4) Major Power Generation Facilities a. Hydroelectric Power (with a capacity of more than 5MW) (as of the end of March 21) 42

b. Thermal Power (as of the end of March 21) 43

c. Nuclear Power (as of the end of March 21) d. New Energy (as of the end of March 21) 44

(5) Electricity Generated and Purchased (Unit: TWh) FY 197 1975 198 1985 199 1995 1998 1999 2 21 22 23 24 25 26 27 28 29 Notes: 1. Figures in parentheses represent the percentage composition of TEPCO's own power output. 2. The sum total of numerical values given in the columns may not agree with the figures given in the total column because fractions are rounded off. 3. Figures for thermal power include geothermal power. 4. Figures for wind power generation were obtained from the Hachijojima Wind Power Generation Plant. (5 kw. Operation started on March 31, 2.) 45

(6) Changes in Power Output Composition by Energy Sources (including purchased power) a. TEPCO (%) 1 3 3.7 8 7 3 22 34 34 4 44 42 44 33 17 33 34 38 23 23 28 (83.7) 29 48 Nuclear 6 4 73 28 2 32 31 31 34 36 37 4 48 39 38 38 44 45 45 (134.8) 4 27 LNG LPG 2 1 13 '73 35 1 12 '8 3 21 1 9 '85 2 24 1 8 '9 5 16 1 7 '95 4 1 1 7 4 1 1 7 4 7 1 7 5 14 1 7 7 2 1 7 9 12 1 6 8 13 1 6 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 '1 '19 (FY) (Planned)(Planned) 8 9 9 17 1 1 6 6 9 12 (34.1) 16 9 (27.7) 1 1(3.4) (1.4) 6 5 (15.6) 11 13 1 6 11 5 1 1 7 Geothermal (199828) Coal Oil Other Gases New Energy etc. 1 Hydro Notes: 1. The planned values are based on the management plan for FY 21. 2. Purchased power by bid, which is already decided for the years 21 and 219, is divided into each energy source. 3. Figures in parentheses for FY 29 are electricity generated (TWh). 4. The figures for new energy etc. consist of wind, solar and waste power generation before FY 28. The figures added geothermal and biomass power generation after FY 29. 46

b. 1 Electric Power Companies (%) 1 3 2 956.5 5 17 8 16 27 27 34 34 34 35 31 26 29 31 31 26 26 29 (279.8) Nuclear 6 71 4 23 23 23 27 27 27 27 28 26 24 26 27 29 3 (282.4) LNG LPG 4 2 2 17 43 2 18 1 24 2 14 1 27 1 12 14 18 1 1 17 11 1 1 19 9 1 1 21 6 1 1 22 9 2 9 '73 '8 '85 '9 '95 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 (FY) 24 1 1 1 1 25 8 1 1 1 26 9 1 1 8 24 8 9 25 12 8 25 1 1 1 1 1 1 1 8 25 (237.9) () 6 (58.) 1(8.6) 1(1.5) 8 (79.3) Coal Others (Bitumious Coal Mixture Geothermal) Oil Other Gases New Energy etc. Hydro Notes: 1. Figures in parentheses are electricity generated (TWh). 2. Totals 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 are given for a total of 9 power companies (except Okinawa Power Company) before 1985. 4. The figures for new energy etc. consist of wind, solar and waste power generation before FY 28. The figures added geothermal and biomass power generation in FY 29. 47

(7) Electric Power Development Program a. Major Electric Power Development Projects Project Name Output (MW) (as of the end of May 21) Month/Year Operations Began Fukushima Daiichi Units No. 7 and No. 8 1,38 each Oct. 216, Oct. 217 Nuclear Higashidori Units No. 1 and No. 2 1,385 each Mar. 217, FY 22 or later Coal Hitachinaka Units No. 2 Hirono Unit No. 6 1, 6 Dec. 213 Dec. 213 LNG Futtsu No. 4 group Kawasaki No. 2 group 1,52 1,92 Jul. 28, Nov. 29, Oct. 21 Feb. 213, 216, 217 Hydro (Pumped Storage) Kazunogawa Kannagawa 1,6 2,82 Dec. 1999, Jun. 2, FY 22 or later Dec. 25, Jul. 212, FY 22 or later Renewable Energies Ukishima Solar Power Plant Ohgishima Solar Power Plant Aug. 211 Dec. 211 Komekurayama Solar Power Plant 1 Jan. 212 HigashiIzu Wind Power Station 18.37 Mar. 212 7 13 b. Demand Outlook FY 29 21 211 214 219 (Unit: TWh) Yearly Average Increase Rate (actual) 219/29 T otal of 1 EP Co. TEPC O Notes: 1. Based on the supply plan for FY 21. 2. Specifiedscale demand includes contracts for at least, 5kW. 3. Total demand figures may not agree with the sum of each item because of being rounded off. 48

c. Peak Demand Outlook (Unit: GW) FY 29 21 211 214 219 (actual) Yearly Average Increase Rate 219/29 TEPCO Total of 1 EP Co. Notes: 1. "Peak demand" here represents the maximum threeday average peak load at transmission end. 2. Based on the supply plan for FY 21. (8) Reserve Capacity (Unit: GW) Notes: 1. Balance of supply and demand for August. 2. Figures for FY 21 and thereafter are based on the management plan for FY 21. 49

<Reference> Summary of Power Plant Siting Procedure (example of nuclear power station) Electric power company National government Local community Selection of site Site selection Land acquisition and fishery compensation Method report Preparation report Submission Recommendation Submission Recommendation inspection Environmental First disclosure hearings Application for designation as major electric power development site Consultation with concerned government agencies for major power sources Resident opinions Governor's opinion Assessment report Submission Designation notice/change order Designation by METI Minister as major electric power development site Operation Construction Preparation for construction Application for authorization to build nuclear reactor Application for making changes in electric structure Application for construction plan authorization Construction starts Application for safety regulation approval Operation starts Safety inspection Request for advice Atomic Energy Nuclear Safety Commission Commission Report Authorization to build nuclear reactor Construction plan authorization Fuel inspection Welding safety control inspection Preoperation inspection Safety regulation approval *1 *2 Periodical inspection *3 Second disclosure hearings Consent of MEXT Minister Resident opinions supplier. power * 1 For an electricity power station other than nuclear plant, its construction plan is presented from an electric * 2 For power plant other than nuclear, preoperation safety control inspection is required. * 3 For power plant other than nuclear, periodical safety control inspection is required. * 4 5

(9) Wide Area Coordination System Operation a. Purpose Implement facility development and business operation efficiently through mutual corporation of electric power companies. b. Recent Situations ide area development Tohoku Electric Power's Higashidori Power Plant Unit 1 (1,1 MW), in which TEPCO participated, began operation on December 8, 25. Interservice area power exchange TEPCO continues to exchange power with Tohoku and Hokuriku electric power companies. area connection 5 Hz Operation of the Soma Futaba Trunk Line began in June 1995 to link the Tohoku and Tokyo regions at 5 kv. 6 Hz Part of the frequency conversion facility at Chubu Electric Power's HigashiShimizu Frequency Conversion Station began operation in March 26. <Reference> Classification of Power Exchange Nationwide exchange (among 9 EP Co.) Power exchange for resource shortage Power exchange for mutual benefit or oversupply Power to be exchanged to make up for shortages by the request of receiving company. Power to be exchanged to achieve reasonable operations of electric power facilities and equipments by taking advantage of differences between power sending and receiving companies in terms of demand time period, supply capacity composition, or power to be exchanged to make effective use of surplus power of a sending company. Bilateral exchange Power exchange for system operation Power exchange for maintenance work and testing Power to be exchanged to make effective use of electric power facilities near the neighboring company's service area (to be supplied in the same quantity at the same time in principle). Power to be exchanged for maintenance works and testings of network facilities. Specified power exchange Power to be exchanged for specific power generating facilities or for customers in specific area, and power to be exchanged according to longterm schedule for widearea coordination. 51

c. History of Wide Area Coordination System Operation at TEPCO 52

d. Current Situation of Interconnection for WideArea Operation Hokkaido DC25kV Tohoku Hokuriku Kyushu 5kV Chugoku 5kV 5kV 5kV 5kV Kansai 5kV FC 3MW Chubu Shin Shinano FC 6MW Sakuma FC 3MW Higashi Shimizu FC max. 1MW SomaFutaba Trunk Line 5kV Tokyo Shikoku DC25kV Regional Interconnection AC/DC Converter DC Transmission Line FC : Frequency Conversion Station 53

(1) Summary of Bid System for Wholesale Supply of Electric Power a. Screening Results FY 1996 FY 1997 FY 1999 Invitation for Bids Bids Successful Bids 1,MW 3,86MW (31 bids) 1,1MW (8 companies) 1,MW 5,86MW (3 bids) 1,8MW (4 companies) 1,MW 2,51MW (11 bids) 1,MW (5 companies) b. List of Successful Bidders q Successful Bidders for FY 1996 (Chronological order) (Total of maximum contracted capacity: 1,12.2 MW) The project was cancelled due to General Sekiyu K.K.'s reasons. w Successful Bidders for FY 1997 (Chronological order) (Total of maximum contracted capacity: 1,71.3 MW) The project was cancelled due to Shinagawa Refractories Co., Ltd.'s reasons. 54

e Successful Bidders for FY 1999 (Chronological order) (Total of maximum contracted capacity: 1,4.3 MW) The project was cancelled due to Taiheiyo Cement Corp.'s reasons. c. IPP Power Supply Procurement (procurement amount: total and by fiscal year) Note: The 55 MW project in 21, the 11 MW project in 22 and 13 MW project in 26 were canceled due to IPP reasons. 55

2. Transmission and Distribution Facilities (1) Transmission / Underground Transmission a. Transmission Facilities by Voltage (as of the end of March 21) Voltage (kv) Route Length (km) Overhead Circuit Length (km) Number of Supports (units) Route Length (km) Underground Circuit Length (km) 5 275 154 66 Below 55 Total Notes: 1. Route length refers to the total length between two points on a line. Circuit length refers to the sum of the route length of each circuit on a line. 2. Due to the Accounting Rules for Electricity Business amendment (effective from March 29, 2), distribution facilities with voltage over 2 kv have been included in transmission facilities since FY 1999. b. Underground Transmission Line Installation Rate TEPCO In Tokyo's 23 wards Total of 1 EP Co. At the End of FY Overhead Lines (km) Underground Lines (km) Underground Installation Rate (%) Overhead Lines (km) Underground Lines (km) Underground Installation Rate (%) Overhead Lines (km) Underground Lines (km) Underground Installation Rate (%) 1965 197 1975 198 1985 199 1995 2 22 23 24 25 26 27 28 29 Notes: 1. Total circuit length of underground lines Underground installation rate (%) = Total circuit length of overhead lines + Total circuit length of underground lines 1 (%) 2. Due to the Accounting Rules for Electricity Business amendment (effective from March 29, 2), distribution facilities with voltage over 2 kv have been included in transmission facilities since FY 1999. 3. Figures are given for a total of 9 power companies (except Okinawa Electric Power Company) before FY 1985. 56

<Reference> 1MV Designed Power Transmission Lines (UHV: Ultra High Voltage lines) Section Length Voltage and Number of Circuits Power Lines Pylons Start of Construction Start of Operations NishiGunma Trunk Line NishiGunma Switching Station HigashiYamanashi Substation 137.7km 1MV design 2 circuits ACSR 61mm 2, 81mm 2 8 conductors Number: 217 Height: 111m average September 1988 April 1992 MinamiNiigata Trunk Line KashiwazakiKariwa Nuclear Power Station NishiGunma Switching Station 11.8km <61.2km> 1MV design 2 circuits <a portion is 5kV> ACSR 61mm 2, 81mm 2 8 conductors <81mm 2 4 conductors> Number: 21 <114> Height: 97m <89m> average March 1989 October 1993 Note: Content in < > applies to sections designed for 5kV Section Length Voltage and Number of Circuits Power Lines Pylons Start of Construction Start of Operations HigashiGunma Trunk Line NishiGunma Switching Station HigashiGunma Substation 44.4km 1MV design 2 circuits ACSR 61mm 2, 81mm 2 8 conductors Lownoise ACSR 96mm 2 8 conductors Number: 7 Height: 115m average September 1992 Line 2: April 1999 Line 1: June 1999 195.4km 1MV design 2 circuits Number: 335 Height: 119m average November 1995 Line 2: July 1999 Line 1: October 1999 MinamiIwaki Trunk Line MinamiIwaki Switching Station HigashiGunma Substation ACSR 61mm 2, 81mm 2 8 conductors Lownoise ACSR 94mm 2, 96mm 2 8 conductors 57

(2) Substation Facilities (as of the end of FY 29) At the End of FY At the Time of TEPCO's Foundation (May 1, 1951) 1955 1965 1975 1985 1995 1999 2 21 22 23 24 25 26 27 28 29 Total of 1 EP Co. 28 Number of Locations Output (million kva) Inclusive of Those Facilities for 275KV Number of Locations Output (million kva) Notes: 1. Figures marked with asterisks (*) are those for frequency conversion equipment as expressed in MW units. (Figures in total of 1 electric power companies include connection and conversion facilities.) 2. Figures in parentheses are for facilities in Tokyo. 3. "Inclusive of those facilities for 275 kv" figures for the 1 electric power companies are calculated on the basis of 187 kv. 4. Figures for the 1 electric power companies are those for FY 28. Figures for FY 29 are being tallied. 58

(3) Distribution Facilities TEPCO 1 EP Co. a. Number of Supports and Transformers for Distribution Facilities Pylons Concrete Poles Steel Poles Wooden Poles Total (as of the end of FY 29) Transformers (piece) Note: Figures in parentheses are polemounted transformers. Source: "Statistics of Electric Power Industry" (consolidated by Federation of Electric Power Companies) At the End of FY b. Underground Distribution Line Installation Rate TEPCO In Tokyo's 23 Wards Central Tokyo (Chuo,Chiyodaand part of Minatoward) (as of the end of FY 29) Total of 1 EP Co. *1 *2 *3 *1 *2 *3 *1 *2 *3 *1 *2 *3 1965 197 1975 198 1985 199 1995 1996 1997 1998 1999 2 21 22 23 24 25 26 27 28 29 *1 = Overhead lines (km) *2 = Underground lines (km) *3 = Underground installation rate (%) Notes: 1. Total circuit length of underground lines Underground installation rate = 1 (%) Total route length of overhead lines + Total circuit length of underground lines 2. Data for central Tokyo for FY 1989 and thereafter are based on those for the entire wards of Chuo, Chiyoda and Minato. 3. In the case of TEPCO, the total length of underground cables for FY 199 and thereafter includes that of transmission cables belonging to the Distribution Dept. 4. Figures are given for a total of 9 power companies (except Okinawa Electlic Power Company) before FY 1985. 59

3. Forced Outages Note: Forced outages caused by disasters and planned construction are excluded. <Reference> SinglePhase ThreeWire Facility Installation Rate for Lighting Service (%) EP Co. Hokkaido Tohoku Tokyo Chubu Hokuriku Kansai Chugoku Shikoku Kyushu Okinawa Total of 1 EP Co. Singlephase Threewire Facility Installation Rate (as of the end of FY 29) Note: Contracts for Electric water heaters are excluded. 6

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IV. Fuels 1. Fuel Consumption (Thermal power) FY Coal (million tons) 197 1975 198 1985 199 1995 2 23 24 25 26 27 28 29 Total of 1 EP Co. 29 Heavy Oil (million kl) Crude Oil (million kl) Naphtha (million kl) NGL (million kl) LNG LPG (million ton) Natural Gas (billion Nm 3 ) City Gas (billion Nm 3 ) Total (million kl: heavy oil equivalent) Note: Saurce: Figures in parentheses represent the percentage composition. Based on unit calorific values for the fiscal years, data for each fuel are given in heavy oil equivalents. "An Overview of Power Supply and Demand," etc. 62

2. Crude Oil / Heavy Oil (1) Crude Oil Purchase and Consumption a. TEPCO's Crude Oil Purchase and Consumption (Unit: 1, kl) FY 2 21 22 23 24 25 26 27 28 29 Indonesia Brunei China Vietnam Australia Sudan Other Total Purchase Total Consumption b. Total Crude Oil Purchase and Consumption for 1 Electric Power Companies (Unit: 1, kl) FY 2 21 22 23 24 25 26 27 28 29 Indonesia Brunei Vietnam Australia Gabon China Sudan Russia Total Purchase Total Consumption Note: The figures of oil purchase by country in FY 28 and FY 29 are not disclosed. Source: "Overview of Power Supply and Demand," etc. (2) Heavy Oil Purchase and Consumption a. TEPCO's Heavy Oil Purchase and Consumption (Unit: 1, kl) FY 2 21 22 23 24 25 26 27 28 29 Purchase Consumption b. Total Heavy Oil Purchase and Consumption for 1 Electric Power Companies (Unit: 1, kl) FY 2 21 22 23 24 25 26 27 28 29 Purchase Consumption Source: "Overview of Power Supply and Demand," etc. 63

(3) Yearly Changes in Crude Oil CIF Pricing FY 1974 1975 1976 1977 1978 1979 198 1981 1982 CIF Price (US$/barrel) FY 1983 1984 1985 1986 1987 1988 1989 199 1991 CIF Price (US$/barrel) FY 1992 1993 1994 1995 1996 1997 1998 1999 2 CIF Price (US$/barrel) FY 21 22 23 24 25 26 27 28 29 CIF Price (US$/barrel) Note: CIF (Cost, Insurance and Freight) price refers to the import price including all expenses (such as freight, fares and insurance premiums) after shipment. It may well be the delivery price to Japanese ports. US$/barrel 138 <Reference> Monthly Changes in Crude Oil Pricing 135.15 13 131.62 12 121.93 12.57 11 18.2 1 11.12 12.56 9 9.84 91.2 95.43 92.88 8 81.25 79.47 78.89 7 61.1 6 61.5 61.32 5 4 56.39 67.82 66.56 71.85 72.6 67.97 64.45 6.58 59.87 58.61 55.2 76.31 72.25 71.14 67.56 69.48 57.9 6.89 65.82 73.69 54.88 45.29 43.17 44.4 73. 69.91 68. 59.36 52.27 47.42 7.18 77.68 74.76 76.54 Jan.6 Apr. Jul. Oct. Jan.7 Apr. Jul. Oct. Jan.8 Apr. Jul. Oct. Jan.9 Apr. Jul. Oct. Jan.1 Mar. Note: Final figures through December 29, preliminary figures for January to February 21. New early report values for March 21. Source: Ministry of Finance, "Trade Statistics Prices" 64

3. LNG (1) LNG Purchase and Consumption a. TEPCO's LNG Purchase and Consumption (Unit: 1, t) FY 1999 2 21 22 23 24 25 26 27 28 29 Alaska Brunei Abu Dhabi Malaysia Indonesia Australia Qatar Darwin Qalhat Sakhalin Spot Contract Total Purchase Total Consumption Note: Japan's total LNG purchase amount to approx. 66.35 million tons (in FY 29). The world's total amount of LNG traded comes to nearly 181.74 million tons (in 29). b. Total LNG Purchase and Consumption for Electric Power Suppliers (Unit:1, t) FY 1999 2 21 22 23 24 25 26 27 28 29 U.S.A. Brunei Abu Dhabi Indonesia Malaysia Australia Qatar Oman Trinidad and Tobago Nigeria Algeria Total Purchase Total Consumption Notes: Source: 1. LNG purchase and consumption results by country for ten general electric power suppliers and Tobata Cooperative Thermal Power Company, Inc. Only those that can be identified by country are listed. 2. The figures of LNG purchase by country in FY 28 and FY 29 are not disclosed. "Overview of Power Supply and Demand," etc. 65

(2) TEPCO's LNG Contract Summary (longterm contracts only) Brunei Das (U.A.E.) Satu (Malaysia) Australia Sellers Contract Quantity (for plateau year) Project Contract Period (from acceptance of the first shipment to expiration) Receiving Terminals (TEPCO) Power Stations 66

Qatar Darwin (Australia) Qalhat Sakhalin II (as of the end of April 21) Papua New Guinea Basic Agreement on Purchasing from the Following Projects Wheatstone 67

4. Coal (1) TEPCO's Coal Purchase and Consumption (Unit: 1, t) FY 22 23 24 25 26 27 28 29 Australia 441 1,762 3,213 3,258 2,964 3,498 3,54 3,384 U.S.A. 4 South Africa China 35 Canada 73 83 45 Indonesia 244 31 154 212 Russia Total Purchase 441 2,6 3,244 3,412 3,249 3,581 3,134 3,424 Total Consumption 34 1,887 3,372 3,417 3,176 3,463 3,99 3,537 (2) Total Coal Purchase and Consumption for 1 Electric Power Companies (Unit: 1, t) FY 1999 2 21 22 23 24 25 26 27 28 29 Total Purchase 3,472 34,34 39,47 4,87 43,95 48,549 5,45 5,595 53,4 52,389 46,23 Total Consumption 31,315 34,367 37,429 41,35 44,557 48,229 5,565 5,65 52,71 5,776 47,855 Source: "Electric Power Supply and Demand Summary," etc. 68

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V. Nuclear Power 1. Nuclear Power Generation (1) General Data on Nuclear Power Plants in Operation Fukushima Daiichi Nuclear Power Station Fukushima Daini Unit 1 Unit 2 Unit 3 Unit 4 Unit 5 Unit 6 Unit 1 Unit 2 * * * Notes: 1. Figures for fuels loaded indicate the weight (in tonsu) of uranium fuel in the upper row and the number (in pieces) of fuel assemblies in the lower row. 2. For Fukushima Daiichi Unit 1, the dates (*) given indicate those after a change in capacity (from 4 MW to 46 MW). 7

Nuclear Power Station KashiwazakiKariwa Nuclear Power Station Unit 3 Unit 4 Unit 1 Unit 2 Unit 3 Unit 4 Unit 5 Unit 6 Unit 7 71

(2) Nuclear Power Plant Capacity Factor Trend (%) 1 9 8 7 6 5 (Nationwide) (TEPCO) 4 3 2 1 '4 '5 '6 '7 '8 '9 FY Notes: 1. Figures decreased in FY 22 and FY 23 due to the suspension of a large number of nuclear plants for inspection and repair. 2. The capacity utilization rates do not include preoperation tests. The figures do not necessarily add up to the total shown because fractions were rounded off. Electricity generation 3. Capacity factor = 1 (%) Authorized capacity Number of calendar hours 72

(3) Nuclear Power Plant Performance Electricity generation Note: Capacity factor = 1 (%) Authorized capacity Number of calendar hours 73

(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 Fukushima Unit 1 1 2 3 37 Daiichi Unit 2 1 1 2 1 5 29 Unit 3 1 1 1 3 19 Unit 4 2 2 9 Unit 5 1 1 1 3 14 Unit 6 1 1 2 13 Subtotal 2 1 5 4 1 4 1 18 121 Fukushima Unit 1 1 1 2 13(6) Daini Unit 2 2 1 1 1 5 9 Unit 3 1 1 8 Unit 4 1 1 1 1 4 6 Subtotal 2 2 1 1 1 2 1 1 1 12 36(6) Kashiwazaki Unit 1 1 2 1* 4 7 Kariwa Unit 2 1 1 4 Unit 3 1 1 2 Unit 4 2 2 4 Unit 5 1 1 2 3 Unit 6 1 1 2 1 5 7(2) Unit 7 2(1) Subtotal 4 2 3 1 4 1 15 29(3) Total 8 4 1 1 4 7 6 6 6 2 45 186(9) Notes: 1. The cumulative total indicates the number of problems that have occurred since each unit entered service. 2. The figures in parentheses indicate the number of occurrences before entering service and are described separately. 3. Unit 1 of each nuclear power plant includes common facilities. Common Facilities include incinerators, solid radioactive wastes storages and port facility, etc. * The figure represents overflow stream occurred at the operating floors of Unit 1 to Unit 2 due to the Niigata ChuetsuOki Earthquake (July 16, 27). 74

Solid Radioactive Wastes Production of Annual (5) b has which and evaporated been has plant the in used water from which waste radioactive lowlevel includes waste Solid 1. otes: N n bee has waste the and condensed, een example filter for drum, been packed inside a has radioactive waste that and lowlevel in concrete, acked into a drum and set p t cloth used in plan or water or material been compacted and incinerated. work which has Undergrou Waste Radioactive Rokkasho Low Level to the sent drums of number the means by ship out drums of number Reduction of. 2 t located a Center nd Disposal Prefecture. in Aomori Rokkashomura th of (as 45, drums KashiwazakiKariwa, 32, drums; Daini, Fukushima 284,5 drums; Daiichi, Fukushima capacity: Storage. 3 FY 29) end of e 75

Volume produced 3, Annual production : Includes the amount newly occurring as a result of power station operations, the portion of waste returning to storage that occurs in the process of making burial filling affixer when waste is taken from existing stored waste, and incinerator ash occurring in the process of incineration / compaction of existing stored waste. Drum reduction by incineration: Number of drums shipped from storage area for purpose of incinerating existing stored waste. Drum reduction by ship out: The number of drums filled with the wastes kept in storage that were sent to the LowLevel Radioactive Waste Underground Disposal Center in Rokkasho. 29,56 25, 2, 15, 1, 5, 9,955 8,35 (Unit : Number of drums) 9,315 8,512 11,219 12,354 4,988 Accumulation (right graduation) 7,317 9,23 7,786 8,148 16,83 19,66 24,25 24,77 24,474 2,644 21,11 23,633 Accumulation (Unit : thousand) 11,926 27 26 25 231,654 24 219,589 222,977 23 23,277 211,713 22 21,21 198,52 25,494 21 193,65 192,89 2 19 FY '89 '9 '91 '92 '93 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 5 5, 1 1, 15 15, 2 2, Volume reduced Cumulative number of stored drums Annual production Drum reduction by incineration Drum reduction by ship out 7,65 8,215 8,195 2,68 12,49 7,296 16,8 8, 24,17 8, 15,74 8,32 17,568 1,2 4,358 9,22 6,912 1,751 11,248 15,153 6,72 2,111 18,87 5,84 22,818 7,96 28,652 6, 24,792 12,768 4,16 4, 16,452 18,255 11,948 17,623 3,8 3,92 <Reference> Units of Radioactivity and Radiation Relationship of units: 1/1, of 1 sievert is equivalent to 1 millisievert (msv). Note: The former units, curie, rad and rem have been replaced since FY 1989 by the new units, becquerel, gray and sievert, respectively, due to adoption of the law on the international new unit system. 76

<Reference> Radiation Doses and Their Physical Effects Notes: 1. For the values in this figure, the effective dose equivalent or effective dose is described. 2. For the amount of natural radiation, the value including the effect of radon by aspiration is described. Sources: "Report of United Nations Scientific Committee on the Effects of Atomic Radiation 2" "ICRP Pub 13," etc. 77

2. Nuclear Fuel Cycle (1) Outline of Nuclear Fuel Cycle Facilities r r * * Notes: *1 : Construction expense for 2, m 3 lowlevel radioactive waste (equivalent to Approx. 1 million 2rdrums) *2 : Construction expense for 1,44 containers of vitrified highlevel radio active waste Note: tu = tones of uranium In spent fuel, uranium and oxygen are combined. A unit of tones of uranium is the weight of spent fuel minus the weight of oxygen. 78

(2) Japan's Procurement of Uranium (as of March 27) Source: "Nuclear Pocket Book 29" Note: st = short ton Short ton is a unit of weight used mainly in the United States; one short ton is equivalent to approx. 97 kg. (3) Outline Plan for Plutonium Utilization in Light Water Reactors (MOX utilization) Plutonium utilization in light water reactors refers to utilizing plutonium in the present nuclear power plants (light water reactors) using MOX fuel, which mixes uranium with plutonium. The electric power industry as a whole is planning to start up the utilization of MOX fuel in 16 to 18 LWR plants by FY 215. The plan for MOX fuel utilization in LWRs will play a vitally important role in securing a stable supply of energy in Japan, a resource poor country, in the future. 79

(4) Amount of Spent Fuel Storage a. Amount of Spent Fuel Storage (Unit: Number of fuel assemblies) (as of the end of March 21) Notes: 1. The amount of change for a nuclear reactor refers to the total of fuel assemblies contained in all of the nuclear reactors at each power station. In order to change fuel, each nuclear reactor is operated to allow storage of the amount for 1 reactor core. 2. Figures in parentheses in the storage capacity after expansion column include expanded capacities for spent fuel pools now under construction or in the planning stage and those to be added after the completion of the capacity expansion work. b. Outline of Common Spent Fuel Storage Facility at Fukushima Daiichi Nuclear Power Station Completed in October 1997. Scale of facility: Approx. 55 m (W) approx. 73 m (L) approx. 35 m (H) Storage capacity: 6,84 assemblies (9 assembly racks 76 units) (Approx. 2% of the amount of total reactor core loading) Approx. 12 m (W) approx. 29 m (L) approx. 11 m (D) Storage system: Water pool system Accessory equipment Cooling and filtering system : 2 systems (Eventual heat exchange with air) Automatic fuel handling machine : 1 unit Cask transporting system : 1 unit Overhead traveling crane : 2 units (Pool area and cask transport incoming and outgoing area) Transportation cask : 6 casks (Building has a 1 cask storage capacity) c. Outline of Spent Fuel Storage Cask at Fukushima Daiichi Nuclear Power Station 8

(5) Overview of Recycled Fuel Storage Center In February 24, TEPCO asked for the cooperation of Aomori Prefecture and Mutsu city in locating of the facility (location cooperation request), and gained approval from the both government in October 25. In November 25, TEPCO and The Japan Atomic Power Company who promotes the business collectively have established RecyclableFuel Storage Company in Mutsu city. This company applied to the Minister of Economy, Trade and Industry for permission for spent fuel storage business for "Recycled Fuel Storage Center" in March 27 via detailed research of the actual place, and acquired the business license in May 21. The company has begun preparatory work in March 28. Conceptual drawing of Recycled Fuel Storage Center 3, ton storage building [approx. 13m 6m (height) 3m] * TEPCO's storage share: approx. 4, tonsu * Japan Atomic Power Company's storage share: approx. 1, tonsu * Note: "Each cask" refers to a storage container that will be put in succession. * Metal casks account for 78 percent of all construction cost. 81

(6) Current Status of Nuclear Fuel Reprocessing Contracts TEPCO has concluded agreements with Nuclear Decommissioning Authority (NDA of the U.K.), AREVA NC (nuclear fuel company in France), Japan Atomic Energy Agency and Japan Nuclear Fuel to reprocess uranium. The following table describes the current status of this endeavor. (as of the end of March 21) 82

(7) HighLevel Radioactive Waste Storage Conditions Highlevel radioactive waste (vitrified material) that is returned from France and the U.K. is all stored and managed in Vitrified Waste Storage Center of Japan Nuclear Fuel Ltd. located in Rokkashomura, Aomori Prefecture. Note: Highlevel radioactive waste is vitrified and put in stainless canisters that measure approx..4 m in diameter, approx. 1.3 m in height, and weigh approx..5 tons. <Reference> Schedule of Geological Disposal Project 1st phase 2nd phase 3rd phase Application Public subscription Research by documents Selection of general researched zone General research Selection of precise researched zone Precise research Site Selection to construct disposal facility Construction Operation Closing Explorations such as borehole surveys Measurements and investigations in underground test facilities Repository construction *1 Based on "Final disposal plan (March 28)" *2 The government can nominate the site for literature survey, taking account of opinions of local communities. In this case, mayor will express whether they will accept the proposals or not. Sources: Nuclear Waste Management Organization of Japan (NUMO), "Geological Disposal of Radioactive Waste in Japan" 83

< Reference> Nuclear Fuel Cycle Concep t q r t! w! e y!2 o u i!1 q w e r t y u i o!!1!2 84

MEMO 85

VI. Accounting 1. Profit and Financial Structure Improvement Targets In view of the current situation of the KashiwazakiKariwa Nuclear Power Station, etc., the FY 21 Business Plan does not set target figures. TEPCO will continue to make maximum effort to achieve the targets set forth in "Management Vision 21." a. Changes in Standard Profits Standard Profits billion yen 4 35 3 25 2 15 1 5 5 1 184.9 28.9 217.3 128.2 146.8158.3 142.5 27.9 159.9 167.5 345.9 32. 319.5 28.8 34.4 384.5397.2 372. 22. 9.1 b. Changes in ROA/ROE ROAROE (%) 12 11.1 1.9 1.7 ROE 1 9.1 9.5 9.8 7.5 7.2 8 6.6 6.3 6.3 5.9 5.4 5.7 6 5.1 5.5 6.3 5.7 4 5.3 5.4 5.3 5.6 4.2 4.4 4.5 5.1 5.4 4.8ROE 4.8 5. 4.5 2 3.4 3.7 3.5 4. 4.1 3.8 2.ROA ROA.2.7 2 4 6 8 6.9 5. Outstanding Amount of InterestBearing Liabilities Shareholders' Equity Ratio (%) Note: ROA: Operating income/average gross assets. ROE: Net income/average shareholders' equity. c. Changes in Outstanding Amount of InterestBearing Liabilities 7.6 7.99 8.52 9.7 9.59 9.89 1.2 1.53 1.5 1.48 1.18 Note: 13.1 12.5 12. 11.4 1.8 1.6 1.1 1. 1.4 1.6 12.2 9.86 13.5 9.42 8.97 8.58 7.9 7.62 7.74 7.18 7.47 7.38 Outstanding amount of interestbearing liabilities: corporate bonds and outstanding amount of debt loan d. Changes in Shareholders' Equity Ratio 14.1 14.9 17.8 16.2 19.6 21.5 18.2 158.6 16.4 17.1 Note: Shareholders' Equity Ratio: (Net asset Share warrant) / Total assets and shareholders' equity 86

<Reference> Numerical Targets of "Management Vision 21" Targets to be achieved by FY 21 Operation Efficiency Improve efficiency by 2% or more from the FY 23 level with equipment safety and securing of quality as major premises Improvement of Balance Sheet Increase shareholders' equity ratio to 25% or higher Business Growth Expansion of Electricity Sales volume Expansion of sales volume by 1 billion kwh or more (cumulative total in FY 24 through FY 21) Electric Power Industry Ensure 3 billion yen or more in sales from businesses other than the electric power industry (Note1), and 5 billion yen or more in operating income from businesses other than the electric power industry (Note2) Note2: The total of operating income of consolidated subsidiaries and affiliates Target of Contribution to Global Environment Reduce the fiveyear average of CO 2 emission intensity (FY 28 through FY 212) by 2% from the FY 199 level 87

2. Balance Sheet (1) NonConsolidated (unit: billion yen) Notes: 1. Fractions smaller than.1 billion yen are rounded down. 2. Since FY 26, the accounting standard related to display of net asset part of balance sheet has been applied. 3. Since FY 29, new energybased power production equipment of new energy is booked as a separate item to comply with the amended Accounting Rules for Electricity Business. 88

(2) Consolidated (unit: billion yen) Assets Liabilities and Net Asset (Shareholders' Equity) Notes: 1. Fractions smaller than.1 billion yen are rounded down. 2. Since FY 26, the accounting standard related to display of net asset part of balance sheet has been applied. 89

3. Statement of Income (1) NonConsolidated (unit: billion yen) Notes: 1. Fractions smaller than.1 billion yen are rounded down. 2. Since FY 29, new energybased power production expenses for new energy are booked as a separate item to comply with the amended Accounting Rules for Electricity Business. 9

(2) Consolidated Note: Fractions smaller than.1 billion yen are rounded down. (unit: billion yen) 91

4. Summary of NonConsolidated Financial Results (unit: billion yen) Notes: 1. Fractions smaller than.1 billion yen are rounded down. 2. Since FY 26, the "nuclear power backend cost" (reprocessing costs of irradiated nuclear fuel, costs for preparation of reprocessing of irradiated nuclear fuel, disposal costs of highlevel radioactive wastes, decommissioning costs of nuclear power units) included with "Other" has been described separately. 92

5. Consolidated Statements of Cash Flow (unit: billion yen) Note: Fractions smaller than.1 billion yen are rounded down. * * * * * * * * * * * *1: "" denotes a decrease *2: "" denotes an increase 93

6. Changes in Ordinary Income (1) NonConsolidated (2) Consolidated 94

7. Changes in Capital (unit: 1, yen) Note: The above way of indicating a capital increase ratio is in compliance with the directions from the Tokyo Stock Exchange started in 1974. 95

8. Changes in Number of Shareholders and Shares (including shareholders and shares less than one unit) At the End of FY 1951 1955 1965 1975 1985 199 1995 2 22 23 24 25 26 27 28 29 Total Number of Shareholders (persons) Individual Shareholders (persons) (Ratio, %) 86,538 17,58 21,853 353,853 384,41 76,579 86,249 817,81 85,519 836,331 821,841 81,25 757,3 811,725 793,488 85,56 15,448 199,118 351,13 38,157 751,212 851,756 81,991 843,746 829,97 815,679 794,956 751,185 85,673 787,44 ( 98.8) ( 98.1) ( 98.6) ( 99.2) ( 98.9) ( 98.8) ( 99.) (99.2) (99.2) (99.2) (99.3) (99.2) (99.2) (99.3) (99.2) 794,653 788,842 (99.3) Total Number of Shares (in 1 thousand shares) 292 2,628 24, 8,179 13, 133,947 135,286 135,286 135,286 135,286 135,286 135,286 135,286 135,286 135,286 135,286 Shares Owned by Individual Shareholders (in 1 thousand shares) (Ratio, %) Capital (billion yen) 126 1,363 9,82 33,33 38,97 43,787 48,169 46,778 5,458 52,912 51,358 49,796 45,9 49,756 48,936 ( 43.4) ( 51.9) ( 37.8) ( 41.5) ( 29.9) ( 32.7) ( 35.6) (34.6) (37.3) (39.1) (38.) (36.8) (33.3) (36.8) (36.2) 1.4 13.1 12. 4.8 65. 67.4 676.4 676.4 676.4 676.4 676.4 676.4 676.4 676.4 676.4 51,235 (37.9) 676.4 <Reference> Comparison with Other Industries as Ratio of Individual Shareholders and Ratio of Individual Stock Ownership (per unit) (as of the end of March 21) Note: The figures for other industries were taken from the report of "28 Shareownership Survey" (conducted jointly by the Tokyo Stock Exchange and other organizations). <Reference> Current Distribution of Shares (per unit) by Owners (as of the end of March 21) 96

<Reference> Major Shareholders (top 1 shareholders) (as of the end of March 21) Note: Fractions smaller than one thousand shares are rounded down. 97

9. Changes in Shareholders' Equity Ratio 74.4 54.5 <Reference> Shareholders' Equity Ratio, by Industry (FY 28) Source: Tokyo Stock Exchange (unit: %) 31. 28.4 23.4 17.1 11. 14.1 16.2 19.6 21.5 17.1 18.2 17.8 16.4 13.5 14.9 12.1 12.5 1.1 1. Changes in Ratio of Recurring Profit to Capital Stock 1. 7.5 5. 6.6 6.3 6.3 5.9 5.5 5.6 5.1 4.5 5.1 4.8 5.4 5. 4.5 3.7 3.5 4. 4.1 3.8 5.5 2.5..7.2 2. 2.1 1.9 1.2.6 2.4 2.5 '89 '9 '91 '92 '93 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 (FY) TEPCO Note: Figures for other industries are those for FY 28. Source: Tokyo Stock Exchange All Industries Manufacturing Industry Chemicals Iron and Steel Electric Equipments Transportation Equipments 98

11. Changes in Costs of Supplying Electricity 5.5 4.9 4.78 4.85 4.88 4.93 4.94 4.83 4.73 4.42 4.54 (13) 4.56 (12) (11) (14) 4.53 4.58 (13) (14) (12) (14) 4.45 4.44 4.47 4.5 4.24 (38) (17) (13) (17) 3.98 3.94 (18) (19) (23) (23) (36) (2) 3.82 (2) 3.6 3.64 3.7 3.73 (27) (19) 3.36 (28) (16) (17) (15) 3.2 (33) (46) (45) (45) (42) (4) 2.99 (32) (46) (37) (45) (4) (4) (46) (47) (48) (36) (37) (34) (46) (36) (26) (23) (3) (37) (46) (45) (5) 2.5 (51) (5) (43) (39) 1.73 1.75 (38) (1) (36) (1) (1) (11) (11) (11) (1) (12) (9) (1) (1) (1) 1.51 (27) (1) (9) (9) (7) (11) (9) (34) (35) (34) 1.26 (36) (9) (37) (9) (9) (9) (39) (33) (8) (8) (9) (4) (7) (8) (31) (34) (8) (8) (7) (27) (28) (3) (3) (3) (32) (31) (31) (33) (33) (33) (35) (34) (34) (34) (32) (33) (31) (3) (32) (11) (26) (26) (11) (12) (23) (25) (24) (26) (11) (2) (21) (12) (21) (21) (2) (19) (17) (19) (19) (21) 5.42 Notes: 1. "Facilities and related costs" means the sum of maintenance expenses, depreciation expenses, interest expenses, and funds for dividends. 2. Figures in parentheses show the percentage composition (%). 3. Due to changes in the Accounting Rule for Electricity Business, depreciation expenses for trial operation has been classified as "Facilities and related costs" and separated from"others" since FY 1996. 4. "Others" includes purchased electricity, rent expenses fees, expenditure for agential tasks, property tax, promotion of power resources development tax, enterprise tax and other. <Reference> Changes in Equipment Expenses and Fuel Costs per kwh of Electricity Sales 99

<Reference> Changes in Exchange Rate (Interbank Monthly Average) < Reference> Annual Exchange Rate (Interbank ) FY Exchange r ate (Yen/Dollar) 3 17 299 273 293 299 292 257 22 23 217 228 25 236 244 221 16 138 128 143 141 133 125 18 99 96 113 123 128 112 111 125 122 113 18 11 3 117 114 11 93 N ote: For FY 1971, the average value in the second half of the year is indicated because a fixed exchange rate sysytem was adopted by August 27 of this year. 1

VII. Electricity Rates and Rate Systems 1. Electricity Rates (1) Overall Electricity Rates for Residential and Power Services Notes: 1. Overall electricity rate = Revenue from electricity sales Additional charges due to the delayed payment Electricity sales Amount of electric power used for business operations and construction work 2. Figure after FY 1999 exclude specifiedscale demand. 11

(2) Electricity Rates Revision History 12

(Reference Data) 13

(3) Unit Price of Electricity (become effective on April 1, 21) Lighting [by electric supply contract] Contract Category Unit Rate (Yen) [Inc. tax] Contract Category Unit Rate (Yen) [Inc. tax] Customer charge per contract 52.5 Up to 5 VA per contract per day 6.39 Up to 2 W per lamp 121.26 Over 5 VA to 1 VA ditto 12.79 Fixed Rate Lighting Service Small Lamp charge appliance charge MeterRate Lighting Service A B Demand charge Energy charge Over 2 W to 4 W Over 4 W to 6 W Over 6 W to 1 W For every 1 W over 1st 1 W Up to 5 VA Over 5 VA to 1 VA For every 1 VA over 1st 1 VA Minimum charge Energy charge 1A 15A 2A 3A 4A 5A 6A Up to 1st 12 kwh (1st block rate) Over 12 kwh to 3 kwh (2nd block rate) Over 3 kwh (3rd block rate) Minimum monthly charge ditto ditto ditto ditto per appliance ditto ditto UP to 1st 8 kwh per kwh over 1st 8 kwh per contract ditto ditto ditto ditto ditto ditto 1kWh ditto ditto per contract 196.31 27.33 419.4 419.4 196.49 35.84 35.84 216.3 17.87 273. 49.5 546. 819. 1,92. 1,365. 1,638. 17.87 22.86 24.13 216.3 Temporary Lighting Service Public Street Lighting Service A B C A B Lamp charge Small appliance charge For every 1 VA over 1 VA up to 5 VA Over 5 VA to 1 kva For every 1 kva over 1 kva up to 3 kva Demand charge Energy charge Demand charge Energy charge Customer charge Up to 2 W Over 2 W to 4 W Over 4 W to 6 W Over 6 W to 1 W For every 1 W over 1st 1 W Up to 5 VA Over 5 VA to 1 VA For every 1 VA over 1st 1 VA Demand charge Energy charge Minimum monthly charge ditto ditto ditto 1A 1kWh 1kVA 1kWh per contract per lamp ditto ditto ditto ditto per appliance ditto ditto 1kVA 1kWh per contract 12.79 127.95 127.95 3.3 26.36 3.3 26.36 47.25 18.66 175.31 243.3 376.35 376.35 176.54 27.14 27.14 246.75 16.73 195.3 Demand charge 1kVA 273. C Energy charge Up to 1st 12 kwh (1st block rate) Over 12 kwh to 3 kwh (2nd block rate) Over 3 kwh (3rd block rate) 1kWh ditto ditto 17.87 22.86 24.13 14

Power [by electricity supply contract] Contract Category Unit Rate (Yen) [Inc. tax] LowVoltage Power Service Demand charge Energy charge 1kW 1kWh 1,71. Summer Other seasons 13.2 12.16 Fixed rate service 1kW Per day 151.64 Temporary Power Service MeterRate Service Demand charge Energy charge 1kW 1kWh 2% higher than ordinary supply rate Summer 15.47 Other seasons 14.22 Agricultural Power Service (for agricultural irrigation purposes) Demand charge Energy charge 1kW 1kWh 42. Summer Other seasons 9.54 8.84 * For Light & Power, LowVoltage Power and Agricultural Power Service, "summer" means a period from July 1 through September 3 each year and "other seasons" means a period from October 1 each year through June 3 next year. 15

Major Optional Rules for Supply of Electricity TimeofDay Lighting Service (nighttime 8hour type) (OtokunaNight 8) TimeofDay Lighting Service (nighttime 1hour type) (OtokunaNight 1) Contract Category For 6 kva or less Demand charge For 7 kva 1 kva For 11 kva and over Energy charge Day hours Night hours Discount Minimum monthly charge For 6 kva or less Discount Energy charge Demand charge For 7 kva 1 kva For 11 kva and over Day hours Night hours Up to 1st 9 kwh (1st block rate) Over 9 kwh to 23 kwh (2nd block rate) Over 23 kwh (3rd block rate) Up to 1st 8 kwh (1st block rate) Over 8 kwh to 2 kwh (2nd block rate) Over 2 kwh (3rd block rate) A discount of 42. yen/kva for eighthourenergized appliances Minimum monthly charge Unit Rate (Yen) [Inc. tax] Contract Category Unit Rate (Yen) [Inc. tax] per contract ditto ditto 1kWh ditto ditto ditto 1,26. 2,1. 2,1. yen + 273. yen (Contracted capacity 1kVA) 21.87 28.7 29.64 9.17 A discount of 241.5 yen/kva for fivehourenergized appliances A discount of 136.5 yen/kva where energizationcontrolled (microcomputercontrolled) nighttime thermal storage type appliances are used per contract per contract ditto ditto 1kWh ditto ditto ditto 36.6 1,26. 2,1. 2,1. yen + 273. yen (Contracted capacity 1kVA) 23.87 3.74 32.48 9.48 A discount of 283.5 yen/kva for fivehourenergized appliances A discount of 178.5 yen/kva where energizationcontrolled (microcomputercontrolled) nighttime thermal storage type appliances are used per contract 36.6 TimeofUse Lighting Service (DenkaJozu) For 6 kva or less Discount Energy charge Demand charge For 7 kva 1 kva For 11 kva and over Day hours For summer Morning and evening hours Night hours For other seasons 1,26. 2,1. 2,1. yen 273. yen (Contracted capacity 1kVA) 33.37 28.28 23.13 9.17 A discount of 241.5 yen/kva for fivehourenergized appliances A discount of 136.5 yen/kva where energizationcontrolled (microcomputercontrolled) nighttime thermal storage type appliances are used For totallyelectrified homes, a 5% discount from the energy charge for TimeofUse Lighting Service (DenkaJozu) (excluding day hours in summer) Minimum monthly charge Demand charge Energy charge 36.6 * For TimeofDay Lighting Service (nighttime 8hour type) (OtokunaNight 8), "day hours" means a time period from 7: a.m. to 11: p.m. every day and "night hours" means a time period other than the day hours. * For TimeofDay Lighting Service (nighttime 1hour type) (OtokunaNight 1), "day hours" means a time period from 8: a.m. to 1: p.m. every day and "night hours" means a time period other than the day hours. * For TimeofUse Lighting Service (DenkaJozu), "summer" means a period from July 1 through September 3 each year and "other seasons" means a period from October 1 each year through June 3 next year. In this service option, "day hours" means a time period from 1: a.m. to 5: p.m. every day while "morning and evening hours" means time periods from 7: a.m. to 1: a.m. and 5: p.m. to 11: p.m. every day. "Night hours" means a time period from 11: p.m. every day to 7: a.m. next day. * The discount for totallyelectrified homes is subject to a ceiling limit of 2,1 yen (including tax) a month. Snow Melting Power Service Contract Category Contract Category Up to first 3 months of the contracted period After 3 months Unit per contract ditto ditto 1kWh ditto ditto ditto per contract Unit 1kW ditto 1kWh Rate (Yen) [Inc. tax] 2,5.5 Rate (Yen) [Inc. tax] 477.75 11.79 NightOnly Service NightOnly B Service Contract Category NightOnly A Service Demand charge Energy charge Energizationcontrolled nighttime thermal storage type appliances Second Night Only Service Demand charge Energy charge Unit per contract 1kW 1kWh 1kW 1kWh Rate (Yen) [Inc. tax] 1,127.28 315. 9.17 15% OFF 21. 8.22 HighLoad LowVoltage Service LowVoltage Power by Season and Time of Day for Agricultural Use Demand charge Energy charge Demand charge Energy charge For 5 kw or less Over 5kW 1kW 1kWh Contract Category For summer Day hours For other seasons Night hours Summer 15.5 Unit per contract ditto 1kWh ditto ditto 1,26. Other seasons 13.84 Rate (Yen) [Inc. tax] 5,355. 5,355. yen + 1,71.yen (contracted capacity5kw) 15.98 14.53 * For HighLoad LowVoltage Service, "summer" means a period from July 1 through September 3 each year and "other seasons" means a period from October 1 each year through June 3 next year. * For LowVoltage power by season and time of day for agricultural use "summer" means a period from July 1 through September 3 each year and "other seasons" means a period from October 1 each year through June 3 next year. In this service option, "day hours" means a time period from 8 a.m. to 1 p.m. every day and "night hours" means a time period other than the day hours. 16 9.48

Electricity Supply and Demand Contract Electricity Supply and Demand Contract (HighVoltage) (ExtraHighVoltage) Contract Category Unit Time/Season Rate (Yen) [Inc. tax] Contract Category Unit Time/Season Rate (Yen) [Inc. tax] Electric Power by Season and Time of Day for Commercial Use HighVoltage Power by Season and Time of Day Electric Power for Commercial use HighVoltage Power Demand charge Demand charge Energy charge Energy charge Demand charge Energy charge Contracted power 5kW or more Contracted power less than 5kW Contracted power 5kW or more Contracted power less than 5kW Demand charge Energy charge Contracted power 5kW or more Contracted power less than 5kW Contracted power 5kW or more Contracted power less than 5kW 1kW 1kWh 1kW 1kW 1kWh 1kWh 1kW 1kWh 1kW 1kW 1kWh 1kWh Daytime Daytime Daytime Peak Summer Other seasons Nighttime Peak Summer Other seasons Nighttime Peak Summer Other seasons Nighttime Summer Other seasons Summer Other seasons Summer Other seasons 1,638. 16.6 15.92 14.56 9.2 1,732.5 1,233.75 15.34 14.71 13.3 9.2 17.23 16.55 15.19 9.2 1,638. 13.75 12.65 1,732.5 1,233.75 12.44 11.47 13.59 12.51 Special HighVoltage Electric Power by Season and Time of Day, A Special HighVoltage Electric Power by Season and Time of Day, B Special HighVoltage Power, A Demand charge Energy charge Demand charge Energy charge Demand charge Energy charge 2kV supply 6kV supply 2kV supply 6kV supply 2kV supply 6kV supply 14kV supply 2kV supply 6kV supply 14kV supply 2kV supply 6kV supply 2kV supply 6kV supply 1kW 1kW 1kWh 1kWh 1kW 1kW 1kW 1kWh 1kWh 1kWh 1kW 1kW 1kWh 1kWh Peak Summer Other seasons Nighttime Peak Summer Other seasons Nighttime Peak Summer Other seasons Nighttime Peak Summer Other seasons Nighttime Peak Summer Other seasons Nighttime Summer Other seasons Summer Other seasons Daytime Daytime Daytime Daytime Daytime 1,585.5 1,533. 13.96 13.38 12.28 9.2 13.75 13.17 12.7 8.81 1,585.5 1,533. 1,48.5 13.96 13.38 12.28 9.2 13.75 13.17 12.7 8.81 13.54 12.96 11.81 8.66 1,585.5 1,533. 12.24 11.28 12. 11.7 Special HighVoltage Power, B Demand charge Energy charge 2kV supply 6kV supply 14kV supply 2kV supply 6kV supply 14kV supply 1kW 1kW 1kW 1kWh 1kWh 1kWh Summer Other seasons Summer Other seasons Summer Other seasons 1,585.5 1,533. 1,48.5 11.7 1.8 11.47 1.59 11.24 1.38 17

(4) Formulas for Calculating Electricity Charges (Monthly Bills) under Major Contract Categories MeterRate Lighting A Service MeterRate Lighting B and C Services Contract Categories Fixed Rate Lighting Service TimeofDay Lighting Service (Nighttime 8hour type) TimeofUse Lighting Service (DenkaJozu) For energy consumption up to 8 kwh For energy consumption of 9 kwh and over Demand charge Energy charge Demand charge Discount Energy charge Demand charge Energy charge Discount Discount for fullyelectrified homes For energy consumption up to 12 kwh For energy consumption over 12 kwh up to 3 kwh For energy consumption over 3 kwh Charge For 6 kva or less For 7 kva 1 kva For 11 kva and over For daytime energy consumption up to 9 kwh For daytime energy consumption over 9 kwh up to 23 kwh For daytime energy consumption over 23 kwh When 5hourenergized appliances are used When energizationcontrolled nighttime thermal storage type appliances are used Charge For 6 kva or less For 7 kva 1 kva For 11 kva and over For summer For other seasons When 5hourenergized appliances are used When energizationcontrolled nighttime thermal storage type appliances are used When the discount for fullyelectrified homes applies For summer For other seasons 52.5 yen (Customer charge) + Lamp charge + Small appliance charge ± Fuel cost adjustment + Solar surcharge 216.3 yen (Minimum charge) ± Fuel cost adjustment + Solar surcharge {216.3 yen + 17.87 yen (Energy consumption 8kWh)} ± Fuel cost adjustment + Solar surcharge MeterRate Lighting B: Demand charge as classified by contract current (1A 6A) MeterRate Lighting C: 273. yen Contract capacity 17.87 yen Energy consumption ± Fuel cost adjustment 17.87 yen 12kWh + 22.86 yen (Energy consumption 12kWh) ± 17.87 yen 12kWh + 22.86 yen 18kWh + 24.13 yen (Energy consumption 3kWh) ± Fuel cost adjustment Demand charge + Energy charge + Solar surcharge 1,26. yen 2,1. yen 2,1. yen + 273. yen (Contract capacity 1kVA) 21.87 yen Daytime energy consumption + 9.17 yen Nighttime energy consumption ± Fuel cost adjustment 21.87 yen 9kWh + 28.7 yen (Daytime energy consumption 9kWh) + 9.17 yen Nighttime energy consumption ± Fuel cost adjustment 21.87 yen 9 kwh + 28.7 yen 14kWh + 29.64 yen (Daytime energy consumption 23kWh) + 9.17 yen Nighttime energy consumption ± Fuel cost adjustment 241.5 yen Total capacity of 5hourenergized appliances (kva) 136.5 yen Total capacity of energizationcontrolled nighttime thermaltype appliances (kva) Demand charge + Energy charge Discount + Solar surcharge 1,26. yen 2,1. yen 2,1. yen + 273. yen (Contract capacity 1kVA) 33.37 yen Daytime energy consumption + 23.13 yen Morning and evening hour energy consumption + 9.17 yen Nighttime energy consumption ± Fuel cost adjustment 28.28 yen Daytime energy consumption + 23.13 yen Morning and evening hour energy consumption + 9.17 yen Nighttime energy consumption ± Fuel cost adjustment 241.5 yen Total capacity of 5hourenergized appliances (kva) 136.5 yen Total capacity of energizationcontrolled nighttime thermal storge type appliances (kva) (23.13 yen Morning and evening hour energy consumption + 9.17 yen Nighttime energy consumption) 5% (28.28 yen Daytime energy consumption + 23.13 yen Morning and evening hour energy consumption + 9.17 yen Nighttime energy consumption) 5% Charge Demand charge + Energy charge Discount Discount for fullyelectrified homes + Solar surcharge Notes: 1. As for Fuel Cost Adjustment, please refer to P19. 2. As for Solar surcharge, please refer to P111. 18

(5) Fuel Cost Adjustment System Standard Unit Price under Fuel Cost Adjustment System Unit Standard Unit Price (Yen) [Inc. tax] MeterRate System Fixed Rate System LowVoltage Supply (Lighting, LowVoltage Power Service, etc.) 1kWh.19 HighVoltage Supply ditto.185 Special HighVoltage Supply ditto.182 Fixed Rate Lighting Service / Public Street Lighting Service, A Temporary Lighting Service, A Lighting Small Appliances Up to 2W Over 2W to 4W Over 4W to 6W Over 6W to 1W For every 1W over 1st 1W Up to 5VA Over 5VA to 1VA For every 1VA over 1st 1VA Up to 5VA Over 5VA to 1VA For every 1VA, over 1st 1VA up to 5VA Over 5VA to 1kVA For every 1kVA, over 1st 1kVA up to 3kVA Temporary Power Service LateNight Electric Power, A Per lamp ditto ditto ditto ditto Per appliance ditto ditto Per contract, per day ditto ditto ditto ditto Per kw, per day Per contract 1.476 2.953 4.429 7.382 7.382 2.25 4.41 4.41.6.119.119 1.19 1.19 1.251 19.5 Calculating Fuel Cost Adjusted Unit Price 1. When the "average fuel price" fluctuats by 1, yen/kr, the fuel cost adjusted unit price per kwh used is treated as the "standard unit price." 2. The average fuel price is the price/krin crude oil equivalents, calculated based on the 3month (actual recorded) prices derived from Foreign Trade Statistics for crude oil, LNG and coal published by Ministry of Finance Japan. The average fuel price is calculated as below. Average fuel price = A + B + C (values less than 1 yen rounded off) A: Average crude oil price/krin each quarter.2782 B: Average LNG price/ton in each quarter.3996 C: Average coal price/ton in each quarter.2239 3. The fuel cost adjusted unit price is calculated based on the average fuel price and the standard unit price. A. If the average fuel price is below 42,7 yen Standard unit price Unit price = (42,7 yen Average fuel price) 1, B. If the average fuel price is above 42,7 yen Standard unit price Unit price = (Average fuel price 42,7 yen) 1, * For lowvoltage power contract customers, if the average fuel price is above 64,1 yen, this 64,1 yen shall be the maximum price. In this case, for the portion of the average fuel price beyond 64,1 yen, no adjustment is to be applied. 19

Calculating Electricity Fee (monthly) under Fuel Cost Adjustment System Electricity Fee (Inc. tax) Demand Charge (Inc. tax) Unit Price of Energy Charges (Inc. tax) Monthly Energy Consumption Fuel Cost Adjustment Amount *1 Fuel Cost Adjusted Unit Price (Inc. tax) If the average price is above 42,7 yen : If the average price is below 42,7 yen : Monthly Energy Consumption *2 Solar Surcharge (Inc. tax) *1 Every month's "fuel cost adjusted unit price" is posted in advance in TEPCO's branch offices, service centers, website and so on and is also noticed by the electricity usage statements customers receive each month. *2 As for Solar Surcharge, please refer to P111. Period for Calculating Fuel Costs & Application to Electricity Fee A fuel cost adjusted unit price for every month shall be calculated on the basis of average fuel prices actually recorded for 3 months. For example, a fuel cost adjusted unit price calculated on the basis of (actual recorded) average fuel prices from January to March, shall be applied to electricity fees for June. [Conceptual Diagram] Period for Estimating Fuel Prices (every 3 months) Jan. Feb. March April May Jun. July Aug. Sept. Oct. Nov. Dec. Application to Electricity Fees for Jan. Feb. March April May Jun. July Aug. Sept. Oct. Nov. Dec. 11

(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" With the start of the "New System for the Purchase of Surplus Electric Power from Solar Power Plants," we have started collecting a "Solar Surcharge" from all our customers who use electricity to recover the cost we incur in purchasing surplus electric power from solar power plants. * As for the purchase conditions etc., please refer to P119. Solar Surcharge Collection Method (for metered customers) Solar Surcharge Electricity Fee (Inc. tax) Demand Charge (Inc. tax) Power Volume Fee (Inc. tax) (Inc. the fuel cost adjustment amount) * Solar Surcharge Unit Price (Inc. tax) Monthly Energy Consumption * The "Solar Surcharge unit price" is shown on the monthly electricity usage statement and the monthly electricity rate bill (electricity rate breakdown statement) as well as on TEPCO's web site. Solar Surcharge Unit Price Calculation Method The "Solar Surcharge unit price" for each charging year, which starts in April of each year and ends in March of the following year, is calculated based on the cost we incurred in purchasing surplus electric power from solar power plants during the preceding year (from January 1 to December 31). Solar Surcharge unit price Total cost TEPCO incurs in purchasing surplus electric power from solar power plants during the previous year (from January 1 to December 31) Power generation cost reduction achieved at TEPCO as a result of the purchase of surplus electric power from solar power plants *1 Overall electricity demand in the current year (estimation) Difference between the past purchasing cost and actual "Solar Surcharge" amount *2 *1 The total cost reduction achieved at TEPCO in the form of reductions in fuel and other costs resulting from the reduction in the amount of electric power that has to be generated by TEPCO to supply electricity to its customers as a result of the purchase of surplus electric power from solar power plants. *2 The total of difference from the purchase cost that arises when the actual electricity demand differs from the estimated electricity demand and the purchase cost deficiency that arises when rounding (truncation) is performed in calculating the unit price. 111

Solar Surcharge Unit Price Calculation Cycle November 29 January 21 April January 211 April January 212 April Total cost TEPCO incurs in purchasing surplus electric power (November and December) Determination of the "Solar Surcharge unit price"* Charging Solar Surcharge to customers (April 1 to March 31) Total cost TEPCO incurs in purchasing surplus electric power (January 1 to December 31) Determination of the "Solar Surcharge unit price"* Charging Solar Surcharge to customers (April 1 to March 31) * The "Solar Surcharge unit price" is calculated every year based on the total cost TEPCO incurs in purchasing surplus electric power, the electricity demand, etc. The Purchase System Subcommittee of a council of the national government then examines the calculated amount to decide whether or not to approve it. Solar Surcharge Unit Price (FY 21) Unit Solar Surcharge Unit Price [Inc. tax] MeterRate System Fixed Rate System LowVoltage Supply (Lighting, LowVoltage Power Service, etc.) 1kWh. HighVoltage Supply ditto. Special HighVoltage Supply ditto. Fixed Rate Lighting Service / Public Street Lighting Service, A Temporary Lighting Service, A Up to 2W Over 2W to 4W Over 4W to 6W Over 6W to 1W For every 1W over 1st 1W Up to 5VA Over 5VA to 1VA For every 1VA over 1st 1VA Up to 5VA Over 5VA to 1VA For every 1VA, over 1st 1VA up to 5VA Over 5VA to 1kVA For every 1kVA, over 1st 1kVA up to 3kVA Lighting Small Appliances Temporary Power Service LateNight Electric Power, A Per lamp ditto ditto ditto ditto Per appliance ditto ditto Per contract, per day ditto ditto ditto ditto Per kw, per day Per contract Yen............... 112

(7) Ratios of Electricity Bills to Household Expenses and Production Amount Source: a. Ratio of Electricity Bills to Household Expenses (all households nationwide) Statistics Bureau, Ministry of Internal Affairs and Communications, "Annual Report on Family Income and Expenditure Survey" b. Ratio of Electricity Bills to Production Amount (total for manufacturing industry sector) Source: Research and Statistics Department, Economic and Industrial Policy Bureau, Ministry of Economy, Trade and Industry, "Census of Manufactures" *1 *2 c. Ratio of Electricity Bills to Production Amount (by industry) *1 Since FY 28, clothes and other textile products are included. *2 Since FY 28, total amount for the "generalpurpose machinery and apparatuses manufacturing industry," "production machinery and apparatuses manufacturing industry" and "businessuse machinery and apparatuses manufacturing industry" combined. (The amount now includes part of the amount for the former "precision machinery and apparatuses manufacturing industry" category because of the change in the classification). Source: Research and Statistics Department, Economic and Industrial Policy Bureau, Ministry of Economy, Trade and Industry, "Census of Manufactures" 113

<Reference> Comparison of Rate Increases for Electric Power and Other Public Services (in Tokyo Metropolitan 23 wards) 2 Postal service (letters, postcards, etc.) Water (1 month) 187 18 161 15 Newspapers (general newspaper, 1 month) 142 1 Japan Railway (ride fares, passes, etc.) City gas (1 month) Household electricity rates (1 month) 96 77 5 Telephone (1 month) 59 FY 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 8 198 Source: Document of Statistics Bureau, Ministry of Internal Affairs and Communications 114

(8) Household Electrical Appliances Usage Cost Reference Chart No. Appliance Air conditioner for 13 2 square meter area (812 tatami mat room) (cooling) Air conditioner for 13 2 square meter area (812 tatami mat room) (heating) Vertical washing and drying machine [heater drying system] (washing capacity 8kg, drying capacity 6kg) Rated Energy Consumption (W) Electric Power Usage Usage Conditions Electric Power (kwh) Value (yen) 1 F luorescent lamp (2W) 18 Turned on 1 hours.18 4.1 Fluorescent lamp (3W) 28 Turned on 1 hours.28 6.4 2 I ncandescent lamp (6W) 54 Turned on 1 hours.54 12.3 3 Compact fluorescent lamp (light bulb shape) (6W type) 1 Turned on 1 hours.1 2. 3 4 LED lamp (light bulb shape) (6W type) 6.9 Turned on 1 hours.7 1.6 5 Induction heating (IH) rice cooker (1.L) (while cooking rice) 1,1 Cooking rice 1 time (white rice 4 cups).19 4.3 IH rice cooker (1.L) (while keeping rice warm) 17(Wh) Keeping rice warm 1 hours (white rice 2 cups).21 4.7 6 Microwave oven 1,46 Heating 2 grams of spinach for 3 minutes at 5W (without water).5 1.1 7 I H cooking heater (1V) 1,3 18 cm enameled steel pan, heating 2 C water to 9 C.18 4. I H cooking heater (2V) 2, 18 cm enameled steel pan, heating 2 C water to 9 C.17 4. 8 T oaster 1, Using for about 3 minutes on automatic toast menu.5 1.1 9 Refrigerator (43L) Electricity Consumption of new JISbased refrigerator for one month Motor 133 (31 days) with temperature setting "refrigerating room 4 C, Heat Pump 177 refrigerated room 18 C", and with the door opened and closed 44. 16.1 1 Electric kotatsu (heated table) 5 Used 1 hour at "medium" setting.1 2.3 11 Electric blanket 66 Used 1 hour at "medium" setting.3.7 12 Electric carpet (2 tatami mat room) 58 Used 1 hour at "medium" setting.21 4.8 13 Electric fan 45 Used 1 hour in "high" mode.4 1. 14 15 Drum type washing and drying laundry machine [heater drying system] (washing capacity 9kg, drying capacity 6kg) Drum type washing and drying machine [heat pump drying system] (washing capacity 9kg, drying capacity 6kg) Average electricity consumption per hour when using 1 hours 48 (Average electricity consumption per hour when using for 1 hours with preset room temperature of 33 C and heat load of 2.2kW).39 8.9 Average electricity consumption per hour when using 1 hours 67 (Average electricity consumption per hour when using for 1 hours.84 19.3 with preset room temperature of 1 C and heat load of 3.1kW) 3 Maximum 1,35 (motor: 25 Electric heater: 1,28) Maximum 81 (motor: 16) For one "washing to draining" of wash of 4.5kg (with test fabrics prescribed in JIS C966) For one "washing to draining" of wash of 4.5kg (with test fabrics prescribed in JIS C966) Washing and drying one 4.5kg load of laundry (with test fabrics prescribed in JIS C966).6 1.3 2.82 64.5 1.64 37.5 16 Clothes dryer (5.kg) 1,4 For "drying" one 4.5kg load of laundry in standard cycle (high power) (the load specified by Japan Electrical Manufactures' Association). 2.73 62.4 17 Iron 1, Using 1 minutes on high setting.9 2. 18 Vacuum cleaner 1, Approx. 2 Used 3 minutes in "high" mode.44 1.1 19 Hair dryer 1,2 Using 5 minutes, with warm air.9 2.1 2 21 22 23 24 CRT TV (36" widescreen) LCD TV (37V) Plasma TV (42V) Stereo (MD component) DVD video recorder 23 228 345 85 37 Watching a movie for 1 hour Watching a movie for 1 hour Watching a movie for 1 hour Listening to CD for 1 hour Watching a movie for 1 hour G arden light (mercury lamp) (4W) 4 Turned on 1 hours.4 9.1 Used 1time garbage disposer (dryer type) 77 Average electricity consumption per day when using for 16 days with 7g of normal garbage per day 1.42 32.5.2.21.35.3.3 4.5 4.9 8..7.6 25 Dishwasher / dryer (tabletop type) 135/1,1/1,235 Washing dishes for 6 people (about 85 minutes) motor/heater/max in standard cycle (wash/dry).9 2.6 26 Air purifier 46 Used 1 hour.5 1.1 27 Dehumidifier (compressor type) 192 Used 1 hour.19 4.3 28 Humidifier (hybrid type) 39 Used 1 hour.39 8.9 Notes: 1. Rated energy consumption (W) based on manufacturer catalog. 2. The above energy consumption figures were found by measuring typical models from manufacturers with a large market share. 3. Value of appliances used Energy consumption under the usage conditions (kwh) unit price/kwh 22.86 yen (tax included) 4. This value was calculated at the unit price 22.86 yen (tax included) per 1kWh of "MeterRate Lightning B" second stage electric power rate unit price, and dose not include base fee. 5. Items marked with an asterisk use values from the manufacturer's catalog. 115

(9) Calculation Process of Electricity Rates Note: Business return is equivalent to interest expense, dividend, and other like. It is the sum total of electric utility fixed assets, nuclear fuel assets, assets under construction, deferred assets, working capital, and designated investment as a rate base, multiplied by the rate of return. 116

2. Electricity Rate Systems (1) Number of Customers Served and Contract Power by Use (as of the end of March 21) Notes: 1. Figures given are based on electric service contracts. 2. Figures given for total of Optional Contracts in Lighting Services are based on the total for "TimeofDayLighting Service (nighttime 8hour, 1hour type)," "TimeofUse Lighting Service" and "HighLoad LowVoltage Service." 3. Figures in parentheses represent those for "LowVoltage Power by Season and Time for Agricultural Use." 4. Figures given for total of Optional Contracts in Power Services are based on the total for "Nightonly Power Service," "Nightonly Power Service, and "Snow Melting Power Service." 5. Figures given are rounded off. 6. The above figures exclude the number of customers of the specificscale demand and are based on electric service contracts. 117

(2) Number of Customers Using Electric Water Heaters under NightOnly Service Notes: 1. Since the system of charging for lighting by time of day began in FY 199, the accounts registered are: nightonly power service + time of day lighting service (those owning nighttime thermal storage devices) and highload lowvoltage contracts (those owning nighttime thermal storage devices). 2. Figures in parentheses are the number of nighttime thermal storage devices owned under "Timeof Day Lighting Service (nighttime 8hour type)," "TimeofDay Lighting Service (nighttime 1hour type)," by TimeofUse lighting service and lowvoltage highload contracts. (3) Summary of Major Optional Tariffs 118

(4) New System for the Purchase of Surplus Electric Power from Solar Power Plants The "New System for the Purchase of Surplus Electric Power from Solar Power Plants" has started since November 1, 29. The system makes electric power companies purchase, under the conditions defined by laws, surplus electric power from solar power generation equipment installed by customers, that is, the electric power generated by solar power generation equipment less the electric power consumed by the users of the equipment. The electric power companies are to collect a Solar Surcharge from all their customers who use electricity to recover the cost incurred in purchasing surplus electric power (For details, please refer to P111 and P112). a. Electric Power That Can Be Purchased Electric power we can purchase is surplus electric power from solar power generation equipment. We can not purchase surplus electric power from solar power generation equipment installed for power generation business. b. Unit Price for the Purchase of Surplus Electric Power Classification Capacity of the Solar Power Generation Equipment Less than 1kW 1kW or more Household Use (lowvoltage supply) In the case where In the case where only solar power nonsolar power generation generation equipment equipment is installed is also installed 48. 39. (yen/kwh including tax) NonHousehold Use (highvoltage supply) In the case where In the case where only solar power nonsolar power generation generation equipment equipment is installed is also installed 24. 2. 24. 2. * The unit prices shown in the table above will be applied, in case that an application for installation of solar power generation equipment is received between April 1, 21 and March 31, 211 and the purchase of surplus electric power starts by June 3, 211. * "The case where nonsolar power generation equipment is also installed" means the case where the customer has nonsolar private power generation equipment (such as a householduse fuel cell, gas engine or battery) in addition to solar power generation equipment and electric power generated by the nonsolar equipment does not flow into our power systems as a reverse power flow but the presence of the nonsolar equipment can cause an increase in the reverse power flow of electric power generated by the solar equipment into our power systems. c. Purchase Period and Revisions of Unit Purchase Price The purchase of surplus electric power is based on the unit purchase price for the fiscal year in which the solar power generation equipment is installed, and that the unit price will be applied for 1 years from the date on which the solar power generation equipment was installed. The unit purchase price will be revised every year and it is planned to decrease every year. Purchase period and unit purchase price (a schematic diagram created from a document published by a national council (Purchase System Subcommittee)) [for the case where solar power generation equipment with a capacity of less than 1kW for household use is installed and no other private power generation equipment of nonsolar type is installed] Unit purchase price Decreases every fiscal year. 29 and 21 48 yen/kwh Purchase period: 1 years 211 212 219 and 22 221 222 Fiscal year Solar power generation equipment installed in or before FY 21 Solar power generation equipment installed in FY 211 Solar power generation equipment installed in FY 212 * The unit purchase prices for FY 211 and the succeeding fiscal years are to be determined before the start of the fiscal year in question by a national council (Purchase System Subcommittee) based on their discussions that take into consideration the current trend of decrease of solar power generation equipment prices and announced by the Minister of Economy, Trade and Industry. 119

(5) Wheeling Service As retail electric power has become deregulated, after the deregulation of electric power market, TEPCO offers its "wheeling service" to PPSs (Power Producer and Supplier) through our power transmission and distribution network. When PPSs supply electricity to their customers*, TEPCO receives electricity from the PPSs and delivers electricity to customers through TEPCO's power transmission and distribution network. * Customers affected by deregulation are those purchasing power rated as high voltage (6kV) or greater. When a PPS is unable to keep up with fluctuations in demand, TEPCO supplies backup power. [Wheeling Service Concept] Regarding wheeling service: TEPCO sets fair charges and network costs that are borne by the customer to whom TEPCO supplies electricity according to the calculation rules set under the Ordinance of the Ministry of Economy, Trade and Industry. [Reference] Rates for "Standard Electricity Transmission Service" (become effective on April 1, 21) When supplied at highvoltages: Demand charge 577.5yen/kW, Energy charge 2.47yen/kWh When supplied at extrahighvoltages: Demand proportioned charge 393.75yen/kW, Energy charge 1.34yen/kWh * Charges are added the Solar Surcharge Application for wheeling service is accepted and related documents are arranged at the TEPCO Network Service Center at the address below. Network Service Center Tokyo Takarazuka Building 12F 113 Yurakucho, Chiyodaku, Tokyo, 16, Japan Tel: 3359179 12

VIII. Capital Investment and Financing 1. Changes in Capital Investment and Plans (billion yen) 1,8 1,68. 1,6 1,59.4 1,541. (9) 1,567.2 (1) (8) (7) 1,399.2 1,4 1,353.4 1,436.5 (1) (1) (1) 1,279.8 1,2 (51) (16) 1,131.6 1,14.3 (49) 1, (1) (54) (17) 1,6.4 (59) (49) 932.2 About 78 billion yen (51) (18) 95.9 (58) (18) (24) (average for FY21 FY212) 8 (41) (52) (52) (48) 645.2 6 (34) (46) 576.1 568.8 59.2 592.1 (28) 55. (23) 464.2 496.3 (2) (17) (15) Others 4 (23) (24) (16) (4) (41) (36) (41) (44) (48) (5) Distribution (49) (39) (39) (48) (53) (58) (57) 2 (32) (33) (32) (31) (36) (42) (34) Power (36) (33) (29) (35) (35) (23) (26) (23) sources '85 '9 '91 '92 '93 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 '1 '11 '12FY Note: Figures in parentheses repesent the persentage composition (%). planned planned planned Notes: 1. Based on the management plan for FY 21. 2. "Distribution" includes transmission, transformation and distribution. "Others" includes nuclear fuels and operation facilities. 121

2. Changes (Net Increase) in Plans for Raising Equipment Funds (1) TEPCO (unit: billion yen) Notes: 1. Figures for the actual results are expressed by dropping fractions smaller than.1 billion yen. 2. Incidental construction costs are excluded. <Reference> Changes (net increase) in Plans for Raising Equipment Funds 2, 1,5 1,353.4 1,68. 1,59.4 1,541. 1,567.2 1,399.2 1,436.5 1,279.8 1, 5 1,14.3 (86) (6) (8) (72) (21) (7) (69) (66) (65) (81) (28) (6) (32) (3) (26) (5) (16) (3) (78) (13) (9) (78) (16) (6) (13) 1,131.6 1,6.4 95.9 (12) (13) (136) 932.2 (147) 645.2 (171) 576.1 (167) 464.2 (246) 55. 496.3 (155) (19) 568.8 (48) (1) (42) 59.2 (55) (12) (33) 592.1 (162) Note: Figures in parentheses represent the percentage composition (%). 122

(2) 1 Electric Power Companies (unit: billion yen) Notes: Source: 1. Figures for FY 29 are those from "Statistics of Electric Power Industry." 2. Figures are expressed by dropping fractions smaller than.1 billion yen. 3. Incidental construction costs are excluded. 4. Numbers are for a total of 9 power companies (except Okinawa Electric Power Company) before FY 1985. "Handbook of Electric Power Industry" <Reference> Changes (1 electric power companies) in Plans for Raising Equipment Funds Notes: 1. Figures in parentheses represent the percentage composition (%). 2. Numbers are for a total of 9 power companies (except Okinawa Electric Power Company) before FY 1985. 123

<Reference> Changes in Private Sector Capital Investment (unit: billion yen) Source: Department of National Accounts, Economic and Social Research Institute, Cabinet Office, "Annual Report on National Accounts" <Reference> Comparison of Investment by Industry (FY 28) (billion yen) 2,5 2, 1,5 1, 5 2,34.4 928.6 1,834.2 1,529.6 1,188. 941.5 1,285.7 1 EPCos. Communication service Automobiles Iron and steel Electrical machinery Chemical industry General machinery* * Total amount for the "generalpurpose machinery and apparatuses manufacturing industry," "production machinery and apparatuses manufacturing industry" and "businessuse machinery and apparatuses manufacturing industry" combined. (The amount now includes part of the amount for the former "precision machinery and apparatuses manufacturing industry" category because of the change in the classification). Sources: Policy Research Institute, Ministry of Finance, "Business Outlook Survey" "Statistics of Electric Power Industry" 124

3. Changes in Amount of Corporate Bonds Issued 198 199 FY 1985 1995 1996 23 24 1997 1998 1999 2 21 22 27 26 29 28 25 125

4. Balance of Corporate Bonds and Loans Payable (billion yen) 11, 1, 1,534.2 1,5.7 1,481.9 1,28.3 19. 289. 17. 1,185.8 13. 71.3 467.3 619. 255. 9,861.3 77.3 64. 415. 9,425.1 Commercial Paper Shortterm Borrowings Longterm Borrowings Bonds 9, 8, 7, 6, 6,936. 426.4 7,995.5 617.5 4,131.8 4,29.1 4,332. 3,941.3 3,631.6 3,523.7 669. 3,191.7 557. 61. 2,771. 8,97. 365. 683. 2,344.7 8,585.2 355. 496. 2,83.9 7,98.9 394. 1,738.3 7,29.8 135. 348. 1,525.7 7,183.1 26. 348. 1,353.1 7,479.9 295. 348. 1,557. 7,748.8 235. 348. 1,811.4 7,384.4 65. 358. 1,792.2 5, 4,779.6 38.6 3,991.1 4, 3, 2,431.7 5,8.8 5,31.8 5,83. 6,61.2 5,767. 5,585.5 5,487. 5,577.3 5,65.2 5,776.5 5,621.1 5,222. 5,279.9 5,354.4 5,169.1 2, 1, 2,39.1 2,518.4 3,246.2 Note: '8 '85 '9 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 (FY) Fractions smaller than.1 billion yen are dropped. 5. Changes in Materials Procurement Cost (unit: billion yen) FY '9 '91 '92 '93 '94 '95 '96 '97 '98 '99 ' '1 '2 '3 '4 '5 '6 '7 '8 '9 Total cost of Products Procurement (a) 668.1 831.1 736.7 877.4 756.4 759. 749.5 696.4 65.7 595.8 599.9 479.3 423.2 364.2 372.6 347.6 354.7 351.4 331.4 322.7 Import Cost of Overseas Products (b) 8.6 2.2 14. 21.6 67.5 48. 24.6 47.1 38.7 42.2 38.2 18.1 22.8 19.2 18.9 18.9 3.2 26.9 52. 28.9 Import Ratio (%) (b)/(a) 1.3 2.4 1.9 2.5 8.9 6.3 3.3 6.8 5.9 7.1 6.4 3.8 5.4 5.3 5.1 5.4 8.5 7.7 15.7 9. Notes: 1. FY 1994 and FY 1995: passed customs for Yokohama Thermal Power Station Units 7 and 8, and for KashiwazakiKariwa Nuclear Power Station Units 6 and 7. 2. FY 1997: passed customs for Chiba Thermal Power Station Unit 2. 3. FY 1999: passed customs for Shinagawa Thermal Power Station Unit 1 and for Futtsu Thermal Power Station Unit 3. 4. FY 2: passed customs for Futtu Thermal Power Station Unit 3. 5. FY 2628: passed customs for Futtu Thermal Power Station Unit 4. 6. FY 28: Procurement cost increased a temporary basis in relation to restoration of the KashiwazakiKariwa Nuclear Power Station. 126

IX. Rationalization and Streamlining 1. Changes in Electric Power Sales per Employee Electricity sales per employee [248 MWh per employee] [134 customers per employee] [29,274 employees] Number of employees '51 '55 '6 '65 '7 '75 '8 '85 '9'91'92 '93 '94 '95'96 '97'98'99' '1'2'3'4'5'6'7'8'9 (FY) Changes in Employees Improvement of Labor Productivity 127

2. Thermal Power Generation Efficiency (LHV: Lower Heating Value) 6 55 Kawasaki Group 2 (Unit 2) about 61% Design Thermal Efficiency by Class Kawasaki Group 1 59% Futtsu Group 3 55.3% Yokohama Groups 7 and 8 54.1% 5 45 42.4 Anegasaki Unit 1 42.7% Kashima Units 5 and 6 43.2% Futtsu Groups 1 and 2 47.2% 46.9% 4 35 197 75 Thermal Power Generation Efficiency (Steam Power Generation) 8 85 9 95 2 5 9 1 216 (FY) Note: Lower heating values (LHV) were estimated from higher heating values (HHV), using the conversion coefficient from General Energy Statistics (FY 24). (%) 5 4 3 32.7 <Reference> 3.7 International Comparison of Thermal Power Generation Efficiency 42.3 42.1 43.2 42.9 41.1 39.4 38.1 35.5 46.9 2 1 China India Australia U.S.A. South Korea Germany France Nordic Countries Japan U.K./Ireland TEPCO Notes: 1. Thermal efficiency values represent weighted average thermal efficiencies of coal, oil, and gas on the power generating end (LHV standard). 2. The thermal efficiency of independent power generation equipments is not included. 3. The figure for TEPCO is FY 29 result. Other figures are FY 26 values. Source: ECOFYS, "INTERNATIONAL COMPARISON OF FOSSIL POWER EFFICIENCY AND CO 2 INTENSITY" 128

3. Transmission and Distribution Loss Rate 4. Changes in Automatization Rate of Hydroelectric Power Stations and Substations Note: Automatization rate = (Number of automatized power stations and substations/total number of power stations and substations) 1 (%) 129

X. Technology Development and Renewable Energy 1. Research and Development (1) Main Themes of FY 21 Research and Development Plan Target a. "Putting the highest priority on ensuring safety and securing stable electric power supply" b. "Ensuring longterm energy security and preserving the global environment" c. "Offering optimized energy service, and further cultivating electricity sales" d. "Improving the profitability by reduction of unit cost and expansion of business area" Contents Aim at the acquisition of internal and external reliability by promoting the technology development that will contribute to safety of human body, public and equipment, technology development linked to creation of society's secure feeling and technology development to ensure the stable supply of electric energy and transmitting the information intensively. Carry out the company's social responsibility toward sustainable growth of society by promoting technology development, such as that to respond to the RPS Law, CO2 collection, feasibility study for storage and electric vehicles, in a forward looking manner to comply with environmental restrictions. Strive to win competition among energy industries by promoting technology development concerning electrification and highperformance products for the expanded use of system electricity such as highefficient heat pump, as well as technology development concerning energy solutions that take customer needs in advance. Promote the continuous growth as whole TEPCO group and improvement of profitability by promoting the technology development that contributes to strengthening of competitive power by reduction of supply cost and promoting the technology development to expand the business area utilizing the knowhow and equipment cultivated in the electric industry. 13

(2) Changes in Research and Development Expenditure (3) Ratio of Research and Development Expenditure to Sales (4) Changes in the Number of Patent Applications *as of April 1, 21 131

2. Electric Vehicles Number of Electric Vehicles in Fleet at TEPCO Offices At the End of FY 1991 1992 1993 1994 1995 1996 1997 1998 1999 2 21 22 23 24 25 26 27 28 29 Number (Electric Vehicle Percentage) 65 (.9%) 14 (1.4%) 13 (1.7%) 13 (1.7%) 13 (1.7%) 13 (1.7%) 13 (1.7%) 13 (1.7%) 13 (1.7%) 132 (1.7%) 139 (1.9%) 145 (2.%) 191 (2.7%) 246 (2.9%) 241 (2.8%) 235 (2.8%) 22 (2.6%) 147 (1.8%) 417 (5.1%) <Reference> Annual CO 2 Emissions per Vehicle (after 1,km run) Fuel consumpltion of light gasoline vehicle : 19.2km/L (from the internet website of Japan Mini Vehicles Association) Fuel consumption of electric vehicle : 1km/kWh (Manufacturer s published 115 mode fuel consumption, as calculated from the distance that can be traveled with a full charge and the total electric energy of the driving batteries) CO 2 emission intensity : Gasoline 2.32kgCO 2 /L (from "Enforcement Ordinance for Law Concerning the Promotion of Measures to Cope with Global Warming" Elecctricity.33kgCO 2 /kwh (target value for FY22 by electric power companies) Charge efficiency :.9 132

3. Renewable Energy (1) Sites Where TEPCO Has Introduced New Energy (as of the end of March 21) Solar Power Wind Power Futtsu Thermal Power Station, Fuji Service Center, Tsurumi Service Center, Tochigi Branch Office, Thermal Power Technical Training Center, Takasaki Service Center, Yamanashi Branch Office, Mito Service Center, Kanagawa Branch Office, Hiratsuka Service Center, Matsudo Sales Center, Otsuka Service Center, Tama Branch Office Higashimurayama Annex, Atami Sales Center, Tsuchiura Service Center, General Training Center, FujiYoshida Sales Center, Sawara Sales Center, Maebashi Service Center, Ueno Service Center, Eco Plaza Kasai TEPCO, TochigiMinami Service Center, Kanuma Office, Ibaraki Branch Office, Hitachi Sales Center, Fujisawa Service Center Kamakura Office, Izu Service Center, Narita Service Center Annex, Kumagaya Service Center, Minami Yokohama Thermal Power Station, Yokohama Thermal Power Station, Yokosuka Sales Center, Musashino Service Center Fuchu Field Office, Komahashi Control Office, Fukushima Daini Nuclear Power Station, Shinjuku Service Center, Higashi Ohgishima Thermal Power Station, Saitama Service Center, Yamato Sales Center, Adachi Sales Center, Kazunogawa Hydroelecttic Power Station (Kazunogawa Dam), Kazunogawa Hydroelecttic Power Station (KamiHikawa River Dam), Choshi Sales Center, Hitachinaka Thermal Power Station, Hirono Thermal Power Station, Research & Development Center, Yokosuka Thermal Power Station (total 47 sites, 524.3kW) Yokosuka Thermal Power Station (.6kW), MinamiYokohama Thermal Power Station (.4kW), Yokohama Thermal Power Station (4kW) 133

(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 Equipment Capacity (MW) Equipment Capacity (MW) Solar (as of the end of 28) Wind (as of the end of 28) q Germany 5,34 q U.S.A. 25,17 w Spain 3,354 w Germany 23,93 e Japan 2,144 e Spain 16,754 r U.S.A. 1,169 r China 12,21 t Italy 458 t India 9,645 y u i o! Korea France Australia Portugal Netherlands 358 18 15 68 57 y u i o! : Italy France U.K. Denmark Portugal 3,736 3,44 3,241 3,18 2,862!3 Japan 1,88 Sources: Solar: IEA/PVPS, "TRENDS IN PHOTOVOLTAIC APPLICATIONS" Wind: GWEC, "GROBAL WIND 28 REPORT" 134

(3) Issues and TEPCO R&D Milestones 135

(4) Purchase of Surplus Power from Solar, Wind and Waste Power Plants Purchases (as of the end of March 21, become effective on FY 1992) <Reference> MWh 4, 35, 3, 25, Purchase of Electricity from Solar and Wind Power Solar Power Wind Power 356,795 263,539 2, 15, 1, 5, 94 95 96 97 98 99 1 2 3 4 5 6 7 8 9 (FY) 136

MEMO 137

XI. Environmental Protection Measures 1. Changes in SOx and NOx Emissions Intensity per Power Output from Thermal Power Stations (g/kwh) 4 (g/kwh) 12 Data for 25 29 1 Sulfur Oxide (SOx) Emissions Intensity =Emissions per kwh of electricity generated by thermal power stations 3 2 1 Emissions intensity 8 6 4 3.4 3.1 2.7.8 Canada FranceGermany Italy ('5) ('5) ('5) ('5) 1.4 UK ('5) 3.3 USA ('5) 2.9 Average for 6 countries.2.9 Japan TEPCO ('8) ('9) (FY) ' 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 Nitrogen Oxide (NOx) Emissions Intensity =Emissions per kwh of electricity generated by thermal power stations (g/kwh) 3 2 1 Emissions intensity (g/kwh) 4 3 2 1 1.6 Canada France Germany Italy ('5) 3.2 ('5) Data for 25 29.8 ('5).6 ('5) 1.4 UK ('5) 1.2 1.2 USA ('5) Average for 6 countries.2.14 Japan TEPCO (FY) ' 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 ('8) ('9) Sources: Estimates are based on "OECD Environmental Data Compendium 26/27" and IEA, "Energy Balances of OECD Countries 28 edition." Figures for Japan are based on a survey of the Federation of Electric Power Companies. 138

<Reference> CO 2 Emissions per kwh of Electricity Usage (for each electric source in Japan) gco2 /kwh 1, 975 8 742 6 887 68 519 4 74 478 47 Combustion of Fuel for Electric Generation Construction of Equipment and Operation 2 88 Coal 38 Oil 13 111 LNG Solar LNG combined 53 29 15 11 Wind 25(Pressurized Water Reactor : PWR) 22(Boiling Water Reactor : BWR) Nuclear Hydro Geothermal Notes: 1. The amounts of emitted CO 2 shown are the calculated amounts of CO 2 emitted as a result of the combustion of fuels for power generation and the consumption of (all kinds of) energies for the associated mining, power generation facility construction, fuel transport and purification and operation and maintenance of facilities. The amount of emitted CO 2 for nuclear power was calculated taking into consideration the planned domestic reprocessing of spent fuels and use of pluthermal (on the premise that the number of times of recycling is one), as well as the generation of highlevel radioactive wastes. 2. Totals may not agree with the sum because of being rounded off. Source: "Report of Central Research Institute of Electric Power Industry," etc. 139

2. Changes in TEPCO's CO2 Emissions and Emissions Intensity *1 Values reflecting carbon credits. *2 Values without carbon credits. Note TEPCO's CO2 emission intensity values were calculated in accordance with the "System for Calculating, Reporting and Publishing Greenhouse Gas Emissions" established pursuant to the "Act on Promotion of Global Warming Countermeasures." The System does not take into account CO2 reduction values such as those created by tradable green certificates. <Reference> List of CO2 Emission Factor for Each Company (FY 28) kgco2/kwh.8.7.588.6.5.4.3.2.469.418.34.332.767.51.55.482.455.462.424.422.436.378.374.412.355.352.348.326.299 Actual Co 2 Emission Factor Adjusted Co 2 Emission Factor.433.1 Hokkaido Electric Power Tokyo Electric Power Kansai Electric Power Kyushu Electric Power Eneserve FPower Summit Energy Tohoku Electric Power Chubu Electric Power Shikoku Electric Power erex ENNET Diamond Power * CO 2 emission factor published based on the "Law Concerning the Promotion of the Measures to Cope with Global Warming" (published by Ministry of the Environment on December 28, 29) 14

3. Active Implementation of Green Procurement and Purchasing "the Basic Procurement Policy" which stipulates TEPCO s basic procurement policy and asks practice for our business partners, and we are promoting the social responsibility on procurement of materials in cooperation with business partners. "" "" "" <Basic Procurement Policy> TEPCO's Basic Procurement Policy What We Ask of Our Business Partners 1 Observe laws and social norms 2 Make safety the top priority 3Make environmental considerations 4Keep an open business attitude 5 Seek to be fair 6Strengthen relationships of mutual trust 1 Observe laws and social norms 2 Make safety the top priority 3 Make environmental considerations 4 Reduce prices and improve quality 5 Improve aftersale service 6 Establish delivery systems 7 Speak candidly 141

4. Internal Environmental Costs (for TEPCO alone in FY 29) Notes: 1. Expenses do not include depreciation costs. 2. Costs for power generation systems for hydroelectric, nuclear and LNG themal power, which contribute to the reduction of CO 2 emissions, are excluded since they cannot be regarded as an additional cost for environmental protection. 142

5. TEPCO's Efforts Toward Industrial Waste Recycling <Major industrial waste, by type> (FY 29) Type of Waste Waste Produced *1 1, t/year Recycling Application Coal ash 475.2 Cement raw material, land reclamation Scrapped concrete utility poles 19.7 Roadbed material, etc. Gypsum reovered through desulfurzation 9.7 Gypsum board, cement raw material, etc. Metal scrap 57.9 Metallic material, recycled cable, etc. Waste oil 8.2 Fuel substitute, heat recovery, etc. Shells 7.5 Fertilizer, cement raw material, soil conditioner, etc. Concrete scrap 1.1 Roadbed material, etc. Wastewater treatment sludge 5. Cement raw material, steel, etc. Heavy / Crude oil ash 2.6 Metal recovery, cement raw material Insulator scrap 3.3 Block, roadbed material, etc. Waste plastics 1.3 Plastic recycling, heat recovery, etc. Thermal insulation material scrap.4 Recycled thermal insulation material, roadbed material, etc. Other 11. Total 774. *1 Waste produced = salvaged material + material reused inhouse + industrial waste (Radioactive waste, which is governed by laws concerning nuclear power, is not included in industrial waste.) *2 Weight after dehydration. 143

<Changes in Industrial Waste Recycling Rate* and Landfill Disposal Volume> 5 97 99 99.7 99.9 99.9 1 99.8 99.9 1 4 35 38.8 93 93 94 94 95 95 3 3.2 29.7 92 25 89 26.3 25.8 91 9 2 15 1 5 86 199 18.2 16.4 16.4 1.3 9. 9.4 6.7 2.9 2.7 1.5.5.5.3 1.2 1. 8 1995 2 25 29 * Recycling rate= Amount recycled (Incl. the amount of valued items and of materials internally recycled) Amount produced Figures are rounded off to the first decimal place. 85 1 144

6. Overview of PCB Treatment Facilities TEPCO Yokohama Recycle Center (located adjacent to Yokohama Thermal Power Station) Japan's first fullscale PCBbased insulating oil treatment facility TEPCO Kawasaki Recycle Center (located adjacent to Higashi Ohgishima Thermal Power Station) PCBbased insulating oil decomposition treatment and polemounted transformer container cleaning facility Operation started: Decomposition treatment: Oct. 1, 22 Cleaning: Nov. 4, 23 Volume of PCBbased insulating oil treatment so far (as of the end of March 21) : Decomposition treatment: approx. 8,8kr (equivalent to 176, units*) Cleaning: approx. 483, units TEPCO Chiba Recycle Center (located adjacent to Chiba Thermal Power Station) Japan's second PCBbased insulating oil treatment facility Operation started: March 15, 22 Volume of PCBbased insulating oil treatment so far (as of the end of March 21) : approx. 4,4kr(equivalent to 88, units*) Operation started: Oct. 16. 21 Volume of PCBbased insulating oil treatment so far (as of the end of March 21) : approx. 9,kr(equivalent to 18, units*) * When converted to number of polemounted transformers with average capacity (3kVA ; oil volume 5r) * *Excluding equipments less than 1kg. 145

XII. Energy Conservation and Recycling 1. Total Energy Efficiency of District Heating and Cooling (DHC) Services (within the TEPCO service area) Makuhari Shintoshin HiTech Business Zone : 1.23 1.5 1.4 1.3 1.2 Central Zone of Takasaki City : 1.28 Harumi Island Zone : 1.24 Areas where unused energy is utilized through DHC by TEPCO subsidiaries (3 areas) (Usage of stream, ground or sewage water) DHC areas by TEPCO subsidiaries and affiliated companies (16 areas) Cogeneration waste heat method Gas method 1.1 1..9.8 DHC of TEPCO subsidiaries and affiliated companies..61.28 Cogeneration waste heat method.68.87.7.6 Gas method.57.75.5 1, 1, 1,, 1,, Amount of Heat Sold (GJ) Notes: Areas of cogeneration systeminstalled power plants were excluded. Total energy efficiency= Amount of heat sold (GJ) / Amount of raw fuels used (GJ) Total Energy Efficiency DHC areas by TEPCO subsidiaries and affiliated companies A. Usage of stream, ground or sewage water.6 1.28.95 1.28 B. Others.6 1.24 Cogeneration waste heat method.68.87 Source: "Heat Supply Industry Manual 29 edition" (actual achievement value in FY 28) Gas method.57.75 146

2. CO 2 Emission per Amount of Heat Unit Sold in District Heating and Cooling (DHC) Services (within the TEPCO service area) CO 2 Emission per Amount of Heat Unit Sold (kg CO 2 /GJ) 11. 1. 9. 8. 7. 6. 5. 4. 3. 2. Areas where unused energy is utilized through DHC by TEPCO subsidiaries (3 areas) (Usage of stream, ground or sewage water) DHC areas by TEPCO subsidiaries and affiliated companies (16 areas) Cogeneration waste heat method Gas method Gas method 64.42 9.12 Cogeneration waste heat method 53.18 68.43 DHC of TEPCO subsidiaries and affiliated companies. 26.54 59.12 Makuhari Shintoshin HiTech Business Zone : 27.65 Central Zone of Takasaki City : 26.54 Harumi Island Zone : 27.34 1. 1, 1, 1,, 1,, Amount of Heat Sold (GJ) Notes: Areas of cogereration systeminstalled power plants were excluded. CO 2 emission per amount of heat unit sold = CO 2 emission (kg CO 2 ) / Amount of heat sold (GJ) Source: "Heat Supply Industry Manual 29 edition" (actual achievement value in FY 28) 3. EnergyIIP Intensity by Industry (FY 1973=1) Note: IIP = Indices of Industrial Production Source: The Energy Data and Modelling Center (EDMC), "Handbook of Energy & Economic Statistics in Japan (21 edition)" 147

4. Energy Conservation for Major Household Electrical Appliance FY 1995 1996 1997 1998 1999 2 21 22 23 24 25 26 27 28 29 412 347 312 3 278 262 252 241 242 237 227 217 213 214 212 76 79 859 889 955 755 Total period 117 738 Total period 99 721 78 Total period 945 692 Total period 919 665 Total period 882 652 644 637 18 Total period 132 Total period 121 Total period 1159 Total period 168 Total period 947 Total period 963 Total period 865 Total period 858 Total period 849 Total period 1492 Power consumption of cooling Power consumption of heating Quoted from standard of Japan Refrigeration and Air Conditioning Industry Association JRA446 (calculation standard for period power consumption of room air conditioners) Source: Japan Refrigeration and Air Conditioning Industry Association 5 1 15kWh Power Consumption 148

Source: The Energy Conserration Center, Japan, "Energy Efficiency Catalog 29 summer/winter edition" <Reference> Power Consumption Comparison for Household Appliances Dish Washing and Drying Machine 1.6% Cloth Drying Machine 2.8% Toilet Seat with Washing Device by Heated Water 3.9% Electric Carpet 4.3% Others 2.2% Air Conditioner 25.2% Refrigerator 16.1% Television 9.9% Lighting 16.1% Note: As the percentages are rounded off, total is not 1%. Source: Agency for Natural Resources and Energy, "Outline of power demand in FY 24" (Estimated performance in FY 23) 149

<Reference> Comparison of Environmental Performance of Heating Appliance kgco 2 /MJ (Yen/MJ).7.68 3.5.6.5.51 2.8 3. 2.5.4 2. 2..3.2.17 1.2.14 1. 1.5 1..1.5. CO 2 Cost CO 2 Cost CO 2 Cost CO 2 Cost. Standard Air Conditioner COP 5.28 High Efficiency Air Conditioner COP 6.21 Oil Heater Gas Stove Comparison of CO 2 Emission and Running Cost per 1MJ for Heating [* Condition of estimation] 1. CO 2 emission intensity: "Act on Promotion of Global Warming Countermeasures" (Operatorspecific Emission Factor)(The values for electrical heating appliances are based on actual data taken by TEPCO in FY 29 (factor after adjustment)) 2. Electric power rate: TEPCO "metered lighting B" second stage electric power rate unit price (as of March 21) 3. Oil price: "Survey on the price (shop price including consumption tax) of kerosene for consumer use (sold at other than filling stations) (Kanto Bureau)," (March 21) The Oil Information Center, The Institute of Energy Economics, Japan 4. Gas rate: gas rate table B for general contract with Tokyo Gas in Tokyo area and its vicinities (March 21) 5. Equipment efficiency: heating by standard air conditioner COP5.28, heating by high efficiency air conditioner COP6.21, and efficiency of oil heater/gas stove 1.. 6. For air conditioner, the value is estimated at outdoor air temperature 7 C as is the JIS standard condition. At outdoor air temperature 2 C, estimated value of CO 2 emission of high efficiency air conditioner is.28[kgco 2 /MJ], and the cost is 2.[Yen/MJ]. * MJ (Mega Joule): Thermal unit. For example, required amount of heat per hour for 1 tatami mat room is 1.8[MJ], derived from heating load of living room (ground floor) (185[W/m 2 ]) specified in Society of Heating, AirConditioning and Sanitary Engineers of Japan Standards (SHASES). 15

5. Major Electrical Appliances and Systems TEPCO is Recommending "" "" Actual Achievement and Target of Number of "FullyElectrified Homes" (within TEPCO service area) (thousand) 2 15 136 142 143 114 1 94 5 25 26 27 28 29 (FY) * Number of FullyElectrified Home... number of homes that adopt FullyElectrified Home for new residences and existing residences Transition of Cumulative Number of "FullyElectrified Homes" (within TEPCO service area) (thousand) 75 7 65 6 55 5 45 4 35 3 25 2 15 1 5 742 598 456 32 26 25 26 27 28 29 (End of FY) 151

" " "" "" "" Histrical Trend "Eco Cute" Cumulative Shipment Figures (Nationwide) (thousand) 2,5 2,25 2, 1,74 1,5 1,24 1, 83 5 48 25 26 27 28 29 (FY) Source: Japan Refrigeration and Air Conditioning Industry Association 152

"" (CO 2 /year ) 1,1, 1,, 9, 8, 7, 6, 5, 4, 3, 2, 1, 25 26 27 28 29 (FY) < Calculation conditions > 1. Hot water load : Institute for Building Environment and Energy Conservation (IBEC) : amount of hot water (43 C) equivalent in L mode (421 liters/day) + energy for maintaining bath temperature (6.7MJ/day). 2. Outdoor air temperature, hot water temperature : Following Japan Refrigeration and Air Conditioning Industry Association (JRAIA) standard (JRA45 : 27R) 3. Electricity consumption : Assumed 3 liters fullauto (heaterless temperature maintaining) type in energysaving mode, calculating electric power for three periods (intermediate, winter, summer) including device efficiency, defrosting and loss final boiling. 4. Gas consumption : Conventional fuelburning water heater (city gas) device efficiency about 8% (based on Tokyo Gas catalog). 5. Basic unit of CO 2 emission : Electricity (actual yearly data of TEPCO), City gas "Law Concerning the Promotion of Measures to Cope with Global Warming Enforcement Order" Accumulated Number of "Eco Cute" (within TEPCO service area) 153

The "FullyElectrified Kitchen" is changing the way we look at this part of the house, making it into a more comfortable environment. Playing a starring role in the "FullyElectrified Kitchen" is the IH Cooking Heater. It offers strong cooking power that makes easy work of fried and boiled foods as well as steaks and broiled fish. The "FullyElectrified Kitchen" is also easy to clean and keep spotless around the kitchen. In addition, the IH Cooking Heater has many safety features, so households with elderly members or children could use it with ease. TEPCO recommends the IH Cooking Heater for making a daily life much easier. Historical Trend of IH Cooking Heater Cumulative Shipment Figures (nationwide) (thousand) 7,5 6,56 6, 5,72 4,83 4,5 3,98 3, 3,15 1,5 Source: 25 26 27 28 29 (FY) Japan Electric Machine Industry Association "" "" 154

"" "" "" <Reference> Increase of Heat Storage Air Conditioning Systems (cumulative) (homes) 1, 1, 9,4 9, 8,9 8, 8,4 7,42 7, 6,7 6, 5,55 6,17 5, 4,87 4, 4,15 3,3 3, 2,46 2, 1,48 1,7 1,99 1, 1995 1996 1997 1998 1999 2 21 22 23 24 25 26 27 28 29 FY * Peak shift cumulative kilo wattage from use of heat storage air conditioning systems at the end of FY 29 was approximately 92MW. 155

XIII. Related Businesses 1. Affiliated Companies (as of the end of March 21) Employees Date Established Capital (including Company Name Description of Major Business Phone (month/year) (million yen) temporary workers) The Tokyo Electric Generation Company, Incorporated Supplying electricity from hydroelectric power July 1928 2,5 217 3637152 Kimitsu Cooperative Thermal Power Company, Inc. Supplying electricity from thermal power June 1967 8,5 119 439521361 Electricity Power Generation KASHIMA KYODO ELECTRIC POWER Co., Ltd. Soma Kyodo Power Company, Ltd. Joban Joint Power Co., Ltd. Supplying electricity from thermal power Supplying electricity from thermal power Supplying electricity from thermal power December 1969 June 1981 December 1955 22, 112,8 56, 131 141 171 2997554 2443612 332565411 The Japan Atomic Power Company Supplying electricity from nuclear power November 1957 12, 1,38 3637174 Telecommuni cations FAMILYNET JAPAN CORPORATION Internet connection service for multiunit housing (condominiums, etc.) October 2 27 62 3577414 Cable Television Broadcasting TEPCO CABLE TELEVISION Inc. Cable television and radio broadcasting November 1989 8,775 83 486387 Information Communication Construction and Maintenance of Information Communication Equipment TEPCO OPTICAL NETWORK ENGINEERING INC. TEPCO SYSTEMS CORPORATION TEPCO Uquest, Ltd. Construction and maintenance operation for FTTHrelated equipment in electricityrelated facility (transformer station etc.), connection of optical fiber cable, construction work for diverging devices Computer system planning, development, maintenance and operation Embedded software December 26 July 1977 October 23 15 35 2 222 1,788 63 33432577 363641117 3358551 AT TOKYO Corporation Data center service June 2 13,378 195 363723 IT Software and Services TOKYO RECORDS MANAGEMENT CO., INC. Japan emarket Co., Ltd. TEPSYS SOLUTIONS CORPORATION Commissioned production, storage, management of information records Electrionic marketplace Development and maintenance of computer software September 1987 2 December 2 1,5 43 363722 13 357652375 October 29 9 29 363728 JAPAN CABLENET HOLDINGS LIMITED Cable TV business holding company March 21 32,5 1,827 34284721 Japan Digital Serve Corporation Digital broadcasting and distribution, broadband content distribution April 2 2,25 44 355737151 Tepco Office Service Corporation Information processing service business related to electricity rate etc. June 1999 1 1,31 3637113 156

Employees Date Established Capital Company Name Description of Major Business (including Phone (month/year) (million yen) temporary workers) TODEN KOGYO CO., LTD. Tokyo Electric Power Environmental Engineering Company, Incorporated Tokyo Electric Power Services Company, Limited (TEPSCO) Tokyo Densetsu Service Co., Ltd. Inspection and maintenance of thermal and nuclear power generation equipment, construction and maintenance of power transmission and conversion equipment and civil engineering and construction equipment, nonlife insurance agent Thermal and nuclear power station environmental protection, facility operations and maintenance, industrial waste, environmental studies, measurements and assessments Civil engineering, construction and electric facility design and supervision Power generation, transmission and conversion equipment patrolling, inspection and repair April 1954 November 1955 December 196 September 1979 3 3 4 5 1,37 1,399 668 912 3637248 363727 363725111 363713 Energy and Environment Facility Construction and Maintenance Tokyo Electric Power Home Service Company, Limited (TEPCO HOME SERVICE CO., LTD.) TOSETSU CIVIL ENGINEERING CONSULTANT Inc. KANDENKO CO., LTD. Turnover operation, publicity of blackout, consultation related to use of electricity and operation related to demand development, design, inspection tour and check of distribution installation, completion check after the construction of distribution installation, registration of distribution installation, unit contract of update operation, installation, sales and mediation of electric water heater etc. Civil engineering construction service Construction and maintenace of power generation transmission, conversion and distribution facilities and communication facilities, thermal power and nuclear power station electric and instrumentation work, internal phone line and air conditioning system work September 1982 October 1983 September 1944 2 1 1,264 2,599 83 6,848 3637266 35857261 354762111 SHINNIHON HELICOPTER CO., LTD. Patrolling of power transmission lines by helicopter, shipping of construction materials July 196 25 12 33567326 JAPAN NUCLEAR SECURITY SYSTEM CO., LTD. Design buiding, leasing and operation of scientific security systems for nuclear powerrelated facilities, security for nuclear fuel shipping July 1977 2 54 363723 Transmission Line Construction Co., Ltd. (TLC) Construction of electric facilities for power transmission, communication, etc. May 22 98 195 3436615 Tokyo Keiki Kogyo Co., Ltd. Repair and replacement of business meters April 1951 1 249 36372422 TEPCO LOGISTICS CO., LTD. Transportation of power distribution materials, management of materials warehouse, etc. July 1977 5 535 3636179 Materials and Equipment TOKO ELECTRIC CORPORATION TAKAOKA ELECTRIC MFG. CO., LTD. Electric machinery and appliance manufacturing and sales, repair and replacement of business meters, electric utility work in buildings and other construction Manufacture, construction, repair and sales of substation equipment, transformers, SF6 gas insulated transformers, power equipment remote monitoring system and high speed 3dimensinal inspection system for electronics applications, etc. September 1928 March 1918 1,452 5,96 924 1,215 36371438 363715 Toshiba Toko Meter Systems Co., LTD Development, production and sales of measuring instruments (including some components of measuring instruments) December 29 48 168 36371433 157

Employees Date Established Capital (including Company Name Description of Major Business Phone (month/year) (million yen) temporary workers) TEPCO RESOURCES INC. TEPCO Australia Pty. Ltd. TEPCO Trading Co., Ltd. Uranium excavation and refing Investment and financing in overseas project companies Purchase and sales of LNG April 1997 March 23 January 26 74,6 C$1, 51, US$1, 1 6 2 3359723 RecyclableFuel Storage Company Pacific LNG Shipping Limited Storage and management of spent fuel from nuclear power plants, and incidental businesses Ownership of LNG tankers November 25 December 2 3, 3,755 48 17525299 Pacific LNG Yuso Limited Operation and management of LNG tankers April 21 95 35517181 Pacific Eurus Shipping Limited Ownership of LNG tankers February 22 3,74 Transocean LNG Yuso Limited Operation and management of LNG tankers December 22 95 35517181 LNG Marine Transport Limited LNG marine transport service October 24 46 11 35517181 Cygnus LNG Shipping Limited Ownership of LNG tankers November 25 4,2 Energy and Environment Supply and Transportation of Fuel Tokyo Timor Sea Resources Inc. (U.S.A.) NANMEI KOUSAN Co., Ltd. TEPCOYu Company, Limited TEPSTAR CO., LTD. Stock owned by Tokyo Timor Sea Resources Pty Ltd (Australia) Sales and marine shipping of heavy oil, etc., thermal power station disaster prevention and security, LNG import representative operation Sales of heavy oil, etc., automobile leasing, lease of institutional use electric appliance etc. Sales of heavy oil, etc., sales of miscellaneous industrial products June 23 March 1955 June 1957 December 1949 39, US$1, 4 1 2 4 53 163 38 3637126 3637186 363618181 TEPCO Darwin LNG Pty. Ltd. Investment in plant and pipeline projects of BayuUndan gas field development project March 23 62,483 A$1, Tokyo Timor Sea Resources Pty. Ltd. (Australia) Participation in gas field development projects June 23 316,668 A$1, NANSO SERVICE CO., LTD. Thermal power station disaster prevention and security, fuel payment acceptance August 1979 2 95 24272497 Japan Nuclear Fuel Limited Reprocessing of spent nuclear fuel March 198 2, 2,361 175712 Pacific Hope Shipping Limited Ownership of LNG tankers August 25 4,71 Japan Coal Development Co., Ltd. Surveying, exploration, development, import and sales of coal resources overseas for electric power January 198 5,2 18 334314781 Nuclear Fuel Transport Company, Ltd. Handling and land and marine transport of spent fuel, radioactive waste, etc. from nuclear power stations, etc., as well as related cargo shipping and handling, ship transporation, etc. April 1973 1,6 117 334383241 CELT Inc. Purchase and sales of LNG January 26 1 158

Company Name Description of Major Business Date Established Capital Employees (including (month/year) (million yen) temporary Phone workers) TOKYO TOSHI SERVICE COMPANY Operation, maintenance and management of heat supply equipment September 1987 4 289 3636151 Bio Fuel Co., Inc. Fuel processing facility planning, design, building, operations and maintenance, and development of biomass and other renewable resources March 25 49 16 35665912 KAWASAKI STEAM NET CO., LTD. Sales and supply of steam, design, construction, operation, maintenance and management of equipment such as steam supply piping October 26 16 453214682 Morigasaki Energy Service Co., Ltd. Electric power and hot water supply and power load adjustment for Tokyo Bureau of Sewerage Morigasaki Wastewater Treatment Center October 22 31 2 33741785 Isehara Energy Service Co., Ltd. Electric power, cold water, steam and other energy supply to Tokai University Isehara Campus March 23 15 Energy and Environment Energy and Environmental Solution TOKYO WATERFRONT RECYCLE POWER CO., LTD. Hitachi Heat Energy Co., Ltd. Japan Natural Energy Company Limited Haneda Solar Power Co., Ltd. Power generation from gasfication/ melting, etc. at Tokyo Super Ecotown Project Heat supply business Service accepting commissions to generate power from natural energy sources Energy supply service to cargo terminals for international airlines in Haneda Airport utilizing photovoltaic power December 22 March 1988 November 2 September 28 11,82 25 395 5 62 11 7 36327319 294246338 3351351 363724849 JAPAN FACILITY SOLUTIONS, Inc. ESCO services, diagnoses and consulting, facility renovation December 2 49 57 352292911 Kanto Natural Gas Development Co., Ltd. Development, extraction, supply and sales of oil and combustible natural gas May 1917 7,92 152 332415511 AOYAMA ENERGY SERVICE Co., Ltd. Heat supply business August 1989 3 6 3349788 Fuchu D.H.C. Co., Ltd. Heat supply business July 1989 48 7 42337521 CLEAN COAL POWER R&D CO., LTD. All tasks incidental to testing and research of IGCC (integrated gasification combined cycle) power generation June 21 1 65 246773111 Tokyo Heat Energy Co., Ltd. Heat supply business April 1985 1 5 335812541 Tas Forest Holdings Pty. Ltd. Afforestation November 1995 11,335 A$1, 159

Employees Date Established Capital Company Name Description of Major Business (including Phone (month/year) (million yen) temporary workers) TODEN REAL ESTATE Co., Inc. Rental and management of office space, company housing and housing for single individuals April 1955 3,2 713 3637211 OZE Corporation Protection and study of natural environment, planting of vegetation, in Oze/ Urabandai area,etc. February 1951 6 13 363711 Real Estate TEPCO Land Management Corportation ReBITA Inc. Utility pole site work, management of power transmission line sites and other land owned by TEPCO, acquisition of power transmission line sites. Purchase, updating and sale of older homes Home updating consulting service July 28 May 25 1 1 88 58 3637111 354689225 MutsuOgawara Habitat Inc. Ownership, management, sale and brokering of real estate, and management, repair, security, cleaning, etc. of real estate November 1991 1 4 175723776 Toso Real Estate Management Co., Ltd. Leasing/ borrowing, purchase, sale and brokering of real estate, and management, repair, security, cleaning, etc. of real estate October 1982 2 171 24325596 Living Environment and LifestyleRelated TF Service Co., Ltd. Tokyo Living Service Co., Ltd. TEPCO PUBLIC RELATIONS CO., LTD. TEPCO HUMMING WORK CO., LTD. CareerRise Corporation Construction contracting, design and supervision, land and building maintenance and management Rental and management of public welfare facilities, company housing, housing for single individuals, gym facilities, management of workplace facilities, consulting on housing and life welfare Management of TEPCO Electric Energy Museum Printing, copying, cleaning, gardening service and others Job placement, temporary staffing December 1966 April 198 April 1984 October 28 June 2 9 5 5 6 2 65 977 446 81 337 358471411 3637156 354456886 4284873 36371568 Tepco Town Planning Corporation Limited Redevelopment and city planning, and consulting, design and building of underground facilities August 21 3 85 35925766 Service The TEPCO Reinsurance Company PCC Limited Tepco Partners Co., Inc. Exclusive reassurance of TEPCO Group Nursingcare insurance business and training related October 22 January 26 12 1 1,17 356217333 TODEN LIFE SUPPORT CO., LTD. Planning, operating and managing feebased nursing home October 2 489 18 334564165 Toden Kokoku Co., Ltd. Utility pole advertising, power distribution line blueprint revision and management, creation of PR plans, agency sales for cell phone communication devices October 1931 2 597 363718111 TEPCO CALL ADVANCE Inc. Contract telephone response and related consulting services, telemarketing planning and sales July 23 15 1,681 36371833 GoodServ Co., Ltd. Agent for various home and office services, including housecleaning August 21 15 45 352835111 Houseplus Corporation, Inc. Building performance evaluation and assurance February 28 97 96 357771434 Kankyou Bika Center Inc. Cleaning of utility pole, buildings, etc. April 1978 15 83 33521381 16

Living Environment and LifestyleRelated Oversea Business Service Oversea Business Employees Date Established Capital Company Name Description of Major Business (including Phone (month/year) (million yen) temporary workers) ATEMA KOGEN RESORT INC. Hotel and golf course management February 1989 1 187 257584888 The Japan Utility Subway Company, Incorporated Daido Industrial Arts Co., Ltd. Houseplus Archtectual Inspection, Inc. Tokyo Electric Power Company International B.V. Eurus Energy Holdings Corporation Tokyo Electric Power Company International Paiton I B.V. TM Energy (Australia) Pty. Ltd. Tokyo Electric Power Company International Paiton II B.V. CIPIGP Ltd. Capital Indonesia Power I C.V. Japan Uranium Management Inc. SAPJapan Co., Ltd. Design, construction and management of common tunnel monitoring systems Creation of utility pole advertising products Confirmatory test pursuant to the Building Standard Law Investment in afforestation projects Supervision and management of wind energy projects, etc. in Japan and abroad Investment in IPP business company in Indonesia Power generation in Australia Investment in IPP business company in Indonesia Investment in IPP business company in Indonesia Investment in IPP business company in Indonesia Owns shares of Uranium One Inc (in Canada) Invests to a management company (in Kazakhstan) of sulfuric acid manufacturing plants January 1986 October 1953 November 1999 July 1999 November 21 May 25 February 22 May 25 January 1995 December 1994 January 29 December 28 1,4 1 3 24, 1, 18,199 34 1, 88,5 A$1, 18 1, 12 USR1, 275.5millon C$ 1 51 3 54 181 336637611 363726969 357771416 35561658 Loy Yang Marketing Holdings Pty. Limited Management and holding company trading electric power generated at the Loy Yang A thermal power station in Australia July 23 25 A$ 21 ITM Investment Company Limited Investment in Umm Al Nar power generation and water desalination project February 23 16 US$1, Great Energy Alliance Corporation Pty. Limited Project company set up to purchase the Loy Yang A thermal power station in Australia June 23 316,5 A$1, 566 ITM O&M Company Limited Operation and maintenance of power generation and desalination equipment at Umm Al Nar power generation and desalination project February 23 AED 318 Star Buck Power Corporation IPP business in Taiwan August 26 3.3 billion TWD 58 TeaM Energy Corporation IPP business in Phillippine December 199 12,162 US$1, 756 161

2. New Businesses Company Name Profile Japan Digital Serve Corporation Digital broadcasting and distribution, broadband content distribution Date Established April 1, 2 (as of the end of May 21) Capital (million yen) 2,25 TEPCO Ownership 18.3% AT TOKYO Corporation Data center service June 26, 2 13,378.5 81.2% Information / Communications FAMILYNET JAPAN CORPORATION Japan emarket Co., Ltd. JAPAN CABLENET HOLDINGS LIMITED Internet connection service for multiunit housing (condominiums, etc.) Electrionic marketplace Cable TV business holding company October 6, 2 Capital injection of TEPCO was on September 3, 24 December 14, 2 March 8, 21 27 1,5 32,5 87.1% 23.% 23.% TEPCO UQUEST, LTD. Embedded software October 31, 23 2 96.7% Japan Natural Energy Company Limited Green Power Certification project (Accept commissions and recommission of power generation from natural energy sources November 1, 2 395 58.% Energy & Environment JAPAN FACILITY SOLUTIONS, Inc. Gas Business Company [internal organization] Bio Fuel Co., Inc. ESCO services, diagnoses and consulting, facility renovation Gas supply for highvolume customers Development of biomass energy Design, building, operation and maintenance of fuel processing facility Transaction and transportation of fuel December 14, 2 March 1, 22 March 15, 25 49 49 45.% 1.% Living Environment and LifestyleRelated Houseplus Corporation, Inc. CareerRise Corporation TODEN LIFE SUPPORT CO., LTD. Tepco Town Planning Corporation Limited TEPCO CALL ADVANCE Inc. ReBITA Inc. Housing performance indication service, housing defects warranty liability insurance service Houseplus Architectual Inspection, Inc. Confirmatory test pursuant to the Building Standard Law November 3, 1999 3 4.4% Job placement, temporary staffing, training, backoffice service, specified management service Planning, operating and managing feebased nursing home Redevelopment and city planning, and consulting, design and building of underground facilities Contract telephone response and related consulting services, telemarketing planning and sales Renovation service (Updating and sale of old houses) February 1, 28 June 2, 2 October 26, 2 August 1, 21 July 1, 23 May 13, 25 97 2 49 3 15 1 59.6% 1.% 95.% 1.% 8.% 96.% TEPCO Partners Co., Inc. Visiting care, care management, visiting nursing, day service January 23, 26 1 83.4% 162

<Reference> Outline of TEPCO Gas Business (billion yen) 1 Results for Sales 9 8 76.1 7 6 58. 5 4 3 31.5 42.8 2 1 2.8 7.9 15.4 23 24 25 26 27 28 29 (FY) 163

XIV. Other Data 1. Energy Dependency of Major Countries (27) Energy Dependency (%) 1 8 6 4 2 2 4 6 82.4% 95.8% Japan 85.2% 85.2% 69.7% 58.6% 48.6% 92.1% 28.8% 38.2% Italy Germany France U.S.A. China Nuclear energy is included in domestic energy. Nuclear energy is not included in domestic energy. 6.9% 7.7% 16.6% U.K. 24.4% Canada 44.3% 53.4% Russia 8 1 81.9% 75.8% Note: Canada and Russia are net exporting countries. Sources: IEA, "Energy Balances of OECD Countries 29 edition" IEA, "Energy Balances of NonOECD Countries 29 edition" 2. Composition of Primary Energy Sources in Major Countries (27) (%) Coal Oil Gas Nuclear Renewable Electricity Energy Imports Total Notes: 1. Minus mark in electricity imports column indicates exports. 2. Total may not work out to be 1 because of rounding off. 3. Renewable energy includes geothermal, solar, hydro, and wind energy sources, etc. Source: IEA, "Energy Balances of OECD Countries 29 edition" 164

<Reference> Japan's Energy SelfSufficiency Rate (%) Note: Selfsufficiency rate (%) = Domestic energy 1 Domestic energy + Imported energy Source: IEA, "Energy Balances of OECD Countries 29 edition" <Reference> SelfSufficiency Rate by Energy Source (27) (%) <Reference> Import and Export of Electricity Related to France (27) (GWh) Note: Number data above reflects balance of electricity import and export between France and each country. Source: Japan Electric Power Information Center, Inc., "Overseas Electric Power Industry statistics 29" 165

3. Japan Energy Supply and Demand Outlook (1) Final Energy Consumption Actual (unit : million kl of crude oil equivalent) Outlook FY 199 FY 25 Reference Case FY 22 Energy Conservation Development Case Reference Case FY 23 Energy Conservation Development Case % % % % % % Total 359 1% 413 1% 41 1% 375 1% 391 1% 345 1% Industrial 181 5% 181 44% 18 45% 177 47% 179 46% 174 5% Residential & Commercial 95 26% 134 32% 134 34% 121 32% 13 33% 13 3% Residential 43 12% 56 14% 56 14% 52 14% 56 14% 47 14% Commercial 52 15% 78 19% 78 2% 68 18% 74 19% 56 16% Transport 83 23% 98 24% 86 22% 78 21% 82 21% 69 19% Source: Total Resource Energy Committee, "Outlook for Longterm Energy Supply and Demand (August 29)" (2) Primary Energy Supply Actual (unit : million kl of crude oil equivalent) Outlook Primary Energy Domestic Supply Energy Sourse FY 199 FY 25 Reference Case FY 22 Energy Conservation Development Case 58 588 596 553 Quantity % Quantity % Quantity % Quantity % Reference Case FY 23 Energy Conservation Development Case 59 515 Quantity % Quantity % Oil LPG Coal Natural Gas Nuclear Hydro Geothermal New Energy Sources, etc. 265 52% 19 4% 85 17% 54 11% 49 1% 22 4% % 13 3% 255 43% 18 3% 123 21% 88 15% 69 12% 17 3% 1 % 16 3% 215 36% 18 3% 12 2% 14 17% 99 17% 19 3% 1 % 22 4% 19 34% 18 3% 17 19% 89 16% 99 18% 19 3% 1 % 3 5% 24 35% 18 3% 119 2% 94 16% 17 18% 19 3% 1 % 29 5% 168 33% 17 3% 92 18% 71 14% 17 21% 2 4% 2 % 38 7% Source: Total Resource Energy Committee, "Outlook for Longterm Energy Supply and Demand (August 29)" 166

4. Long Term Supply and Demand Outlook for Electric Power (1) End of Fiscal Year Equipment Capacity (electric companies) (unit : GW) Actual Outlook FY 22 FY 23 FY 199 FY 25 Energy Conservation Energy Conservation Reference Case Development Case Reference Case Development Case Installed Capacity 172.12 241.37 257.82 28.54 288.21 295.77 Enegy Source Quantity % Quantity % Quantity % Quantity % Quantity % Quantity % 14.9 6% 143.3 59% 138.31 54% 137.61 49% 142.3 49% 12.9 41% Oil, etc. 53.47 31% 46.62 19% 42.6 16% 42.6 15% 42.6 15% 42.6 14% Coal 12.23 7% 37.67 16% 37.58 15% 37.88 14% 38.43 13% 3.3 1% LNG 38.39 22% 58.74 24% 58.67 23% 57.67 21% 61.81 21% 48.81 17% Pumped Storage Type Geothermal New Energy Sources 31.48 36.32 19.31 17.1.24 18% 21% 11% 1% % 49.58 45.74 2.61 25.13.52 21% 19% 9% 1% % 6.15 49.13 21.58 27.55.53 23% 19% 8% 11% % 6.15 49.25 21.7 27.55.53 21% 18% 8% 1% % 63.15 49.33 21.58 27.75.53 22% 17% 7% 1% % 63.15 5.77 23.2 27.75 1.2 21% 17% 8% 9% % 2.5 1% 9.7 4% 33. 12% 32.9 11% 59.75 2% Source: Total Resource Energy Committee, "Outlook for Longterm Energy Supply and Demand (August 29)" (2) Power Generation (electric companies) (unit : TWh) Electrical Energy Output Energy Source Thermal Oil, etc. Coal LNG Nuclear Hydro Conventional Pumped Storage Type Geothermal New Energy Sources Others Nonfossil Energy (Republication) Actual FY 199 FY 25 737.6 Outlook FY 22 FY 23 Energy Conservation Energy Conservation Reference Case Development Case Reference Case Development Case Quantity % Quantity % Quantity % Quantity % Quantity % Quantity % 446.6 61% 594. 6% 622.4 53% 47.1 45% 59. 49% 38. 32% 21.8 71.9 163.9 21.4 88.1 78.8 9.3 1.5 29% 1% 22% 27% 12% 11% 1% % 17.2 252.9 233.9 34.8 81.3 71.4 9.9 3.2 5.6 4.4 988.9 11% 26% 24% 31% 8% 7% 1% % 1% % 236.8 38.6 1,172.8 1,46. 77. 434.5 83.2 77.5 5.7 3.4 29.4 7% 2% 26% 37% 7% 7% % % 3% 48.5 19.5 231.1 434.5 8.5 78.1 2.4 3.4 57.5 5% 18% 22% 42% 8% 7% % % 5% 242.6 276.7 1,24.9 7.7 469.4 82.8 77.5 5.4 3.4 59.2 6% 2% 23% 39% 7% 6% % % 5% 36.3 134.6 137.1 469.5 88.9 83.4 5.4 7.5 9.7 964.6 291. 39% 476.2 4% 55.5 47% 575.9 55% 614.8 51% 656.6 68% 4% 14% 14% 49% 9% 9% 1% 1% 9% Source: Total Resource Energy Committee, "Outlook for Longterm Energy Supply and Demand (August 29)" 167

5. Security Index of Various Countries (27) (%) Dependent Ratio Imported Energy Dependent Ratio Oil Energy Dependent Ratio Imported Oil Dependent Ratio Imported Crude from Hormuz Oil Consumption (M ton) Japan U.S.A. United Kingdom Germany France Canada Italy Sweden India China Russian 82.4 28.8 16.6 58.6 48.6 53.4 85.2 33.4 24.2 7.2 83.1 44.8 38.9 32.6 31.5 31.6 35.1 42.1 26.4 32.5 2.2 19.9 99.6 65.1 16.4 95.7 98.7 7.4 91.6 1. 72.2 47.5 27.1 72.5 1.9.4 2.4 1.6 8.7 11.3. 221.8 884.5 78.7 118.3 92.2 12. 8.9 14.5 12.1 375.7 13.4 Notes: 1. Minus mark indicates exports. 2. The figures in the "Dependent ratio imported crude from Hormuz" column are figures for imports from Saudi Arabia, Iran, Qatar, Kuwait, UAE, Bahrain and the neutral zone. 3. OPEC countries include Saudi Arabia, Iran, Qatar, Kuwait, UAE, Iraq, Indonesia, Algeria, Angola, Nigeria, Venezuela, Libya, and the neutral zone. (The Ecuador's membership right was suspended at OPEC's general assembly in 1992, and Ecuador regained its membership in 27.) (Gabon joined the Organization in 1975, and the withdrawal from OPEC was approved at OPEC's general assembly in 1996.) 4. The figures in the "Dependent ratio imported crude from Hormuz" column are figures for 29. The figure for Japan does not match the figures shown in the table below because Japan uses a different statistical methodology. 5. The figures in the "Oil consumption" column are the amounts of oil consumed in FY 28. Sources: IEA, "Energy Balances of OECD Countries 29 edition" IEA, "Energy Balances of NONOECD Countries 29 edition" IEA, "Oil, Gas, Coal and Electricity 1Q29" BP, "BP Statistical Review of World Energy 29" 6. Changes in Japan's Crude Oil Imports and Security Index FY 1973 1979 1985 199 1995 2 22 23 24 25 26 27 28 Crude Oil Imports (million kl) Dependent Ratio Crude Oil from Middle East (%) Dependent Ratio Crude Oil from OPEC (%) Dependent Ratio Crude Oil from Hormuz (%) 288.61 277.14 197.26 238.48 265.53 254.6 241.9 244.85 241.81 249.1 238.65 242.3 234.41 ( 16.9) ( 2.6) (7.4) (13.1) (3.) (2.4) (.9) (1.2) (1.2) ( 3.) (4.2) (1.4) (3.1) 77.5 75.9 68.8 71.5 78.6 87.1 85.3 88.5 89.5 89.1 88.9 86.4 87.8 92.9 87.5 71.6 78. 79.9 87.6 85.6 9.4 91.9 9. 9.3 87.7 88.2 75.3 66.3 56.7 63. 71.4 81.1 79.3 83.9 85. 85.4 86. 83.1 84. Notes: 1. Figures in parentheses for crude oil imports represent the rate of increase against previous year. 2. The figures in the "Dependent ratio imported crude from Hormuz" column are figures for imports from Saudi Arabia, Iran, Qatar, Kuwait, UAE, Bahrain and the neutral zone. 3. OPEC countries include Saudi Arabia, Iran, Qatar, Kuwait, UAE, Iraq, Indonesia, Algeria, Angola, Nigeria, Venezuela, Libya, and the neutral zone. (The Ecuador's membership right was suspended at OPEC's general assembly in 1992, and Ecuador regained its membership in 27.) (Gabon joined the Organization in 1975, and the withdrawal from OPEC was approved at OPEC's general assembly in 1996.) Sources: "Oil Reference Monthly Report" "Yearbook of Metal Resources and Petroleum Products Statistics" 168

7. Power Generation Costs for Each Power Source Trial calculations by Advisory Committee on Energy and Natural Resources, Electricity Industry Committee of Advisory Committee for Natural Resources and Energy (January 24) < based on operations commencing FY 22 > <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 $ $$ "" 169

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