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Annual Rept 1978
	ML17317B488
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Site:	Cook
Issue date:	12/31/1978
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ZQ 2. RQE 8Q 2'RQ ODEUM 0 K,K ANNUALREPORT l978 No'ncE AMERICAN ELECTRIC POWER SYSTEM THE ATTACHED FILES ARE OFFICIAL RECORDS OF THE DIVISION OF DOCUMENT CONTROL. THEY HAVE BEEN CHARGED TO YOU FOR A LIMITED TIME PERIOD AND MUST BE RETURNED TO THE RECORDS FACILITY BRANCH 016. PLEASE DO NOT SEND DOCUMENTS CHARGED OUT THROUGH THE MAIL. REMOVAL OF ANY PAGE(S) FROM DOCUMENT FOR REPRODUCTION MUST

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The Company's Annual Report Mr. H. D. Post (Form 10-K) to the Securities and Assistant Treasurer Exchange Commission willbe available American Electric Power on or about March 31, 1979 to shareowners Service Corporation upon their written request and at no cost. 2 Broadway Please address such requests to: New York, N. Y. 10004 Transfer Agent of Cumulative Prcfcrred Stock Morgan Guaranty Trust Company of New York 30 West Broadway, New York, N. Y. 10007 Registrar of Cumulative Preferred Stock Irving Trust Company 1 Wall Street, New York, N. Y. 10015

INDIANA & MICHIGAN ELECTRIC COMPANY 2101 Spy Run Avenue, Fort Wayne, Indiana 46801 Contents Background of the Company 4 Consolidated Summary of Operations 5 Management's Comments on Consolidated Summary of Operations 6-7 Auditors'pinion 8 Consolidated Statement of Income ~ ~ ~ 9 Consolidated Balance Sheet 10-11 Consolidated Statement of Sources of funds for Plant and Property Additions 12 Consolidated Statement of Retained Earnings 13 Notes to Consolidated Financial Statements 14-23 Operating Statistics and Balance Sheet Data 24-25 Directors and OfBcers of the Company . ~ ~ ~ ~ ~ 26 Price Range of Cumulative Preferred Stock ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 27

INDIANA & MICHIGAN ELECTRIC COMPANY 2101 Spy Run Avenue, Fort Wayne, Indiana 46801 Background of the Company INDIANA& MtcHIGAN ELEGTRIc CoMPANY (the Company) is a subsidiary of American Electric Power Company, Inc. (AEP) and is engaged in the generation, purchase, transmission, and distribu-tion of-electric power. The Company was organized under the laws of Indiana on February 21, 1925, and is also authorized to transact business in Michigan and West Virginia. Its principal executive oAices are in Fort Wayne, Indiana.

Indiana & Michigan Power Company, the generating subsidiary of the Company, was formed in 1971 to own, complete the construction of, and operate the Donald C. Cook Nuclear Plant (the Nuclear Plant). Unit No. 1 of the Nuclear Plant was placed in commercial operation on August 23, 1975. Unit No. 2 was placed in commercial operation on July 1, 1978. The subsidiary sells all of the plant's generation to the parent for distribution to the latter's customers.

The Company serves 231 communities and approximately 437,000 customers in a 7,740-square-mile area of northern and eastern Indiana and a portion of southwestern Michigan. This area has an estimated population of 1,566,000. Among the principal industries served are manufacturers of automobiles, trucks, automotive parts, aircraft parts, steel, ferrous and nonferrous castings, farm machinery, machine tools, electric motors, electric transformers, electric wire and cable, glass, textiles, rubber products, food products and electronic components. In addition, the Company supplies wholesale electric power to other electric utilities, municipalities, and cooperatives.

The Company's generating plants and important load centers are interconnected by a high-voltage transmission network. This network in turn is interconnected either directly or indirectly with the following other AEP System companies to form a single major integrated power system:

Appalachian Power Company, Kentucky Power Company, Kingsport Power Company, Michigan Power Company, Ohio Power Company, and Wheeling Electric Company. The Company is also interconnected with the following other utilities: Central Illinois Public Service Company, The Cincinnati Gas & Electric Company, Consumers Power Company, Commonwealth Edison Com-pany, Illinois Power Company, Indiana-Kentucky Electric Corporation (a subsidiary of Ohio Valley Electric Corporation), Indianapolis Power & Light Company, Northern Indiana Public Service Company, and Public Service Company of Indiana, Inc.

INDIANA & MICHIGAN ELECTRIC COMPANY AND GENERATING SUIISIDIARY Consolidated Summary of Operations Year Ended December 31, 1978 1977 1976 1975 1974 (In Thousands)

OPERATING REVENUES ELECTRIC ..$ 603,480 $ 512,824 $ 416,193 $ 363,355 $ 287,606 OP ERATING EXP BNSES:

Operation:

Fuel for Electric Generation ............ 125,277 74,052 70,127 55,775 55,216 Purchased and Interchange Power (Net) ... 116,308 144,833 126,712 121,194 111,161 Other . 605001 44,706 40,251 37,800 27,959 Maintenance 32,724 28,452 20,140 17,078 17,747 Depreciation 59,844 48,824 47,852 32,734 24,853 Taxes, Other Than Income Taxes .. ~... ~... 26,432 23,408 18,920 14,015 10,956 Federal and State Income Taxes ........... 23,060 18,149 (8,625) 6,026 (3,086)

Total Operating Expenses ........ 443,646 382,424 315,377 284,622 244,806 OPERATING INCOME 159,834 130,400 100,816 78,733 42,800 OTHER INCOME AND DEDUCTIONS:

Allowance for Funds Used During Construction 28,874(a) 45,482(a) 59,454(a)

Allowance for Other Funds Used During Con-struction 27,974 26,889 Miscellaneous Nonoperating Income Less De-ductions 1,040 952 718 135 1,537 Total Other Income and Deductions 29,014 27,841 29,592 45,617 60,991 INCOME BEFORE INTEREST CHARGES ......... 188,848 158,241 130,408 124,350 103,791 INTEREST CHARGES:

Total Interest Charges .. 96,648 80,772 76,534 70,822 70,388 Allowance for Borrowed Funds Used During Construction (Credit) ................ (22,627) (19,651)

Net Interest Charges ............ 74,021 61,121 76,534 70,822 70,388 CONSOLIDATED INCOME BEFORE CUMULATIVE EFFECT OF ACCOUNTING CHANGES ........ 114,827 97,120 53,874 53,528 33,403 NON-RECURRING CUMULATIVE EFFECT OF AC-coUNTING CHANGEs (Net of $ 603,000 Appli-cable Taxes) 8,151 CONSOLIDATED NBT INCOME . $ 114,827 $ 97,120 $ 53,874 $ 53,528 $ 41,554 (a) Not reclassified into debt and. equity components since allocation based on then existing capital structure would not necessarily be comparable to allocation under the FERC formula used after 1976.

Management's Comments on Consolidated Summary of Operations The amounts shown in the ConsoHdated Summary Increase (Decrease) of Operations and discussed below refiect only the 1977 vs. 1976 results of past operations and are not intended as any (In Millions) representation as to the results of operations for any Coal Oil Nuclear Total future period. Reference is made to the consolidated Cost of Fuel Consumed .. $ 5.1 $ 4.1 $ 2.4 $ 11.6 Generation Level and financial statements, related notes, and Operating Fuel Mix ............. (2.8) 1.0 (5.9) (7.7)

Statistics and Balance Sheet Data for additional infor- Overall Increase mation concerning results of operations. (Decrease) $ 2.3 $ 5.1 $ (3.5) $ 3.9 1978 vs. 1977 Operating Revenues Electric (In Millions)

Coal Oil Nuclear Total Electric operating revenues increased by $ 96,631,000 Cost of Fuel Consumed .. $ 23.7 $ 4.4 $ 3.3 $3 1 A (23% ) in 1977 over 1976 and by $ 90,656,000 (18% ) Generation Level and in 1978 over 1977. Factors associated with the in- Fuel Mix ............. (2.2) 5.7 16.3 19.8 creases and related estimated amounts are as follows: Overall Increase ........ $ 21.5 $ 10.1 $ 19.6 $ 51.2 Increase (Decrease) The cost of fossil fuel consumed increased signifi-1977 vs. 1976 1978 vs. 1977 cantly in 1977 and 1978. The increase in 1977 was (In Millions) affected by there having been a refund of approximately Base Rates and Fuel Cost Adjust- $ 4,000,000 to the Company in settlement of litigation mcnts $ 109.3 $ 53.8 with a supplier of fuel oil. (Such amount was recorded Sales Volume ................... (21.2) 51.1 as a reduction to fuel for electric generation for 1976 Sales Mix . 8.2 (14.2) and is reflected in the increase shown above in the Other Operating Rcvenucs ....... 0.3 cost of oil in 1977 from 1976.) A decrease in the Overall Increase ... $ 96.6 $ 90.7 quantity of nuclear fuel consumed in 1977 was related to the planned outage of Unit No. 1 of the Nuclear The increase in operating revenues in 1977 over Plant for refueling. The increase in 1978 also reflected 1976 was primarily attributable to rate increases placed the placing of Unit No. 2 of the Nuclear Plant in com-in effect during 1976 and 1977 and to the recovery of mercial operation during July. The utilization of the increased fuel costs pursuant to the Company's fuel- relatively more expensive fuel oil (to conserve coal adjustment clauses. Growth in operating revenues dur- supplies) to generate electricity during the coal miners'trike ing 1977 was limited due to a 17% decrease in kilowatt- which ended in March 1978 contributed to the hour sales for resale. The increase in operating reven- increase in 1978 over 1977.

ues in 1978 over 1977 reflected a 29% increase in The purchased and interchange power increase of kilowatt-hour sales for resale, the recovery of increased $ 18,121,000 (14% ) in 1977 and decrease of fuel costs, and rate increases placed in effect during $ 28,525,000 (20%) in 1978 primarily refiect the 1977 and 1978. Conservation measures by some cus- utilization of the Nuclear Plant as described above.

tomers have tended to limit the growth of operating revenues in both 1977 and 1978. Other operation expense increased by $ 15,295,000 (34%) in 1978 over 1977 mainly due to higher costs of labor, materials, supplies, and services, and was also Operating Expenses affected by test generation prior to, and increased Fuel for electric generation increased in 1977 over generation due to, placing of Unit No. 2 of the Nuclear 1976 by $ 3,925,000 (6'rc) and in 1978 over 1977 by Plant into commercial operation.

$ 51,225,000 (69% ). Factors relating to these increases The increase in maintenance expense in 1977 over and the related estimated amounts are shown below: 1976 of $ 8,312,000 (41%) was associated with cer-

INDIANA dc MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY MANAGEMENT'S COMMENTS ON CONSOLIDATED

SUMMARY

OF OPERATIONS (Concluded) tain increased maintenance activity in 1977 which had tributable to increased applicable revenues, and to previously been deferred and with higher labor cost Michigan Single Business Tax pertaining to the Gen-and increased costs of materials, supplies, and services erating Subsidiary.

as regards power production maintenance. Maintenance Information concerning Federal income taxes (in-expense increased by $ 4,272,000 (15%) in 1978 over cluding a reconciliation of actual Federal income taxes 1977 largely because of increasing cost levels and to such taxes computed at statutory rates) is shown in increased power plant, transmission and distribution Note 3 of Notes to Consolidated Financial statements.

maintenance activities.

The increase in depreciation expense in 1978 over Allowance for Funds Used During Construction 1977 of $ 11,020,000 (23%) was chielly due to the placing of Unit No. 2 of the Nuclear Plant and certain The allowance for funds used during construction environmental protection facilities at the Company's (AFUDC), including the portion shown as a credit to Tanners Creek Plant in commercial operation. interest charges, increased by $ 17,666,000 (61%) in 1977. This increase was related to an increased amount Taxes, other than income taxes increased by invested in construction (including Unit No. 2 of the

$ 4,488,000 (24%) in 1977. This was due to increases Nuclear Plant and precipitator installation projects at in utility plant in service and the completion in 1976 two of the Company's plants) and to the elfect of the of the amortization (approximating $ 3,000,000 for Generating Subsidiary's compounding AFUDC begin-that year) of certain deferred credits associated with ning in 1977.

property taxes which had been deferred pursuant to regulatory authorization. The increase in taxes, other Interest Charges than income taxes in 1978 over 1977 of $ 3,024,000 (13%) was largely attributable to increased Indiana In 1978, total interest charges increased by Property Tax resulting from greater assessed valuation $ 15,876,000 (20% ) over 1977; this was related to ad-of property, increased Indiana Gross Income Tax at- ditional long-term debt outstanding.

Auditors'pinion To the Shareowners and the Board of Directors of Indiana & Michigan Electric Company We have examined the balance sheets of Indiana & Michigan Electric Company and its gen-erating subsidiary, Indiana & Michigan Power Company, consolidated, as of December 31, 1978 and 1977 and the related statements of consolidated income, retained earnings and sources of funds for plant and property additions for the respective years then ended. Our examinations were made in accordance with generally accepted auditing standards and, accordingly, included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

As discussed in paragraphs three and five of Note 2 of Notes to Consolidated Financial State-ments, the Company is collecting certain wholesale revenues subject to possible refund and has been incurring charges for interchange power subject to refund by its affiliated interchange power suppliers. An initial decision in the interchange power proceeding in February 1978, could, if sustained, result in substantial refunds to the Company. In addition, the Company is involved in antitrust matters discussed in paragraphs three and five of Note 10 of N'otes to Consolidated Financial Statements.

In our opinion, subject to the etfect on the financial statements identified above of such adjust-ments, if any, as might have been required had the outcome of the rate and antitrust matters referred to in the preceding paragraph been known, such financial statements present fairly the financial position of the above companies, consolidated, as of December 31, 1978 and 1977 and the results of their operations and their sources of funds for plant and property additions for the years then ended, in conformity with generally accepted accounting principles applied on a consistent basis.

New York, New York February 19, 1979 (March 2, 1979 as to paragraph five of Note 10 of Notes to Consolidated Financial Statements)

INDIANA 4t6 MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY Consolidated Statement of Income Year Ended December 31, 1978 1977 (In Thousands)

OPERATING REYENUEs ELEGTRIc (Notes 1 and 2) .... ~...... $ 603,480 $ 512,824 OPERATING EXPENSES:

Operation:

Fuel for Electric Generation . 125,277 74,052 Purchased and Interchange Power (Net)

(Notes 2 and 9) .. 116,308 144,833 Other 60,001 44,706 Maintenance (Note 1) . 32,724 28,452 Depreciation (Note 1) . ~ ~ ~ ~ ~ ~ ~ 59,844 48,824 Taxes, Other Than Income Taxes (Note 9) . 26,432 23,408

. State Income Taxes . (378) 704 Federal Income Taxes (Notes 1 and 3) . 23,438 17,445 Total Operating Expenses ... 443,646 382,424 OPERATING INCOME 159,834 130,400 OTHER INcoME AND DBDUGTIGNs (Notes 1 and 3):

Allowance for Other Funds Used During Construction ........ 27,974 26,889 Miscellaneous Nonoperating Income Less Deductions ........ 1,040 952 Total Other Income and Deductions .............. 29,014 27,841 INCOME BEFORE INTEREST CHARGES . 188,848 158,241 INTEREST CHARGES:

Interest on Long-term Debt 89,397 73,188 Interest on Short-term Debt 5,964 6,697 Miscellaneous Interest Charges (Note 1) 1,287 887 Total Interest Charges 96,648 80,772 Allowance for Borrowed Funds Used During Construction (Credit) (Note 1) (22,627) (19,651)

Net Interest Charges . 74,021 61,121 CGNsoLIDATBD NET INcoME $ 114,827 $ 97,120 See Notes to Consolidated Financial Statemenrs.

Consolidated Balance Sheet December 31, 1978 1977 ASSETS AND OTHER DEBITS (In Thousands)

ELEGTRIc UTILITYPLANT (Note 1):

Production $ 1,345,070 $ 864,902 Transmission 421,644 401,562 Distribution 257,186 244,103 General and Miscellaneous (includes Nuclear Fuel) . 68,209 40,965 Construction Work in Progress . 305,136 555,500 Total Electric Utility Plant . 2,397,245 2,107,032 Less Accumulated Provision for Depreciation ....... 410,520 358,826 Electric Utility Plant, Less Provision ..... 1,986,725 1,748,206 OTHER PRQPERTY AND INYEsTMENTs (Notes 1 and 4) 170,299 137,421 CURRENT ASSETS:

Cash (Note 8) 21,264 54,735 Special Deposits and Working Funds . 6,750 24,065 Temporary Cash Investments (at cost, which approximates market) 8,494 Accounts Receivable:

Customers 46,277 38,052 Associated Companies 7,511 9,382 Miscellaneous 4,498 4,968 Accumulated Provision for Uncollectible Accounts (299) (221)

Materials and Supplies (at average cost or less):

Construction and Operation Materials and Supplies 12,783 11,468 Fuel 16,112 17,320 Accrued Utility Revenues . 13,811 18,149 Prepayments and Other Current Assets 3,467 4,322 Total Current Assets . 132,174 190,734 DEFERRED DEBITS:

Unamortized Debt Expense (Note 1) . 3,143 2,172 Property Taxes 1,422 1,450 Deferred Collection of Fuel Costs (Note 2) ...... 1,584 1,655.

Other Work in Progress 9,010 4,780 Other Deferred Debits 45,606 36,521 Total Deferred Debits ..................:...... 60,765 46,578 Total $ 2,349,963 $ 2,122,939 Sea Notes to Consolidated Financial Statements.

10

INDIANA & MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY December 31, 1978 1977 LIABILITIES AND OTHER CREDITS (In Thousands)

CAPITALIZATION:

Coinmon Stock No Par Value (Note 5):

Authorized 2,500,000 Shares Outstanding 1,400,000 Shares . $ 56,584 $ 56,584 Premium on Capital Stock (Note 5) . 381 381 Other Paid-in Capital (Note 5) 470,228 410,228 Earnings (Note 6)

..'etained 136,829 104,566 Total Common Shareowner's Equity .......... 664,022 571,759 Cumulative Prefer'red Stock (Note 7) 227,000 187,000 Long-term Debt (less portion due within one year) (Note 8) 1,043,090 977,062 Total Capitalization (less long-term debt due within one year) 1,934,112 1,735,821 CURRENT LIABILITIES:

Long-term Debt Due Within One Year (Note 8) ......... 7,536 61,421 Short-term Debt (Note 8):

Notes Payable to Banks . 69,490 49,650 Commercial Paper . 55,450 52,200 Accounts Payable:

General 50>460 19,650 Associated Companies 15,305 16,306 Dividends Declared:

Common Stock 14,252 11,360 Cumulative Preferred Stock 4,754 3,854 Customer Deposits 1,909 1,739 Taxes Accrued . 20,005 18,804 Interest Accrued 18,338 19,041 Other Current Liabilities 16,439 16,653 Total Current Liabilities 273,938 270,678 CoMMITMENTs AND CGNTINGENGIBs (Note 10)

DEFERRED CREDITS AND OPERATING RESERVES:

Deferred Income Taxes (Note 1) 120,921 102,143 Deferred Investment Tax Credits (Notes 1 and 3) ........ 8,503 10,785 Other Deferred Credits and Operating Reserves .......... 12,489 3,512 Total Deferred Credits and Operating Reserves . ~ 141,913 116,440 Total . $ 2,349,963 $ 2,122,939

Consolidated Statement of Sources of Funds for Plant and Property Additions Year Ended December 31, 1978 1977 (In Thousands)

FUNDS FROM OPERATIONS:

Consolidated Net Income . $ 114,827 $ 97,120 Principal Non-fund Charges (Credits) to Income:

Depreciation 59,853 48,837 Provision for Deferred Income Taxes (Net) ............ 18,779 13,535 Deferred Investment Tax Credits (Net) ................ 3,423 5,038 Allowance for Other Funds Used During Construction .... (27,974) (26,889)

Other (Net) 506 72 Total Funds from Operations . 169,414 137,713 FUNDs FRQM FINANGINGs:

Issuances and Contributions:

Long-term Debt . 369,839 135,391 Cumulative Preferred Stock 38,486 38,120 Capital Contributions from Parent Company ............ 60,000 58,000 Short-term Debt (Net) 23,090 Total 491,415 231,511 Less Retirements:

Long-term Debt . 357,877 10,873 Short-term Debt (Net) 46,163 Net Funds from Financings . 133,538 174,475 DIVIDENDS ON COMMON STOCK (62,692) (52,920)

DIVIDENDS ON CUMULATIVEPREFERRED STOCK .............. (18,357) (14,041)

SALES OF PROPERTY 42,416 97,311 OTHER CHANGES (NET) (13,675) (4,523)

DEGREAsE (INGREAsE) IN WoRKING CAPITAL (Excluding Short-term Debt and Long-term Debt Due Within One Year) (a)... 92,615 (61,061)

Total $ 343,259 $ 276,954 PLANT AND PROPERTY ADDITIONS:

Gross Additions to Utility Plant . $ 340,209 $ 272,433 Gross Other Additions . 31,024 31,410 Total Gross Additions 371,233 303,843 Allowance for Other Funds Used During Construction ...... (27,974) (26,889)

Total $ 343,259 $ 276,954 (a) Represented by decrease (increase) as follows:

Cash and Cash Items $ 59,280 $ (30,020)

Accounts Receivable (5,806) (3,534)

Materials and Supplies . (107) (5,851)

Accounts Payable 29,809 (11,096)

Taxes Accrued 1,201 (1,087)

Other (Net) 8,238 (9,473)

$ 929615 $ (61,061)

See /Votes to Consolidated Financial Statements.

l2

INDIANA dc MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY Consolidated Statement of Retained Earnings December 31, 1978 1977 (In Thousands)

Balance at Beginning of Year $ 104,566 $ 76,286 Consolidated Net Income 114,827 97,120 Total 219,393 173,406 Deductions:

Cash Dividends Declared:

Common Stock 62,692 52,920 Cumulative Preferred Stock:

4'le % Series 495 495 4.56% Series . 273 273 4.12% Series 165 165 7.08% Series ....... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2,124 2,124 7.76% Series 2,716 2,716 8.68% Series 2,604 2,604 12 % Series 3,600 3,600

$ 2.15 Series . 3,440 2,064

$ 2.25 Series . 2,940 Total Cash Dividends Declared ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 81,049 66,961 Capital Stock Expense . 1,515 1,879 Total Deductions . 82,564 68,840 Balance at End of Year (Note 6) $ 136,829 $ 104,566 See Notes to Consolidated Financial Statements.

Notes to Consolidated Financial Statements

1. Significant Accounting Policies: Income is charged with the costs of labor, materials, The common stock of the Company is wholly owned supervision, and other costs incurred in maintaining the by American Electric Power Company, Inc. (AEP). properties. Property accounts are charged with costs of

, The consolidated financial statements include the ac- betterments and major replacements of property, and counts of the Company and its wholly owned subsidiary the accumulated provisions for depreciation are charged Indiana & Michigan Power Company (the Generating with retirements, together with removal costs less salvage.

Subsidiary). The Generating Subsidiary was formed to Nonutility property, other property investments, and own, complete construction of and operate the Donald other investments are generally stated at cost.

C. Cook Nuclear Plant, the first unit of which has been Income Taxes in commercial operation since 1975 and the second unit Deferred Federal income taxes, reduced where ap-of which was placed in commercial operation during plicable by investment tax credits, are provided by the July 1978. Significant intercompany items have been Company and the Generating Subsidiary generally to eliminated in consolidation. A minor inactive subsidiary the extent that such amounts are allowed for rate-has not been consolidated.

making purposes. On October 1, 1978, the Company The accounting and rates of the Company and the and its Generating Subsidiary expanded deferred tax Generating Subsidiary are subject in certain respects to accounting to additional timing differences pursuant to the requirements of state regulatory bodies and in cer- an order of the Public Service Commission of Indiana.

tain respects to the requirements of the Federal Energy The Company and the Generating Subsidiary prac-Regulatory Commission (FERC). The consolidated tice deferral accounting for the effect of tax reductions financial statements have been prepared, with full res- resulting from the application of investment tax credits ervation of legal rights, on the basis of the accounts to provisions for current and certain deferred Fedeial which are maintained for FERC purposes. income taxes. The deferred investment tax credit ap-plicable to current Federal income taxes payable is Utility Plant, Other Property and Investments amortized over 30 years.

and Depreciation Electric utility plant is stated at original cost. Gen- Pension Plan erally, the plant of the Company and the Generating The Company and the Generating Subsidiary par-Subsidiary is subject to first mortgage liens. ticipate with other companies in the AEP System in The companies'capitalize, as a construction cost, an a trusteed plan to provide pensions for all employees, allowance for funds used during construction, an item subject to certain eligibility requirements. The plan was not representing cash income, which is defined in the previously contributory on the part of employees, but applicable regulatory systems of accounts as the net as of January 1, 1978, required employee contributions cost of borrowed funds used for construction purposes were eliminated as to substantially all employees. The and a reasonable rate on other funds when so used. pension plan conforms to the Employee Retirement Thc respective composite rates used by the Company Income Security Act of 1974 (ERISA).

and the Generating Subsidiary were increased to 10.5%, Pension costs for the years ended December 31, and 10.2%, respectively, during 1978 (effective Janu- 1978 and 1977 were approximately $ 2,624,000 and ary 1) from 8.5% used by both companies in 1977, $ 2,170,000, respectively, representing the cost of cur-(applied by the Company on an annual basis and by rently accruing benefits. There were no unfunded prior the Generating Subsidiary on a semiannual compound service costs as of December 31, 1978. Effective Janu-basis). ary 1, 1979, benefits of the plan were modified. The The companies provide for depreciation on a straight- change resulted in unfunded prior service costs of line basis over the estimated useful lives of the property. approximately $ 1,970,000, which will be amortized The current provisions are determined largely with the over 30 years. The plan may be modified or terminated use of functional composite rates as follows: at any time, subject to limitations of labor agreements.

Functional Composite Employees Savings Plan Class of Annual Property Rate The Company and the Generating Subsidiary par-Production: ticipate with other AEP System companies in a trusteed Steam Nuclear . 4.0% savings plan which became effective January 1, 1978 Steam Fossil-fired 3.1% and is available to employees who have met eligibility Transmission .. 2.9%

requirements. The savings plan conforms to the appli-Distribution . 3.3%

General 3.5% cable provisions of ERISA. Each employer contributes 14

INDIANA & MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY to the plan an amount equal to 50% of its employee- (In Thousands) 1978 $ 24,981 participants'ontributions up to 6% of their regular 27,968 1977 compensation. Benefits to participating employees are Prior to 1977 S0,368 based solely upon amounts contributed to the partici- Total $ 103,3 17 pants'ccounts. By its nature the plan is fully funded at all times. The cost of the plan for the year ended On February 23, 1978, an administrative law judge December 31, 1978 totaled $ 607,000. of FERC issued an initial decision ordering one of the affiliated interchange power suppliers to make certain Orher refunds, after recomputing interchange charges for the The Company accrues unbilled revenues for services period subsequent to June 1975 on the basis of the rendered subsequent to the last billing cycle through interconnection agreement in effect prior'to that date, month-end. but excluding from such calculations as member ca-Miscellaneous nonoperating income for the years pacity, in the case of the Company, the capacity owned ended December 31, 1978 and 1977 includes gains by the Generating Subsidiary and, in the case of an-amounting to $ 261,000 and $ 306,000, respectively, on other member of the System, the capacity owned by its certain long-term debt reacquired. generating subsidiary. If the change is finally ordered Debt discount or premium and debt expense are by FERC, the Company could become entitled to re-being amortized over the lives of the related debt issues funds in a substantial amount. Certain intervenors have and the amortization thereof is included within miscel- urged that changes be made in the interconnection laneous interest charges. agreement, which would have 1he opposite effect, in-creasing the amounts payable by the Company. The

2. Operating Revenues and Operating Expenses: AEP System subsidiaries, including the Company, have filed a brief which urges that the action of the admin-The Company has collected retail revenues under istrative law judge be revised so as to sustain the origi-final orders of the Public Service Commission of Indi-nal amounts charged,'but cannot predict the final out-ana which became effective in February 1977 and come of the proceeding or the effect thereof on the September 1978. The 1977 order has been appealed Company.

to a court of appeals and certain parties have initiated Operating revenues derived from domestic govern-proceedings looking toward an appeal from the 1978 mental entities represent approximately 8% and 10%

order.

of total operating revenues for 1978 and 1977, respec-In September 1978, FERC ordered that the Com-tively. Operating revenues derived from a certain pany refund approximately $ 3,000,000 to a municipal wholesale customer represent approximately 12% and customer. The Company recorded the refund in the third quarter of 1978. The effect of such refund on 7% of total operating revenues for 1978 and 1977, respectively.

prior periods was not material.

Revenues collected by the Company from wholesale In 1978 the Company received approval of the Public Service Commission of Indiana to collect, over rate increases placed into effect subject to possible a five-year period ending in 1983, substantially all of refund (exclusive of the amount refunded as described its deferred fuel costs.

above) are estimated as follows:

(In Thousands) 3; Federal Income Taxes:

1978 $ 20,777 The details of Federal income taxes are as follows:

1977 16,439 Year Ended Prior to 1977 5,224 December 31, Total $ 42,440 1978 1977 Charged (Credited) to Operating (In Thousands)

See Note 10 for information with respect to an anti- Expenses:

trust decision enjoining the Company from charging Current Federal Income Taxes (Nei) . $ 1,357 $ (1,128) certain wholesale rates.

Deferred Federal Income Taxes Commencing in June 1975, operating expenses in- (Net) . 18,658 13,535 clude the effect of changes in rates charged for inter- Deferred Investment Tax Credits change power transactions" between the Company and (Nei) 3,423 5,038 other companies in the AEP System. The effect of Total .................... 23,438 17,445 Charged to Other Income and such changes was to increase the charges to the Com- Deductions ...... .......... . 936(a) 537 pany, subject to possible refund by its interchange Total Federal Income Taxes $ 24,374 $ 17,982 power suppliers, by the following estimated amounts: (a) Includes deferred income taxes of $ 121,000.

15

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

The consolidated effective Federal income tax rates were less than the statutory rates'or the years 1978 and 1977. The following is a reconciliation of the differences between the amount of Federal income tax expense reported in the Consolidated Statement of Income and the amount of Federal income taxes computed by multiplying consolidated net income before Federal income taxes by the statutory tax rate.

Year Ended December 31, 1978 1977 (InThousands)

Consolidated Net Income $ 114,827 $ 97,120 Federal Income Taxes 24,374 17,982 Pre-Tax Book Income . $ 139,201 $ 115,102 Federal Income Tax on Pre-Tax Book Income at Statutory Rate of 48% ....... $ 66,816 $ - 55,249 Increase (Decrease) in Federal Income Taxes Resulting from Excess of Tax over Book Dcprcciation . (19,691) (16,080)

Allowance for Funds Used During Construction and Items Capitalized on the Books but Deducted for Tax Purposes . (25,853) (24,005)

Mine Devclopmcnt and Exploration Expense . (4,680) (1,962)

Provision for Revenue Refunds (888) (2,912)

Amortization of Pollution Control Facilities . (4,080) (1,609)

Miscellaneous Items . 109 (5,633)

Federal Income Tax on Cunent-Year Taxable Income (Separate-Return Basis) . 11,733 3,048 Reduction Due to System Consolidation (11,733) (3,048)

Minimum Tax on Preference Items ................................................................. 650 18 Currently Payable 650 18 Adjustments of Prior-Year Accruals (Nct) (276) (774)

Adjustments for Tax Losses (a):

Federal Income Taxes . 7,503 68 Investment Tax Credit . (5,705) 97 Current Federal Income Taxes (Net) 2,172 (591)

Deferred Federal Income Taxes (Net of Amortization) Resulting from the Following Timing Differences:

Depreciation (Liberalized and Asset Depreciation Range) . 17,439 13,931 Unbilled Revcnuc (1,221) 3,315 Accelerated Amortization of Emergency Facilities (Amortization of Prior-Year Provisions) ........ (1,848) (1,882)

Provision for Revenue Refunds . 2,213 Other 2,188 1,154 Investment Tax Credit Applicable to Deferred Federal Income Taxes on Certain Timing Ditferences ~ 2,221 (5,196)

Deferred Federal Income Taxes (Net) 18,779 13,535 Deferred Investment Tax Credits (Net)...... 3,423(c) 5,038 Total Federal Income Taxes.......................................................... $ 24,374 $ 17,982 (a) The AEP System allocates Federal income taxes currently payable in accordance with SEC regulations, which require that the benefit of tax losses be allocated to the AEP System companies with taxable income.

The benefits of these tax losses, without affecting taxes payable, are reallocated to.the AEP Sy'tem companies giving rise to such losses, as it is expected that these losses would be usable in subsequent years to reduce taxes payable of the loss companies.

16

INDIANA h, MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY (b) In accordance with an order of the SEC under the Public Utility Holding Company Act of 1935, a tax loss of the Generating Subsidiary is to be first applied to reduce the taxable income of the Company and any unused amount is to be allocated among the other System companies included in the consolidated Federal income tax return, but with the provision that any losses so allocated to other System companies shall be reallocated to the Company if usable by it in subsequent years. The effect of tax losses allocated to other companies would be included in the reallocation referred to in (a) above.

(c) The System consolidated Federal income tax return for'1977, filed in 1978, showed a taxable income which was less than that estimated for the year-end accrual. The decrease was principally attributable to additional percentage repair allowance deductions of the Company and affiliated companies and mine development expense deductions of the Company claimed over the estimated amounts utilized in pre-paring the 1977 year-end accrual. These differences had no significant effect on the amount of income taxes payable for 1977 because of the effect of investment tax credits; however, total System Federal income taxes for 1977 would have been reduced due to the related reversal of deferred investment tax credits. The increase in income ($ 3,194,000) resulting from these differences in estimates was recorded by the Company in the third quarter of 1978.

The Company joins in the filing of a consolidated 4. Other Property and Investments:

Federal income tax return with its affiliated companies The following is an analysis of other property and in the AEP System. Unused System investment tax investments: Year Ended credits at December 31, 1978 aggregated approximately December 31, 1978 1977

$ 201,000,000, of which approximately $ 21,300,000 (In Thousands) may be carried forward through 1981, $ 52,800,000 Nonutility Property and Other through 1982, $ 20,500,000 through 1983, $ 27,400,000 Property Investments:

Western Coal Lands Acquired as through 1984, and $ 79,000,000 through 1985. Of Source of Low4ulfur Fuel ... $ 149,713 $ 120,799 these amounts, approximately $ 26,000,000 had been Other Coal Properties and Fuel-applied as 'a reduction of deferred income taxes prior Handling Facilities .......... 4,946 3,692 Misccllancous (Nct) ........... 15,495 12,674 to December 31, 1978 and will not be refiected in net Subtotal ...........,.... 170,154 137,165 income when realized in future years except as af- Ohio Valley Electric Corporation Sub-ordinated Notes .................. 56 fected by changes in deferred income taxes. Other Investments .................. 145 200 Total Other Property and The System consolidated Federal income tax re- Investments ..'............. $ 170,299 $ 137,421 turns for the years prior to 1965 have been settled.

5. Common Stock, Premium on Capital Stock, The returns for the years 1965 through 1969 together and Other Paid>>ln Capital:

with certain unrecorded refund claims relating to the There were no common stock transactions and no years 1965, 1966 and 1967 are currently being settled transactions affecting premium on capital stock during on the basis of a net refund for the period, the amount the years 1978 and 1977. The Company received from of which the System companies deem immaterial. The its parent cash capital contributions of $ 60,000,000 in returns for=the years 1970 through 1973 have been 1978 and $ 58,000,000 in 1977; such contributions reviewed by the Internal Revenue Service and addi- were credited to other paid-in capital.

tional taxes for those years have been proposed, some of which the System companies have protested. In the 6. Retained Earnings:

opinion of the System companies, adequate provision Various restrictions on the use of retained earnings has been made for such additional taxes. for cash dividends on common stock and other pur-poses are contained in or result from covenants in mortgage indentures, debenture and bank loan agree-ments, charter provisions, and orders of regulatory authorities. Approximately $ 48,500,000 at December 31, 1978 was so restricted.

17

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

7. Cumulative Preferred Stock The following is an analysis of cumulative preferred stock Amount Redemption Current Restricted Par Shares December 31, Series Call Price ()a Prior to Value Outstanding 1978 1977 (In Thousands) 4 Vs% $ 106.125 $ 100 120,000 $ 12,000 $ 12,000 4.56% 102.000 100 ,60,000- 6,000 6,000 4.12% 102.728 100 40,000 4,000 4,000 7.08% 106.450 100 300,000 30,000 30,000 7.76% 107.320 100 350,000 35,000 35,000 8.68% 107.440 100 300,000 30,000 30,000 12 112.000(b) 9/I/80 100 300,000 30,000 30,000

$ 2.15 27.150 5/I/82 25 1,600,000 40,000 40,000

$ 2.25 27.250 3/I/83 25 1,600,000 40,000 Total Cumulative Preferred Stock . ........ $ 227,000 $ 187,000 (a) Callable at the option of the Company, at the price indicated plus accrued dividends. The involuntary liquidation preference is par value.

(b) A sinking fund for thc 12% series requires the Company to provide, on or before October I of each year, beginning in 1980, for the purchase, or redemption at $ 100 a share, of 15,000 shares of such series. The Company has the right, on each sinking fund date, to redeem an additional 15,000 shares. Unless all sinking fund provisions have been met, no distribution may be made on the common stock.

In 1976 shareowners authorized the issuance of up to 4,000,000 shares of $ 25 par value cumulative preferred stock (which ranks equally with the $ 100 par value cumulative preferred stock) and in 1978 increased the authori-zation to 7,200,000 shares. In 1977 the Company issued and sold 1,600,000 shares of the $ 2.15 series and in 1978 the Company issued and sold 1,600,000 shares of the $ 2.25 series.

At December 31, 1978, authorized shares of cumulative preferred stock were as follows:

Shares Par Value Authorized

$ 100 . 2,250,000 25 . 7,200,000

8. Long-term Debt, Short-term Debt, Lines of Credit, December 31, and Compensating Balances: Series Due 1978 1977 Long-term debt by major category was outstanding (In Thousands) 7 % 1998 $ 35,000, $ 35,000 as follows (less portion due within one year): 8vs% 2000 50,000 50,000 8Vs% 2003 40,000 40,000 December 31, 9'%003(e) 255,000 1978 1977 9Vs% 2008 100,000 Unamortized Debt First Mortgage Bonds ..............

'(In Thousands)

Discount Net (552) (262)

$ 832,286 $ 482,826 Sinking Fund Debentures ........... 24,083 25,260 Less Portion due Within One Year ..

835,286 3,000 539,999 57,173 Notes Payable to Banks, due 1980 .. 82,000 360,000 Installment Purchase Contracts ...... 99,841 99,750 Total $ 832,286 $ 482,826 Other Long-term Debt .........:... 4,880 9,226 (a) Retired February I, 1978.

Total (less portion due within (b) Retired September I, 1978.

one year) $ 1,043,090 $ 977,062 (c) Guaranteed by American Electric Power Company, Inc.

(d) These bonds are obligations of the Generating Subsidiary.

First mortgage bonds outstanding were as follows: The unamortized discount amounted to $ 189,000 and

$ 221,000 at December 31, 1978 and 1977, respectively.

December 31, (e) Sinking fund payments are required as follows:

Series Due 1978 1977 10% series due 1985 $ 750,000 annually on March 1.

10ss% series due 1984 $ 2,250,000 annually on Decem-(In Thousands) 68% 1978(a) ...... $ $ 30,000 ber I, through 1983, with the noncumulative election to redeem an additional $ 2,250,000 in each year.

3 1978(b) 2sik % 1980 18,015 24,173 18,015 9'%eries due 2003 $ 11,500,000 annually on June I, 1980 through 1991 and $ 13,500,000 annually on June I, 3V4% 1982 16,046 16,046 1992 through 2002 with the noncumulative option to IOV4% 1982 70,000 70,000 redeem an additional amount in each of the specified 3Ys% 1983 13,762 13,762 years from a minimum of $ 100,000 to a maximum 11 1983 60,000 60,000 equal to the scheduled requirement for each year, but 3 Vs% 1984 15,082 15,082 with a maximum ootional redemption, as to all years 10vs % 1984(c)(d)(e) . 66,000 70,500 in the aggregate, of $ 75,000,000.

10 3vs% 1988 1985(e) ...... 13,500 14,250 4si4% 1988 22,974 22,974 In January 1979, the Company issued $ 80,000,000 17,557. 17,557 4%% 1993 42,902 42,902 of 10V4% first mortgage bonds due in 1987. The 18

INDIANA & MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY Generating Subsidiary has a delayed-delivery contract Consolidated long-term debt outstanding at Decem-to sell an additional $ 45,000,000 of its first mortgage ber 31, 1978 is due as follows:

bonds, 9th% Series due 2003, on March 1, 1979. Principal Amount The indentures relating to the first mortgage bonds (In Thousands) contain improvement, maintenance and replacement 1979 $ 7,536 provisions requiring the deposit of cash or bonds with 1980 118,859 the trustee, or in lieu thereof, certification of unfunded 1981 15,032 property additions. The Company has elected to use 1982 101,304 unfunded property additions to meet these provisions 1983 89,035 in the past. Later Years . 721,505 Sinking fund debentures of the Company outstanding Total $ 1,053,271 were as follows:

December 31, At December 31, 1978 and 1977, the principal 1978 1977 amounts of debentures reacquired in anticipation of (In Thousands) sinking fund requirements were $ 2,183,000 and 5Vs% Due 1986 7V4% Due 1998 Unamortized Debt Premium Total

$ 12,076 11,941

$ 24,083 66 '5

$ 12,491 12,694

$ 25,260

$ 1,815,000, respectively. The companies may make additional debenture or first mortgage bond sinking fund payments of up to $ 3,050,000 annually ($ 2,250,000 relating to Generating Subsidiary) ~

Installment purchase contracts of the Company were The interest rate on the long-term notes payable to as follows: banks (an average of 12.2% at'December 31, 1978 December 31, and 8.4% at December 31, 1977) depends on the 1978 1977 prime commercial rate plus a fractional percentage.

(In Thousands) The Generating Subsidiary has informal arrangements City of Lawrcnceburg, Indiana: with the banks to maintain average compensating bank 8Vi% Series due 2006 ...... $ 25,000 $ 25,000 balances equal to approximately 15%. of certain of the 7% Series duc 2006 ........ 40,000 40,000 6Fs% Series due 2006 ...... notes outstanding on an average basis or such smaller 12,000 12,000 City of Sullivan, Indiana: amount as the banks consider appropriate in view of 6os% Series due 2006 ...... 25,000 25,000 other banking relationships or, in lieu thereof, to pay Unamortized Debt Discount ... (2,159) (2,250) a fee'n any draw-down of the compensating balances Total $ 99,841 $ 99.750 based on the approximate effective interest cost of the Under the terms of certain installment purchase con- related notes, assuming the full compensating balances tracts, the Company is required to pay purchase price had been maintained: At December 31, 1978 and 1977, installments in amounts sufficient to enable the cities the compensating balances under the arrangements were approximately $ 9,800,000 and $ 34,100,000, re-to pay interest on and the principal (at stated maturi-ties and upon mandatory redemption) of related pol- spectively. The effective interest rate, representing the lution control revenue bonds issued to finance the con- actual interest rates on the notes outstanding adjusted struction of pollution control facilities at the Company's for the effect of the compensating balance require-ments, averaged 13.9% at December 31, 1978 and Tanners Creek and Breed Plants.

was approximately 9.6% at December 31, 1977.

Other long-term debt of the. Company outstanding consisted of: Short-term debt and'interest rates thereon were as December 31, follows:

1978 1977 1978 1977 (In Thousands) (Dollars in Coal reserve obligations payable in Weighted average interest rates for debt Thousands) equal annual installments through 1980 with interest at 8% .......... $ 8,252 outstanding at end of year:

$ 12,377 Notes payable due 1978 through Notes Payable to Banks ............ 10.9% 7.8%

1985, 6%-7%

Other 902 262 934 Commercial Paper .................. 11.2%%uo 7.4%

162 Maximum amount of debt outstanding at 9,416 13,473 any monthwnd during the year:

Less portion due within one year...;.. 4,536 4,247 Notes Payable to Banks ............ $ 69,490 '87,400 Total $ 4,880 $ 9,226 Commercial Paper ............. ~...~ $ 55,450 $ 76,042 19

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued) 1978 1977 Year Ended December 31, (Dollars in Thousands) 1978 1977 Weighted average interest rate of debt (In Thousands) outstanding during the year (a): Taxes, Other Than Income Taxes:

Notes Payable to Banks ............ 9.4% 6.6% Real and Personal Property Taxes.. $ 14,617 $ 13,609 Commercial Paper .................. 9.1% 6.6%%uo State Gross Sales, Excise and Fran-chise Taxes, and Miscellaneous Average amount of debt outstanding State and Local Taxes .......... 9,842 8,078 during the year:

Social Security Taxes Federal and Notes Payable to Banks ............ $ 31,862 $ 39,457 State 1,973 1,721 Commercial Paper .................. $ 36,211 $ 58,716 3 26,432

' 23,403 (a) Average interest rates arc determined by dividing inter-est expensed for the year by average month-cnd debt.

(a) Includes power purchased from OVEC of approximately

$ 1,558,000 in 1978 and $ 476,000 in 1977.

(b) Includes interchange power sold to OVEC of approxi-mately $ 908,000 in 1978 and $ 956,000 in 1977.

The Company had unused short-term bank lines of Charges to income for royalties and advertising are credit of approximately $ 144,000,000 and $ 208,000; less than 1% of gross revenues in each case.

000 at December 31, 1978 and 1977, respectively, Sales and purchases of energy and interchange power under which notes could be issued with no maturity transactions are regulated by the various commissions more than 270 days after date of issue. The available having jurisdiction.

lines of credit are subject to withdrawal at the American Electric Power Service Corporation pro-banks'ption, and $ 135,000,000 and $ 200,000,000, respec- vides certain services to the Company and the affiliate tively, of such lines are shared with other AEP System companies in the AEP System. The costs of the ser-companies. In accordance with informal agreements vices are determined by the service company on a with the banks, compensating balances of up to 10% direct-charge basis to the extent practicable and on or, in certain instances, equivalent fees are required reasonable bases of proration for indirect costs. The to maintain the lines of credit, and, on any amounts charges for services are made on a cost basis but in-actually borrowed, generally either additional compen- elude no compensation for the use of equity capital, sating balances of up to 10% are maintained or adjust- all of which is furnished to the service company by ments in interest rates are made. Substantially all bank AEP. The service company is subject to the regulation balances are maintained by the Company to compensate of the Securities and Exchange Commission under the the banks for services and for both used and available Public Utility Holding Company Act of 1935.

lines of credit.

10. Commitments and Contingencies:

9. Supplemental Income Statement Information and Related-Party Transactions: The construction budget of the Company and the Electric operating revenues shown in the Consoli- Generating Subsidiary for the year 1979 is estimated dated Statement of Income include sales of energy to at $ 241,000,000 and, in connection therewith, com-AEP System companies of approximately $ 17,500,000 mitmcnts have been made.

and $ 14,500,000 for the years ended December 31, The Company participates with its parent, two asso-ciated utility companies, several unaffiliated utility 1978 and 1977, respectively.

companies, and Ohio Valley Electric Corporation Operating expenses shown in the Consolidated State-(OVEC) in supplying the U.S. Department of Energy ment of Income include certain items not shown sepa-(POE) with the power requirements of its plant near rately, as follows: Portsmouth, Ohio. The proceeds from the sales of Year Ended December 31 power by OVEC are designed to be sufficient for 1978 1977 OVEC to meet its operating expenses and fixed costs, including amortization of long-term debt capital (bal-(In Thousands) ance approximately $ 43,300,000 as of December 31, Purchased Power (a) ........... $ 6,241 $ 2,965 1978), over a period ending in 1982, and to provide Interchange Power (Net):

for an annual return on its equity capital. The Com-AEP System Electric Utilities . 80,043 140,957 pany, as a participant, is entitled to receive from Other Companies (b) -......... 30,024 911 OVEC, and is obligated to pay for, 7.6% of the power

$ 116,308 $ 144,833 not required by DOE. The power agreement terminates 20

INDIANA & MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY in 1979 but DOE has notified OVEC of its desire to transactions involved in the investigation; the auditor's negotiate an extension to 1992. report was filed in December 1978. The AEP System In 1978, three court prbceedings brought in recent companies are engaged in a continuing program for years by certain municipalities in Indiana and Michigan, the'rderly and economic divestment of a limited all wholesale customers of the Company were com- amount of real estate, acquired in connection with the incd into a single consolidated case in a U.S. District housing and industrial development programs, that was Court and a fourth action was commenced in the same subject to question.

court. A trial of the consolidated case was held and in In 1975, an investigation was commenced under the January 1979 the court ruled for the plaintiffs that th e Federal Power Act concerning the reasonableness and C ompany, its parent, and American Electric Power prudence of the coal-purchasing policies and practices S ervice Corporation have violated the antitrust laws, of members of the AEP System, the manner in which awarded thc municipalities damages of approximately wholesale fuel-adjustment clauses are implemented by

$ 12,100,000 when trebled, placed limitations on the System members, and related matters. In 1978 the Company's putting into effect or charging wholesale FERC staff issued a preliminary report which alleged rates to the plaintiffs and enjoined the Company from overcharges of approximately $ 10,000,000 on the part certain practices. The financial statements at December of the entire AEP System, of which only a relatively 3 1, 1978 do not include any provision for such dam- small portion relates to the Company's operations. The ages. The companies are appealing the decision and rcport also questioned certain aspects of the AEP provisions of the judgment awarding monetary dam- System's fuel positions and policics. The AEP System ages have been stayed. companies are preparing a response to these allegations.

In another proceeding, the Company is awaiting de- In 1976 a cable-television organization filed an anti-cision on its appeal to FERC, filed in 1977, with re- trust suit in a U.S. District Court alleging that the spect to a ruling by an administrative law judge on a Company, with five telephone companies named as complaint made to the, commission by the same group co-conspirators, had attempted to monopolize com-of municipalities. That complaint, alleging that the munications by terminating contracts and increasing municipal electric systems had been threatened with charges for the rental of utility poles, and sought dam-termination of wholesale electric service, had earlier ages which when trebled would aggregate more than been upheld by thc FERC judge. $ 150,000,000. In early 1979, the court entered a In March 1979, two other municipal customers judgment denying damages and injunctive relief.

brought a separate action against the Company, its The companies are subject to certain developing parent and the Service Corporation alleging violations laws and regulations with respect to air and water of the antitrust laws and seeking damages of at least quality, land use, and other environmental matters.

$ 7,000,000 before trebling and other remedies. Certain While the companies are unable to predict the ultimate issues in the complaint are similar to those tried in the effect of such laws and regulations, it is possible that consolidated case discussed in the second preceding they may be rcquircd to pay penalties for failure to paragraph. comply during certain periods or that compliance there-As previously reported, the Securities and Exchange with may require the companies to incur substantial Commission (SEC) had commenced an investigation, additional costs to modify or replace existing and pro-through its staff, into certain aspects of thc AEP Sys- posed equipment and facilities.

tem's operations, including its promotion of all-electric Other highly complex litigation relates to the Donald housing during the 1960's and the acquisition and C. Cook Nuclear Plant's fuel-supply contracts. Two operation of certain coal and transportation properties. contractors, United Nuclear Corporation and General The SEC staff had maintained that commission au- Atomic Company (GAC), are variously obligated to thorization should have been obtained for some of the supply uranium concentrates and six fabricated nuclear-tiansactions. The AEP System companies disagreed fuel reloads to the Company. Each contractor claims, b ut did agree to a negotiated settlement in order to among other things, that it is not or may not be obli-avoid long litigation with the SEC. As a result, the gated to make dcliverics of uranium concentrates or fab-AEP System companies agreed to a consent order in ricated nuclear-fuel'reloads and that it is entitled to a a U. S. District Court in which they neither admitted price higher than contracted. The Company received nor denied the allegations. As part of the agreement, a the first two reloads and assured delivery of the remain-special auditor was appointed to review intercompany ing four reloads through rights-reserved agreements charges and costs associated with thc programs and with GAC, which were incorporated into injunctive 21

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded) orders of the court. Under the agreements, pending the length from 2 to 35 years. Most of the leases require court's judgment and without prejudice to the ultimate the companies to pay related property taxes, mainte-rights of the parties, the reloads were to be supplied nance costs, and other costs of operation. The com-at a higher provisional cost to the Company. In panies expect that in the normal course of business, 1978, a U.S. District Court entered judgment ordering leases will generally be renewed or replaced by other GAC to pay the Company damages of approximately leases. The greatest part of the rentals is under leases

$ 16,000,000 and to deliver the remaining reloads at having purchase options or having renewal options for the price specified in the contract. GAC has appealed substantially all of the economic lives of the properties.

the judgment. A stay of the monetary portion of the judgment has been granted, but motions to stay the Rentals are analyzed as follows:

specific-performance portion of the judgment have been Year Ended denied. December 31, The companies intend to apply to regulatory com- 1978 1977 missions to provide, through future increased rates, for (In Thousands) the costs that will be incurred to store spent nuclear Gross Rentals $ 60,000 $ 32,000 fuel and to decommission the Nuclear Plant at the end Less Rental Recoveries (including of its service life. The, companies plan to effect modifi- Sublease Rentals) (a) ......... 1,000 1,000 cations to increase the present spent-fuel storage ca- Net Rentals (b) $ 59,000 ~31 000 pacity of the Nuclear Plant to permit normal operations (a) Includes amounts paid for or reimbursed by associated through the carly 1990's, at a cost which is not ex- companies.

pect'ed to cause a material increase in the construction (b) Classified as:

budget. The companies are also studying alternative Operating Expenses ............... $ 51,000 $ 26,000 methods of decommissioning the Nuclear Plant but Clearing and Miscellaneous cannot reasonably estimate, at this time, the future Accounts (portions of which are costs that will be. incurred. charged to income) 8,000 5,000 The Price-Anderson Act limited the public liability $ 59 000 $ 31 000 of a licensee of a nuclear plant to $ 560,000,000 for a single nuclear incident, to be covered in part by pri- Future minimum lease payments, by year and in the vate insurance with the balance to be covered by agree- aggregate, under the companies'apital leases and ments of indemnity with the Nuclear Regulatory Com- noncancelable operating leases consisted of the follow-mission. The Generating Subsidiary has purchased ing at December 31, 1978:

private insurance in the maximum available amount of Capital Operating

$ 140,000,000. In the event of a nuclear incident in- Leases(a) Leases volving any commercial nuclear facility in the country, (In Thousands) the Generating Subsidiary, together with other licensees 1979 $ 6,000 $ 7,000 could be individually assessed $ 5,000,000 per incident 1980 6,000 7,000 for each reactor owned (subject to a maximum of 1981 6,000 7,000

$ 10,000,000 in any year for each reactor owned in the 1982 6,000 7,000 event of more than one incident). The Price-Anderson 1983 5,000 7,000 indemnities have been decreased by 'the aggregate Later Years . 74,000 74,000 amount which is assessable against existing licensees Total Future Minimum Lease Payments 103,000 $ 109,000 and will continue to decrease as new operating units Less Estimated Interest Element are licensed. Included Therein (b) .............. 61,000 The Generating Subsidiary has procured property Estimated Present Value of Future insurance in the maximum available amount of $ 220,- Minimum Lease Payments ......... $ 42,000 000,000 for damage to the nuclear plant facilities and (a) Excludes leases of nuclear fuel, all of which are capital is a self-insurer for any property loss in excess of that leases. Nuclear fuel rentals comprise the unamortized balance amount. of the lessor's cost (approximately $ 99,000,000 at December 31, 1978 and $ 93,000,000 at December 31, 1977), less salvage value, if any, to be paid over the period of usage in proportion

11. Leases: to heat produced, and carrying charges on the lessor's unrecov-ered cost. It is contemplated that portions of the presently The companies, as part of their operations, lease leased material will be replenished by additional leased material.

property, plant, and equipment under leases ranging in (b) Interest rates used range from 4.9% to 12.1%.

.22

INDIANAc% MICHIGANELECTRIC COMPANY AND GENERATING SUBSIDIARY The following is a pro forma analysis of leased prop- 12. Vnaudited Quarterly Financial Informationt erties under capital leases and related obligations, The following consolidated quarterly financial in-assuming that such leases were capitalized: formation is unaudited but, in the opinion of the Company, includes all adjustments (consisting of only December 31, normal recurring accruals) necessary for a fair pres-1978 1977 entation of the amounts shown:

(In Thousands)

Nuclear Fuel $ 143,000 $ 132,000 Quarterly Periods Operating Operating Net Ended Revenues Income Income Coal-Mining'nd Coal-Transportation (In Thousands)

Equipment ........................- 15,000 17,000 1978 Real Estate . 13,000 13,000 Mar. 31............ $ 145,106 $ 41,553 $ 32,196 Electric Distribution System Property 12,000 12,000 June 30";.......... ~.... 157,958 40,183 34,491(a)

Sept. 30............ 152,218 40,749 22,739(b)

Other 11,000 10,000 Dec. 31............ 148,198 37,349 25,401(a)

Gross Properties under Capital Leases 194,000 184,000 1977 Less Accumulated Provision for Mar. 31................. 128,258 31,821 23,191 Amortization 58,000 53,000 June 30................. 118,070 30,698 22,871 Net Properties under Capital Leases.. $ 136,000 $ 131,000 Sept. 30................. 133,016 33,812 25,817 Dec. 31................. 133,480 34,069 25,241 Obligations under Capital Leases '(a) .. $ 141,000 $ 136,000

'ad (a) Includes increases in AFUDC of approximately $ 1,567,000 recorded in the second quarter and $ 3,372,000 recorded in (a) Including an estimated $ 37,000,000 and $ 31,000,000, re- the fourth quarter relating to changes in AFUDC rates, spectively, due within one year. applied in each case effective as of January 1, 1978.

(b) Includes the effect of a revenue refund (see Note 2), and a change in tax estimate (see Note 3).

capital leases been capitalized, any additional 13. Vnauditcd Replacement-Cost Information:

net expense would have been insignificant..The pro Estimated replacement-cost and related amounts forma data do not give recognition to offsetting ad- pertaining to depreciation, as of and for the years justments in allowable revenues that the companies ended December 31, 1978 and 1977, of productive believe would normally be expected to occur through capacity (as represented by property in service, ex-the regulatory rate-making process, if the related leases cluding nondepreciable items such as land and exclud-had been c'apitalized. ing other amounts for which replacement-cost data are Included in the above analyses of future minimum not required to be computed) are considerably greater lease payments and of properties under capital leases than the related original-cost amounts reported in, the and'related obligations are certain leases as to which consolidated financial statements. A quantitative analy-portions of the related rentals are paid for or reim- sis of such unaudited replacement-cost information is bursed by associated companies in the AEP System included in the Company's 1978 Annual Report based on their usage of the leased property. The Com- (Form 10-K) to the Securities and Exchange Commis-pany cannot predict the extent to which or proportion sion. Reference is made elsewhere herein for informa-in which the associated companies will utilize the tion with regard to obtaining a copy of thc Company's properties under such leases in the future. 'Form 10-K for the year 1978.

23

Operating Statistics and Balance Sheet Data 1978 1977 1976 1975 1974 OPERATING STATISTICS ELECTRIC OPERATING REVENUES (Thousands):

From Kilowatt-hour Sales:

Residential:

Without Electric Heating ............ $ 96,624 $ 90,833 $ 71,888 $ 69,438 $ 53,265 With Electric Heating ............... 54 067 46,948 37,447 33,493 27,080 Total Residential 150,691 137,781 109,335 102,931 80,345 Commercial: 96 370 92,312 72,527 69,176 50,554 Industrial 121,346 109,357 80,233 75,167 63,314 Sales for Resale:

Municipalities 39,121 44,091 26,841 22,551 23,493 Cooperatives 1 7/732 15,619 10,491 9,178 7,548 Other Electric Utilities .............. 166 441 103,517 110,382 75,887 55,994 Total Sales for Resale ........... 223,294 163,227 147,714 107,616 87,035 Miscellaneous . 7,729 6,062 2,573 4,650 3,389 Total from Kilowatt-hour Sales .... 599,430 508,739 412,382 359,540 284,637 Other Operating Revenues ............... 4 050 4,085 .3,811 3,815 2,969 Total Electric Operating Revenues .. $ 603 480 $ 512,824 $ 416,193 $ 363,355 $ 287,606 SGURGEs AND SALEs oP ENERGY (Millions of Kilowatt-hours):

Sources:

Net Generated Steam:

Fossil Fuel 7,231 7,317 7,701 7,255 8,815 Nuclear Fuel 10,101(a) 4,786 6,809 4,458(a)

Net Generated Hydroelectric ........ 75 68 72 89 73 Net Generated Other 14 Subtotal 17,407 12,171 14,582 11,802 8,902 Purchased 301 182 232 368 694 Net Interchange 4 475 7,922 6,523 6,778 8,451 Total Sources . 22,183 20,275 21,337 18,948 18,047 Less: Losses, Company Use, Etc....... 1,340 1,270 1,290 1,305 1,335 Net Sources 20 843 ~

19,005 20,047 17,643 16,712 Sales:

Residential:

Without Electric Heating .... 2,352 2,456 2,384 2,374 2,181 With Electric Heating ...... 1 622 1,605 1,577 1,451 1,413 Total Residential ...... 3 974 4,061 3,961 3,825 3,594 Commercial 2 498 2,671 2,579 2,464 2,192 Industrial . 4 319 4,473 4,209 3,835 4,134 Sales for Resale:

Municipalities 1,585 1,642 1,527 1,522 1,847 Cooperatives 814 786 754 690 651 Other Electric Utilities . ~... 7 468 5,195 6,849 5,152 4,166 Total Sales for Resale .. 9 867 7,623 9,130 7,364 6;664 Miscellaneous 185 177 168 155 128 Total Sales . 20 843 19,005 20,047 17,643 16,712 (a) Includes 691 million kilowatt-hours in 1978 and 2,309 million kilowatt-hours in 1975 as test generation. The fuel cost associated with such generation is charged to other operation expense.

24

INDIAIVA d'c MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY AYERAGE CosT oF FUEI. CGNsUMED (a): 1978 1977 1976 1975 197k Cents per Million Btu:

Coal 109.68 74.96 65.89 56.09 51.68 Fuel Oil . 229.68 168.80 76.72(b) 190.44 187.38 Nuclear 34.65 29.72 26.34 27,.83 Overall 71.16 59.12 46.47(b) 65.56. 69.51 Cents per Kilowatt-hour Generated:

Coal 1.11 ~ 73. .63 .54 .49 Fuel Oil . 2.40 1.88 .84(b) 2.11 1.'85 Nuclear .38 .33 .28 .30 Overall .75 .61 .47(b) .53 .67 RESIDENTIAL SERVICE AVERAGES:

Annual Kwh Use per Customer Total 10)260 10,641 10,439 10,305 ,. 10,525 With Electric Heating .... 22)067 22,830 23,200 22,153 23,239 Annual Electric Bill Total $ 389 $ 361 $ 288 $ 277 $ 234 With Electric Heating .... $ 736 $ 668 $ 551 $ 511 $ 439 Price per Kwh (Cents)

Total 3.79 3.39 2.76 2.69 2.22 With Electric Heating .... 3.34 2.93 2.37 2.31 1.89 NUMBER oF ELEGTRlc CUsToMERs Year-End:

Residential:

Without Electric Heating ............ 315,472 313,085 . 312,211 310,953 281,904 With Electric Heating .......... ~... 74 900 72,059 69,237 66;812 64,233 Total Residential ............... 390 372 385,144 381,448 377,765 346,137 Commercial 42,106 41,907 41,703 41,456 37,593 Industrial 2 689 2,500 2,452 2,418 2,416 Sales for Resale:

Municipalities 23 23 23 22 23 Cooperatives 64 6i 59 58 58 Other Electric Utilities ............... 20 16 15 18 6 Total Sales for Resale ........... 107 100 97 98 87 Miscellaneous 1 331 1,304 1,280 1,259 1,167 Total Electric Customers ........ 436 605 430,955 426,980 422,996 387,400 BALANCE SHEET DATA Year-End (Millions)

Utility Plant . $ 2,397 $ 2,107 $ 1,933 $ 1,771 $ 1,630 Accumulated Provision for Depreciation ....... 410 359 317 275 249 Net Utility Plant 1,987 1,748 1,616 1,496 1,381 Total Assets and Other Debits ............... -2)350 2 123 1,914 1,764 1,545 Common Stock, Premium on Capital Stock, and Other Paid-in Capital 527 467 409 367 318 Retained Earnings . . 137 105 76 80 71 Cumulative Preferred Stock . 227 187 147 147 117 Long-term Debt (c) 1,051 1,038 914 895 739 (a) Excludes effect of deferred collection of fuel costs.

(b) Includes effect of refund received from supplier of fuel oil resulting from scttlcmcnt of litigation concerning pricing. Without such refund, the average cost of fuel oil for 1976 would have been 173.27 cents pcr million Btu and 1.91 cents pcr kilowatt-hour gcncratcd, and the overall cost of fuel would have been 49.33 cents pcr million Btu and 0.50 cents pcr kilowatt-hour generated.

(c) Including Portion Duc Within One Year.

25

INDIANA & MICHIGAN ELECTRIC COMPANY Directors FRANK N. BIEN GERALD P. MALONEY (a)

W. A. BLAGK (f) RICHARD C. MENGE LAWRENCE R. BRUNKB J. F. STARK RICHARD E. DISBROW JoHN TILLINGHAsT (m)

J. LEE FLANAGAN W. S. WHITE, JR.

E. W. HBRMANSEN RORERT O. WHITMAN (b)

G.,E. LEMAsTERs Officers W. S. WHITE, JR. RQBERT O. WHITMAN (c)

President Treasurer J. F. STARK (g) PETER J. DBMARIA (d)

Executive Vice President Treasurer W. A. BLAcK (f) H. D. ANDERSON, JR.

Execulive Vice President Assistant Secretary and J. F. STARK (I1)

Assistant Treasurer Senior Vice President ALLEN H. STUHLMANN FRANK N. BIEN Assistant Secretary and Vice President Assistant Treasurer RICHARD E. DISBROW JOHN F. DILORENZO, JR.

Vice President Assislant Secretary JOHN E. DOLAN (I) CBDRIC L. MAST (j)

Vice President Assistant Secretary A. JosEPH DowD WARREN O. KELTNBR (IC)

Vice President Assistant Secretary GERALD P. MALONEY WILLIAME. OLSON Vice President Assistant Secretary RICHARD C. MENGE PETER J. DEMARIA (C),

Vice President Assislant Treasurer JoHN TILLINGHAsT (m) WILLIAMN. D'ONOFRIO (I)

Vice President Assistant Treasurer "JOHN R. BURTON ~

GERALD R. KNORR (1)

Secretary Assistant Treasurer Tlte principal occupation of each of the above directors and officers of Indiana

& Michigan Electric Company, with ten exceptions, is as an ogicer of American Electric Power Service Corporation of New York, N. Y. Tlte excep-tions are the Messrs. IY. A. Black, Lawrence R. Brunke, J. Lee Flanagan, E. IY.

Hennansen, IYarren O. Keltner, G. E. LeMasters, J. F. Starl, Richard C.

Menge, Alien H. Stuhhnann, and Cedric L. Mast whose principal occupations are as officers of Indiana & Michigan Electric Company, as indicated.

(a) Elected April 25, 1978 (h) Elected July 1, 1978 (b) Resigned April 25, 1978 (i) Elected July 1, 1978 (c) Resigned April 27, 1978 (I) Resigned January 1, 1979 (d) Elected April '27, 1978 (k) Elected January 1, 1979 (e) Resigned April 27, 1978 (I) Elected March 1, 1979 (f) Elected July 1, 1978 (m) Resigned March 29, 1979 (g) Resigned July 1, 1978 26

INDIANA 4 MICHIGAN ELECTRIC COMPANY Price Range of Cumulative Preferred Stock By Quarters (1978 and 1977) 1978 Quarters 1977 Quarters Cumulative Preferred Stock 1st 2lld 3rd 4th 1st 2lld 3rd 4th

($ 100 Par Value) 4Ys% Series Dividends Paid Per Share $ 1.03125 $ 1.03125 $ 1.03125 $ 1.03125 $ 1.03125 $ 1.03125 $ 1.03125 $ 1.03125 Market Price $ Per Share (OTC)

Ask (high/low)

Bid (high/low) 40/40 43th/43Yi 4.56% Series Dividends Paid Per Share $ 1.14 $ 1.14 $ 1.14 $ 1.14 $ 1.14 $ 1.14 $ 1.14 $ 1.14 Market Price $ Per Sharc (OTC)

Ask (high/low)

Bid (high/low) 46/45 4.12% Series Dividends Paid Per Share $ 1.03 $ 1.03 $ 1.03 $ 1.03 $ 1.03 $ 1.03, $ 1.03 $ 1.03 Market Prie'e $ Per Share (OTC)

Ask (high/low) 46/46 Bid (high/low) 45/45 43/43 45/45 45/44 46/44 7.08% Series Dividends Paid Per Share $ 1.77 $ 1.77 $ 1.77 $ 1.77 $ 1.77 $ 1.77 $ 1.77 $ 1.77 Market Price $ Per (NYSE)

Share High Low 79Yi 74 76 697/s 69'7th 77th 64Y4 81 76th 81'7Ys 83th 77 SOYi 75 7.76% Series Dividends Paid Per Share $ 1.94 $ 1.94 $ 1.94 $ 1.94 $ 1.94 $ 1.94 $ 1.94 $ 1.94 Market Price $ Per Share (NYSE) High 85 84Y4 867/s 82 89 89th 91 89 Low 80'/rs 75 76 74 82th 84th 86s/4 84 8.68% Series Dividends Paid Per Share $ 2.17 $ 2,17 $ 2.17 $ 2.17 $ 2.17 $ 2.17 $ 2.17 $ 2.17 Market Price $ Per Share (NYSE) High 98 93 987/s 94'h 99 99s/4 101th 997/s Low 91Yi 82 83Yi 82 94th 91 96 94 12% Series Dividends Paid Pcr Share $ 3.00 $ 3.00 $ 3.00 $ 3.00 $ 3.00 $ 3.00 $ 3.00 $ 3.00 Market Price $ Per Share (NYSE) High 116 113 113 s/4 112s/4 123 120 s/s 123Y4 121 Low 111th 109 108'/4 103 117 117 118'h 113Y4

($ 25 Par Value)

$ 2.15 Series~

Dividends Paid Per Share $ .5375 $ .5375 $ .5375 $ .5375 $ .215 $ .5375 $ .5375 Market Price $ Per Share (NYSE) High 23N 227a 23th 227/s 25s/4 25 Low 22s/4 20Y4 21Y4 19s/s 24Ys 23Y4

$ 2.25 Series'~

Dividends Paid Per Share $ .7125~~~ $ .5625 $ .5625 Market Price $ Per Share (NYSE) 21'4~/s High Low 24 21s/4 24Ys 20Ys OTC Over-the-Counter NYSE New York Stock Exchange

~ Issued in May 1977

~~ Issued in March 1978

~~~ Includes partial dividend for first quarter.

Note The above quotations bid and asked represent prices between dealers and do not represent actual transactions.

Market quotations provided by National Quotation Bureau, Inc. Dash indicates quotation not available.

27

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mrrrrrrrrrrrrr Other Comtntnks'ronsmtssLM Uncs TANNERS CREEK Q ~~

Lml Ot OCAROORN Lls.lCJ I5 IOWll 5 I COHIAIH to 0 to 20 30 50 ttcses 1 Hrrlesov srs t Alt st to 0 1 Ael NCAA t LtCs NC teel s scenes Ccn toter ten ~ 1 5 AOAOYA1, IL Y.C.

I-2 INDIANA & MICHIGAN ELECTRIC COMPANY AND GENERATING SUBSIDIARY

E)j(ON XN-NS-TP-009 NUCLEAR EXXON NUCLEAR COMPANY INC.

FUEL STORAGE RACKS CORROSION PROGRAM, BORAL STAINLESS STEEL

. CONTROLLED DISTRIBUTION LIST

~Co No. Name 001-015 f1.0. Bandeira(PSEKG) 016 J.E. Birchler "017 T.G. Eckhart E. E. Garrett

'18 019 W.S. Nechodom 020 J.H. Nordahl 021 J.H. Riddle 022 B.T. Stiles 023 Document .Control-HR 024 Document Control-RTC 025-064 h1.0. Bandeira (PSE&G) 065 T.G. Eckhart 066 W; E: Ferguson 067 Dr. J. Weeks (BNL) 068 Dr. A.B. Johnson (BNWL) 069 W.H. Baker. (SRP) 070 R.C. Karzmar (B8P)

Use. reproduction, transmittal or disclosure of the above Information i ~ subject to the restriction on the first or title patte of this document.

'N-NS-TP-009 E ON U CLEAR FUEL STORAGE RACKS CORROSION PROGRAM, BORAL STAINLESS STEEL November 9, 1978 NOTICE This document contains 'information proprietary to Exxon Nuclear Company, Inc. It is submitted in confidence and is to be used solely for the purpose for which it is furnished and returned upon request.

Thi,s document and such information is not to be reproduced, transmitted, disclosed or used otherwise, in whole or in part, without the written authorization of Exxon Nuclear Company, Inc.

Use, reproduction, transmittal or disclosure of the above information Is sub/act to the restriction on the first or title page of this document.

GR405

I XN-NS-TP-009 E ON UCLEAR IMPORTANT NOTICE REGARDING CONTENTS AND USE OF THIS DOCUMENT Exxon Nuclear Company's warranties and representatives concerning'he subject matter of this document are those set forth in the Agreement between Exxon Nuclear Company, Inc. and the Customer pursuant to which this document'is issued.'ccordingly, except as otherwi"se expressly provided in such Agreement, neither Exxon, Nuclear Company, Inc. nor'ny person acting on its behalf makes any warranty or re-

'resentation, expressed or implied, with respect to the accuracy, completeness, or usefulness of the information

'contained in this document, or'that the use of any information, apparatus, method or process disclosed any liabilities with '

~

respect to the use of, or for damages resulting from the use of any information, apparatus,.method or process disclosed in this document.

2. The information contained herein is for the sole use of Customer.

3: In order to avoid impairment of rights of Exxon Nuclear Company, Inc. in patents or inventions which may be included in'he in-formation contained in this document, the recipient; by of this- document agrees not .to publish or make its'acceptance public'se (in the patent sense 'of the term) of such informatioA until so autho'rized in writing:by Exxon Nuclear Company, Inc., or until after six (6) months following termination, or expiration.,

of the. aforesaid Agreement and any extension thereof, unless otherwise expressly provided in the Agreement. No rights or

'icenses in or to any patents are implied by the furnishing.

of this document.

Use, reproduction, transmittal or disclosure of the above Information ls subfect to the restriction on the first or title page of this document.

GR405

I I

XN-l5- I P-l)(8/NP VALIDATING SIGNATURES VALIDATING SIGNATURES'evision No. and Date Revised Sections Revised Pages Prepared By Project llanager Date /I la 7P Concurred By iH t r. flechanical Engr.

Date ////6/ 7 Hgr. Licensing Compliance Date tl Approved By Ngr. Storage Engr.

Services Date ll [o /7g

XN-NS-TP-009 E ON UGLEAR TABLEOF CONTENTS

~Pa e ABSTRACT 1.0 'NTRODUCTION 2.0 TEST PROGRAM DESCRIPTION 2-1 2.1- Specimen Description- 2-1

'2. 2 Envi ronment Description 2-2 2.3 Initial Measurements 2-3 r

3.0 SUf 1f 1ARY 3-1 RESULTS 4-1 4.1 Internal Environment of Edge-Sealed and Storage Cell Specimens 4-1 4.2 Visual Appearance 4-2 4.3'.4 Weight Gain 4-3 Pitting 4-5 4.5 'etallography 4-6 4.5.1 Sur'face Corrosion Films 4-6 4.5.2 Edge 4-7 Attack'ulges 4.5.3 LIST OF REFERENCES.

APPENDICES Appendix A - Test Program (Tables and Figur'es)

Appendix B - Detailed Test Results (Tables and Figures)

Use, reproduction, transmittal or disclosuro of the'above Information ls subiect to the restriction on the first or title patte oi this document.

GR~5

XN-NS-TP-009 E ON UCLEAR ABSTRACT Exxon Nuclear Company, Inc. has conducted a Boral*-Stainless Steel Corrosion Program during the past 18 months to establish additional performance information for use of Boral plates in spent fuel stor-age applications. The program consisted of a detailed review of related literature, an evaluation of test programs conducted by others, and additional'corrosion tests performed at Exxon Nuclear P

faci1 ities.

The objective of the Exxon Nuclear test program was to obtain corrosion data for Boral-304 stainl'ess steel test specimens in simulated PWR fuel pool environments so that reliable predictions could be made of what physical changes would occur in a defective,

,i.e.,j unsealed spent fuel storage cell after a 40-year exposure.

The Exxon Nuclear test's indicate that storage cells, containing a leak simulating hole, wi 11 sustain aluminum corrosion at a rate which can be expected to consume 3.25 to 3.4 percent of the aluminum in .the Boral core after a 40-year exposure.

Should Boral plates be exposed to a typical PWR pool environment, the material is subjected to pitting, edge attack, and internal gas pressuri-zation; but no effect on criticality safety is expected over the lifetime of storage cells due to dislodgement of 84C particles.

r

The, Boral test samples discussed in this report are a neutron absorbing, shielding material manufactured by the Brooks and Perkins Company. The Boral specimens are a composite. material consisting of boron carbide evenly dispersed within a matrix of aluminum and clad with aluminum.

Use, reproduction, transmittal or disclosure of the above fnformation is subject to the restriction on the first or title patte of this document.

XN-NS-TP-009 E ON UCLEAR 1.0 INTRODUCTIOH Prior to designing racks utilizing stainless steel clad Boral plates in PIJR pool environments, Exxon Nuclear initiated, (during 1976 and early 1977), a review of applicable material corrosion literature and conducted analyses of test results performed by others.

1 Exxon Nuclear's review of the related literature*, and performance of Boral in similar environments, indicated that there should be no.

adverse effect on nuclear safety analyses of storage racks in a Pj(R pool environment. To provide further assurance of satisfactory material performance, Exxon Nuclear initiated a test program in February, 1977 to evaluate Boral clad in stainless steel 304 specimens in environ-ments simulating utilization in Exxon Nuclear PllR storage rack applications.

List of appropriate material contained in Reference section of this report.

Use, reproduction, transmittal or disclosuro of the abovo Information Is subject to the restriction on tho first or title page of this docurnont.

XN-NS-TP-009 E)$ ('ON NUCLEAR

2. 0 TEST PROGRAM DESCRIPTION

.2.1 SPECIMEN DESCRIPTION Exxon Nuclear's test program placed emphasis on investigation of Boral .utilized in conditions typical of expected storage cells and PIER pool water environments. Consequently, storage cell component sections were fabricated which r'esembled the larger, full-size storage cells. Specifically, these reduced-size storage cell specimens consisted of inner and outer stainless steel 304 shrouds into which four (4) Boral plates were inserted. The co'mplete assembly was sealed welded, resulting in 6" high x 6" wide test specimens. Each completed cell specimen was made to simulate a leaking condition by drill-ing 1/16-inch'oles as described in Appendix A.

In order to separately observe and measure various corrosion and material properties during the test, additional test specimens were utilized. These additional specimens consisted of 2" x 2" coupons made as follows:

1) Open-edge Boral/stainless steel composite; 2.) Sealed-edge Boral/stainless steel composites with a leak simulating hole; and,

3) Unencapsulated Boral coupons.

2-1 Use, reproduction, trensmittel or disclosure of the shove Inlormotion is sub/ect to'the restriction on the first or titl~ pege of this document.

GR405

XH-NS-TP-,009 E)gj('ON NUCLEAR

'02 ENVIRONMENT DESCRIPTION Insulated nine (9) gallon polyethylene tanks,'ith'fitted

'overs, were used for the plain Boral and open-edged Boral-stainless specimens. Thirty (30) gallon tanks of the same construction were used for the closed-edge tests. Each tank was fitted with a stainless immersion heater and stirring .

mixer, which were, affixed through openings in the tank covers.

A stainless steel screen was used to hold the specimens off the bottom of the tanks and permit circulation of the environ-ment on all sides. In order to isolate the plain Boral,speci-mens from the stainless steel screen, a pedestal was fashioned from phenolic plastic. The open-edged composite samples, a 2" x 2" Boral piece sandwiched between two 2" x 2" stainless steel pieces, were held together with four (4) flet-clip springs, one along each edge. Tjiese were placed on the stain-,

less screens so that the clips'held the specimens in a hori-zontal position over the screen.

The initial environment in each tank was deionized water with a pH of 5.85 and.a conductivity of-0.75 ji mho'/cm.. Boric acid (H3803) and lithium hydroxide (LiOH H20) additions were made to produce the, following:

Environment A) Deionized water plus 13.3 g/1 Boric Acid (resulting in 2300 ppm Boron at 150'f).

. 2-2 Use, reproduction, transmittal or disclosure oi the above Iniormatlon Is subject to the restriction on the lirst or title page of this document.

GR~5

I I

XN-NS-TP-009 E ON UCLEAR Environment B) Deionized water, 13.3 g/1 Boric Acid, 0.0121 g/1 lithium hydroxide Environment C) Deionized water plus 0.0121 g/1 lithium hydroxide The specimens, were immersed in each environment on July 1, 1977. The initial temperature and pH of each environment were measured as follows:

~H

5. 20

~F 146. 4

5. 53 147.'2 9.15 153.4 The temperature and pH were measured daily. The temperature showed some fluctuations and variacs were installed in order to gain better temperature control. The pH in the borated solutions, 1 and 2, remained constant but in the alkaline tank, C, it dropped into the 7 range within four (4) days. In order to keep the solution pH in the alkaline range,'ddi-tional additions of lithium hydroxide were made.

2.3 INITIAL MEASUREMENTS Appendix A of this report contains descriptions of all Boral and stainless steel specimens utilized for'he test program.

The initial measurements and cleaning programs are also pro-vided in Appendix A.

2-3 Use, reproduction, transmittal or disclosuro of the above information is subject to the restriction on the first or title patte of this document.

G R405

XN-NS-TP-009 E ON UCLEAR 3.0

SUMMARY

No corrosion, pitting, nor stress-corrosion cracking was observed on any of the stainless steel coupons, or storage cell specimens used in this study. The austenitic stainless steel can be expected to withstand exposure to 'borated fuel pool environments for the pro-jected forty-year life of spent fuel racks. Similarly, without a, leak path through the stainless steel liners, the interior Boral plates would not be subject to degradation as a result of aqueous corrosion. In the situation of a leak path through the stainless liners which permits the interior space to fill with the pool environ-ments, ther".results of the 2 month, 6 month, and 12 month exposure studies, show that Boral is subject to general corrosion, pitting and,edge attack, and clad deformation due t'o internal gas pressurization. To various degrees, the severity of each of these corrosion effects depends on the particular environment chemistry and the specific geometry of the exposed materials. Based on comparisons between the four (4) specimen types and the three (3) environments used in this study, the following summary can be drawn concerning the corrosion resistance of Boral and its suitability for use when exposed in stainless lined storage cells to borated environments.

The general corrosion rate, as determined by weight gain measurements,.

decreased significantly between the 2, 6, and 12 month exposure times.

When all the storage cell specimen data are examined on a semi-'log plot, the amount'f aluminum consumed in conversion to oxide after a 40-year exposure, ts: 3.3 percent for the low pH and 3.4 percent for the higher pH environments.

3-1 Use, reproductiontrensmittal or disclosure of the ebove lnforrnetion is subject to the restriction on the first or title pege of this document.

GR~5

Xt>-nS-TP-oog E ON UCLEAR The weight gains were lowest for the storage cell specimens in each of the three (3) environments, followed in general by the plain, open-edged, and edge-sealed specimens. The weight gains, measured for the plain and open-edged specimens, were nearly identical to each other in the three (3) environments. This similarly indicates that galvanic coupling between the stainless steel in the open-edged specimens does not accelerate general corrosion in the Boral.

In all three (3) environments, the edge-sealed specimens showed the greatest weight gain.

The high pH environment produces a slightly higher amount of corro-sion and, on the average, the highest corrosion rates at the end of the test. This appears to be due to the less protective character of the oxide films formed in the high pH environment.

Pitting was observed on the exterior aluminum surfaces of the Boral after only 18 days of exposure. Pits were observed on the plain specimens in areas beneath the supporting 'plastic pedestal, which indicates a differential aeration mechanism is operating. Pitting was more extensive in the low pH environment and in those regions of the specimens where ease of replenishment with the bulk solution was greatest. In the storage cell specimens, pitting was confined only to those areas near the leak simulating holes; also these specimens showed the least number of pits.

The frequency of'pitting did not increase significantly with increased exposure time. The size and depth of the pits continued to increase, however. The maximum pit depth, after 12 months, was 0.032". As pitting progresses into the Boral some aluminum binder is corroded and the B4C particles become embedded in corrosion products.

Similar considerations apply to edge attack of the Boral. However, the depth of edge attack did not increase significantly between the 3-2 Use, reproduction, trensmlttel or disclosure of the above Information is subject to the restriction on the first or title pette of this document.

GR405

I I

XN-HS-TP-009 E ON UCLEAR 6 and 12 month exposure. The deepest edge penetration, 0.028", was measured on the open-edged specimen in the low pH environment.. No measurable edge attack was observed in the vicinity of the leak simulating hole in the Boral plates of the storage cell specimens.

Gas generation, due to corrosion of the aluminum in Boral, has 'been observed .in the edge-sealed specimens and the storage cell specimens.

This gas has been observed to bubble from the upper hole in each of the storage cells. In several of the specimens removed after 12 months, bulges were observed between the aluminum cladding and the B4C aluminum core. (See Figures 4.2 and 4.3, Appendix B). Internal gas genera'tion, blocked from escape by the buildup of corrosion products in conjunction with occasional un-bonded layers of the Boral matrix, is believed to be the cause of these bulges.

'he occasional unbonded layers of the Boral matrix occurred randomly and were observed in concentrated areas of very small B4C particles (i.e., >150 mesh). It has been determined that, the Boral .specimens provided by Brooks and Perkins for the ENC corrosion test program con-tained a much higher concentration of small B4C particles than utilized for production Boral plates. Accordingly, it is possible that the small bulges observed on the sealed specimens may not occur in finished plates where improved B4C and aluminum bonding result with larger B4C particles.

The occasional lack of bonding between B4C and aluminum particles also allows a small amount of water to enter the inner portions of the bulged specimens. Normally, water does not penetrate into well-bonded Boral

'plates and no internal corrosion can occur.

The small bulges have not been reported or observed in prior related corrosion test programs. They appear to be a .self-limiting phenomenon>

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XN-NS-TP-009 E ON UCLEAR where the gaseous corrosion product both causes the bulge and dis-places the water causing the corrosion. Aninspection of both the aluminum cladding and inner Boral matrix demonstrates that no clad pitting or deterioration of the inner face of cladding and Boral material occurred near the bulged areas. Consequently should random small bulges occur, any dislodgement of B4C particles. will be of no significance on neutron shielding or attenuation properties.

3-4 Use, reproduction, transmittal or disclosure ol the above information Is subiect to the restriction on the first or title pape of this document.

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f ON VCLfAR XN-NS-TP-009 4.0 RESULTS On June 30, 1978, after a nominal 12-month exposure, the remaining three (3) plain Boral and three open-edged Boral-stainless composite specimens, were removed from the three (3) heated tanks. On August 10, 1978, the edge-sealed, and storage cell. specimens, were removed from their environments. These twelve (12) samples were subjected to visual, metallographic, weight gain, and pit depth measurement analyses.

This section of the report- places emphasis on the de-tailed results obtained from the storage cell specimens.

Appendix B presents additional test results for other specimens and contains most referenced tables and figures for information presented in this section. Table 4.1 provides specimen identification numbers and exact lengths of exposure for each of the twelve (12) specimens eval-uated during the final period.

4;1 Internal Environment Of Ed e-Sealed And Stora e Cell S ecimens The pH of the solution, within the edge-sealed and storage cell specimens, was measured using indicator paper for the former, and a Beckmann pH meter for the latter. Approximately 2.5 grams of solution was contained in the edge-sealed speci-mens and 39 grams in the cell specimens.

In Table 4.2 is a summary of the interior pH of the edge-sealed and cell specimens for the 2-, 6-, and 12-month exposures.

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XN-NS-TP-009 E ON U CLEAR

. For the high pH 'lithium environment,.the interior pH consistently devalue shows a decrease in pH toward a neutral .

for all exposure 'times. A similar trend toward a more neutral pH is, exhibited for the acidic environments for exposures up to 6-months. After 12-months, the interior pH is the same as the bulk'olution or, slightly more acidic.

4.2 Visual A earance The storage cell specimens were disassembled and cut open-1 to separate the Boral plates from the stainless liners.

A visual examination of each Boral piece was conducted using a low power stereo-microscope. The following

'observations were noted:

Stora e Cell S ecimen jaj3 S.C.S.-3 t

Surfaces'ere generally metallic in coloration. Extra corrosion products', and some, pitting, were seen on the faces and along the edges where the leak simulating holes were drilled through the stainless liners.

Stora e Cell S ecimen 0'6 S.C:S.;6)

Specimens are darker than SCS-3. Pitting is much less.

Rust existed along edges where holes were drilled.

Bulges were observed in the dimple area of plate S.C.S.-6(l),.

, on both the. outside and inside.

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XN-NS-TP-009 E ON-UCLEAR Stora e Cell S ecimen k9 S.C.S.-9 l

Specimens were white in coloration with rust colored deposits along the edges where h'oles were drilled. B4C stringers were evident, but no pitting. Plate .S.C.S.-9(4) had a l-l/4u pure aluminum stri p on one short edge.

4.3 Wei ht Gain After the visual analysis, the appropriate Boral plate specimens were weighed, oven-dried, and *reweighed 'in order to determine the amount of absorbed moisture, in the core and the change in weight due to exterior and inte-rior corrosion; The 'specimens were dried in stages in an air-circulating oven for two.(2) hours at 150, 200, 250'F, and for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months at 300'F. The original weight, the weight prior to oven-drying, and the dried weight for each specimen, is listed in Table 4.3.

A summary of the moisture absorbed weight percentages,

,for the 2-month,'6-month, and 12-month exposures, 'is given in Table 4.4. The overall average for all specimens, environments, and exposures, was 0.47$ . This corresponds to a minimum average porosity level in the Boral core of approximately 1;5X.'he absorbed moisture decreased between 2-months and 6-months and increased between 6-months and one year. This may be the result of an initial decrease in porosity as corrosion products were generated in the core followed by a porosityincrease as additional corrosion enlarged the pores; The greatest moisture absorption occurred in the open-edged specimens in the A environment.

also showed-the greatest number of pits and would, This'pecimen therefore, contain the greatest amount of material capable 4-.3 Use, reproduction, transmittal or disclosure of the above Information is subJect to the restriction on the first or litle page of this document.

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XN-NS-TP-009 E ON UCLEAR

'f absorbing moisture. The least moisture, on the average, was in the storage cell Boral plates, which may be due to

,their larger size and lower edge to volume ratio.

In'able 4.5, the corrosion weight gain percentages are summarized for all the specimens tested in the program.

The values, in -brackets, have been corrected to account for the fact that certain of the 6" x 4" Boral plates in the cell specimens contain a strip of solid aluminum along one edge. Since this strip did not contain the normal porous core structure, it could contribute weight gain only by external surface corrosion. To make valid comparisons, using these specimens, their weight was re-duced by a factor corresponding to the reduced core volume. Under the assumption that the weight gain per-centages are an indication of the extent of uniform corrosion in these specimens, the results presented in Table 4.5 show that the corrosion rates have decreased with increased exposure time. The results are plotted for each specimen type as a function of environment in Figures 4.4 through 4.6.

The .weight gains are largest for the edge-sealed 'specimens in each environment. Similarly, they are the smallest for the storage cell specimens. In between, with very similar results, are the plain and open-edged specimens. The similar weight gains, experienced by these two (2) specimen types, show that the general corrosion is not accelerated due to coupling with stainless steel.

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XH-NS-TP-009 E ON UGLEAR IJhen the weight gain values for the storage cell speci-m'ens are considered on a semi-logarithmic scale, the relationship appears to be amenable to extrapolation, as shown in Figures 4.7 through 4.9. From these figures, the extrapolated weight gain percentage and the calculated percent of aluminum consumed after 40 years exposure, are:

Al Consumed, I 4.4 3.3 4.5 3.4 4.5 3.4 4.4 ~Pittin To evaluate the extent of pitting in the 12-month exposure specimens, the corrosion products were clean'ed from the surfaces of a portion of one of the four (4).plates from each cell specimen. A summary of the pitting frequency and pit depth, for. the 6-month and 12-month exposures, is given in Table 4.6. The pit diameter for the 12-month, specimens is also given in the table.

,Table 4.6 shows that the pitting characteristics after 12-months were very similar to those after 6-months.

Those specimens and environment combinations which did

,not pit or showed little pitting tendency after 6-months, showed no or few pits after 12-months, however, those with significant pits after 6-months had a large number of

'pits after 12-months. Increased pitting was observed in the plain specimens in the A environment and in the edge-sealed specimens in the A and 8 environments. The 'other specimens showed nearly the same number of pits after 12-months as after 6-months.

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NH-NS-TP-009 E QN U CLEAR The pit depth, however, increased with the extended 12-month exposure.. In some cases where pits had not pene-trated the aluminum clad in 6-months, they had done so after 12 months.

4.5 Metallo ra h Sections of Boral from each specimen were mounted and metallographically polished in order to observe the thickness of surface oxidation films, the depth of edge attack, the undercutting around drilled holes, and the nature of surface bulges. Sections were made along an edge for the plain =and open-edged specimens, and through the drilled hole in the Boral for the edge-sealed and storage cell specimens. In addition, sections through bulges in the, specimens were made to characterize these structures. The specimens were back-filled with epoxy under vacuum conditions to impregnate surface porosity, then rough polished on silicon'arbide papers and final .

polished on di'amond using automatic vibratory equipment.

4.5.1 Surface Corrosion Films The surface corrosion films on several of the specimens were thick enough to measure using a filar eye piece at a magnification of 400. The film thickness, as measu'red for these specimens, is listed in Table 4.7. The thickness for the C environment specimens was thickest, being a maximum of 8.2 microns for the plain specimen. Hhere the bulge in this specimen caused the surface layer to break apart, the corrosion films were much thicker. Appendix B contains photographs showing the surface film in one area away from a bulge and, for comparison, on a bulge.

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XW-NS-TP-009

~ E ON U CLEAR 4.5.2 Ed e Attack Table 4.7 also shows the depth of corrosive attack at the Boral coupon edges in the plain and open-edged specimens.

The attack was greatest in the A environment and was somewhat greater in the'pen-edged specimen than in the plain specimen. Only one specimen of the six (6) edge-sealed and storage cell types showed accfslerated corrosion around the partially drilled leak simulating hole. This was the edge-sealed specimen in the C environment. The similarity in edge attack between the plain and open-edged

'pecimens again indicates a lack of corrosion acceleration due to galvanic coupling. of the Boral to stainless steel.

4.5,3 ~Ou1 es Several bulges were observed on the 12-month exposure specimens. Similar bulges were not observed on specimens exposed for 2- or 6'-months. Table 4.8 1'ists the number of bulges observed on each specimen. Photographs, demonstrating bulged areas are shown on Figures 4.2 and 4.'3.

The bulges are separations between the aluminum clad and the B4C-aluminum matrix. They appear to result from gas pressure caused by internal corrosion. The corrosion of aluminum would generate hydrog'en gas following the reaction 2A1 + 3H20 ~A1203 + 3H .

2'-7 Use, reproduction, transmittal or disclosure of the above information Is subject to the restriction on the first or title page of this document..

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XN-NS-TP-009 EQON

, NUCLEAR Such gas .generation has been observed in the edge-sealed

'and storage cell specimens. To generate a bulge would require sealing of the edges with corrosion products the internal gas pressure to increase suffi.ciently to'nable to expand the ten mil aluminum cladding. The edge-sealed'pecimens each had four (4) bulges. These specimens also showed the largest corrosion weight gains which could result in the sealing of edges in these specimens.

4-8 Use, reproduction, transmittal or disclosure of the above Information is subject to the restriction on the first or title page of this document.

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XN-NS-Tf'-009 E ON UCLEAR REFERENCES Corrosion Data Survey Fifth Edition, NACE 1974, P. 34.

(2) A Guide to.Corrosion. Resistance, J. P. Polar, Climax Molybdenum Co., P. 54 (3) Corrosion and Corrosion Product Release in Neutral Feedwater s E. G. Bru'sh and M. L. Pearl, Corr. V. 28, No.,4, April 1972, Pp. 129-136.

(4) Stress Corrosion Crackin'g Problems and Research in Energy Systems Proceedings ERDA Meeting 2/24/75. ERDA 76-98, Edited by L. C. Janniello (5) Corrosion Resistance of Metals and Alloys, F'. L. Langue and H. R. Copson, Chapter 5, Corrosion Testing, P. 136. (1963) Reinhold Publishing Corp.

(6) Fundamental As ects of Stress-Corrosion Crackin, NACE 1969, Stress-Corrosion Cracking of Iron-Nickel-Chromium Alloys, R. M. Latanision, R. M. Staehle, P. 214.

(7) Corrosion and 'Corrosion Control Herbert H. Uhlig, John Wiley 8 Sons, New York 1971, P. 309.

.(8) "Aqueous Corr. of Aluminum Part I Behaviour of 1100 Alloy" J. E. Draley and M. E. Ruther, Corr. 12 441t 1956.

(9) Reactor Technolo - Selected Reviews 1964 USAEC Aluminum Alloys, J. E. Draley and ll. E. Ruther, P. 215.

(10) "Resistance to Corrosion and Stress Corrosion," W. H. Binaer, E. H. Hollingsworth and D. 0. Sprowls, in Aluminum Vol. 1, ASM, Ohio, 1967.

Atlas of Electrochemical Equilibria in Aqueous Solutions, Marcel Pourbaix Pergamon Press, New York (1966).

(12) Aqueous Corrosion of Aluminum Part I Behavior of 1100 Alloy, J. E. Draley ll. E. Ruther, Corr. 12 44lt', 1956.. 'nd (i3) 'Observations on the Mechanisms and Kinetics of Aqueous Aluminum Corrosion,"

VS H. Troutner, Corr. 13 595 (1957)

(i4) A Survey of Materials and Corrosion in Dry'ooling Applications, A. B. Johnson,Jr.

D. P. Pratt and G. E. Zima, BNlJL-1958, UC-12 1976.

(15) Private Communication between R. McGoey and B. C. Fryer.

Dynamic Corrosion Studies for the High Flux Isotope Reactor, J. L. English and J. C. Griess, ORNL-TM-'1030 1966,,0ak Ridge National Laboratory.

(17) Galvanic Corrosion of Al Alloys I Effect of Dissimilar Metal, F. Mansfeld, D. H. Hengstenberg and J. V. Kenkel Corr. Vol. 30, No. 10," Oct. 1974, P. 343.

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XN-NS-TP-009 E ON UCLEAR APPENDIX A BORAL SPECIMENS Thirty (30) pie'ces of Boral, 2" x 2", were received from Brooks and Perkins. Twenty-seven (27) were used in the tests and the remain-ing held for spares and basic metallography. The Boral material is 0.078-i'nches thick with an aluminum clad thickness of 0.010-inches,.

and a B4'C-aluminum matrix thickness of 0.058-inches. The core contains 10 a minimum of 0.020 grams, per square centimeters, of B The samples .to be used in the tests were numbered according to a Controlled Test Procedure. The Boral pieces were cleaned ultrasonically for 5 minutes in reagent grade alcohol, rinsed in alcohol, and air-dried.

The rtwo (2) surfaces of each piece were then photographed at a magni-fication of 1.5X to record the initial microscipic condition.

In order to determine the initial weight of each Boral sample, they were dried in, an oven at 300'F for one hour, cooled in a desicca-tor, and weighed. The weight of each piece is listed in Table 2.1..

Specimens 19-27 were weighed after a 1/16u hole had been drilled in the center of one face to an approximate depth of .040-'inches.

STAINLESS STEEL SPECIMENS The stainless steel samples (T-304 '2B Stainless Sheet) were cleaned .

and passivated according to the following schedule: Ultrasonically cleaned in detergent water for 30 minutes and tap water rinsed, passivated in room temperature 15% nitric acid for 30 minutes, rinsed in distilled water, and wiped dry.

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XN-NS-TP-009 E ON UCLEAR The 'specimens were then oven-dried at 300'F for one hour, cooled in a desiccator, and weighed. The sample number, size, and weights are given in Table 2.2. Specimens 19a-27a were weighed after' 1/16" hole was drilled through the center of each.

EDGE-SEALED AND STORAGE CELL SPECIMENS I

The nine (9) edge-sealed specimens were-made of a 2" x 2" Boral coupon sandwiched between two (2) 2-1/2" x 2-1/2" stainless pieces.

The perimeter of the sandwich was sealed with RTV sealant in such a way that a gap, approximately 1/4" deep, exists between the sealant and the Boral edge. A 1/16" hole was drilled through one of the stainless liners and into the Boral, approximately .040-inch deep, at the center of one face. The coupons were filled with the- appro-priate solution and ingress to the interior occurs, through the center hole. The depth of the hole, in each Boral coupon, is listed in Table 2.3.

The storage cell samples were received from Brooks and Perkins on July 7, 1977. Each of the nine (9)'ell samples were weighted with the following results:'torage Cell S ecimen Wei(eht Kq 2.754 2.700 2.694 2.705 2.716 2.719 2.725 2.727 2.753 Use, reproduction, transmittal or disclosure of the above Inlormatfon is subject to the restriction on the llrst or title patte ol this document.

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XN-NS-TP-009 E ON UCLEAR Three (3) 1/16n holes were drilled through the stainless steel shroud to enable the environment to enter the interior of the shroud to simulate a leak. Two (2) holes were drilled through the steel liner adjacent to the longitudinal welds on opposite sides of the cell specimen. The holes were located at the space just abov'e the Boral plates at the top and bottom of the steel liner. A third hole was drilled in the center of the face with'the exterior lohgitudinal weld which penetrated through the stainless liner and partially into the Boral plate.

A-3 Use, reproduction, transmittal or disclosure of the above Information is subject to the restriction on the first or title patte of this document.

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NN-NS-TP-009 E ON UCLEAR.

TABLE 2.1 S ecimen No. ht; ms.

1 13. 07534 2 12.92862 3 13.15619 4 13.01482 5 12.50052 6 12.94034 7 12.65638 8 12.45607 9 12.67761 10 12.78939 11 12.73945 27'lei 13.04195 12 13 12.83988 14 12.97783 15 13. 16179 16 12.25492 17 12.70607 18 12.88145 19 12.73691 20 12.76902 21 12.81245 22 12.74536 23 12.82162 24 12.79287 .

25 12.31567 26 13.00877 12.74711 A-4 Use, reproduction, transmittal or disclosure of the shove Iniormstlon Is subject to the resttiction on the ilrst or title psge of this document.

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XN-'NS-TP-009 E ON U CLEAR TABLE 2.2 Ho. Size . ~Wi N; . N.'ize llei ht, ms.

10a 2"x2" 38.89595 19a '-1/2ux2-1/2" 60.79322 II lob 39.82520 19b 61.05405 lla 38.89082 20a 60.84419 lib 39.68805 20b 60.94462 12a 38.53197 21a 61.03033 12b 38.68259 21b 61.39631 13a 39.56829 22a 61.41475 13b, 3,8.. 40278 22b 60.85141 14a 40.03330 23a 60.90979 14b 39.96712 23b 61.79174 r

15a 38.85374 24a 61 '0493 15b 38.63247 '24b 61.08312

'5a 16a 38.82814 60.93235 16b 38.75806 25b 60.80852

'7a 38.63605 26a 60.88068 17b 38.41275 26b 60.78854 18a 39.01611 27a 60.75921 18b, 38.70722 27b 60.78874 A-5 Uso, reproduction, transmittal or disclosure of the abovo Information Is subject to tho restriction on the first or titlO page of this document.

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XN-NS-TV-009 E ON UCLEAR TABLE 2.3 S ecimen No. Hole De th Inches

~

1.9 .047 20 .035 21 .. 035 22 .035 23 .039 24 .047 25 ~ 047 26 ~ 051 27 .047 A-6 Use, reproduction, transmittal or disclosuro oi tho above information Is subject to the rostrlction on the rirst or titlo page oi this document.

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XN-NS-TP-009 E ON U CLEAR APPENDIX 8 6 Section 4.0 (Tables and Figures) 6 Supplemental Test Results For Other Test Specimens Use, reproduction, transmittal or disclosure of the above Information is subject to the restriction on the first or title patte of this document.

XN-NS-TP-OO9 E ON U CLEAR TABLE 4.1 SPECIMEN IDENTIFICATION 'NUMBER AND EXPOSURE TIME*

Environment 1 1 E~dd d Ex osure Da s A (Boron) 2 .12 364 B (Boron and Lithium) 15 364 C (Lithium) 8 17 364 Storage Cell Environment ~d-E 1 d E~i Ex osure Da s)

A (,Boron) 21 S.C.S.-3 (1,2,3,4) 370 B (Boron and Lithium) 24 S.C.S.-6 (1,2,3,4) 370 C (Lithium) 27 S.C.S.-9 (1,2,3,4) 364 A total of 36 specimens were utilized during the test program.

Specimens not listed above were. evaluated during the 2-month and 6-,month'evaluation phases.

- Values in parenthesis are the four (4) individual Boral plates .

contained within the storage cell specimens.

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XN-NS-TP-009 E ON UCLEAR TABLE 4.2 INTERIOR SOLUTION H

~E ~dkk ~dd -1 1 d ~EC 11 A (Boron) 2 Ho. 5.0 5.8 6 Ho. 5.0 6.1 5.9 12 Ho. 4.8 5.0 5.0 B (Boron and Lithium) 2 Ho. 5.6 6.0

'6 Ho. 5.7 6;5 5.9 12 Ho. 5.6 5.0 5.2 C (Lithium) 2 Ho. 8 ..5 7.9 6 Ho. 9.2 7.5 7.8 12 Ho. 9.6 7.0 7.8 Use, reproduction, transmittal or disclosure of the above information Is subject to the restriction on the first or title patte of this document.

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XN-NS-TP-009 E ON UCLEAR TABLE 4.,3 12-MONTH EXPOSURE WEIGHT OF BORAL PLATES FROM STORAGE CELL Cell/ 'Original Weight As Weight As sW h W Corr.

Plate ~Mt. ms Removed ms Dried ms On Dr in ms ~ms)

S.C.S.-3 (1) 76.8973 79.26654 78.82035 "-0. 44619 +1. 92305 (4) 77.6335 78.,83673 79.47447 -0.36226 +1.84097 (3) . 78.3163 80.57643 80.13166 -0.44477 +1.81536 (2) 76.7407 78.95639 78.61309 -0.34330 +1.87239 S.C.S.-6 (2)- 76. 5611 78.84505 78.54603 -0.29902 +1.98493 (3) 77.2583 79.35079 79.12012 -0.23067 +1.86182 (4) 76.7592 78.17358 78.01435 -0.15923 +1.25515 (1) 77.7683 80.42402 80.09471 -0.32931 +2.32641 S.C.S.-9 (3) 78. 0971 80.74073 80.44607, -0.29466 +2.34897 (4) 78. 0672 80. 12927 79.96575 -0.16352 +1.89855 (1) 77. 1018 79.47767 . 79.22429 -0.25338

+2.12249'1.88411 (2) 77.0113 79.08118 78.89541 -0.18577 B-4 Use, reproduction, trsnsmittsl or disclosure of the shove informstion is sutsiect to the restriction on the first or title psge of this document.

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I W W W W W W W W W W W W W W W TABLE 4.4 ZO MOISTURE ABSORPTION-i<EIGHT PERCENTAGE

SUMMARY

0 hei ht Loss Percenta e On Dr in 4

4 4

A Environment B Environment C Environment D ecimen T o

S e 2 Mo. 6 Ho. 12 Ho. 2 Ho. 6 Mo. 12 Ho. 2 Mo. 6 Ho. 12 Ho.

o c n

4 o Plain 0.44 0.39 0.71 0.40 0.30 0'.41 0.42 0.17 0.55 4

~ II o3 Open-Edged 0,62 0. 59 1.27 0.55 0.31 0.57 0.70 0.22 0.55 o

Z 0 4 a 0

VI 4

Sealed-Edged 0.53. 0.37 0. 65 0.63 0.36 0.55 0.49 0.28 0.59

~

0 o o 0

Storage Cell Specimen II 4 4 (4 Plate Average) 0.29 0.41 0.54 0.33 0.32 0.33 0.23 0.48 0.29 o~ < 0 4

4 4 Specimen Average 0.47 0.44 0" 79 0.48 0.32 0.46 0.46 0.29 0.50 o o 3>>

4 0 4

C o'

0<

I CI)

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CO

20 TABLE 4.5 CORROSION WEIGHT GAIN PERCENTAGE g) 4 D

0 A Environment B Environment .C Environment 0 C0. ecimen T e 2 IIo. 6 11o. 2 Ho. 2 tho.

6 No. 12 Ho.

n S 2 Ho. 6 Ho. 12 Ho.

0 0 4

OI n

Q n

Plain 1.68 2.85 3.34 1.79 2.83 3.06 1.84 2.99, 3.63 0

0 Z 0 Open-Edged 2. 00 2.91 2. 85 1. 94 2.93 3.03 2.21 3.24 3.81

%1

~0 n

0 0 0 0

0 Sealed-Edged 2.18 3. 62 3.81 2.19 3.12 3.96 2.69 4.10 4.46 D

o4 n

0 0' Storage Cell Specimen n

C 0

(4 Plate Average) 1.39 1. 94 2.41 '(1.49 (2.00) ~(2.54 ~(1.73 ~(1.98 2.66 0 0 n

0 3

O 0 0 4 Specimen Average 1.81 2.83 3.10 1.83 2.72 3.12 2.12 3.08 .

3.64 VI

>C I

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XN-NS-TP-009 E ON UCLEAR P

TABLE 4.6

SUMMARY

OF PIT MEASUREMENTS AFTER 6-MONTH AND 12-MONT)l,EXPOSURE Thru Clad Hax. Pit Pit Specimens and Total Pit/Area Pit/Area Depth Diameter Environment ~Ex osure (f/s . in. f/s .in. ~in. ~in.)

.Plain 2(A) 12 Ho. 3.7 2.3 0.032 0.16 i(A) 6 Mo. 1.2 0.5 0.015 4(B) 12 Ho.

5(B) 6 Mo.

8(c) 12 Mo.

9(c) 6 Ho.

0 en-Ed ed i2(A) 12 'Ho. 13 3 10. 0 0.020 0.19 io(A) 6 Mo. 11.8 5.1 0.019 i5(B) 12 Mo. 2.5 1.5 0. 021 0.07 i3(B) 6 Mo. 2.9 0.6 0.013 i7(c) 12 Mo. 3.8 2.2 0.018 '0.13 16(c) 6 Ho. 3.0 0.3 0.011 Sealed-Ed ed 21(A) 12 Mo. 3.9 0.7 0. 015 0. 06.

20(A) 6 Ho.

24(B) 12 Mo. 5.2 0.9 0. 019 0.04 23(B) 6 Ho. 0.3

.27(c) 12 Mo.

26(c) 6 Ho. 0 2

~ 0.2 0. 017 Stora e Cell S ecimens S.C.S.-3(A) 12 Ho. 0.7 0.1 0. 014 0.07 S.C.S -2(A)

~ 6 Mo. 0.9 0.2 0.011 S.C.S.-6(B) 12 flo. 0.1 S.C.S.-5(B) 6 Mo. 0.3 0.1 0. 012 s.c.s.-9(c) 12 Mo.

s.c.s.-8(c) 6 Mo.

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Xf<-NS-TP-009 E ON UCLEAR TABLE 4.7 SURFACE OXIDE THICKNESS AND DEPTH OF UNDERCUTTING Specimen and Undercutting At Oxide Thickness Environment) Ed e and Hole in. Microns 2(A) 0. 020 3' i2(A) 0. 028 ~

Not f1easurable 21(A) Not Measurable 2.9 S.C.S-3(A) Not Measurable Not f1easurable 4(B) 0.008 3.6 i5(B) 0. 007 4.6 24(B) Not Measurable Not Measurable S.C.S-6(B) Not Measurable Not Measurable 8(C) 0. 005 8.2 17(C) 0. 009 Not Measurable 27(C) 0. 014 5.5 S.C.S.-9(C) Not t1easurable Not I'1easurable B-8 Use, reproduction, transmittal or disclosure of the above information Is subject to the restriction on the first or title patte oj this document.

GR~5

XN-NS-TP-009 E ON UCLEAR TABLE 4.8 BULGES OBSERYED ON 12-MONTH EXPOSURE SPECIMENS

~Secimen Hei ht in. Di ameter in. Environment 3 (1) S.C.S. .004 .23 A 3 (2) S.C.S. A 3 (3) S.C.S. A 3 (4) S.C.S. A 6 (1) S.C.S. .003 .3 B 6 (1) ,S AC.S. .009 .25 B 6 (1) S.C.S. .005 .2 6 (1) S.C.S. .017 .25 B 6 (1) S.C.S. .005 .3 B 6 (2) S.C. S'. B 6 (3) S.C.S. B 6 (4) S.C.,S. B 9 (1) S.C.S.

9 (2) S.C.S.

9 (3) S.C.S.

9 (4) S.C.S.

2 Plain A.

12 Open-Edge .009 .4 A 21 Edge-Seal .027 .54 A 21 Edge-Seal . 008. .49 A 21 Edge-Seal . 020 .43 A 21 Edge-Seal .015 .40 A 4 Plain 15 Open-Edge 24 Edge-Seal .009 .26 24 Edge-Seal .01 .29 24'4 Edge-Seal . 004 .2 Edge-Seal .003 .25 B.

8 Plain .086 1.43 ~

C 8 Plain .004 .15 C

,17 Open-Edge C 2? Edge-Seal .014 .47 C 27 Edge-Seal ,. 026 .51 C 27, . Edge-Seal .027 .9 C

27. Edge-Seal .010 .39 C B-9 Use, reproduction, transmittal or disclosure of the above information is subject to the restriction on the first or title patte of this document.

G R405

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XN-NS-.TP-009 FIGURE 4.1 Photo ra h 1 PRETEST BORAL SPECIMEN (With 'Large Number of Unbonded Areas)

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FIGURE 4.3 L CLOSEUP VIEW OF BULGED SPECIMEN*
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W W % W W W W W % % W 8 Plain Open-Edged Edge Sealed 5.0 Storage Cell 4.0 3.0 cv .
CB GJ 2.0 1.0 I 1 2 10 Exposure Time, t1onths FIGURE 4.4 Height Gain Percentage for "A" Environment Specimens.
" 8 Plain Q Open Edged EI Edqe Saaled 5.0 V Storage Cell 4;0 cR 3.0
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FIGURE'4.5 'Height. Gain Percentage Ve'rsus Time For "8" Environment Specimens
8 Plain Q Open Edged H Sealed Edged 5.0 Storage Cell 4.,0 3.0 2.0 1.0 12 Exposure Time, Honths FIGURE 4 6 ':Jeight Gain Percentages Versus Time For "C" Environs)ent Specimens,
4.35 OC I
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12 480 I (40 yr.) CD CD Exposure Time, months FIGURE4.7 Semi-Log Plot Shoiving Height Gain Percentage For "A" Er vironm nt Storage Cell Specimens, Extrapolated to 40 Years.
I I
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4.5 480 (40 yr.)
Exposure Time, fIonths FIGURE 4.8 Semi-Log Plot Showing ':Ieight Gain Percentage for "8" Environment Storage Cell Specimens, Extrapolated to 40 years.
l2 480 Exposure Time, Months (40 yr.)
FIGURE 4.9 Semi-Log Plot Shoving !,"eight Gain Percentage for "C" Environment Storage Cell Specimens, Extrapolated to 40 years.
XN-NS-TP-009 E ON U CLEAR 12-MONTH EXPOSURE WEIGHT OF NON-STORAGE CELL BORAL SPECIMENS Specimen 8 Original Weight As Weight As h W h W Corr.
Environment ~Mt. ms Removed ms Dried ms On Dr in 'ms
~ms 2 (A) 12.92862 13.45214 13.36061 -0. 09153 +0.43199 4 (8) 13.01482 13.46598 13.41246 -0.05352 +0.39764 8 (C) 12.45607 12.97673 12.90873 -0.06800 +0.45266 i2 (A) 13. 04195 13. 57893 13.41358 -0.16535 +0.37163 15 (8) 13. 16179 13.56057 -0.07550 +0.39878 13.63607'3,26022 i7 (C) 12.70607 13.19047 -0.06975 +0.48440 21 (A) 12.81245 13.38430 13.30083 -0.08347 +0.48839 24 (8) 12.79287 13.36994 13.30008 -0.06986 +0.50721 27 (C) 12.74711 -13.39136 13.31581 -0.07555 +0.56870 I ~
8-19 Uso, reproduction, transmittal or dlsclosuro of the shove Information Is subject to tho restriction on the first or title page of this document.
GR~5
XN-NS-TP-009 E ON UCLEAR SUPPLEMENTAL VISUAL INSPECTION OBSERVATIONS
~5i 52 5 if 1igh<< 4 g.
Several pits were evident under the pedestal area and the edges were completely covered with white tan corrosion products.
a i 4444 5 if d igh iy dh d k surface coating. No pits under pedestal area and the edges were black but showed no corrosion products except a few rus't streaks.
a 4 2 1igh g y << f tion.'hree (3) black spots, one about 1-inch in dia-meter, corresponded to areas where the surface clad had
'ulged away from the B<C aluminum matrix. The black were made up of stripes and looked as if the defor-
'pots mation associated with the bulge had broken the protec-tive oxide film, allowing rapid corrosion of the under-lying metal. Similar bulges were seen on six (6) of the other specimens and are discussed in another section of this report.
~gi 412- h'id h dgi kg 1 g 2 dg The surface coloration was grey with white and brown corrosion products as'in the plain specimen from the A environment.
415-fh 1 4 d k h h A tank specimen but showed less pitting.
8-20 Use, reproduction, transmittal or disclosure ol ihe above Inlormation is subject to the restriction on the first or title page of this document.
I XN-NS-TP-009 E ON 4 U CLEAR
~gi ~ 411 - Th 1 1 1 11gh 2 d the exposed edges were covered with loosely adherent white corrosion products. Some pits near edges.
Figure 2 shows the edge-sealed specimens from the three (3) environments. The surfaces are those where the leak simulating hole was drilled through the stainless cover and partially through the Boral. The coloration is similar to what was observed in the plain and open-edged specimens. The amount of corrosion products on the specimen edges, however, was much less.
421 hh d 2 1 d 1 d around the center hole and some white corrosion on edges.
Shallow pitting was on some areas but no pits evident through the cladding. A small bulge existed on side opposite hole.
~di sitee. 424 - 1. 1. 1 d h h 1 d 24C stringers showing but few, if any, deep pits.
421 C 1 1 1 hh 11'gh g (2) bulges, one large on hole side and one, small oppo-Edges are heavily covered with white corrosive products.
8-21 Use, reoroduction, transmittal or disclosure of the above Information Is subject to the restriction on the first or title page of this document.
4 GR~S
I This Document contains proprietary infor-mation and is not to be transmitted or re-produced without specific wri tten approval from Combustion Engineering, Inc.
Copy No. Qf CALVERT CLIFFS UNIT I CYCLE 4 June, 1980 REPORT. OF POWER DISTRIBUTION EPISODE October 1979 - May 1980
TABLE OF CONTENTS PAGE
SUMMARY
I I. NARRATIVE I I I. CORE PARAMETER OBSERVATIONS AND DIAGNOSTICS 17 A. Physics Analyses
1. Core Follow Model and Results
a. Reactivi ty
b. Axial Shape Index
c. Radial Power Distribution
d. Power Coefficients
2. Burnup Distr ibution Perturbation Model and Results
3. General Physics Conclusions B. Core Differential Pressure . 23 C. Temperature Distribution D. Postulated Mechanisms 26 IV. CHEMISTRY OBSERVATIONS, EVALUATIONS, AND ACTIONS 40 A. Routine Water Chemistry Surveillance Program
1. Reactor Coolant System
2. Chemical and Volume Control System
3. Makeup Demineralized Episode Chemistry B. Power Distribution Episode Chemistry 53
1. Trends of Significant Chemistry Parameters a-. pH
b. Conductivity
c. Lithium
I I
I I
I I
PAGE
d. Suspended Solids
e. Hydrogen
f. Oxygen
g. Iodine Activity
h. Ammonia
2. Evaluations and Actions
a. Reactor Coolant System Lithium Concentration
b. Hydrazine Addition to Reactor Coolant System
c. Oxygen Ingress to Reactor Coolant System
d. Hydrogen Peroxide Treatment
e. Reactor Coolant System Crud Samples Modifications to Chemistry Surveillance Prognam C. Post-Episode Chemistry History 144 D. Permanent Modifications to the Routine Water Chemistry 154 Surveillance Program E.Section IV Attachments 156 F.Section IV References 171 Y. CONCLUSIONS AND LESSONS LEARNED 172 APPENDIX A Chemistry Results of the Unit 1 Hydrogen Peroxide 174 Treatment
SUMMARY
ff t In 1 ate October, 1979, Ca 1 vert Cl i s Uni 1 Reactor Core began to exhibi t unpre'dieted behavior. The local power distribution began to grow asyometric axially and an abnormal shift in power to the core periphery began to occur.
The initiation of the core power distribution change proceeded by about two weeks the beginning of a slow increase in differential pressure across the
,reactor core. The increase in differential pressure across the reactor core peaked at 1.8 psid, 13% above normal,. The supposition was that the increase in differential pressure reflected deposition of crud on core surfaces. The crud acted as a neutron absorber and/or insulator, thereby, forcing a core power redistribution.
Concern for the effect of the anomalous core behavior on the safety analysis and the crud layer on fuel integrity led to successive power level decreases until 50% was reached in early November.
The crud was postulated to consist of corrosion products from Reactor Coolant System (RCS) surfaces. The higher than normal amount of corrosion products were probably caused by an abnormally high ingress of Oxygen into the RCS, The source of=,that ingress was found and isolated in late October. By this time, the axial power imbalance had reached a peak of ill. The canbination of power level decreases and isolation of the Oxygen source coincided with a slowing and eventual reversal of the growth in axial power imbalance.
However, core differential pressure (dp) remained at 1 to 1.8 psid above normal.
Plant Site and Combustion Engineering Task Forces were organi,zed to determine the cause of anomalous core behavior, to assess its effect on plant safety, and to seek a resolution. A comprehensive diagnositic program was implemented including development of a model of the phenomenon. The Task Forces labored from early November through late January, 1980. Meanwhile, the situation" slowly corrected itself and by late January, all core parameters, with the exception of core dp, were near normal. Core dp was still 1.8 psid above normal.
I I
I I
I
SUMMARY
(cont'd)
During a cold shutdown in late January, the RCS was treated with hydrogen peroxide. Significant crud releases were observed and upon return to power operation, core dp was observed to be normal, No fuel failures were observed during the episode. In late March, the issue was considered satisfactorily resolved and the Task Forces were disbanded.
Task Force investigations resulted in the implementation of several permanent changes to plant surveillarice and operating instructions.
Several hardware modifications are also being pursued. In order to assess any lasting effect of the episode on fuel integrity, a fuel inspection program will be performed at the next refueling, currently scheduled for October, 1980.
In late May, 1980, Unit 1 is operating at full power and all core and fuel performance parameters are normal.
I I
I
I I. NARRATIVE At approximately 0800, October 22, 1979, the Plant Nuclear Engineer observed that. the Axial Shape Index (ASI), Planar Radial Peaking Factor (F ), and Integrated Radial Peak (.F ) had been steadily xy since the previous week. Azimuthal
'ncreasing tilt (T ). had been q
holding steady at about .006. Predictions indicated that F r and Fx should experience a very slow decrease in magnitude with core burnup.
During the next three days, The Plant Staff increased surveillance on the critical core parameters from once every eight hours to once every hour and prepared local power distribution maps in order to assess the degree of local change in power distribution since October 13. In addition, a systematic review of other plant information was begun. Specifically, beginning with Cycle 4 Startup, trends of the following parameters were evaluated:
- Hydrogen Overpressure in the Volume Control Tank
- Differential pressure across Reactor Core and Reactor Coolant Pumps
- Hydrogen concentration in the Reactor Coolant System On October 25 a package of raw core power distribution data was forwarded to Combustion. Engineering (CE) for analysis in accordance with a standard core verification program performed for Calvert Cliffs by CE, At about 0800 on October 25, the measured peak linear heat rate was 10.7 Kw/ft.,
F was 1.45, Fx was 1.56, T was about .007, and Internal Axial Shape Index was +7.6X. Out of a precautionary concern for fuel integrity, the Plant Nuclear Engineer limited reactor power such that a summation of measured power level plus the Axial Shape Index would not exceed 108K, This was a simple technique for maintaining the peak linear heat rate at or below that which had been successfully experienced through October 25.
On October 26, the Plant Nuclear Engineer began a periodic transmittal of core parameter trend data to CE. See Figures II,1 and II.2.
F h
NARRATIVE (cont'd)
On October 26, the Plant Staff suspected the cause of the increasing pressure drop across the reactor core was due to an increasing crud deposition on fuel surfaces and began a search for sources of Oxygen into the Reactor Coolant System. During this time, it was also observed that trend data indicated a lower than normal Hydrogen concentration in the Volume Control Tank. By October 29, the source of Oxygen had been identified and isolated. While Number 11 Deborating Ion Exchanger was in service (See Figure II.3), it appears that air was introduced into the purification system via the Instrument Air header.
Instrument air is normally used to transfer spent resin. Apparently, two (2) valves (1-IA-234 and I-CVC-151) leaked by their seats allowing air to be introduced into the outlet of the ion exchanger, When sampled, the ion exchanger outlet had an Oxygen concentration of 300 ppb, The ion exchangers were bypassed and the Instrument Air header drain valve (I-CVC-154) was opened and left open to ensure that the header remained depressurized; thereby precluding introduction of Oxygen into the Reactor Coolant System.
On October 27, CE verified the power redistribution observed by the Plant Nuclear Engineer. The core was experiencing a slowly increasing roll of power toward the core center and toward the core bottom. Whereas prediction did indicate a slow roll in power to the core center, the measured roll was greater than the prediction. The prediction did not indicate a roll in power toward the core bottom.
Early the week of October 29,the Plant Staff and CE concluded that the cause of the power redistribution was a crud buildup on the fuel rod surfaces, preferentially to the top of the core. The crud would contain iron and other oxidized constituents of stainless steel which would act as a mild poison to the fission reaction; and in addition, the crud may change the heat transfer characteristics across the fuel rod resulting in an increasing Doppler feedback effect, This conclusion was also consistent with a small reactivity anomaly evident in a trend of measured versus predicted boron concentration in the Reactor Coolant System.
See Figure II.4.
I I
I I
I I
I I
NARRATIVE (.cont'd)
/
On November I, the Plant Staff and CE began a discussion of strategies for removing crud from the fuel rods, In addition, the Plant Staff began analyzing for Hydrogen at a Reactor Coolant System hotleg sample point. At no time prior to and during the observation of the core power redistribution was Oxygen observed in the Reactor Coolant System (RCS).
However, as a precaution, the Hydrogen concentration in the Volume Control Tank was increased resulting in a corresponding increase in Hydrogen concentration in the Reactor Coolant System.
On November 2, the Plant Nuclear Engineer directed CE to begin a correlation of crud thickness and other characteristics with reactor power redistribution as well as a quantitative evaluation of its effect on the safety analysis.
On November 3, the Plant Chief Engineer organized a Power Distribution Task Foi ce chaired by the Plant Nuclear Engineer and consisting of the Plant Radiation-Chemistry Engineer and the Plant Operations Engineer.
On November 5, the ISE Regional Office was informed of the Power Distri-bution Episode by the Shift Supervisor and also by the Plant Chief Engineer.
In addition, the Plant Nuclear Engineer responded to a query from the NRC Project Manager for Calvert Cliffs. At this time, no plant technical specifications had been exceeded. The parameter closest to a limit was T
F which was measured at 1.64. Limit is 1.66.
On November 6, CE informed the Task Force that CE's preliminary evaluation revealed the possibility of lithium concentration in the presence of local boiling in the porosities of the crud layer. Therefore, CE recommended a decrease to 805 power in order to alleviate that concern and to gain more margin. The Task Force concurred and reactor power was decreased to 805.
I I
NARRATIVE (cont'd)
By November 7, the strategy for removing crud had been developed. Lithium concentration would be increased slightly from less than I ppm to about 2 ppm in the Reactor Coolant System, thereby raising pH and creating an environment for slow dissolution of the crud layer. At this time, CE had completed their evaluation and determined that the appropriate power level for precluding local boiling in crud porosities at the hottest point in the core was 50K. CE recommended that the increase in lithium concentration in the RCS take place at that power level.. The Task Force concurred.
In addition to determing the cause of and resolving the power mal-distribution, a charge to the Task Force was to keep the Plant and Offsite Safety Comnittees informed. Beginning November 5, the Plant Safety Committee was briefed periodically and on November 8 the Task Force made a written report to the Offsite Safety Committee.
By November 8,, the reactor had been stabilized at 50% power and lithium additions to the RCS had begun in order to gain and maintain the concentration in the RCS at about 2 ppm. The purification ion exchanger was put back in service. Also, CE formed a Task Force consisting of members with physics, thermo-hydraulics, materials, and chemistry backgrounds..
On November,9, Brookhaven National Laboratory (BNL) began investigation of the anomaly at the request of NRC staff. Plant data was provided BNL via CE engineers who were diagnosing the anomaly and developing a model.
By November l7 potential causes for the anomaly other than crud had been reviewed and discarded including: broken CEA finger, mechanical flow blockage, pressurizer heater insulation, and buildup of isotope(s) with high neutron cross sections. Also on November 17, the first in a long series of reactivity (temperature and pressure as well as power) coefficient measurements were made. It yielded a larger than normal power coefficient.
The other coefficients were normal.
I I
I I
NARRATIVE (,cont'd)
By November 19, core parameters (ASI -and F xy )
had stabilized to well within technical specification limits and core dp was steady at 14.7 psid.
CE recommended a power increase to 60Ã for further evaluation of core parameter trends. The Task Force concurred and power was increased to 60% on November 21 after performance of another power coefficient measurement. During the next ten days, CE completed a review of the effect of the power redistribution and reactivity anomalies on the safety analysis and concluded that a conservative evaluation of the data would allow operation at 70K power. As long as core dp remained less than 15.0 psid with no discernable upward trend and other core parameters (ASI, F ) remained steady or improved, concern for fuel integrity at xy 70K power was minimal. On November 30, CE recommended a power increase to 705. Fx was 1.49 (down from a high of 1.64 on November 6) and decreasing, ASI was steady and core dp was 14.6 psid. The Task Force concurred in the CE recommendation and on November 30 power was increased to 70K for the purpose of additional observations and measurements at higher power level.
On December 5, another power coefficient measurement was performed and indicated an improving, trend but a still significantly higher than normal value. A fifty liter millipore crud sample was also collected and sent to CE for analysis of its constituents. During the following week, contingency plans were refined for a Hydrogen Peroxide treatment to remove crud and for a fuel inspection (visual and zirc-oxide layer thickness measurements).
On December 8, 9, and 10 a series of pressure, temperature and power coefficient measurements were performed. The purpose of the pressure (void) coefficient measurement was to detect the presence of voiding in the porosities of the inferred crud layer. None was evident. However, ASI and Fx values had shown significant and unpredicted increases over those values existing at the 60K power plateau. Therefore, when data collection was completed on December 10, power was reduced to 50K.
I I
I I
NARRATIVE (cont')
During the next 10 days, plans were laid and procedures prepared for a Hydrogen Peroxide treatment. RCS lithium concentration was allowed to drift toward zero in anticipation of a cold shutdown for the treatment. Meanwhile CE was evaluating the data from the 70Ã power plateau as well as that from reactivity coefficient measurements made on December 13, 14, 16 and 17. Several power coefficient measurements were performed on Unit 2 for comparison with Unit 1 coefficients. Unit 2's measured results were normal and as predicted.
On December 20, it was concluded that an unexplainable increasing trend in core dp over the last ten days (14.6 to 15.5 psid) probably reflected an oxidizing medium in the RCS. An oxidizing medium would make the Hydrogen Peroxide treatment ineffective. Consequently, beginning December 20, hydrazine additions were made to RCS makeup water at every addition of makeup water to the Volume Control Tank.
Also, CE was not yet able to adequately model the burnup and power dependent behavior of the power maldistribution. The phenomenon was obviously more complicated than that .explained by any single postulated mechanism (neutron cross section of crud, insulating effect of crud/zir c oxide, boron concentration in crud porosities, etc.). Consequently, even though F was slowly decreasing and ASI was stable, a power increase was premature.
On December 22, it was concluded that the increase in core dp was probably due to a combination of aerated RCS makeup water and short term injections of air into purification ion exchangers during resin transfer. Procedures were changed to remove all inservice ion exchangers from service during a resin transfer anywhere in the system. This action, in combination with the hydrazine addition, coincided with a stabilization of core dp at 15.5 psid.
I I
I I
NARRATIVE (cont'd)
Power coefficient measurements on December 27 and January 2, 1980 continued to show an improving trend. Other core parameters as well as core dp were still stable or improving. Based on this encouraging evidence, CE recommended an increase to 60% power in order to detect any change in the power dependent behavior of the maldistribution. The Task Force concurred with the CE recommendation and power was increased to 60K on January 3.
On January 5, a power coefficient measurement at 60K power confirmed an improving trend. In addition, the power dependence of the core parameters continued to approach normal. Core dp unexplainably stepped up to 15.6 psid on December 4 but stabilized there. On January 7, this encouraging trend prompted a CE recommendation to increase power to 70K for further measuremeqts and observation of the power dependence of core parameters. The Task Force concurred and power was increased to 70K. As a contingency, work on a full core replacement option was begun; the core replacement to consist of about half new fuel and half previously discharged fuel.
The results of power coefficient measurements on January 11 and 14 as well as observation of a near normal power dependence of core parameters at the 70K power plateau were encouraging. However, core dp was still about 15.5 psid; 1.8 psid above normal. For this reason, power was decreased to 50% on January 15 and remained there until the Unit was put in cold shutdown on January 26 for TMI related modifications.
Power coefficient measurements on January 17, 18, and 19 added to the expanding data base and continued to confirm improving trends. However, core dp did not budge from 15.6 psid.
I I
I I
, NARRATIYE (,cont'd)
On January 22 NRC staff was briefed on the episode by BG&E and CE at a meeting in Bethesda. At the previous request of NRC staff BGSE also explained the procedure for Hydrogen Peroxide treatment.
NRC staff declined to be an impediment to performance of a Hydrogen Peroxide treatment or to be an advocate of a fuel inspection.
On January 26, coincident with the start of cold shutdown, Hydrogen Peroxide treatment of RCS was initiated. Three Hydrogen Peroxide injections were made on January 27. Encouraging crud releases were observed. Clean up of the RCS via purification ion exchangers continued until late January 29. Calibration of the core dp sensing device was confirmed. Effect on core dp was ambiguous until the plant was returned to a hot shutdown condition on February 10 at which time core dp was measured at 14.0 psid. This improvment exceeded the most optimistic predictions. Therefore, contingency plans for continuing the decrudding process by raising Lithium concentration in the RCS to 15 ppm while remaining in hot shutdown were delayed, From February 10 through 11, a short post-shutdown zero power test program including a critical boron concentration measurement, iso-thermal temperature coefficient measurement and a worth measurement of CEA 5-1 was performed. Measured data agreed with predictions.
Based on this evidence, near normal values of core parameters. and a near normal core dp, power was increased to the 505 test plateau on February 12.
During the next week, core dp slowly decreased to 13.8 psid, A power coefficient measurement on February 15 yielded near normal results.
Other core parameters were near normal. Based on this encouraging D
evidence, power was increased to 70K on February 19.
I I
I I
I
NARRATIVE (cont'd)
Power coefficient measurements on February 21 and 22 continued to show improvement. Other core parameters and core dp'were normal, There was still no evidence of fuel failures associated with the episode, A conservative treatment of the effect of the episode on the safety analysis ~
justified 100% power operation. Out of a concern for any lingering effects of the episode on fuel integrity power was increased to 85'l on February 23 for an interim period and then to 1005 on March 6, After two weeks at 1005 and with all symptoms of the power distribution episode gone, on March 21 the Task Force concluded with CE's concurrence that special surveillance in effect during the episode could be relaxed toward normal. In addition, work on a core replacement option was terminated and Lithium concentration in the RCS was allowed to drift down to normal operating r ange. Lessons learned were incorporated into plant procedures and the Task Force was disbanded.
On March 21, core parameters including core dp were as predicted for an unperturbed core.
Power Level 2700 NWth Core dp 13,7 psid, steady Fx 1.425, slowly decreasing ASI +,01, steady (,unrodded core)
Local Power Distribution - normal Reactivity Anomaly - near zero ppm boron The fuel performance indicators were also normal.
I 131 ~.00~cc I 133 a. 034/cc
I NARRATIVE (cont'd)
On May 27 the nominal values of those same parameters were:
Power Level 2700 MWth Core dp 13.6 psid, steady F 1,415, slowly decreasing xy ASI +.Ol, steady (.unrodded core)
Local Power Distribution -
Anomaly - near zero boron normal'eactivity ppm I - 133 ~.003 ~cc I - 133 ~,03 ~/cc Figures I I. 5 and I I. 6 trend power 1 evel, core dp, Fand AS I from September 1979 through May 1980.
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I I I I I

I I I. CORE PARAMETER OBSERVATIONS AND DIAGNOSTICS A. Ph sics Anal ses Two types of physics analyses of this event were conducted. The first analysis was a simulation of the spatial perturbation required I to produce the observed effects. The second analysis involved core follow using a three-demensional ROCS model to quantify the departure of various core parameters from their expected values and is presented below.

1. Core Follow Models and Results A three dimensional coarse mesh nodal model (ROCS) was used for all analyses. Two sets of cross-sections were used. One set was based on the CEPAK spectrum code and had been previously used in the design of this reactor cycle. The othe'et was based on the assembly integral transport code DIT. This latter model better predicts reactivity levels and radial power distributions and was used more extensively in this analysis.

Each major parameter characterizing the core is described, and comparisons between measured and calculated values is given.

a. Reactivity A measure of the core reactivity is given by the soluble boron concentration. As the anomaly progressed, the core reactivity decreased, requiring a reduction in the soluble boron concentration of about 40 ppm at full power.

If this reduced boron concentration is input to a calculational model which does not contain any additional poison, the calculated reactivity will be high by an amount equal and opposite to the additional poison worth. 17

The results of such calculations are given in Figure III.l. Prior to the event, 13 values of boron concentration taken at full power were used to define the unperturbed reactivity level. During the event (10/24/79 to 12/3/79) a strong power dependence of the reactivity can be seen, Translated into a power coefficientt, his bias is equal to f-.85 x 10 ao/XP) which is almost as big as the unperturbed power coefficient itself. Since the measured boron concentrations are taken after 2-3 days of steady power operation, one must attribute a time constant of less than or equal to 1 day (3 time constants to reach equilibrium) to the power dependence. After 12/23 the reactivity level returned to normal.

b. Axial Shape Index The measured axial shape index (ASI) is displayed as a function of power level in Figure III.2. Following an increase of the ASI during 1005 power operation between 10/10 and ll/6, a linear variation with power can be seen, except for a small displacement following a four pump loss of flow incident on 11/12/79. During recovery, the ASI became strongly negative.

This is a consequence of having accumulated more burnup in the bottom half of the core during the previous two months, thus shifting the power to the top after recovery, The difference between measured and calculated ASI is given in Figure III.3. Again a linear dependence of the perturbation with power level can be seen. The difference in ASI during recovery is somewhat misleading because the core follow model does not account for the distorted burnup distribution. Never-theless, the change in ASI between 12/3 and 12/23 is an indica-tion of partial recovery.

c. Radial Power Distribution The power distribution distortion during the event was characterized by a shift to the bottom of the core as well as a shift to the core center. The amplitude of the radial shift was monotonic with core height suggesting that most of the reactivity defect was associated with the upper, outer region of the core. Therefore, the maximum radial peaking factors were located near the top, in the region covered by the fourth level of Rhodium detectors.

Two quantities were used to characterize the radial distri-bution, i.e., planar radial peaking factor, F, and gross shift amplitude. xy'adial The evolution of F versus power level is given in Figure III.4. The comments made about ASI'lso apply to F xy The measure of the gross radial shift is dipicted by the ratio R of predicted to measured power in the nine central assemblies. Thus I-R represents the fractional difference between measured and predicted power at the core center. If 1-R is positive, the measured power is higher than predicted in the central region. The evolution of 1-R is shown at 80K and 20K of core elevation in Figures III.5 and III.6, respectively. At the upper elevation, values as large as 12K can be seen. There is also a positive correlation with power level. At the lower elevation, the trends are too small to be significant, indicating no radial perturbation at the first level of Rhodium detectors. 19

I I I I I I

d. Power Coefficients Measured and predicted power coefficients are given in Figure III.7.

During the event, the measured coefficients were about 0.30 to 0.40 x 10 ap/XP larger than the predicted values, which further confirmed the anomaly in power dependent reactivity. The difference between predicted and measured power coefficients is given in Figure 111.8, together with the bias and uncertainty bands defined for this parameter from the analysis of a broader data base. During November and early December, the difference was substantially larger than the one-sigma uncertainty, and marginally larger than the K-sigma uncertainty. A deviation in power defect of 0. 175K hp is obtained by integrating the average error in power coefficient (.35 x 10 hp/%P) between 50 and 100K power. This error is about 45% of the reactivity defect displayed in Figure III.l (0.4% ap) based on steady state boron concentrations at various power levels. Thus, the power coefficients confirm the direction, but not the magnitude, of the reactivity anomaly. Two scenarios can be proposed. ( 1) The power coefficient is affected by a phenomenon having a very short time constant, and in addition the steady state reactivity is also affected by a phenomenon having a longer time constant (days). (2) Both power coefficients and steady state reactivities are affected by the same phenomenon, which has a time constant of about one hour. The power coefficient measurement, being performed over a period of half an hour, is taken during the reactivity transient and is only affected by about half of the reacti vi ty shi ft. 20

I I I I

Benchmark measurements were also performed on Calvert Cliffs Unit 2, Cycle 3 to establish the value of the power coefficient in an unperturbed core under similar conditions of burnup and power level. These results, given in Figures III.7 and III.B, show no significant departure from the prediction.

2. Burnup Distribution Perturbation Model and Results As a result of operation with a distorted power distribution, the bottom of the core accumulated more exposure and the top less than would have occurred under normal operating conditions. After return to normal operation, the ASI was expected to be more top peaked because of the reduced burnup in this region-than would have been the case without the power distribution anomaly. This effect was assessed in order to determine what constituted "normal operation".

In order to model the effect of the actual fuel burnup distribution, the ROCS burnup and fuel isotopics were adjusted to be consistent with the measured burnup distribution at 4120 NWD/T (,12/25/79), the date at which the core seemed to have recovered from the anomaly. This adjustment was made as follows: For each incremental burnup value', one can calculate the change in any isotopic concentration N. In other words, the quantity zN BBU was calculated for each depletable isotope for each node in the ROCS

  .model. This derivative term     was multiplied   by the   difference in accumulated burnup over Cycle 4 between         CECOR   and ROCS. For each isotope at each node      an  incremental concentration     was   calculated by:

21

N = aN ( (Bu - Bu (BOC) CECOR (Bu - Bu (BOC) ROCS 'BU in which (Bu - Bu (BOC) is the nodewise burnup accumulated CECOR during Cycle 4 in CECOR and (Bu - Bu (BOC) is the same quantity CS for ROCS. hN was then added to the ROCS concentration file. The correction was equivalent to about -300 MMD/T for the top half of the core and +300 MMD/T for the bottom half of the core. Using this modified concentration file, the core follow depletion was repeated for the period of 12/23/79 to I/24/80. As expected, the quantity most sensitive to this change was the ASI which became 0.07 more negative. The difference between the measured shape index and the shape index calculated using the updated burnup distribution is given in Figure III.9. A difference of .05 between measured and predicted ASI is now obtained, which might suggest that the power-dependence of the perturbation had disappeared by 1/24/80, but that a residual fixed perturbation remained. One must also consider that the correction to the burnup distribution assumes that CECOR has accumulated the correct exposure over Cycle 4. This correction did not take into account CECOR measurement uncertainties in instrumented assemblies of CECOR synthesis uncertainties in uninstrumented assemblies, The effect of the modified burnup distribution on the radial power distribution is not as strong. At the 80K core elevation, it produced a 1X change in radial shift (Figure III.5) and at 20K core elevation, the effect was negligible. This correction to the burnup distribution should be considered as giving a more qualitative rather than quantitative assessment of the post-event power distribution. An assessment as to whether the core has recovered should not be based on the ASI alone, but upon the entire range of measured data. 22

I 1 I l

3. General Physics Conclusions In conclusion, a strong perturbation took place between September and December, 1979, which affected many physics parameters of the core. After a slow buildup during October, a strong power dependence of the perturbation was observed in November. This power dependence has a time constant no greater than a few hours as evidenced by the rapid changes in power distributions following a change in power level and by the increased measured power coefficients.

In mid December a strong recovery of al,l the physics parameters discussed above took place, leaving only a residual bias to the ASI and the power coefficient. B. Core Differential Pressure The core differential pressure (dp) history from 9/21/79 to 1/22/80 is illustrated in Figure III.10. In general, the data are consistent with alternating per iods of increasing and decreasing flow resistance which may be the result of crud formation, migration or changes in surface roughness in both the reactor core and in the steam generators. The core dp remained elevated above a normal value of about 13.8 psid by as much as 1;8 psi during the September to January period, and, except for downward "spikes" in early and late. October, the general trend was one of increasing core dp throughout the period. Two points should be emphasized: (1} During the peak of the physics anomalies (roughly the period from late October to early December) the core dp anomaly was at its minimum value, running about 0.8 to 1.0 psi above normal; however, as dp increased during December and January to a maximum value of

1. 8 psi above normal, the physics anomalies were apparently disappearing.

23

I I I I ll I

Although it is true that core dp may be related to frictional characteristics of the crud surface as well as to the amount of crud, the opposing trends of dp and physics anomalies must be regarded as evidence against a reactivity effect model which depends directly on the thickness of a crud layer. (2) The initial rise in dp, from about 9/21/79 to 10/8/79 was quite rapid relative to some crud formation mechanisms which are thought to require months. This initial rise in dp was equal to the maximum dp anomaly observed at any time during the September-hnuary period. Tem erature Distribution In-core thermocouple (T/C) indications have been examined for several periods for any evidence of crudding effects. Typical results are shown in Figures III.11 and III.12 since power levels and power distributions were quite different from day to day during the anomaly, temperature rises indicated by the T/C's are normalized by the predicted temperature rises in the assemblies in which the T/C's were located. The figures show differences in this normalized parameter between several selected pairs of dates. Examination of other T/C data similar to that illustrated in Figures III.11 and III.12 indicates that there was a characteristic change in T/C behavior between 9/7 and 9/14 and that this changed behavior persisted to at least 1/5/80. Temperature distributions obtained on or after 9/14 were essentially invariant. However, when temperature distributions prior to 9/14 are compared to distributions obtained on or after that date, the latter temperatures are seen to be systematically higher, typically by 5 to 15K of the assembly aT. This increase was consistent with a reduction in guide tube flow in the instrumented fuel assemblies, presumably due to crud formation. A-small fraction of the temperature anomaly had disappeared by 1/25/80. Following the Hydrogen Peroxide treatment, further improvement, but not a return to normal, was noted. 24

~ 'e, Several points should be emphasized with respect to T/C indications: (1) The T/C indications evidencing crud increased in advance of either core dp or physics indications of crud, that is, in late August as opposed to September or October; this is evidence that crud was forming at this early date. (2) There does not appear to be any systematic distribution of temperature increase or decrease within the core which would indicate preferential crud formation in either the periphery or the center; this is probably evidence that a small amount of crud in guide tubes and/or instrument thimbles is enough to cause the maximum observed AT change, with a "saturation" effect applying to any further crud formati on. (3) The T/C readings, like the core dp indications, appear to be larger after the peak of the physics anomaly, i.e., from early December to early January. This is probably evidence of further crud shifting in the core at this later time. (4) T/C's in the Calvert Cliffs Units have been unreliable during normal operation in the sense that absolute values are not predictable from a knowledge of the core operating conditions only, Significant biases due- to unknown causes apparently exist. Thus, T/C evidence must only be interpreted as indication of a trend. 25

I I I I 'I I I

D. Postulated Mechanisms Many potential mechanisms were evaluated. It was concluded that the primary contributions may come from the poisoning effect of crud and boron, with a contribution from Doppler due to an increase in fuel temperature, A11 these mechanisms assume that crud deposition occurred preferentially in the upper peripheral region of the core, Crud deposition may induce local boiling, increase clad oxidation rate, increase fuel temperatures and increase local concentrations of boron. The physics calculations defined the order of magnitude of the effects required to match the observed core power distribution during the anomaly. It was concluded that the poisoning effect was greatest in the outermost region of the core and a maximum in the upper portion of that region. In order to explain the physics observations at 100% power, it is necessary to invoke poison concentrations at this axial location of at least +80 mg/cm of crud (,25K Ni, 485 Fe, 27K 0) on the cladding or a plating of more than 0.05 mgB t/cm nat on the cladding or an increase of more than 1800 F in the fuel average temperature, or some combination of these mechanisms, The main conclusions reached were: The observed physics anomalies were almost certainly related to the presence of an abnormal amount or type of crud in the core, This is supported by the measured high core differential pressure. It is very unlikely that the physics anomalies were caused solely or even predominantly by fuel heat up and associated Doppler effects, It is difficult to conceive of a mechanism which substantially increases the fuel temperature without an associated increase in cladding temperature. Cladding temperature incr eases of the required magnitude would have caused the fuel rods to fail through excessive oxidation, yet no failures were observed. 26

1 I I

A combination of crud-related mechanisms which could have produced the observed anomalies includes the poisoning effect of crud itself, boron deposition in the crud both under boiling and non-boiling conditions, fuel heat up due to oxide formation, and the thermal insulating effect of crud. In the postulated scenario boron concentration in the crud provides the major contribution to the physics anomaly. However, this requires very rapid boron migration into and out of porous crud. There is no known independent evidence for such a phenomenon. Similar neutronics effects have been observed in other reactors. These anomalies were ascribed to a mechanism involving crud (but not boron) by which the power-reactivity relationship was affected. The details of this mechanism are unknown. 27

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l IV. Chemistry Observations and Evaluations A. Routine Water Chemistry Surveillance Program The water chemistry program at Calvert Cliffs is outlined in a definitive set of procedures contained in Calvert Cliffs Instruction ¹406 (Attachment-(la-d). Collectively, this set of chemistry and radiochemistry procedures forms the nucleus of a detailed, rigidly characterized system for the analysis of significant parameters to determine, trends and identify abnormal conditions. The basis for the chemistry surveillance program at Calvert Cliffs is formed from the Combustion Engineering (CE) Power System Nuclear Steam Supply System Chemistry Manual (CENPD - 28) (Reference 1). The analytical methodologies, sampling locations, sampling frequencies and parameter specifications recommended in the CE Chemistry Manual have been strictly incorporated into the site specific Calvert Cliffs chemistry program. Insofar as the Calvert Cliffs Unit I Power Distribution Episode is concerned, the chemistry control of the following systems'need be evaluated:

l. Reactor Coolant System (RCS)

2. Chemical and Volume Control System (CVCS)

3. Makeup Demineralized Water System (RC M/U) 40

1. Reactor Coolant System A detailed discussion of the Reactor Coolant System chemistry monitoring program is contained in Chemistry Procedure 1-202 (Reference 2).

Table 1 of RCP 1-202 (Attachment 2a-b), characterizes the procedures/ specifications/frequencies associated with significant parameters in the RCS. This is a site specific procedure which incorporates the recommendations of CENPD-28 as regards RCS chemistry. Specification Sheet 5'-3 (Attachments 3a, b, c and d), outlines the CE recomnended sampling location, frequencies, specifications and corrective actions for the analysis specified. As regards the power distribution episode the following RCS chemistry parameters are of significance: (a) pH, (b) conductivity, (c) lithium, (d) suspended solids, (e) hydrogen, (f) iodine 131/133, (g) iodine ratio, (h) ammonia. Nominal RCS water chemistry is illustrated in Figures lA - H for the period of time 07/01/80 to 07/31/80. It is readily apparent from an examination of the figures that the water chemistry parameters were controlled to values well within both the CE and site specific limits. Table IV.A. 1 summarizes the nominal observed chemistry values obtained from examination of the figures together with both the CE recommended and site specific guidelines. 41

TABLE IV.A.1 Parameters Nominal Observed CE Recommended Site Specific (Units) Value (a) pH (Standard} 5.0 to 7.0 4.5 to 10.2 4.5 to 10.2 Unit at 25 Co (b) Specific 0.0 to 20.0 Consistent with Consistent Conductivity concentration (s mho/cm) of additives ( C) Li thi UAl 0.0 to 1.0 0.2 to 1.0 1 ppAl maxlAlUAl (ppm} (d) Suspended 0.0 to 250 500 or 500 maximum Solids 2000 (4 hrs.) s/s (ppb)

(e) Hydrogen 10 to 60 10 to 50 10 to 50 (cc/kg)

(f) Oxygen <10 ~100 ~100 (ppb) (g) Activity N/A Not Specified Not Specified 133

     ? 131/?

(h) Ammonia (500 Not Specified (ppb)

*It should     be noted that the CE  recommended  analysis method   for RCS hydrogen concentration is by    means  of volume control tank calculations.

42

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2. Chemical and Volume Control System A detailed discussion of the CVCS chemistry monitoring program is contained in Chemistry Procedure 1-215 (Attachment 4)which characterizes the procedures/specifications and frequencies associated with parameters of a critical nature in the CVCS. This is a site specific procedure which incorporates the recommendations of CENPD-28 (Reference 1). Insofar as the power distribution episode is concerned the parameter of significance is the volume control tank (VCT) hydrogen, over-pressure. The recommended hydrogen over pressure of 9-45 psia corresponds to VCT calculated hydrogen concentrations of 10-50 cc/kg. This is dependent upon establishing nominal values for vapor 1

phase hydrogen concentrations. VCT hydrogen concentrations are illustrated in Attachement 1E. Inspection of the data demonstrates that VCT over pressure (calculated RCS hydrogen concentration)was within specification during routine operations.

3. Makeup Demineralized Water System A comprehensive explanation of the reactor coolant makeup water system (RC M/U) chemistry monitoring program is located in chemistry Procedure 1-201 (Reference 4). Table I of RCP1-201 (Attachment 5) describes the procedures/

specifications and frequencies associated with the reactor coolant system. This is a site specific procedure which incorporates the recommendations of CENPD-28 (Reference 1). The recomnended chemistry guidelines of CENPD-28 as regards RC M/U are illustrated in table form as specification Sheet 2-1 (Attachment 6a-b). Examination of the operational chemistry data logsheets (Reference 5) verified that routine chemistry values were within the guidelines of both the site specific and CE, specifications. Table IV.A.2 illustrates the nominal observed values obtained for significant parameters together with the recommended specifications. 51

w-/ TABLE IV.A.2 ~ Parameter Nominal Observed CE Site Specific Units Value S ecif i cati ons S ecif i cati ons (1) pH 925 C (Standard Units) 6.0 6.0 - 8.0 5.8 - 8.0 (2) Specific Conductivity 0.5 2.0 maximum 2.0 maximum mhos/cm) (3) Chloride (ppm) (. 08 0. 15 maximum 0.15 maximum (4) Sodium (ppb) C1.0 Not Specified 10 maximum (5) Silica (ppm) 0.02 maximum 0.02 maximum (6) Flourides (ppm) <0.05 0.1 maximum 0.1 Naximum . 52

II I I

B. Power Distribution Episode Chemistry

1. Trends of Significant Chemistry Parameters

a. pH (Figures B. 1 - 8)

During the period 08/04/70 to 03/31/80 including the period of the power distribution episode, the pH of the RCS was controlled within the range 5.0 - 8.0 (measured at 25 C). This range of values is consistent with the normal operating guidelines established by CE in the Reactor Plant Chemistry Manual and incorporated into RCP 1-202. Table IV.A. 1 illustrates this point. A nominal value for pH during the power distribution episode would be 6.5.

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b. Conductivity (Fig'ures B.9-16)

The specification regarding RCS conductivity is that the values be consistent with coolant additives, Under normal operating conditions, the reactor coolant contains only boric acid and lithium hydroxide chemical additives in significant concentrations. Ouring the initial stages of the power distribution episode RCS condictivity was controlled to within the specification noted in Table IV.A.l in that conductivity was consistent with pH and boron concentration. In response" to a CE recommendation, hydrazine injection to the RCS was initiated during normal operation. Whereas conductivity previously ranged from 10-20~mhos/cm , new data points were in agreement with the concentration of chemical additives in the RCS. The increase in baseline conductivity caused by ammonia decomposition products of hydrazine was anticipated. There were several occasions during the power distribution episode where significarit conductivity increases in the RCS were initiated by the injection of excessive quantities of N H into the CVCS. These out-of-trend conductivity values (i.e. 1/10/79 conductivity-160 mhos/cm) are discussed in Section IV.B.2.6. It should be noted that conductivity was at all times consistent with the concentration of chemical additives (boric acid, lithium hydroxide, and hydrazine) in the RCS and that the introduction of impurities was not a problem during the power distribution.

-62

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                                                                                                            ~ '
                                                                                                            ~        I
                                                 - t                                                                            f I= ~

t ~ ~

"~

4 = ~

                                          ~   ~

4 ~=~

                              ~ ~ ~

4 - ~ t

= ~

4-

                                                                       =~
                                                            ~ =     =  ~                                  -~

t ~ .- ~ -=.t-4$

4~ 4~ ~-

l ( tttttt l; X '.1 rt tat CtIttl<tttt tttttt:tt FIGURE 8.24 l[' ~ I l I l l ~ -. ~ *-. =~

                                                                             -g3/31/1 g 0

I I ~ t t t ~

                                       *     ~

l . I t I

                                                                                                                          ~  l
              . I ~                                                                                                        *~

5= I

                                                           -   ~ .
                                                                                                              ~

l

~ ~

0 i 0 0 I l j*- -i l I 0

  '                  0 i                    I i       '                                                                   ~ ~   ~ ~    ~
                                                                                                                                               ~ .

1 i I ~

                             '-. i
                                                                           ~

I r.-"=- I 0 0 t 0 I'

                     ~
                                                                                                                                          -~
                                                                                                                                         ' t           ~
                                                ~ j                             ~"

0 ~ .

. ~

0

                                         ~:-
                                                                                ~ =
                                                                                      -~
                                ~ :-            ~-    - .~

i-'-- "

00-

~ R l

Suspended Solids (,Figures B.25-32) Figures B.25 through B.32 present the concentrations- of suspended solids (s/s) found in the reactor coolant during the months of August 1979 through March 1980. The data indicates that for the period 08/01/79 to 11/ll/?9 (Figures 8.25, B.26, B.27 and B.28) the levels were well within the CE and site specific guidelines of a 500 ppb maximum for normal operation.'alues obtained were generally less than 25 ppb. On 11/08/78 the sampling frequency was increased from weekly to daily. Except for spikes attributable to plant power transients, suspended solids remained low (average ~50 ppb) until early Oecember (Figure B.29). At this time, levels increased and became erratic, ranging from 100,to 500 ppb. These increases were attributed to the spalling of crud off the core, apparently as a result of chemistry actions taken in early November. Core dp began to rise during the second week of Oecember, possibly as a consequence of an increase in the roughness of the remaining core crud deposits due to spalling. Concurrently, the reactivity and power distribution anomalies appeared to recede, as discussed on Section III. The very large spike of 1/10/80 followed an inadvertent over-addition of hydrazine, and is discussed in Section IV,B.2.b, The addition of hydrogen peroxide to the RCS during cold shutdown on 1/27 produced a large increase on suspended solids, as expected. The hydrogen perioxide ti eatment is further discussed in Section IV.B.2,d.

It ' 4 ~ I 4, 4 I 80@ j i jap I I

i I

                  ~               'lB/02!  I I i
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FIGURE B.26 4 t t. t f I

                      '!             i 4

4

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t SM. tt f

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~~

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ttt tt 4 ~ t 4 4-

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FIGURE B.28 f ~ ,) ~ -= I .IL I ~

                                                                                                         ~ 1
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mm. I \ f ~ = ~- ll j i-- i II I I I~"

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%70

~5 FIGURE B.29 i Git-t-tt-.B;

                                                                                  ~ I ~ t        j f     I Bl9SPENBE

12/01 '--'-=12RC

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I FIGURE i --SECT-I.O e SPRY 1

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I S".I Pi lt I IO IO IIE Cit!.'ilE'ER lt ttlt tl'.32

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I

e. Hydrogen (Figures B.33-40)

Examination of Figures B.33 through B.40 illustrate the following points: (1) During the period 08/01/79 to ll/1/79 hydrogen in the RCS was controlled within the guidelines of both

                                                               'E and site specific specifications (Reference Table IV,A.l).

All samples obtained during this period were in the range of 10-50 cc/kg. Note that the analysis method for RCS hydrogen is performed utilizing VCT vapor phase hydrogen concentration. (2) Subsequently the hydrogen concentration in the RCS was increased to a nominal range of 50-80 cc/kg. This modification to the chemistry program was prompted by a CE recommendation to increase RCS hydrogen inventory. 89

l FIGURE B.33 EQ j:.i i .ei i J ~ i

t

~ ~

DTiLA

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FIGURE B.34

                                                                                                                                                                               ~
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00

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FIGURE B.3S t g

t I I B --. ~ I ~ I

                                   ,~      <<- t-   .H~4. 80       EN     i               T I

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W & W & W W ( 15 'I tj t0 It! II'tllv!t!I (Ijjtli FIGURE B.36 I

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HYY. R EN-FIGURE B.37 I 2 I

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I m m m M' ( ( FIGURE B.38 I I 88i 5 I'.v,. 9'. ~ =- I II 5

                                                                                       .HY        EN        .~. -5=-          S-t   ~

5 VCT, C !LCuLATED.... OT t G I 5

~-

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I ( $ HIII! '411! ':I 1 '4! "('Ills!I!7 1$ !4,4 c( FIGURE B.39 I' 1 ~ 1

                                        ...BE Tjl N'             -
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0 jVCT: CALCULAT 0 I OT'

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t t ~W W ( ~

                                           ~      4~ tt                                                           t

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FIGURE 8.40

~ ~

EV' P

~=

I I P I I I I J I

                                                                                                                    -VCT CALCULATED I ~ -~ - I-     -      -i                 P P                                                      6 -

I I ~.

                                     --j -- =- ~ I                      P-i P

I I

                                                               ~ -kP I
                                                                             ~

I+ t

                                                                                                                           ~       Il I

I i

                                                                             ~ I
                                                                                    ~ .
                                                                               ~

I~ I

                                                                        ~  '                                                              ~   '
                                                                                                             "-              I I. ~     ~
                                                                     ~
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P

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                         ~ .
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I~ P P J ~~ P P 1 = ~

I

                                                                                        ~  ~
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I

f. Oxygen (Figures B.41-48)

A detailed study of Figures B.41 through B.48 generate the following points of interest: (1) RCS oxygen concentrations under normal operating conditions were at all times within the CE and site 'specific guidelines (Reference Table IV.A.1}. A nominal value for oxygen data points was <10 ppb. (2) In early November 1979, plant staff routinely analyzed the oxygen concentration in the VCT (based upon a charging pump discharge sample point). Although not recommended by by Reference 1 this action was prompted by a subsequent CE recommendation to investigate sources of oxygen ingress to the RCS. Nominal values for VCT oxygen were less than 100 ppb. However, on several occasions (i.e. December 20, 1979, 800 ppb) there were significant increases in oxygen values. Sources of oxygen ingress were determined to be via the resin transfer system and from partial aeration during storage of the normally deaeratedmakhup water. Oxygen ingress to the RCS is discussed in Section IV.B.2.c. (3) In late December hydrazine injection to the CVCS was established as a normal operation. The purpose for the hydrazine addition was to compensate for oxygen concentrations in the RCS makeup water due to air absorption in the demineralized water storage tank. Pursuant to a CE recommenda-tion hydrazine was injected at a rate and concentration sufficient to establish an approximately 10:1 hydrazine to

       ,oxygen   ratio. The   ratio    was  later modified to      5:1 in response to subsequent     CE  recommendations.          Further discussion of the hydrazine/oxygen conqgntration is contained               in""Section
                                                             ~ -".

IV.B.2.b. 1

                                      *                               ~:  v"

ll ~ l I. I

FIGURE g 4)

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FIGURE S.42

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se 5'ttE ;Er x .8 ro rtE CE~rrrtEEEt ts tttt c. FIGURE ~ -43 P P ~ "~ ~ * ~ ' BEEi-TWIN-WI. I P..l

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FIGURE B.44

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I FIGURE 8.45 1

~~

1

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FIGURE B.46

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I ,g.'odine Activity (Figures 8.49-64) Figures 8.49 through 8.64 depict iodine activity values obtained during the power distribution episode. Values obtained for the radio-nuclides Iodine-131 and Iodine-133, as well as 'the ratio of I-131 to I-133 showed normal variation with plant conditions. Fluctuations due to power transients and operation of the purification system were as expected. 107

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h. Ammonia (Figures B.65-72)

Examination of data regarding RCS amnonia concentration generates the following observations (1) Prior to the injection of hydrazine to the CVCS via RCS makeup water, the RCS armonia concentration was maintained to within the CE recommended level of 500 ppb (Table IV.A.l). Nominal values were <100 ppb. (2) Subsequent to the hydrazine injections, RCS ammonia concentrations were a function of the injection levels and ion exchanger media condition. Those instances of

       'excessive    RCS ammonia concentrations were    a  result of increased. hydrazine injection concentrations       (.i.e.

January 10, 1980, 14 ppm).

I I I I

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2. Evaluations and Actions

a. Reactor Coolant System Lithium Concentration As discussed previously, RCS lithium concentration is normally maintained at less than 1.0 ppm, As a result of unexpected increases on axial shape index, radial peaking factors, reactor vessel differential pressure and abnormal power distributions, on ll/08/79 CE recommended that RCS lithium concentration be increased to a maximum of 2.2 ppm (Reference 6). The resson for the recommendation was to increase crud solubility in an attempt to transfer it from core surfaces. As evidenced from examination of the lithium plots, plant staff implemented the recommendation as part of near term corrective action. Lithium concentration in the RCS remained at the prescribed level until CE's recommendation of 03/07/80 to reduce the chemical parameters to original specifications (Reference 7). It should be noted that on several occasions RCS lithium concentrations drifted slightly above the lithium concentration guideline. These deviations were caused by nodal chemistry control problems associated with plant operation and were not consider ed significant. For instance, on 03/Ol/80, an aberrant episode in lithium concentration occurred (Reference 8) over a three day period. The maximum lithium concentration observed was 2.4 ppm at 2000 hrs. on 03/04/80 for a period of less than 10 hours. The nominal lithium range of (1.8-2.2) was exceeded for approximately 30 hours. The apparent cause of the perturbation was the removal of an ion exchanger from service following a planned power transient. Lithium hydroxide monohydrate (liOH.H20) additions to the RCS were not coordinated with the purification system lineup. As a result, obersved lithium concentrations was in excess of anticipated values. Investigation into the cause of the anomaly resulted in the ion exchanger being placed in service with subsequent RCS lithium concentration reduced to within the nominal operating band. The incident is displayed in detail in Figure IV.B.2.a.l. No significant effects on the power anomaly were observed due to the minor excursions from normal lithium concentrations experienced during this and associated incidents.

133

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b. Hydrazine Addition to Reactor Coolant System Based on a concern for potential air ingress into the RCS on 12/11/79, CE recommended that hydrazine be added to the VCT i'n quantities which were based on analysis of oxygen in the makeup water (Reference 9). After an evaluation of the recommendation to insure that there would be no effect on overall RCS chemistry, plant staff initiated continuous injection of hydrazine to the RC makeup pump discharge during normal operation. The hydrazine was injected at a rate and concentration that would provide an excess of hydrazine to the RCS.

Plant staff was concerned that hydrazine additions would significantly increase RCS ammonia concentrations. Examination of Figures 8.65 through B.72 illustrates that baseline ammonia level in the RCS increased when hydrazine was injected into the makeup water. On several occasions, excessive levels of hydrazine in the RC makeup resulted in significant increases in RCS amnonia and conductivity levels. The initial incident occurred on 1/10/80 and was accompanied by a rapid "decrease in cote differential pressure, The event was caused by the inadvertent addition of 15 gallons of 35 wtX hydrazine to the chemical addition metering talk. Hydrazine injection to the RCS makeup occurred from 2000 on 1/9/80 to 0730 on 1/10/80, when the injection was terminated and an investigation conducted. Sampling at the charging pump discharge showed a hydrazine level of 3.2 ppm compared to a nominal value of approximately 300 ppb. The excessive ammonia level which resulted from hydrazine, decomposition caused release of lithium from the in-service ion exchanger due to an'upset in the equilibrium concentration. 135

Lithium increased to approximately 3.8 ppm as a direct result of this incident (Reference 10), It was postulated by CE that the cause of the core differential pressure drop was due to the ammonia forcing lithium from the resin bed. The sudden high lithium concentration caused crud removal from the core. Subsequent hydrazine levels outside the nominal band have been observed in the CVCS as a result of operational difficulties with the temporary injection system. 136

N

c. Oyygen Ingress to Reactor Coolant System As a result of concerns regarding the introduction of air into the RCS via the.RC makeup water the following modifications to chemistry procedures were initiated:

(1) VCT hydrogen addition rates were recorded and monitored to determine if consumption was excessive and samples were taken to establish a baseline for oxygen entering the RCS through the purification system under normal conditions. (2) Initial quantification of oxygen ingress was accomplished by performing daily oxygen analysis downstream of the charging pumps. These analyses were performed at the following conditions during normal power operations: (a) Just prior to adding makeup to the YCT; at the low extreme of the normal operating band. (b) Within 15-30 minutes after adding makeup to the VCT; at'he high extreme of the normal operating band, (3) If oxygen at the charging pump discharge was measured at greater than 5 ppb, samples were taken at the following locations to determine possible sources of air ingress: (a) Charging pump suction (b) Volume control tank (VCT) (c) Reactor (primary) water storage tank

         ,(d)    Letdown system ion exchanger         inlet   and   outlet 137 4  '          ~ ( p 'V       6'Q y$ g4 -' - 4~ ~

N ~ In addition, the following modifications to operating procedures and hardware were made to prevent oxygen ingress from the resin transfer system to minimize air ingress from the RC makeup water and to increase solubility of crud in the RCS. (1) Hydrazine leaving the VCT was controlled to stoichiometric quantities based on analysis of 02 in the makeup water entering the'CT. (2) Hydrogen overpressur e in the VCT was increased to a level sufficient to increase H2 dissolved in the RCS to 40 cc/kg. (3) Nitrogen instead of air was used to transfer resin. (4) Two leaking valves in the resin transfer system were repaired. (5) The leaking power operated relief valve was repaired. Evaluation of Figures 8.41 through 8.48 describing oxygen levels in the RCS and VCT reveals that the combined corrective action recommended by CE (References 12, 13) and implemented by plant staff was effective in minimizing oxygen ingress. 138.

d. Hydrogen Peroxide Treatment The hydrogen peroxide treatment, initiated on January 27, 1980, was very successful in returning core differential pressure back to pre-episode levels. A complete and detailed documentation of the chemistry and radiochemistry aspects of the addition is contained in Appendix A. The following is a summary of the results of the hydrogen peroxide treatment:

1. The hydrogen peroxide chemical treatement combined with the plant cold down/heat up temperature shock reduced core differential pressure from 15.6 psi to the pre-episode value of 13.8 psi.

2. A total volume of 15.1 liters of hydrogen peroxide was added to the RCS in three separate injections.

3. Increases in total Co-58 activity and suspended solids indicated the hydrogen peroxide treatment produced a significant crud release.

4. Based on a comparison of data collected here with the results of an EPRI study, reactor core deposits appear to be the major source of activity released.

5. Approximately 600 Curies of Co-58 was removed from the coolant during and following the hydrogen peroxide treatment.

6. Hydrogen peroxide additions did not cause unexpected changes in shutdown radiation fields.

139

Il I

8. Reactor Coolant System Crud Samples As part of the assessment of the power distribution episode, two samples of circulating crud were taken from the reactor coolant and submitted to CE's Nuclear Laboratory for analyses.

The following is a summary of analyses performed and results obtained: ~Sam le ¹1 was taken on December 6. 1979 near the peak of the core physics anomaly, with the plant at 70% power. It was hoped that the sample would provide clues as to the cause of the anomaly. ~Sam le ¹2 was taken on January 28, 1980; with the plant at cold shutdown, during a crud burst generated by the addition of hydrogen peroxide. This sample was taken to satisfy an NRC request for information on the composition of crud released due to hydrogen peroxide. The following analyses were performed on the samples: visual examination and (.for Sample ¹2) drying and weighing mounting for X-Ray fluorescence v - spectroscopy (for Sample ¹1) X-Ray fluorescence to determine elemental composition (atomic number 12 - magnesium) X-Ray diffraction to determine crystalline compounds for (Sample ¹1) digestion in oxidizing acids to provide liquid solution for atomic absorption and emission spectroscopy elemental analyses by atomic absorption

     -  Sample    ¹1:     Li,  Be, Na, Mg,   Ca
     -  Sample    ¹2: Li,      Na, Mg, Ca, Cr, Fe, Ni emission spectroscopy          for  boron 140

I Sample 81 was found to be nickel-rich, with a substantial concentration of nickel metal. The reactor coolant system had apparently been chemically reducing at the time the sample was taken. The overall composition was consistent with corrosion product release expected from the major system materials. Most of the material originally came from the steam generator tubing (Inconel-600}. The immediate source of the crud (in-core or out-of-core surfaces) could not be established. Nothing was found which could be related to the anomaly. Sample A'2 contained iron and nickel in about equal proportions. This composition was consistent with observations that peroxide additions favor the dissolution of nickel relative to iron oxides. The cnud appeared to have been released from core surfaces. Nothing was found in either sample which would raise concerns relative to accelerated corrosion of fuel cladding due to the deposition of these materials. h 141

f,. Modification to Chemistry Surveillance Program Ouring the power distrubtion episode, periodic adjustments in the chemistry surveillance program were implemented. For the most part, these changes were prompted by recommendations from CE followed by evaluation by plant staff to assess impact on overall chemistry management prior to implementation. The following modifications to the routine chemistry surveillance program were instituted (.Reference 16, 17): (1) The following parameters are now analyzed in accordance with the predetermined sampling frequencies and the results recorded in a graphic form in order to reveal any trends that may develop. The parameters of interest are RCS oxygen and hydrogen concentra-tions, and the Iodine 131/133 ratio.'2) Hydrogen inventory requirements in the primary system are recorded/graphed/evaluated. This information is displayed in a graphic form in conjunction with Item (1) above. (3) Volume Control Tank (VCT) hydrogen consumption rates are recorded/ graphed/reviewed to determine if excessive consumption is taking place. .(4) A baseline level for oxygen concentration in the effluent of the RCS ion exchanger's under normal operating conditions (steady state power no abnormal plant evolutions) was established; (5) Oxygen ingress into the RCS was quantified by performing an analysis on samples taken at the char ging pump discharge. A daily sample must meet one of the following criteria: 142

ll l

Sample obtained just prior to adding makeup to the VCT. (Low end of normal operating band). Sample obtained within 15-30 minutes after adding makeup to the VCT. (High end of normal operating band). If this sample indicates a higher than expected oxygen concentration, then additional samples are taken at other potential air ingress points, e.g.: Charging pump, suction VCT RCS makeup to the VCT Reactor water storage tank Purification system ion exchanger 143

% ~ 5 l

C. POST-EPISODE CHEMISTRY HISTORY An examination of post-episode trends of significant chemistry parameters generates the following observations: (1) pH (Figure C.l) was controlled within the normal pre-episode quidel ines established by CENPD-28. (t) ~td ti it (Fig t.d) i t itl t " t of chemical additives. New baseline level was increased above pre-episode concentration due to the presence of hydrazine in the RC makeup water. (3) Lithium ( Figure C.3} was reduced to pre-episode levels of less than 1.0 ppm toward the end of March 1980. (d) ~gd d )id (Fig t.d) t ii d itti d - di d levels less than 25 ppb and well within the guidelines of both CE and site specific guidelines of less than 500 ppb. (5) ~H dro en (Figure C.5) was controlled within the upper portion of the allowable band to ensure an adequate hydrogen inventory in the RCS. (6) Ox en H drazine (Figure C.6) Hydrazine was maintained well in excess of measured oxygen levels in accordance with CE guidelines. RCS oxygen values continued to remain within the pre-episode recomended specifications. (7) Iodine 131 133 Activities (Figures C.7,8) Reflects no adverse effect of the power distribution episode on fuel performance. (8) Ammonia (Figure C.9) is consistent with the concentration of hydrazine injected into the RCS. Observed levels were within the CE guidelines. 144

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I D. PERMANENT MODIFICATIONS TO THE ROUTINE WATER CHEMISTRY SURVEILLANCE PROGRAM The significant changes incorporated into the routine water surveillance chemistry program are summarized below: (1) Modifications to the frequency and surveillance location for RCS hydrogen. (2) Increased surveillance frequency for analytical methodology associated with monitoring for fuel performance (iodine activities). (3) Incorporation of a correction factor for the RCS hotleg hydrogen determination to compensate for the inefficiency of the gas purging evolution at the degassing station, (4) Maintenance of VCT physical parameters at levels that will ensure adequate hydrogen concentrations are maintained in the VCT and therefore, in the RCS. (5) Increased Control/Analysis for CVCS hydrazine/oxygen to minimize oxygen ingress into the RCS. (6) Detailed procedures for the injection of hydrazine into the CVCS to minimize control problems. In addition, the feasibility of installing a permanent deaerator in the effluent of the demineralized water storage tahk is being evaluated. It is projected that the installation of the deaerator will minimize oxygen ingr ess into the RCS and eliminate operational problems associated with injection of the oxygen scavenger, hydrazine, and the subsequent RCS chemistry perturbations (ammonia, resin equlibrium). 154

I ~ ( I I

The table below lists the nominal values obtained for significant chemistry following the power distribution episode compared to pre-episode values. It also lists the post-episode specifications. Parameters Pre-Episode Post-Episode Post-Episode Nominal Value Nominal Value Specification

1) pH 8 25 C 5.0 to 7.0 6.5 to 7.5 4.5 to 10.2 (Standard Units)

2) Conductivity 0.0 to 20.0 10.0 to 40.0 Consistent w/

Qmhos/cm) additives

3) Lithium 0.0 to 1.0 0.0 to 1.0 1.0 ppm maximum

  .'(ppm)

4) Suspended 0 0 to 250 425 ppb 500 ppb maximum Solids (ppb) based on VCT Hydrogen

5) Hydrogen 10-30 50-70 Consistent w/over-(cc/kg) pressure & concentration in VCT

6) Oxygen/Hydrazine N/A 5:1 ratio 5:1 ratio

7) Oxygen (ppb) (10 Z10 Z100

8) Ammonia (ppb) 10 1000 'ot Specified

9) Fuel Performance N/A N/A N/A Parameters 155

I I

E. SECTION IV ATTACHMENTS (la-d) Calvert Cliffs Instruction 8406, Index of Rad-Chem Procedures. (2a-b) RCP-1-202. Specifications and Surveillance. Reactor Coolant System. Table l. (3a-d) Reactor Coolant System - Operating Chemistry Specification Sheet 83-3. CENPD-28. (4) RCP-1-215. Specifications and Surveillance Chemical and Volume Control System. Table 1. (5) RCP-1-201. Specifications and Surveillance Makeup Demineralized Water System. Table l. (6a-b) Makeup Water System - Operating Chemistry Specification Sheet 0'2-1. CENPD-28. 156

I I I I I l

CURRENT REV. RCP 1 << 100 Series - General Information II 1 101" Methods for Revising and Changing Rad-Chem Procedures 1 - 102" Records 1 - 103 QC Procedure 1 - 104 Standard Safety Precautions RCP 1 - 200 Specification &.Surveillance Scope of Section 200

  ,1 -     201"   Make-up Demineralized Water 1 -    202"   Reactor Coolant System 1 -    203"    Companent    Cooling/Service Water System 1 -    204%   Refueling     &  Spent Fuel Pool System 1 -    205"   Safety Infection System 206+   Liquid   Waste Releases 207%    Boric Acid Storage Tanks 1   -  208"    Boric Acid Storage Tanks 1   -  209     Domestic Water System                                                  0 1  210" '. Steam Generators 1   -  211+    Condensate,     Feedvater and Main Steam System
  '1 <<212         Sewage   Treatment Plant 213"    Neutralizing      Tank 214     Auxiliary Boilers 1  215"       CVCS  Systems     --                                                   6-1  216"      Stator Cooling        System                                            0 217"   Diesel. Gen. Jacket Cooling 218    Unmonitored Discharge Surveillance Program Ch. 13 "Required     POSRC  Reviev 157

I

'l l

AI MMINtNI ( Ib CHEMISTRY AND RADIOCHEMISTRY PROCEDURES MANUAL - RCP 1 RCP 1 300 Series - (future use) CUEGKNT REV. RCP 1 400 Series (future use) RCP 1 -500 Series Sampling Requirements 1 - 501" Sampling Techniques 1 - 502>> Sampling of Cases for Activity 1 - 503>> Post-Accident Sampling of Reactor Coolant h Containment Conditions 0 RCP 1 600 Series (future use) RCP 1 - 700 Series - (future use) RCP 1, 800 Series - (future use) RCP 1 - 900 Series - Water Chemistry Procedure 1 - 901 Determination of Conductivity 1 902 Determination of pH 1 - 903 'etermination of Boron 1- 904 Determination of Gases 905 Determination of Dissolved Oxygen

   . 1  906       Determination of Chloride 1  907       Determination of Fluoride 1  908       Determination of Lithium and Sodium 1  909       Determination of Ammonia 1-   910      Determination of Hydrazine                                  2 1-   911      Determination of Suspended,    Dissolved and Total Solids 1  912       Determination of Total Hardness                             0 1  913       Determination of   Alkalinity "Required      POSRC  Reviev Ch. 14 158

l'

( ATTACHMENT lc I~EX OF WATER CEEYISTRY AHD RADIOCEE!&STRY PROCEDURES MANUAL RCP 1

             ,r CURRZn aZV. 8 e
     ~

RCP t1 914.. Determination ~ of Phosphate e t 1 915 Determination of Chromate 0 1 916 Determination of Soluble Silica 2

3. 917 DeterMnation of Nicke3.

1 918 Determination of Total Iron 1 - 919 Determination of Copper 0 1,, 920 Determination of Sulfite 0 1 '921 . Determination of Free Hydroxide 0 1- 922' 923'etermination of Residual Chlorine Determination of Morpholine 1 924 Determination of Sevage Treatment Plant Chemistry 0 1 925 Determination of Turbidity 0 1 926 . Determination of Chromium y e t y 1 927 Determination of Chliform Populations in Domestic

and 'Waste. Water .'- . 1 928 Determination of Oi1 and, Grease 5

~ ~

e RCP 1 1000 ~ Series Radiochemistry Procedures

                 '1  1001+              Determination of Gross                 Beta-Gamma    (Alpha)

Degassed Activity 1 1002 ."., Determination of Gaseous Activity-.' 0

                       -'"10D3 :;-Pete ccettoieooof Zo~e A'cttvity

=. ~~-. '"=:.-,D . .'.3.004.-.-..Radiochemical:Analysis for Radioactive Cesium 0 A

                '1 = 1005" Determination of Barium and. Lanthanum                                           0 1    '006 Determination of Strontium Activity
                                                       ~

e

1 1007>> Determination of Tritium Activity ~ y 1 .1008 Determination of Corrosion Product Activity

                                                      ~                         ~

t '\ ,:--':=.- 'Reauired POSRC Reviev

Ch. 9 159

l l

'ATTACHMENT 1d INDEX OF MATER CHEMISTRY A1G) RADIOCHEMISTRY PROCEDURES MAIAJAL - RCP 1 CURRENT mr. f 1 - 1009 Determination of E RCP 1 1100 Series - Purchase Specification 1 1101 Plant Chemicals 0 P 1 1102 Resins RCP 1 1200 Series - Special Procedures 1 1201 Auxiliary Boilers 0 1 1202 Determination of Mater and Sediment in Fuel Oils 0 1 1203" Determination of the Ability of TSP to Dissolve 1- 1204 Observation Well Depth Recorder 5 Well Water Usage Records 1 1205 Special Procedure for Nuclear Grade Resin Surveillance 1 - 1206< Special Procedure for Reactor Coolant System Hydrogen Peroxide Treatment 0 "Required POSRC Reviev Ch. 14 160 a >~

S: 4 gl 4'

RCP 1-202 ATTACHMENT (Za) Rev. 8 Page 2 SPECIFICATIONS AND SURVEILLANCE REACTOR COOIANT SYSTEM TABLE I HOT LEG (OR LETDOWN SX 6458) ANALYSIS/PROCEDURE SPECIFICATION FREQUENCY A (1) B (1)

1. +H 6 25 C/902 4. 5 lo.2 5/w 3/w Consistent with

2. S ecific conductivit /901 conc. of additives 5/w 3/W

3. Boron/903 (Tech S ec 3.1.1 5 3.9.1) Variable /tr (2) /24hrs.

4. Lithium/908 (max) (3) 5/w 5 Chloride/906 (Tech S ec 3 4 7) O.15 m (:~) 1/72hr. 1/72hrs.

6. Fluoride/907 (Tech S ec 3.4.7) 0.15 m (max) 1/72hrs. 1/72hrs.

7. Sus ended Solids/911 o.5 (max) 1/W 1/W draxine/910 1.5x measured 0 conc. (4) None

9. Ammonia/909 (5) 1/w None O. 0 en/905 (Tech S ec 3 4 7) O.1O m (M~) (6) 1/72hrs. None

1. dro en/904 10-50cc/k (7) 1/W None

2. Nitro en/904 Not snecified s Re i AS REQUIRED

3. Total Activit (Tech S ec 3.4.8) 100/E uCi/ (max) (8) >1/72hrs. /W

14. I13 'Dose E uivalent (Tech S ec 3.4.8) 1 uCi/ (8) 1/14da s None

5. Geo s l(D sed A tielt Not s ec ified 1/W

6. Gross Aleha Activit /1001 Not snecified 1/W

7. I131/I133 Ratio/1003 Not s ecified 1/W del t

  '8   Tr'tium/1007                                            Not s   ecified           1/W

15. Crud Activit /1008 Not snecified 1/M 1/M (Tech Spec

     . E Determination/1009          Table 4.4-4)              Not saecified             1/6mths.       None Iod'ne isotopic l       ana~sis (Tech Spec 3.4.8)                               Not specified             (9)            (9) e 161

4 5 C

C RCP 1-202 Rev. 7 . Page 3 ATTACHMENT 2b) SPECIFICATIONS A'/D SURVZILZAiCE REACTOR COOLAIlT SYST&f TABLE I NOTES (1) Frequency A = Modes 1, 2,, 3, 4 Frequency B = Modes 5, 6 (2) Required 1/24 hrs. to verify shutdown margin per Tech. Spec. 3.1.1. in Mode In Mode 6, 1/72 hrs. a" per Teen. Spec. 3.9.1. (3) Normal range 0.2 to 1.0ppm. Lithium should be maintained 0.2-0.5 when Q ~50ppm. 0 (4) Prior to exceeding 150 F. Tne presence of hydrazine will be verified following any chemical addition of hydrazine to the coolant. (5) Normal concentration about 1.0ppm. (6) Must be within specification prior to heatup M50 F. (7) Hydrogen must be maintained <<ithin these limits for all plant operation above 1M'. Less then 5cc H2/hg H20 (STP) is required for opening the reactor coolant system to atmosphere. (8) If the total activity pl00/E uCi/g or 01.0 uCi/g dose equivalent I-131 perform analysis 821 of this procedure 1/4 hrs. until the activity is returned to within

   ,~  specification.   ~

(9) This analyst.s shall be performed according to the following schedule:

a) Once per 4 hours, whenever the dose equivalent I131 exceeds 1.0 uCi/gram (until the RCS specific activity is restored within its limits), and b) One sample between 2 and 6 hours following a thermal power change exceeding 15K of the rated thermal power within a one hour period. 162

4 II j

ATTACHMENT (3a TABLE 3-3

SUMMARY

OF REACTOR COOLANT CHEMISTRY SPECIFICATIONS Anal sis Precore ~CL di 0 eratin pH 9 77'F 9.0 - 10.4 4.5 - 10.2 4.5 - 10.2 Conductivity Note 1 'ote 1 Note 1 Hydrazine 30 - 50 ppm 30 - 50 ppm 1.5 X Oxygen ppm (max. 20 ppm) Arenonia <50 ppm <50 ppm <0.5 ppm Dissolved Gas <10 cm STP kg H20 prior to a depressur-ization shu'tdown Oxygen <0.1 ppm <0.1 ppm <O.l ppm Suspended <0.5 ppm <0.5 ppm <0.5 ppm Sol i ds 2.0 ppm max. 2.0 ppm max. 2.0 ppm max. Chloride <0.15 ppm <0.15 ppm <0.15 ppm Fluoride <O.l ppm <O.l ppm <O.l ppm Boron Refueling .Concentration <4400 ppm Lithium 1 to 2 ppm 0.2 - 1.0'pm 0.2 - 1.0 ppm (Note 2) (Note 3) Hydrooen 10 - 50 cm STP kg H20 (Note 4) Iodine-131 Note 5 Tri tium Note 5 Reactor Coolant Note 5 Liquid Activity Note 5 NOTE 1: Consistent with concentration of additives. NOTE 2: Refer to Section 3.3.2.1 for the length of time this specification will be in force. NOTE 3: If the purification ion exchanger is being saturated in situ with Li maintain 1-2 ppm Li until saturation is rene/ed (indicated by Li breakthrough), then revert to 0.2 - 1.0 ppm Li. Saturation should be ac~omplished prior to criticality. NOTE- 4: <5 cm (STP)/kg(H 0) before securing the reactor coolant pumps. NOTE 5: See FSAR, Techni/al Specifications. Revision 2 163

aj aa m ass e SPECIFICATION SHEET NO. 3-3 SYSTEM REACTOR COOLANT OPERATING Sample Sampling Analysis Location Frequency Specifications Corrective Action Notes

'pH                1.Hot Leg Loop                    4.5 to.10.2(             1.Confirm value.            a) Frequency Code (Measured  at       or Purifica-                                            2.Perform 0 Hp                1  = 1/week 25'C)              tion Fil ter                                               and  lithiflm               2 =  2/week Inlet (PF                                                  analysis to Inlet)                                                     determine cause.            5 =  5/week 2 'urification                                             3.Valve in standby column      2Y = 2/year Ion Exchanger                                              if  high pH due to hiqh     S = During shut-Outlet (IX                                                 lithium.                         downs and Outlet)                                                 4.Add   Li-7   if too  low.         startups

5. If pH change due to AR = As required high 0 , follow b)The pH limit of corrective action 10.2 must not be under that heading. exceeded; see Section 3.3.2 for further discussion.

Reactor Makeup 6.0 - 8.0 1.Confirm value. Water Tank . 2.Drain and refill req'd. if Oxygen 1.Hot Leg Loop Less than 0.1 ppm 1.Resample to confirm c)Hydrazine is added 2.Reactor Makeup value. to recircul ating Water Tank 2. If during hqatup, add reactor cool ant hydrazine(c> to 1.5 during heatup if times 02 concentra- required to remove tion. excess 02. The

3. Perform Hp anal ys i s system cannot if at power, add Hp exceed 150'F until the 02 operating as required.

4.If pH and Hp also low limit or a hydra-out-of-spec, add zine residual is N2H4. established. Hydrogen Hot Leg Loop 2 10 to 50 cm (STP 1.Add Hp as required. <5 cm (STP)/kg H 0 Hp/Kg H20 2.Degas as required. before securifg reactor coolant um '/otal Dissolved Hot Leg Loop. AR <10 cm (STP)/ kg H20 1.Degas as required. Gas prior to shutdown

l

                                            .SPECIFICATION SHEET NO. 3-3 REACTOR COOLANT   -  OPERATING (Continued)
                                                                          'YSTEM Sample           S  pl  ng Analysis  Location           Frequency       Specifications                Corrective Action                                    Notes Atanonia  Hot Leg Loop                      Less Than 0.5 ppm      1.      Initiate or increase                        (d) Amnoni a i s due to or  PF  Inlet                     NH3                            pur~f~cat>on flow.                              hydrazine decomposi- n 2.0r reduce Np content                                  tion or radiolytic of Reactor Coolant,                             combination of as                                              N2  and H2.

applicable.'.Initiate Lithium 1.Hot Leg Loop Daily; 0.2 to 1.0 flow to de- (e)To determine when or PF Inlet after ppm lithiating bed if high. when bed saturation additions; takes place during and AR; 2.Add Li-7 if Low. lithiation. (Note 1) 2.IX Outlet 1 Boron 1.PF Inlet Add boric acid or (f)Boron concentration or Hot Leg makeup as required. varies with burn-Loop I up. The predicted 2.Reactor Zero concentration is Makeup Water found in the Final Tank Safety Analysis 3.Volume Report of each Control Tank plant. Liquid 4.Refueling Mate (f) NOTE 1:At least every 4 X7 Tank hours during ( A) 5.IX Outlet (whe (f) boration or dilution operations. tlat deborating) ~ Wo 0 6.Pressurizer (f) Prior to and after boration/dilution, Chloride 1.PF Inlet Less Than 0.15 ppm 1.Check IX Outlet operations, unless-or Hot Leg Loo these are part of 2.IX Outlet 2. Initiate or increase a casualty, then purification flow. sampling should be Fluoride 3.Reactor Less Than Q.l ppm 3.Check Reactor Water ASAP. Makeup Water Makeup Tank and bleed Tank and feed, as required. 4.Isolate and shift 4.Volume columns. Control Tank 5.Replace resin bed, Liquid as re uired.

l 4

SPECIFICATION SHEET NO. 3-3 SYSTEM REACTOR COOLANT - OPERATING (Continued) Sample Sampling Analysis Location Frequency . Specifications Corrective Action Notes Solids: 1.Concentra- 1.Hot Leg Loop 1,S Less Than 0.5 ppm 1. Initiate or Increase (l)The abnormal tion of Purification Flow. condition of 0.5 Suspended 2.PF Inlet 1,S (max. of 2.0 ppm) 2.Bleed and feed if no to 2.0 ppm is Solids extra purification is permitted for up (Crud) available. to 4 hours to

3. If maximum limit of allow for crud 2.0 ppm is exceeded, burst conditions.

an orderly shutdown is required. (m)Suspended solids level must not exceed 2.0 ppm,

2. Total Reactor Plant Less Than 0.5 ppm Bleed and Feed or re- the design limit Solids Makeup Tank place water to reduce of most major solids level . primary components.

3.Activity 1.Hot Leg Loop 1,S As it relates to Initiate or increase of Sus- E (g) purification flow. (n)These will indicate pended 2.PF Inlet 1,S the ability of the Solids filter and IX bed (i) 3.IX Inlet to remove the solids. 4.IX Outlet(n) Tritium 1.PF Inlet or 1 (g) Hot Leg Loop 2.Reactor 2Y Concerning Waste Makeup Water disposal Tank

4 RCP 1 215 ATTACHMENT 4 REV. 6 PAGE 3 SPECIFICATION.". AND SURVEILLANCE CVC.", SYSTEMS TABLE l Analysis Procedure/Method S ecification F~reeu'ene A. Ion Exchanmrs

1. Conductivity/901 AS REQUIRED

2. pH 6 25oC/902 AS REQUIRED 3~ Boron/903 DF = 2(min) (2.)(~) AS REQUIRED

4. Chloride/906 0.15 ppm (max) AS REQUIRED

5. F1uoride/907 0.1 ppm (max) AS REQUIRED

6. Lithium/908 AS REQUIRED Quantitative Gamma DF = 10(min) (2) 1/M Activity avg

8. Dose Rate, Vessel Contact N.S. 1/M B. Filters

1. Suspended Solids/911 DF = 10 (min) 1/M e

C. YCT

         'ydrogen/904                        9-45 psia                                  3/W (1)     Should be consistent     vith  concentrations    of chemical additives.

(2) DF = influent/effluent. (3) When deborating ion exchanger is operating. 167

'g

'5

i<PELP-t WE=lYI r r~mmr ~m~~ A dh JP~BI 4 CALVERT CLtFFS SPEClPICATIOHS Pi<D St.G<VE "LLNtCE RSCE DtC..~ N$L'j NUCLEAR POWER PLANT POSRC=---- PJKE UF DBIXgEFALIZZD dATEF ( l h>ci i% a'@sf'TTACHMENT 5 TABLE 1 Reactor Coolant eke Up Pumps Discharge Anal/ s is Procedure/Method S ecification Fre uen 1) 1 pH g 25aC/902 5.8 to 8.0 5/y

2. Conductivity/901 2.0 umho/cm3 (max) 5/w 3, Chio ide/906 0 ~5 pX (~~)

4. Sodium/@gal 10 ppbCw<~)

5. Silica/916 0.02 ppm (m~)

I" 1. Samples may be collected from either units or other suitable sample point off the r actor coolant make up pump Derineralized vater system. 168

1 li SHEET NO. 2-1 I'PECIFICATION SYSTEM MAKEUP WATER Sample Sampling S ecifications Analysis Location Frequency Normal Abnormal Corrective Action Notes onducti vi ty Makeup 1.Continuous (1. 0 1.0-2.0(') 1. Isolate offending (a) See Section 2.3.2 Water In Line pmho/cm gmhos/cm train. for further discus-System- De- Monitor 2.Perform pH, Cl sion of the out-of-mineralizer 2.Daily Grab and Conductivity spec condition. Effluent Sample on grab samples Makeup water that (MWS Demin. 3.Prior to put- from effluent lin exceeds 2 0 ymhos/cm Effluent) ting train on and from tank tha is unacceptable for line it feeds. use . 3.Commence Resin Regeneration if out-of-spec con-dition verified (otherwise, clean cell s) .

4. Check performance of entire train i water volume sine last regeneration is low.

Demin. l. Daily 6.0-8. 0 6.0 b))- 1.Isolate offending (b) A pH as low as 5.8 is pH MWS Effluent 2. Prior to 8.0 train. acceptable only if putting train 2.Check performance caused by C02 absorp-on line of entire train tion. Boil sample if water volume according to Section since last regen- 6.4.13; Remeasure eration.is low. pH. Cdrrect as (c) 'See Section 2.3.3 necessary. for further discus-3.If C02 is not the sion of the Out-problem, commence of-Spec condition. regeneration.

f SPECIFICATION SHEET NO. 2-1 SYSTEM .MAKEUP WATER (Continued) Sample Sampling . S ecifications Analysis Location Frequency Normal Abnormal Corrective Action Notes Chloride MWS Demin. 1. Daily <0.15 ppm 0.15( ) 1. Isol ate Offending d) See Section 2.3.4 Effluent Grab ppm train. for discussion of Sample 2.Check performance the Out-of-Spec 2.Prior to of entire train condition. putting trai on line if water volume since last regen-eration is low. Fluoride MWS Demin. As required <0.1 ppm 3.Cmmence resin Effluent for. Primary regeneration if makeup chloride level verified. Si02 MWS Demin. 1. Daily <0.01 ppm 0.0 - .02 1. Isolate Offending e) This frequency should Effluent Grab Samples train, be revised at end of 2.If analysis con- preservice period. firmed, reduce f) See Section 2.3.5 flow through for discussion of the train. Out-of-Spec condi-3.Follow corrective tion. action outlined > Section 2.3.5.

if F. SECTION IV REFERENCES Combustion Engineering Power"Systems. Nuclea} Steam Supply System Chemistry Manual CENPD-28. Revision ¹2.

2. "

RCP-1-202. Specifications and Sur veil lance. React'or Coolant System

3. RCP-1-215. Specifications and Surveillance. Chemical and Volume Control System.

4. RCP-1-201. Specifications arid Surveillance. Makeup Demineralized Water.

5. RCP-1-102. Recor ds. Chemi cal Log 1-102-2. 07/Ol/80 to 07/31/80.

6. Letter dated 11/08/79. BG&E-10276-70, P. W. Kruse to L. B, Russell

Subject:

Calvert Cliffs Unit I Power Distribution Anomaly Letter dated ll/19/79. BG&E-10276-75, P. W. Kruse to L. B. Russell

Subject:

Calvert Cliffs Unit I Power, Distribution Anomaly

7. Letter dated 03/07/80. BG&E-10276-99, P. W. Kruse to L. B, Russell

Subject:

Calvert Cliffs Unit I Power Escalation Program

8. Memorandum dated 03/11/80. R. F. Eherts to PDTF

Subject:

Unit I Power Anomaly Letter dated 12/ll/79. BG&E-10276-8, P. W. Kruse to L. B. Russell

Subject:

Calvert Cliffs Unit I Power Distribution Anomaly Memorandum dated Ol/15/80. A. J. Kaupa to PDTF

Subject:

Hydrazine Addition Letter dated 01/15/80. BG&E-10276-88. P. W. Kruse to L.. B, Russell

Subject:

RCS Hydrazine Addition

12. Letter dated 02/15/80. BG&E-10276-93, P. W. Kruse to L. B. Russell

Subject:

Calvert Cliffs Unit I Crud Anomaly

13. Letter dated 12/ll/79. BG&E-10276-87, K. W. Kruse to L, B. Russell

Subject:

Calvert Cliffs Unit I Power Distribution Anomaly

14. Letter dated 01/19/80. BG&E-10276-87, P. W. Kruse to L. B. Russell

Subject:

Volume Control Tank Level Memorandum dated 01/04/80. R. F. Eherts to PDTF 15.'6.

Subject:

Discussions with D. Morgan, Combustion Engineering Memorandum dated 02/26/80. R. F. Eherts to J. R. Speciale/PDTF

Subject:

Unit I RCS Chemistry

17. Memorandum dated 02/26/80. R. F. Eherts to J. R. Speciale/PDTF

Subject:

Unit I Power Anomaly 171.

V. CONCLUSTIONS AND LESSONS LEARNED Although the evidence is circumstantial, it is reasonable to infer that the reactivity and power distribution anomalies were'caused by the slow buildup of crud on the core surfaces. The deposition of crud was preferential to the core top and periphery, The crud was a product of the corrosion of RCS surfaces by slightly higher than normal Oxygen levels in the RCS, The source of the Oxygen was instrument air from an ion exchanger resin flush system. Two in servies values leaked past their seats and increased the Oxygen concentration in the water of the purification section of the CVCS to approximately 300 ppb for several weeks. Although this concen-, tration was further diluted prior to injection back into theRCS, it was apparently enough to overpower the scavenging effect of the Hydrogen in the RCS. Once the conditions for oxidation of RCS surfaces had been established, the normal Oxygen concentration levels in RCS makeup water were enough to maintain that oxidation state even though the original abnormal source of Oxygen had been isolated. In order to mitigate the effect of Oxygen ingress during this episode and to preclude it from reoccurring in the future, the following short and long term actions have been or are being taken: (I) The leaking resin flush valves were repaired. (2) The resin flush medium has been changed from air to nitrogen. (3) The RCS makeup rate has been reduced by the action of rebuilding a power operated pressurizer relief valve which was a significant source of leakage from the RCS. (4) Chemistry procedures have been modified to tighten surveillance at potential sources of air ingress into the RCS. (5) Gauges have been added which allow monitoring of any pressure buildup in the nitrogen header supplying the ion exchangers, Although it is not expected that the introduction of nitrogen to the RCS would result in an anomaly such as that caused by Oxygen, the monitoring of header pressure provides an extra measure of conservatism to prevent the inadvertant introduction of insoluble gas to the RCS. 172

Jl (6) Hydrazine in stochiometric concentrations is metered into the RCS makeup water at the point of its injection into the CVCS. A control scheme is being developed to automate this process. (7) Pertinent core and fuel performance parameters are being trended and the surveillance and evaluation frequency has been increased. (8) The feasibility of deaerating the RCS makeup water is being investigated. (9) A fuel inpsection program forthe purpose of documenting any lasting effects of the episode is being developed for performance at the next refueling. 173

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J '~. I ( APPENDIX A CHEMISTRY RESULTS OF THE UNIT 1 HYDROGEN PEROXIDE TREATMENT DISCUSSION On January 27, 1980, hydrogen peroxide was added to the Unit 1 reactor coolant system and various chemistry parameters were monitored in order to determine the effectiveness of the ex-pected chemical shock to the system. Hydrogen peroxide has been added to a number of other nuclear facilities and an EPRI report has been published which documents the findings of a limited sur-vey of utility experience and the results of two intensive test programs (reference 1). The pertinent findings of that report wele:

l. Greater than 90$ of the Co-58 activity in the primary coolant is nonfilterable subsequent to the peroxide injection or oxy-genation.

2. In-core deposits are the major source of the activity released duping shutdown with or without peroxide injection.

3. Peroxide or oxygen addition had no major impact on primary system shutdown radiation fields.

4. Oxygenation and hydrogen peroxide addition produce similar effects on'he release of Co-58. This results from the in-terrelationship of oxygen and hydrogen peroxide caused by radiolytic effects in the core,

5. Since Co-58 is present predominantly as a nonfilterable species subsequent to oxygenation or the addition of hydrogen peroxide, neither dropout nor the high radiation fields associated with dropout would be expected to occur.

The main purpose for performing the hydrogen peroxide treatment os Unit 1 was to affect a chemical shock to such a degree that an im-provement in core differential pressure would be manifested. It should be pointed out that the EPRI report concluded that the hydrogen peroxide technique, "can be of significant value in eliminating the occurrence of significant releases when purification to reduce re-fueling platform manpower exposures would impact on the refueling outage schedule". Although Ft. Calhoun observed improvement in reac-tor coolant flow as an apparent result of the hydrogen peroxide tech-nique (reference 2), the EPRI work did not address any effects rela-tive to possible core parameter improvements. There is, therefore, no other evidence that the hydrogen peroxide treatment will result in a decrease in core differential pressure. PLANT PROCEDURE FOR HYDROGEN PEROXIDE ADDITION A plant procedure was prepared for the hydrogen peroxide treatment (reference 3). The procedure delineated the initial conditions 174

required, the collection of baseline data, the addition of the peroxide and the sampling/surveillance program needed to monitor the effectiveness of the addition on the reactor coolant system chemistry. Of crucial importance was the performance of. the chem-ical and volume control ion exchangers. The ion exchangers were needed to control the expected high coolant activity which would result from the solubilization of the Co-58 isotope and also control other corrosion products. In order to determine the endpoint of the hydrogen peroxide addition certain chemistry parameters needed to be monitored carefully after each addition. The plants in the EPRI study appeared to monitor Co-58 activity increases after peroxide additions as a primary para-meter. In addition, oxygen and hydrogen peroxide levels were consid-ered useful in determining the endpoint. The decision was made to terminate hydrogen peroxide injections when there was an inability to produce an "effective" chemical shock as determined by suspended solids, oxygen, and Co-58 activity. Therefore, a combination of these parameters would be utilized to determine the endpoint for the additions. Another aspect of the procedure considered important was the operation of the reactor coolant pumps. It was decided that the first be added to the loop from which letdown was being peroxide would withdrawn. Therefore, 12A and 12B pumps would remain in service during and fol-lowing the first addition and then the other loop would be flushed by switching to one pump per loop operation. By operating the pumps in this manner flushing of the core and steam generator surfaces would be more effective and purification could then be employed for removal of'soluble and insoluble crud. III. RESOLTS A. Chronolo of Events Table 1 consists of a chronology of events before, during, and after the peroxide addition. Of particular note is the venting and repressurization of the volume control tank (VCT) with nitrogen prior to shutdown in order to reduce the hydrogen in the coolant to a level corresponding to the lower end of the. normal operating concentration, (i.e., 10-50 cc hydrogen/kg water). Following shutdown, degassification continued until hydrogen was less than 5 cc hydrogen/kg water. The increased rate by which the hydrogen was successfully lowered may be attributed to a lowering of the normal operating band of the VCT water level. This increased the efficiency of gas stripping in the VCT vapor. Also 'of note from Table I are the periodic changes in the reactor coolant pump operation. As mentioned earlier this was accomplished intentionally in order to insure a hi.gh degree of effectiveness from the peroxide additions. 175

B. Peroxide Additions A total of 15.1 liters of hydrogen peroxide was added to the reactor coolant system within approximately 9 hours. Table 2 lists the peroxide additions and gives a comparison of theroe-tically calculated oxygen levels with observed oxygen levels based on the overall decomposition reaction 2H 0 ~ 2H 0 + 0 The data shows that the last peroxide addition resulted in close to predicted oxygen levels indicating that equilbrium had been reached. C. Effects on Chemistr Figure 1 is a plot of the Co-58 activity, Co-60 activity, and Co-58/Co-60 ratio during the peroxide additions. Figure 2 is a plot of other chemistry data collected. The peroxide additions are highlighted by arrows at the times the addition was completed. The addition of the hydrogen peroxide resulted in significant changes in the chemistry of the reactor coolant system. Of particular note were the increases of Co-58 total activity and suspended solids. As expected, the increase in solubility. of cobalt and nickel oxides present in the crud caused high dissolved Co-58 activity levels and the sudden shock on converting the chemistry from a reducing environment to an oxidizing environ- " ment caused crud to spall off system surfaces as indicated by the increase in crud levels. The resulting oxygen levels re-flect the addition of the peroxide and appear to show that con-sumption of the oxygen occurred while conversion of the oxides to soluble forms took place. criteria for termination of the hydrogen peroxide addition I'he to the reactor coolant system was based on several parameters. One of the critical parameters monitored was the oxygen level in the reactor coolant system. The oxygen level showed a decrease in a short time following the first addition showing that the system had not yet,come to an equilibrium. At 2040 hrs., following the second addition, the oxygen level was .25 ppm, while the next or final injection brought the oxygen level up to 1 ppm. This level was close to predicted and indicated that oxygen was essentially at equil'ibrium (Table'); The next

sample at 2400 hrs. showed a constant level of oxygen of 1 ppm. in addition to the oxygen parameter, suspended s'olids and Co-58 levels had peaked earlier and showed a slight decreasing trend which was expected because of the small purification flow rate of 40 gallons per minute. Peroxide additions were therefore terminated at 0020 hrs. on 1/28/80. 176

                             ~
                                 'I d

o g Reference (1) concluded that in-core deposits were the major source of the activity released during shutdown. The addition of hydrogen peroxide to Unit 1 appear to confirm that con-clusion. Reference (1) showed that the average Co-58/Co-60 ratio of crud deposited on steam generator diaphragms was significantly lower than the ratio observed during the release of crud following peroxide addition. This was attributed to increasing solubility of crud on core surfaces vice out-of-core surfaces. Table 3 shows the results of smears taken from Unit 1 and Unit 2 steam generator diaphragms. Figure 1 shows the ratio 'of Co-58 to Co-60 during and following the peroxide additions. The data shows that Co-58/Co-60 ratio following the peroxide addition was about'00 whe'reas the steam generator diaphragm typical ratio is considerably lower. These results

appear to confirm that the majority of the crud observed in the reactor coolant system following the .peroxide addition to Unit 1 came from in-core surfaces. Reactor Coolant S stem Cleanu During the addition of peroxide letdown flow was approximately 40 gpm. At 1400 hrs. on 1/28/80, flow was increased to a nom-inal 120 gpm to more rapidly affect cleanup. During these periods two purification ion exchangers were in service. They consisted of a cation removal ion exchanger and a mixed bed (cation and anion removal) ion exchanger. Both ion exchangers were utilized in series operation. Table 4 shows the Co-58 decontamination factors (DF's) determined across the ion exchangers at various times. Cleanup of the reactor coolant system while utilizing reactor coolant pump operation continued until about 2000 hrs. on 1/29/80 when draining of the system was started. After that time the shutdown cooling system remained in-service to coatinue to remove soluble Co-58 and suspended solids. During the peroxide addition, Co-58 levels increased to 2 yCi/cc as opposed to the baseline data of 6 x 10-a pCi/cc and the normal shutdown levels of 4 x 10 to 8 x 10-~ pCi/cc. The system was

not allowed to be opened or drained down in order to allow a j cleanup of the system to baseline levels. This was to insure that the radiation levels of the system components would not be higher than normal due to a possible redistribution of the crud. Purification was maintained until the Co-58 levels returned to normal shutdown cooling levels and the system was not experiencing additional crud releases while alternating reactor coolant pump operation. The decreasing trend in suspended solids, except for a small crud release and corresponding increase in Co-58 activity levels at 0800 on 1/29/80, indicated that cleanup was effective. The 12 hour period on 1/29/80 from 0800 to 2000 hrs. indicated that the system chemistry was continuing to trend down to normal shutdown levels. Therefore normal shutdown conditions had been achieved and the draining of the system could begin. In addition, shutdown radiation .levels were showing a continuing downward trend towards normal shutdown levels. 177

gi t ~

It has been estimated that from the period 1510 hrs. on 1/27/80 thru 1400 hrs. on 1/28/80, 282 curies of Co-58 were removed from the coolant. This assumed a nominal flow rate of 40 gpm. From 1400 hrs. on 1/28/80 thru 2000 hrs. on 1/29/80, 291 curies of Co-58 were removed at a nominal flow rate of 120 gpm. Therefore the total Co-58 activity removed from the coolant starting with the peroxide addition until draining of the coolant was initiated was 573 Curies. Effects on Shutdown Radiation Levels During and following the peroxide addition several areas were selected iii the plant for intensive radiation level monitoring. The following locations were selected:

l. 812 Purification Ion Exchanger Valve 1-SI-306 (Outlet flow control valve on safety injection)

3. Ill and 012 Shutdown Cooling (SDC) Heat Exchanger:

4., bllA and ~11B Cold Leg 012 Purifichtion Ion Exchanger was monitored in order to deter-mine when it should be removed from service since the radiation level is a critical parameter with respect to use of shipping casks for ultimate disposal of the resin. The ion exchanger reached a peak radiation level of 600-900 R/hr about 14 days following the last peroxide addition and it was then removed from service. The radiation levels at the other locations are shown in Figure 3. The radiation levels monitored at SI-306 and the SDC heat exchangers show maximum readings near the times of the peroxide additions. This appears to reflect the crud release which occurred at that time. The radiation levels at 811A and ~llB cold leg do not appear to reflect the crud release, however, there is a gradual decrease in radiation levels at those locations and may be an indication of the clean-up of the system. Historical data regarding previous radiation levels at these locations appea~ to support the fact that the dose rates shown in Figure 3 existed before without the peroxide treat-ment. Dose rates up to 350 mR/hr on the SDC heat exchangers have been experienced during previous shutdowns as well as dose rates of about 150 mR/hr on 811A cold leg. SI-306 dose rates have generally averaged about 60 mR/hr during previous shutdowns which is close to the average dose rate experienced following the peroxide treatment. 178

E F. Effects on Core Differential Pressure The addition of hydrogen peroxide to the Unit 1 reactor coolant system appears to be responsible for the reduction of the core di'fferential pressure observed following heat-up on February ll, 1980. Figure 4 shows the various core parameters monitored and their respective values prior to and after the"hydrogen peroxide chemical shock. Core ap dropped from 15.7 psi to 13.8 psi or about a 12K reduction. Based on the results of the hydrogen peroxide treatment the following summary is given:

1. The hydrogen peroxide chemical shock appears to have reduced core differential pressure by 12%.

2. A total volume of 15.1 liters of hydrogen peroxide was added to the RCS in three separate injections.

3. Increases in total Co-58 activity and suspended solids indicate the hydrogen peroxide produced a significant crud release.

4. Based on a comparison of data collected here with the results of the EPRI study, in-core deposits appeared to be the major source of activity released.

5. Approximately 600 Curies of Co-58 was removed from the coolant during and following the hydrogen peroxide treatment.

6.'eroxide additions did not cause unexpected changes in shutdown radiation fields. 179

TABLE 1 CHRONOLOGY OF EVENTS FOR H ~OTREATMENT OF U-1 RCS 1/25/80 0830 hrs. RCS Hydrogen 18.2 ccH /kg H 0 2000 Vented E Repressurized VCT w/N 2 2105 Vented 5 Repressurized VCT 4 times w/N 2120 Commenced Reducing Power for Shutdown 2357 Opened TG Output 1/26/80 0110 hrs. Stop 12A E 12B RCP 0150 Commenced Cooldown 0200 RCS Hydrogen 13.5 ccH /kg H 0 2 2 0245 Started 12B RCP Stop 1 1B RCP 0400 RCS Hydrogen 7.8 ccH /kg H 0 2 2 0446 In Mode 4 0600 RCS Hydrogen 4.5 ccH /kg H 0 2 2 0700 Secured Degassing VCT; Filled 8 Vented 4 times 0920 Stop 11A 5 12B RCP's 0925 Start'SDC with ll LPSI 0936 Restart llA 5 12B RCP's 1215 In Mode 5 1343 Start LPSI Pump on SDC 1720 Completed Press 5 Vent VCT 1/27/80 0220 hrs. Removed rll purif ion exchanger from service, 812-purif into service deborating in service Ill 0635 Start 12A RCP Stop 11A RCP 0854 Stop 12B RCP Start 11B RCP 180

TABLE 1 (CONT'0) 1/27/80 1035 Stop 12A RCP Start 12B RCP

       . 1225         Stop 118    RCP Start   12A RCP 1250         Started addition of 9.1 Liters of Hydrogen Peroxide
         '415          Completed add     of  Hydrogen Peroxide to RCS 1736         Stop 12A RCP,     Start llB    RCP 1746         Started Addition of 2.0 Liters Hydrogen Peroxi.de     to  RCS 1816         Stop 12B    RCP Start   12A RCP 1835         Completed add     of  Hydrogen Peroxide 2058         Stop 11B    RCP Start   12B RCP I

2110 Started Addition of 4.0 Liters Hydrogen Peroxide to RCS 2155 Completed add of Hydrogen Peroxide to RCS 1/28/80 1030 Stop 12A RCP Start 11B RCP 1315 Start 13 Charging Pump (ll Already Running) 1335 Start 12 Charging Pump 1400 Increased Puri. Flow to ~120 gpm 1530 Completed Collection of Suspended Solids Sample for Chemical Analysis 1830 Stop 11B RCP Start 12A RCP 1/29/80 0230 Started 11B RCP Stop 12A RCP 1030 Start 12A RCP Stop 11B RCP 1125 l2 purif IX 'from .service'emove and placed 11 Deborating IX & 11 Purif IX In Series 1151 Stop all RCP's 181

TABLE 1 (CONT'D) 1/29/80 1248 Start 11B RCP 1252 Start 12A RCP 1825 Start 12B RCP Stop 11B RCP 2150 Stop 12A 8 B RCP 2155 Stop SDC Flow Thru IX 2200 Stop 12 5 13 Char ging Pump 2220 Stop 11 Charging Pump 2233 Start 11 Charging Pump 1/30/80 0200 Stop 11 LPSI 0630 Purification on SDC 182

TABLE 2 THEORETICAL VERSUS OBSERVED OXYGEN LEVELS FOLLOWING HYDROGEN PEROXIDE ADDITIONS ADDITION VOLUME . THEORETICAL OBSERVED RATIO TIME ADDED(LITERS OXYGEN(PPM) OXYGEN PPM) THEORETICAL/OBSERVED 1415 9.12 '.57 0.100 15.7 1835 2.0 0.76 0.250 3.04 2155 4.0 I. 52 1.00 1.52 183

TABLE 3 TYPICAL Co-58/Co-60 RATIOS FROM STEAM GENERATOR DIAPHRAGMS UNIT 1 Co-58/Co-60 ACTIVITY(uCi ) Co-58/Co-60 RATIO Outage 82 2. 38E-1/1. 30E-1 Outage f3 5. 26E-1/1.29E-l 4.1 UNIT 2 Outage 01 6. 89E-1/7. 48E-2 9.2 Outage 82 7. 44E-1/8. 78E-2 8.5 184 I/

TABLE 4 Co-58 DECONTAMINATION FACTORS Co-58 Activity (pCi/ml) DECONTAMINATION DATE TIME INLET OUTLET FACTORS i 1/27 0247 4.7 E-1 6.6E-4 712 1/27 1800 1.54 8.5E-4 1812 1/28 0800 1.17 4.3E-4 2720 1/28 1600 8.1 E-1 2.3E-3 352 1/28 .2000 4.5 E-1 3.5E-3 128 1/28 2400 3.3 E-1 7.8E-3 1/29 0800 1.2 E-1 2.8E-3 1/29 1145 2.3 E-1 1.3E-3 1772 1/29 2000 1.3 E-1 4.9E-3 , 26~ > Decontamination factors were taken across ~12 purifi'cation ion exchanger (cation) and Ill deborating ion exchanger (mixed bed) in series operation 2 812 purification ion exchanger removed from service and Ill purification ion exchanger (cation) placed in service at 1125 hrs. on 1/29/80, 185

I REFERENCES

1. EPRI Report HP-692, "Effects of Hydrogen Peroxide Additions on Shutdown Chemistry .Transients at Pressurized Mater Reactors",

April 1978

2. "Fort Calhoun-l, Reactor Coolant System Peroxide Treatment 11/10/74 to ll/13/74", Principal Investigator-D. J. Horgan

3. RCP 1-1206 "Reactor Coolant System Hydrogen Peroxide Treatment" Revision 0, January 9, 1980 186

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