Annual Report (Form 10-K), fiscal year 1994

ITEM 1. BUSINESS
ACQUISITION AND MERGER
On March 31, 1992, Western Resources, Inc. (formerly The Kansas Power and Light Company) (Western Resources) through its wholly-owned subsidiary KCA Corporation (KCA), acquired all of the outstanding common and preferred stock of Kansas Gas and Electric Company (KG&E) for $454 million in cash and 23,479,380 shares of Western Resources common stock (the Merger). Western Resources also paid approximately $20 million in costs to complete the Merger. Simultaneously, KCA and Kansas Gas and Electric Company merged and adopted the name Kansas Gas and Electric Company (the Company, KG&E).
Additional information relating to the Merger can be found in Management's Discussion and Analysis of Financial Condition and Results of Operations and Note 1 of the Notes to Financial Statements.
GENERAL
The Company is an electric public utility engaged in the generation, transmission, distribution and sale of electric energy in the southeastern quarter of Kansas including the Wichita metropolitan area. The Company owns 47 percent of Wolf Creek Nuclear Operating Corporation, the operating company for Wolf Creek Generating Station (Wolf Creek). Corporate headquarters of the Company is located in Wichita, Kansas. The Company has no gas properties. At December 31, 1994, the Company had no employees. All employees are provided by Western Resources.
For discussion regarding competition in the electric utility industry and the potential impact on the Company, see Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, Other Information, Competition included herein.
The Company's business is subject to seasonal fluctuations with the peak period occurring during the summer. Approximately one-third of residential kilowatthour sales occur in the third quarter. Accordingly, earnings and revenue information for any quarterly period should not be considered as a basis for estimating results of operations for a full year.
Discussion of other factors affecting the Company are set forth in the Notes to Financial Statements and Management's Discussion and Analysis included herein.
ELECTRIC OPERATIONS
General
The Company supplies electric energy at retail to approximately 272,000 customers in 139 communities in Kansas. The Company also supplies electric energy to 27 communities and 1 rural electric cooperative, and has contracts for the sale, purchase or exchange of electricity with other utilities at wholesale.
The Company's electric sales for the last five years were as follows:
1994 1993 1992 1991 1990 (Thousands of MWH) Residential 2,384 2,386 2,102 2,341 2,270 Commercial 2,068 1,991 1,892 1,908 1,838 Industrial 3,371 3,323 3,248 3,194 3,093 Wholesale and Interchange 1,590 2,004 1,267 1,168 1,688 Other 45 45 46 46 48 ----- ----- ----- ----- ----- Total 9,458 9,749 8,555 8,657 8,937
The Company's electric revenues for the last five years were as follows:
1994 1993 1992 1991 1990 (1) (Dollars in Thousands) Residential $220,067 $219,069 $194,142 $219,907 $214,544 Commercial 167,499 162,858 154,005 155,847 151,098 Industrial 181,119 179,256 174,226 172,953 168,294 Wholesale and Interchange 38,750 45,843 28,086 29,989 36,152 Other 12,445 9,971 3,792 16,272 16,553 -------- -------- -------- -------- -------- Total $619,880 $616,997 $554,251 $594,968 $586,641
(1) See Note 4 of the Notes to Financial Statements for impact of rate refund orders.
Capacity
The aggregate net generating capacity of the Company's system is presently 2,498 megawatts (MW). The system comprises interests in twelve fossil fueled steam generating units, one nuclear generating unit (47 percent interest) and one diesel generator, located at seven generating stations. One of the twelve fossil fueled units has been "mothballed" for future use (see Item 2.



ITEM 2. PROPERTIES
The Company owns or leases and operates an electric generation, transmission, and distribution system in Kansas.
During the five years ended December 31, 1994, the Company's gross property additions totalled $358,486,000 and retirements were $130,238,000.
ELECTRIC FACILITIES Unit Year Principal Unit Capacity Name No. Installed Fuel (MW) (2)
Gordon Evans Energy Center: Steam Turbines 1 1961 Gas--Oil 150 2 1967 Gas--Oil 367
Jeffrey Energy Center (20%): Steam Turbines 1 1978 Coal 140
2 1980 Coal 143 3 1983 Coal 140
La Cygne Station (50%): Steam Turbines 1 1973 Coal 343 2 1977 Coal 335
Murray Gill Energy Center: Steam Turbines 1 1952 Gas--Oil 46 2 1954 Gas--Oil 74 3 1956 Gas--Oil 107 4 1959 Gas--Oil 105
Neosho Energy Center: Steam Turbine 3 1954 Gas--Oil 0 (1)
Wichita Plant: Diesel Generator 5 1969 Diesel 3
Wolf Creek Generating Station (47%): Nuclear 1 1985 Uranium 545 ----- Total 2,498
(1) This unit has been "mothballed" for future use.
(2) Based on MOKAN rating.
The Company jointly-owns Jeffrey Energy Center (20%), La Cygne Station (50%) and Wolf Creek Generating Station (47%).
ITEM 3.

ITEM 3. LEGAL PROCEEDINGS
Information on legal proceedings involving the Company is set forth in Note 10 of Notes to Financial Statements included herein.
ITEM 4.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
Information required by Item 4 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
PART II
ITEM 5.

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
On March 31, 1992, Western Resources through its wholly-owned subsidiary KCA, acquired all of the outstanding common and preferred stock of KG&E. As a result, the Company's common stock was delisted from the New York Stock Exchange and the Pacific Stock Exchange.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
FINANCIAL CONDITION
The results of operations for the years ended December 31, 1994 and 1993, and the nine months ended December 31, 1992, included herein, refer to the Company following the merger with Western Resources, Inc. (formerly The Kansas Power and Light Company) through its wholly-owned subsidiary, KCA Corporation, on March 31, 1992 (the Merger) (see Note 1).
Pro forma results of operations for the twelve months ended December 31, 1992 presented herein, give effect to the Merger as if it occurred on January 1, 1992 and were derived by combining the historical information for the three month period ended March 31, 1992 and the nine month period ended December 31, 1992. Additional information relating to changes between years is provided in the Notes to Financial Statements.
GENERAL: The Company had net income of $104.5 million for 1994 compared to net income of $108.1 million in 1993. The decrease in net income is primarily due to increases in income taxes as a result of the completion of the accelerated amortization of certain deferred income tax reserves and the receipt of death benefit proceeds from corporate-owned life insurance policies in the third quarter of 1993. As of December 31, 1993, the Company had fully amortized the deferred income tax reserves related to the allowance for funds used during construction capitalized for Wolf Creek Generating Station (Wolf Creek). The completion of the amortization of these deferred income tax reserves increased income tax expense and thereby reduced net income by approximately $12 million in 1994, and in the future will reduce net income by this same amount each year.
LIQUIDITY AND CAPITAL RESOURCES: The Company's liquidity is a function of its ongoing construction program, designed to improve facilities which provide electric service and meet future customer service requirements.
During 1994, construction expenditures for the Company's electric system were approximately $69 million and nuclear fuel expenditures were approximately $21 million. It is projected that adequate capacity margins will be maintained through the turn of the century. The construction program is focused on providing service to new customers and improving present electric facilities.
Capital expenditures for 1995 through 1997 are anticipated to be as follows:
Electric Nuclear Fuel (Dollars in Thousands) 1995. . . . . . . . . . $53,961 $ 21,400 1996. . . . . . . . . . 47,388 8,100 1997. . . . . . . . . . 42,453 24,000
These expenditures are estimates prepared for planning purposes and are subject to revisions from time to time.
The Company's net cash flows to capital expenditures exceeded 100 percent for 1994 and during the last five years has also averaged in excess of 100 percent. The Company anticipates all of its cash requirements for capital expenditures through 1997 will be provided from net cash flows. The Company also has $16 million of bonds maturing through 1999 which will be provided from internal and external sources available under then existing financial conditions.
During 1994, the Company continued to take advantage of favorable long- term interest rates by refinancing long-term debt issues. The embedded cost of long-term debt was 7.3% at December 31, 1994, a decrease from 7.7% at December 31, 1993.
On January 20, 1994, the Company issued $100 million of First Mortgage Bonds, 6.20% Series due January 15, 2006. The net proceeds were used to reduce short-term debt.
On February, 17, 1994, the Company refinanced the City of La Cygne, Kansas, 5 3/4% Pollution Control Revenue Refunding Bonds Series 1973, $13,980,000 principal amount, with 5.10% Pollution Control Revenue Refunding Bonds Series 1994, $13,982,500 principal amount, due 2023.
On April 28, 1994, three series of Market-Adjusted Tax Exempt Securities totalling $46.4 million were sold on behalf of the Company at a rate of 2.95% for the initial auction period. The interest rates are being reset periodically via an auction process. As of December 31, 1994, the rate on these bonds was 4.10%. The net proceeds from the new issues, together with available cash, were used to refund three series of Pollution Control Bonds totalling $46.4 million bearing interest rates between 5 7/8% and 6.8%.
On November 1, 1994, the Company terminated a long-term agreement which contained provisions for the sale of accounts receivable and unbilled revenues, and phase-in revenues (see Note 6).
In 1986, the Company purchased corporate-owned life insurance policies (COLI) on certain of its employees. The annual cash outflow for the premiums on these policies from 1992 through 1994 was approximately $27 million. See Note 2 of the Notes to Financial Statements for additional information on the accumulated cash surrender value. The borrowings are expected to produce annual cash inflows, net of expenses, through the remaining life of the policies. Borrowings against the policies will be repaid from death proceeds.
The Company's short-term financing requirements are satisfied, as needed, through short-term bank loans and borrowings under other unsecured lines of credit maintained with banks. At December 31, 1994, short-term borrowings amounted to $50 million compared to $155.8 million at December 31, 1993. The decrease is primarily the result of the issuance of the $100 million of bonds on January 20, 1994 (see Note 5).
The KG&E common and preferred stock was redeemed in connection with the Merger, leaving 1,000 shares of common stock held by Western Resources. The debt structure of the Company and available sources of funds were not affected by the Merger.
The Company's capital structure at December 31, 1994, was 64 percent common stock equity and 36 percent long-term debt. The capital structure at December 31, 1994, including short-term debt was 62 percent common stock equity and 38 percent debt. As of December 31, 1994, the Company's bonds were rated "A3" by Moody's Investors Service, "A-" by Standard & Poor's Ratings Group, and "A-" by Fitch Investors Service.
RESULTS OF OPERATIONS
The following is an explanation of significant variations from prior year results in revenues, operating expenses, other income and deductions, and interest charges. Additional information relating to changes between years is provided in the Notes to Financial Statements.
REVENUES
The operating revenues of the Company are based on sales volumes and rates authorized by the Kansas Corporation Commission (KCC) and the Federal Energy Regulatory Commission (FERC). Rates charged for the sale and delivery of electricity are designed to recover the cost of service and allow investors a fair rate of return. Future electric sales will continue to be affected by weather conditions, competition from other generating sources, competing fuel sources, customer conservation efforts and the overall economy of the Company's service area.
The KCC order approving the Merger provided a moratorium on increases, with certain exceptions, in the Company's electric rates until August 1995. The KCC ordered refunds totalling $32 million to the combined companies' (Western Resources and the Company) customers to share with customers the Merger-related cost savings achieved during the moratorium period. Refunds of approximately $4.9 (Company's portion) million were made in April 1992 and December 1993 and the remaining refund of approximately $8.7 million (Company's portion) was made in September 1994 (see Note 1).
On March 26, 1992, in connection with the Merger, the KCC approved the elimination of the Energy Cost Adjustment Clause (ECA) for most retail customers of the Company effective April 1, 1992. The fuel costs are now included in base rates and were established at a level intended by the KCC to equal the projected average cost of fuel through August 1995. Any increase or decrease in fuel costs from the projected average will impact the Company's earnings.
1994 Compared to 1993: Total operating revenues for 1994 of $619.9 million increased less than one percent from revenues of $617.0 million for 1993. The increase can be attributed to higher revenues in all retail customer classes. While residential sales remained virtually unchanged, commercial and industrial sales increased over two percent during 1994. Partially offsetting these increases was a 21 percent decrease in wholesale and interchange sales as a result of higher than normal sales in 1993 to other utilities while their generating units were down due to the flooding of 1993.
1993 Compared to 1992: Total operating revenues increased $62.7 million or 11 percent in 1993 compared to 1992 pro forma revenues. The increase is due to the return of near normal temperatures during 1993 compared to unusually mild winter and summer temperatures in 1992. All customer classes experienced increased sales volumes during 1993. The number of cooling degree days recorded for the city of Wichita were 1,546 for 1993, a 23 percent increase from 1992. Contributing to the increase in wholesale sales were sales to neighboring utilities to meet peak demand periods while those utilities' units were down as a result of the summer flooding.
Partially offsetting these increases in revenues was the amortization of the Merger-related refund.
OPERATING EXPENSES
1994 Compared to 1993: Total operating expenses for 1994 of $470.9 million increased slightly from total operating expenses of $469.6 million for 1993. Federal and state income taxes increased $13.5 million and maintenance expense increased three percent primarily as a result of the major boiler overhaul of the Company's coal fired La Cygne 1 generating station.
The increase in income tax expense was due to the completion at December 31, 1993, of the accelerated amortization of deferred income tax reserves related to the allowance for borrowed funds used during construction capitalized for Wolf Creek. The completion of the amortization of these deferred income tax reserves increased income tax expense and thereby reduced net income by approximately $12 million in 1994, and in the future will reduce net income by this same amount each year.
Partially offsetting the increases in total operating expenses were lower fuel costs, due to decreased electric generation during 1994, and lower other operations expense.
1993 Compared to 1992: Total operating expenses increased $45.5 million or 11 percent in 1993 compared to 1992. Fuel and purchased power expenses increased $21.4 million or 23 percent primarily due to increased generation resulting from increased customer demand for electricity during the summer peak season. Federal and state income taxes increased $28.6 million primarily as a result of higher net income. General taxes increased $4.8 million primarily due to an increase in plant, the property tax assessment ratio, and higher mill levies.
Partially offsetting these increases in total operating expenses was a decrease in other operations expense of $10.1 million primarily as a result of merger-related savings for the entire year of 1993 and reduced net lease expense for La Cygne 2 resulting from refinancing of the secured facility bonds (see Note 7) compared to pro forma operating expenses of 1992.
OTHER INCOME AND DEDUCTIONS: Other income and deductions, net of taxes, decreased significantly in 1994 compared to 1993 primarily as a result of increased interest expense on higher COLI borrowings. Interest on COLI borrowings increased $9.1 million in 1994 compared to 1993. Also contributing to the decrease was the receipt of death benefit proceeds from COLI policies in the third quarter of 1993.
Other income and deductions, net of taxes, increased slightly in 1993 compared to 1992 due to the increased cash surrender values of COLI policies and the receipt of death benefit proceeds. Partially offsetting these increases was higher interest expense on COLI borrowings.
INTEREST CHARGES: Interest charges decreased 12 percent in 1994 compared to 1993 primarily as a result of the refinancing of higher cost fixed-rate debt. Also accounting for the decrease was the impact of increased COLI borrowings which reduce the need for other long-term debt and thereby reduced interest expense. COLI interest is reflected in Other Income and Deductions on the Income Statement. The Company's embedded cost of long-term debt decreased to 7.3% at December 31, 1994 compared to 7.7% and 7.8% at December 31, 1993 and 1992, respectively.
Interest charges decreased $12.4 million in 1993 compared to 1992 as the Company continued to take advantage of lower interest rates on variable-rate and fixed-rate debt by retiring and refinancing higher cost debt.
MERGER IMPLEMENTATION: In accordance with the KCC Merger order, amortization of the acquisition adjustment will commence August 1995. The amortization will amount to approximately $20 million (pre-tax) per year for 40 years. Western Resources and the Company (combined companies) can recover the amortization of the acquisition adjustment through cost savings under a sharing mechanism approved by the KCC as described in Note 1 of the Notes to the Financial Statements. While the combined companies have achieved savings from the Merger, there is no assurance that the savings achieved will be sufficient to, or the cost savings sharing mechanism will operate as to, fully offset the amortization of the acquisition adjustment.
OTHER INFORMATION
INFLATION: Under the ratemaking procedures prescribed by the regulatory commissions to which the Company is subject, only the original cost of plant is recoverable in revenues as depreciation. Therefore, because of inflation, present and future depreciation provisions are inadequate for purposes of maintaining the purchasing power invested by common shareholders and the related cash flows are inadequate for replacing property. The impact of this ratemaking process on common shareholders is mitigated to the extent depreciable property is financed with debt that can be repaid with dollars of less purchasing power. While the Company has experienced relatively low inflation in the recent past, the cumulative effect of inflation on operating costs may require the Company to seek regulatory rate relief to recover these higher costs.
ENVIRONMENTAL: The Company has taken a proactive position with respect to the potential environmental liability associated with former manufactured gas sites and has an agreement with the Kansas Department of Health and Environment (KDHE) to systematically evaluate these sites (see Note 3).
Although the Company currently has no Phase I affected units under the Clean Air Act of 1990, the Company has applied for an early substitution permit to bring the co-owned La Cygne Station under the Phase I guidelines. The oxides of nitrogen (NOx) and air toxic limits, which were not set in law, will be specified in future Environmental Protection Agency (EPA) regulations. The EPA's proposed NOx regulations were ruled invalid by the U.S. Court of Appeals for the District of Columbia Circuit in November 1994, and until such time as the EPA resubmits new proposed regulations, the Company will be unable to determine its compliance options or related compliance costs (see Note 3).
COMPETITION: As a regulated utility, the Company currently has limited direct competition for retail electric service in its certified service area. However, there is competition, based largely on price, from the generation, or potential generation, of electricity by large commercial and industrial customers, and independent power producers.
The 1992 Energy Policy Act (Act) requires increased efficiency of energy usage and has effected the way electricity is marketed. The Act also provides for increased competition in the wholesale electric market by permitting the FERC to order third party access to utilities' transmission systems and by liberalizing the rules for ownership of generating facilities. As part of the Merger, the Company agreed to open access of its transmission system for wholesale transactions. During 1994, wholesale revenues represented less than seven percent of the Company's total revenues.
Operating in this competitive environment could place pressure on utility profit margins and credit quality. Wholesale and industrial customers may threaten to pursue cogeneration, self-generation, retail wheeling, municipalization or relocation to other service territories in an attempt to obtain reduced energy costs. Increasing competition has resulted in credit rating agencies applying more stringent guidelines when making utility credit rating determinations.
The Company is providing reduced electric rates for industrial expansion projects and economic development projects in an effort to maintain and increase electric load. In 1994, The Boeing Company announced it would develop its 777 jetliner in Wichita and Cessna Aircraft Company announced it would build a production plant in Independence, Kansas along with expanding its Wichita facilities, with an addition of 2,000 jobs.
In order to retain its current electric load, the Company has and will continue to negotiate with some of its larger industrial customers, who are able to develop cogeneration facilities, for long term contracts although some negotiated rates may result in reduced margins for the Company. During 1996, the Company will lose a major industrial customer to cogeneration resulting in a reduction to pre-tax earnings of approximately $7 to $8 million. This customer's decision to develop its own cogeneration project was based partially on factors other than energy cost.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
TABLE OF CONTENTS PAGE
Report of Independent Public Accountants 21
Financial Statements:
Balance Sheets, December 31, 1994 and 1993 23 Statements of Income for the year ended December 31, 1994 24 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Cash Flows for the years ended December 31, 1994 25 and 1993 (Successor), the period March 31 to December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Taxes for the years ended December 31, 1994 26 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Capitalization, December 31, 1994 and 1993 27 Statements of Common Stock Equity for the years ended 28 December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Notes to Financial Statements 29
SCHEDULES OMITTED
The following schedules are omitted because of the absence of the conditions under which they are required or the information is included in the financial statements and schedules presented:
I, II, III, IV, and V.
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors of Kansas Gas and Electric Company:
We have audited the accompanying balance sheets and statements of capitalization of Kansas Gas and Electric Company (a wholly-owned subsidiary of Western Resources, Inc.) as of December 31, 1994 and 1993, and the related statements of income, cash flows, taxes, and common stock equity for the years then ended. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audits to obtain reasonable assurance whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Kansas Gas and Electric Company as of December 31, 1994 and 1993, and the results of its operations and its cash flows for the years then ended in conformity with generally accepted accounting principles.
As explained in Note 8 to the financial statements, effective January 1, 1993, the Company changed its method of accounting for postretirement benefits.
ARTHUR ANDERSEN LLP
Kansas City, Missouri, January 25, 1995
INDEPENDENT AUDITORS' REPORT
Kansas Gas and Electric Company:
We have audited the 1992 financial statements of Kansas Gas and Electric Company (a wholly-owned subsidiary of Western Resources, Inc.) listed in the accompanying table of contents. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
In our opinion, such financial statements present fairly, in all material respects, the results of the Company's operations and its cash flows for the periods indicated in conformity with generally accepted accounting principles.
DELOITTE & TOUCHE LLP
Kansas City, Missouri January 29, 1993
KANSAS GAS AND ELECTRIC COMPANY NOTES TO FINANCIAL STATEMENTS
1. ACQUISITION AND MERGER
On March 31, 1992, Western Resources, Inc. (formerly The Kansas Power and Light Company) (Western Resources) through its wholly-owned subsidiary KCA Corporation (KCA), acquired all of the outstanding common and preferred stock of Kansas Gas and Electric Company (KG&E) for $454 million in cash and 23,479,380 shares of Western Resources common stock (the Merger). Western Resources also paid $20 million in costs to complete the Merger. The total cost of the acquisition to Western Resources was $1.066 billion. Simultaneously, KCA and KG&E merged and adopted the name of Kansas Gas and Electric Company. The Merger was accounted for as a purchase. For income tax purposes the tax basis of the Company's assets was not changed by the Merger. In the accompanying statements, KG&E prior to the Merger is labeled as the "Predecessor" and after the Merger as the "Successor". Throughout the notes to financial statements, the "Company, KG&E" refers to both Predecessor and Successor.
As Western Resources acquired 100% of the common and preferred stock of KG&E, the Company recorded an acquisition premium of $490 million on the balance sheet for the difference in purchase price and book value and increased common stock equity to reflect the new cost basis of Western Resources' investment in the Company. This acquisition premium and related income tax requirement of $311 million under Statement of Financial Accounting Standards No. 109 (SFAS 109) have been classified as plant acquisition adjustment in electric plant in service on the balance sheets. Under the provisions of the order of the Kansas Corporation Commission (KCC), the acquisition premium is recorded as an acquisition adjustment and not allocated to the other assets and liabilities of the Company.
The pro forma information for the year ended December 31, 1992 in the accompanying financial statements gives effect to the Merger as if it occurred on January 1, 1992, and was derived by combining the historical information for the three month period ended March 31, 1992 and the nine month period ended December 31, 1992. No purchase accounting adjustments were made for periods prior to the Merger in determining pro forma amounts, other than the elimination of preferred dividends, because such adjustments would be immaterial. This pro forma information is not necessarily indicative of the results of operations that would have occurred had the Merger been consummated on January 1, 1992, nor is it necessarily indicative of future operating results or financial position.
In the November 1991 KCC order approving the Merger, a mechanism was approved to share equally between the shareholders and ratepayers the cost savings generated by the Merger in excess of the revenue requirement needed to allow recovery of the amortization of a portion of the acquisition adjustment, including income tax, calculated on the basis of a purchase price of KG&E's common stock at $29.50 per share. The order provides an amortization period for the acquisition adjustment of 40 years commencing in August 1995, at which time the full amount of cost savings is expected to have been implemented. Merger savings will be measured by application of an inflation index to certain pre-merger operating and maintenance costs at the time of the next Kansas rate case. While Western Resources and the Company (combined companies) have achieved savings from the Merger, there is no assurance that the savings achieved will be sufficient to, or the cost savings sharing
mechanism will operate as to fully offset the amortization of the acquisition adjustment. The order further provides a moratorium on increases, with certain exceptions, in the Company's Kansas electric rates until August 1995. The KCC ordered refunds totalling $32 million to the combined companies' customers to share with customers the Merger-related cost savings achieved during the moratorium period. Refunds of approximately $4.9 (Company's share) million for the Company were made in April 1992 and December 1993 and the remaining refund of approximately $8.7 (Company's share )million was made in September 1994.
The KCC order approving the Merger required the legal reorganization of the Company so that it was no longer held as a separate subsidiary after January 1, 1995, unless good cause was shown why such separate existence should be maintained. The Securities and Exchange Commission order relating to the Merger granted Western Resources an exemption under the Public Utility Holding Company Act (PUHCA) until January 1, 1995. Western Resources has been granted regulatory approval from the KCC which eliminates the requirement for a combination. As a result of the sales of Western Resources' Missouri Properties, Western Resources is now exempt from regulation as a holding company under Section 3(a)(1) of the PUHCA.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
General: The financial statements of KG&E include, through March 31, 1992, its 80% owned subsidiary, CIC Systems, Inc. (CIC). In April 1992, the Company disposed of its 80% interest in CIC. KG&E owns 47 percent of Wolf Creek Nuclear Operating Corporation (WCNOC), the operating company for Wolf Creek Generating Station (Wolf Creek). The Company records its proportionate share of all transactions of WCNOC as it does other jointly-owned facilities. The accounting policies of the Company are in accordance with generally accepted accounting principles as applied to regulated public utilities. The accounting and rates of the Company are subject to requirements of the KCC and the Federal Energy Regulatory Commission (FERC).
Utility Plant: Utility plant (including plant acquisition adjustment) is stated at cost. For constructed plant, cost includes contracted services, direct labor and materials, indirect charges for engineering, supervision, general and administrative costs, and an allowance for funds used during construction (AFUDC). The AFUDC rate was 4.07% for 1994, 4.41% for 1993, 6.51% for the nine months ended December 31, 1992, and 6.70% for the three months ended March 31, 1992. The cost of additions to utility plant and replacement units of property is capitalized. Maintenance costs and replacement of minor items of property are charged to expense as incurred. When units of depreciable property are retired, they are removed from the plant accounts and the original cost plus removal charges less salvage are charged to accumulated depreciation.
Depreciation: Depreciation is provided on the straight-line method based on estimated useful lives of property. Composite provisions for book depreciation approximated 2.7% during 1994, 2.9% during 1993, 2.9% during the nine months ended December 31, 1992, and 3.0% during the three months ended March 31, 1992 of the average original cost of depreciable property.
Cash and Cash Equivalents: For purposes of the Statements of Cash Flows, cash and cash equivalents include cash on hand and highly liquid collateralized debt instruments purchased with maturities of three months or less.
Income Taxes: Income tax expense includes provisions for income taxes currently payable and deferred income taxes calculated in conformance with income tax laws, regulatory orders and Statement of Financial Accounting Standards No. 109 (SFAS 109) (see Note 9).
Investment tax credits previously deferred are being amortized to income over the life of the property which gave rise to the credits.
Revenues: Operating revenues include amounts actually billed for services rendered and an accrual of estimated unbilled revenues. Unbilled revenues represent the estimated amount customers will be billed for service provided from the time meters were last read to the end of the accounting period. Unbilled revenues of $21.4 and $22.3 million at December 31, 1994 and 1993, respectively, are recorded as a component of accounts receivable on the balance sheets. At December 31, 1993, certain amounts of unbilled revenues were sold (see Note 6).
The Company had reserves for doubtful accounts receivable of $1.9 and $3.0 million at December 31, 1994 and 1993, respectively.
Fuel Costs: The cost of nuclear fuel in process of refinement, conversion, enrichment, and fabrication is recorded as an asset at original cost and is amortized to expense based upon the quantity of heat produced for the generation of electricity. The accumulated amortization of nuclear fuel in the reactor at December 31, 1994 and 1993, was $13.6 and $17.4 million, respectively.
Cash Surrender Value of Life Insurance Contracts: The following amounts related to corporate-owned life insurance contracts (COLI), primarily with one highly rated major insurance company, are recorded on the balance sheets:
1994 1993 (Dollars in Millions) Cash surrender value of contracts. . . $320.6 $269.0 Borrowings against contracts . . . . . 311.2 (269.0) ------ ------ COLI (net) . . . . . . . . . . . . $ 9.4 $ 0.0 ====== ====== The COLI borrowings will be repaid upon receipt of proceeds from death benefits under contracts. The Company recognizes increases in the cash surrender value of contracts, resulting from premiums and investment earnings on a tax free basis, and the tax deductible interest on the COLI borrowings in Corporate-owned Life Insurance (net) on the Statements of Income. Interest expense included in corporate-owned life insurance (net) on the statements of income was $21.0 million for 1994, $11.9 million for 1993, $5.3 million for the nine months ended December 31, 1992, and $1.9 million for the three months ended March 31, 1992.
Reclassifications: Certain amounts in prior years have been reclassified to conform with classifications used in the current year presentation.
3. COMMITMENTS AND CONTINGENCIES
Manufactured Gas Sites: The Company was previously associated with six former manufactured gas sites which contain coal tar and other potentially harmful materials. The Company and the Kansas Department of Health and Environment (KDHE) conducted preliminary assessments of these sites at minimal cost. The results of the preliminary investigations determined the Company does not have a connection to two of the sites.
The Company and KDHE entered into a consent agreement governing all future work at the four remaining sites. The terms of the consent agreement will allow the Company to investigate these sites and set remediation priorities based upon the results of the investigations and risk analysis. The prioritized sites will be investigated over a 10 year period. The agreement will allow the Company to set mutual objectives with the KDHE in order to expedite effective response activities and to control costs and environmental impact. The Company is aware of other utilities in Region VII of the EPA (Kansas, Missouri, Nebraska, and Iowa) which have incurred remediation costs for such sites ranging between $500,000 and $10 million, depending on the site and that the KCC has permitted another Kansas utility to recover its remediation costs through rates. To the extent that such remediation costs are not recovered through rates, the costs could be material to the Company's financial position or results of operations depending on the degree of remediation and number of years over which the remediation must be completed.
Spent Nuclear Fuel Disposal: Under the Nuclear Waste Policy Act of 1982, the U.S. Department of Energy (DOE) is responsible for the ultimate storage and disposal of spent nuclear fuel removed from nuclear reactors. Under a contract with the DOE for disposal of spent nuclear fuel, the Company pays a quarterly fee to DOE of one mill per kilowatthour on net nuclear generation. These fees are included as part of nuclear fuel expense and amounted to $3.8 million for 1994, $3.5 million for 1993, $1.6 million for the nine months ended December 31, 1992, and $.5 million for the three months ended March 31, 1992.
The Company along with the other co-owners of Wolf Creek are among 14 companies that filed a lawsuit on June 20, 1994, seeking an interpretation of the DOE's obligation to begin accepting spent nuclear fuel for disposal in 1998. The Federal Nuclear Waste Policy Act requires DOE ultimately to accept and dispose of nuclear utilities' spent fuel. The DOE has filed a motion to have this case dismissed. The issue to be decided in this case is whether DOE must begin accepting spent fuel in 1998 or at a future date. Wolf Creek contains an on-site spent fuel storage facility which, under current regulatory guidelines, provides space for the storage of spent fuel through the year 2006 while still maintaining full core off-load capability. The Company believes adequate additional storage space can be obtained as necessary.
Decommissioning: On June 9, 1994, the KCC issued an order approving the decommissioning costs of the 1993 Wolf Creek Decommissioning Cost Study which estimates the Company's share of Wolf Creek decommissioning costs, under the immediate dismantlement method, to be approximately $595 million primarily during the period from 2025 through 2033, or approximately $174 million in 1993 dollars. These costs were calculated using an assumed inflation rate of 3.45% over the remaining service life, in 1993, of 32 years.
Decommissioning costs are being charged to operating expenses in accordance with the KCC order. Electric rates charged to customers provide for recovery of these decommissioning costs over the life of Wolf Creek. Amounts so expensed ($3.5 million in 1994 increasing annually to $5.5 million in 2024) and earnings on trust fund assets are deposited in an external trust fund. The assumed return on trust assets is 5.9%.
The Company's investment in the decommissioning fund, including reinvested earnings was $16.9 million and $13.2 million at December 31, 1994 and December 31, 1993, respectively. These amounts are reflected in Decommissioning Trust, and the related liability is included in Deferred Credits and Other Liabilities, Other, on the Balance Sheets.
The Company carries $118 million in premature decommissioning insurance. The insurance coverage has several restrictions. One of these is that it can only be used if Wolf Creek incurs an accident exceeding $500 million in expenses to safely stabilize the reactor, to decontaminate the reactor and reactor station site in accordance with a plan approved by the Nuclear Regulatory Commission (NRC), and to pay for on-site property damages. If the amount designated as decommissioning insurance is needed to implement the NRC-approved plan for stabilization and decontamination, it would not be available for decommissioning purposes.
Nuclear Insurance: The Price-Anderson Act limits the combined public liability of the owners of nuclear power plants to $8.9 billion for a single nuclear incident. The Wolf Creek owners (Owners) have purchased the maximum available private insurance of $200 million and the balance is provided by an assessment plan mandated by the NRC. Under this plan, the Owners are jointly and severally subject to a retrospective assessment of up to $79.3 million ($37.3 million, Company's share) in the event there is a major nuclear incident involving any of the nation's licensed reactors. This assessment is subject to an inflation adjustment based on the Consumer Price Index and applicable premium taxes. There is a limitation of $10 million ($4.7 million, Company's share) in retrospective assessments per incident per year.
The Owners carry decontamination liability, premature decommissioning liability, and property damage insurance for Wolf Creek totalling approximately $2.8 billion ($1.3 billion, Company's share). This insurance is provided by a combination of "nuclear insurance pools" ($500 million) and Nuclear Electric Insurance Limited (NEIL) ($2.3 billion). In the event of an accident, insurance proceeds must first be used for reactor stabilization and site decontamination. The Company's share of any remaining proceeds can be used for property damage up to $1.2 billion (Company's share) and premature decommissioning costs up to $118 million (Company's share) in excess of funds previously collected for decommissioning (as discussed under "Decommissioning").
The Owners also carry additional insurance with NEIL to cover costs of replacement power and other extra expenses incurred during a prolonged outage resulting from accidental property damage at Wolf Creek. If losses incurred at any of the nuclear plants insured under the NEIL policies exceed premiums, reserves, and other NEIL resources, the Company may be subject to retrospective assessments of approximately $13 million per year.
Although the Company maintains various insurance policies to provide coverage for potential losses or liabilities resulting from an accident or extended outage, the Company's insurance coverage may not be adequate to cover the costs that could result from a major accident or extended outage at Wolf Creek. Any substantial losses not covered by insurance, to the extent not recoverable through rates, would have a material adverse effect on the Company's financial position and results of operations.
Clean Air Act: The Clean Air Act Amendments of 1990 (the Act) require a two-phase reduction in sulfur dioxide and oxides of nitrogen (NOx) emissions effective in 1995 and 2000 and a probable reduction in toxic emissions. To meet the monitoring and reporting requirements under the acid rain program, the Company installed continuous monitoring and reporting equipment at a total cost of approximately $2.3 million. The Company does not expect additional equipment to reduce sulfur emissions to be necessary under Phase II. Although the Company currently has no Phase I affected units, the owners have applied for an early substitution permit to bring the co-owned La Cygne Station under the Phase I regulations.
The NOx and air toxic limits, which were not set in the law, will be specified in future EPA regulations. The EPA's proposed NOx regulations were ruled invalid by the U.S. Court of Appeals for the District of Columbia Circuit in November 1994, and until such time as the EPA resubmits new proposed regulations, the Company will be unable to determine its compliance options or related compliance costs.
Federal Income Taxes: During 1991, the Internal Revenue Service (IRS) completed an examination of the Company's federal income tax returns for the years 1984 through 1988. In April 1992, the Company received the examination report and upon review filed a written protest in August 1992. In October 1993, the Company received another examination report for the years 1989 and 1990 covering the same issues identified in the previous examination report. Upon review of this report, the Company filed a written protest in November 1993. The most significant proposed adjustments reduce the depreciable basis of certain assets and investment tax credits generated. Management believes there are significant questions regarding the theory, computations, and sampling techniques used by the IRS to arrive at its proposed adjustments, and also believes any additional tax expense incurred or loss of investment tax credits will not be material to the Company's financial position and results of operations. Additional income tax payments, if any, are expected to be offset by investment tax credit carryforwards, alternative minimum tax credit carryforwards, or deferred tax provisions.
Fuel Commitments: To supply a portion of the fuel requirements for its generating plants, the Company has entered into various commitments to obtain nuclear fuel, coal, and natural gas. Some of these contracts contain provisions for price escalation and minimum purchase commitments. At December 31, 1994, WCNOC's nuclear fuel commitments (Company's share) were
approximately $12.6 million for uranium concentrates expiring at various times through 1997, $122.9 million for enrichment expiring at various times through 2014, and $56.5 million for fabrication through 2012. At December 31, 1994, the Company's coal and natural gas contract commitments in 1994 dollars under the remaining term of the contracts are $721 million and $9 million, respectively. The largest coal contract was renegotiated in early 1993 and expires in 2020 with the remaining coal contracts expiring at various times through 2013. The majority of natural gas contracts expire in 1995 with automatic one-year extension provisions. In the normal course of business, additional commitments and spot market purchases will be made to obtain adequate fuel supplies.
Energy Act: As part of the 1992 Energy Policy Act, a special assessment is being collected from utilities for a uranium enrichment decontamination and decommissioning fund. The Company's portion of the assessment for Wolf Creek is approximately $7 million, payable over 15 years. Management expects such costs to be recovered through the ratemaking process.
4. RATE MATTERS AND REGULATION
Elimination of the Energy Cost Adjustment Clause (ECA): On March 26, 1992, in connection with the Merger, the KCC approved the elimination of the ECA for most retail customers effective April 1, 1992. The provisions for fuel costs included in base rates were established at a level intended by the KCC to equal the projected average cost of fuel through August 1995, and to include recovery of costs provided by previously issued orders relating to coal contract settlements and storm damage recovery discussed below. Any increase or decrease in fuel costs from the projected average will impact the Company's earnings.
Rate Stabilization Plan: In 1988, the KCC issued an order requiring that the accrual of phase-in revenues be discontinued effective December 31, 1988. Effective January 1, 1989, the Company began amortizing the phase-in revenue asset on a straight-line basis over 9-1/2 years. At December 31, 1994 approximately $61 million of deferred phase-in revenues remained on the Balance Sheet.
Coal Contract Settlements: In March 1990, the KCC issued an order allowing the Company to defer its share of a 1989 coal contract settlement with the Pittsburg and Midway Coal Mining Company amounting to $22.5 million. This amount was recorded as a deferred charge on the balance sheets. The settlement resulted in the termination of a long-term coal contract. The KCC permitted the Company to recover this settlement as follows: 76% of the settlement plus a return over the remaining term of the terminated contract (through 2002) and 24% to be amortized to expense with a deferred return equivalent to the carrying cost of the asset. Approximately $18 million of this deferral remains on the balance sheet at December 31, 1994.
In February 1991, the Company paid $8.5 million to settle a coal contract lawsuit with AMAX Coal Company and recorded the payment as a deferred charge on the Company's Balance Sheet. In July 1991, the KCC approved the recovery of the settlement plus a return equivalent to the carrying cost of the asset, over the remaining term of the terminated contract (through 1996).
5. SHORT-TERM BORROWINGS
The Company's short-term financing requirements are satisfied through short-term bank loans and uncommitted loan participation agreements. Maximum short-term borrowings outstanding during 1994 and 1993 were $172.3 million on January 4, 1994 and $175.8 million on December 14, 1993. The weighted average interest rates, including fees, were 4.5% for 1994, 3.5% for 1993, 6.4% for the nine months ended December 31, 1992, and 7.1% for the three months ended March 31, 1992.
6. LONG-TERM DEBT
The amount of first mortgage bonds authorized by the KG&E Mortgage and Deed of Trust (Mortgage) dated April 1, 1940, as supplemented, is limited to a maximum of $2 billion. Amounts of additional bonds which may be issued are subject to property, earnings, and certain restrictive provisions of the Mortgage. Electric plant is subject to the lien of the Mortgage except for transportation equipment. Debt discount and expenses are being amortized over the remaining lives of each issue. The improvement and maintenance fund requirements for certain first mortgage bond series can be met by bonding additional property. The sinking fund requirements for certain pollution control series bonds can be met only through the acquisition and retirement of outstanding bonds.
On November 1, 1994, the Company terminated a long-term agreement which contained provisions for the sale of accounts receivable and unbilled revenues (receivables) and phase-in revenues up to a total of $180 million. Amounts related to receivables were accounted for as sales while those related to phase-in revenues were accounted for as collateralized borrowings. At December 31, 1993, outstanding receivables amounting to $56.8 million, were considered sold under the agreement. The weighted average interest rate, including fees, on this agreement was 4.6% for 1994, 3.7% for 1993, 6.6% for the nine months ended December 31, 1992, and 7.9% for the three months ended March 31, 1992.
7. SALE-LEASEBACK OF LA CYGNE 2
In 1987, the Company sold and leased back its 50 percent undivided interest in the La Cygne 2 generating unit. The lease has an initial term of 29 years, with various options to renew the lease or repurchase the 50 percent undivided interest. The Company remains responsible for its share of operation and maintenance costs and other related operating costs of La Cygne 2. The lease is an operating lease for financial reporting purposes.
As permitted under the lease agreement, the Company in 1992 requested the Trustee Lessor to refinance $341.1 million of secured facility bonds of the Trustee and owner of La Cygne 2. The transaction was requested to reduce recurring future net lease expense. In connection with the refinancing on September 29, 1992, a one-time payment of approximately $27 million was made by the Company which has been deferred and is being amortized over the remaining life of the lease and included in operating expense as part of the future lease expense. At December 31, 1994, approximately $24.8 million of this deferral remained on the Balance Sheet.
Future minimum annual lease payments required under the lease agreement are approximately $34.6 million for each year through 1999 and $680 million over the remainder of the lease.
The gain of approximately $322 million realized at the date of the sale has been deferred for financial reporting purposes, and is being amortized over the initial lease term in proportion to the related lease expense. The Company's lease expense, net of amortization of the deferred gain and a one- time payment, was approximately $22.5 million for 1994 and 1993, $20.6 million for the nine months ended December 31, 1992, and $7.5 million for the three months ended March 31, 1992.
8. EMPLOYEE BENEFIT PLANS
Pension: The Company maintains noncontributory defined benefit pension plans covering substantially all employees of the Company prior to the Merger. Pension benefits are based on years of service and the employee's compensation during the five highest paid consecutive years out of ten before retirement. The Company's policy is to fund pension costs accrued, subject to limitations set by the Employee Retirement Income Security Act of 1974 and the Internal Revenue Code.
The following table provides information on the components of pension cost for the Company's pension plans (dollars in millions):
April 1 | Jan.1 to 1994 1993 to Dec.31 | March 31 (Successor)|(Predecessor) Pension Cost: | Service cost . . . . . . . . . . $ 3.7 $ 3.2 $ 2.5 | $ .8 Interest cost on projected | benefit obligation . . . . . . 9.7 9.5 6.7 | 2.1 (Gain) loss on plan assets . . . 2.1 (14.1) (5.8) | (9.0) Net amortization & deferral. . . (11.4) 4.9 (1.0) | 6.7 ------ ------ ------ | ------ Net pension cost . . . . . . . $ 4.1 $ 3.5 $ 2.4 | $ .6 ====== ====== ====== ======
The following table sets forth the plans' actuarial present value and funded status at November 30, 1994 and 1993 (the plan years) and a reconciliation of such status to the December 31, 1994, 1993, and 1992 financial statements (dollars in millions):
1994 1993 1992 Reconciliation of Funded Status: Actuarial present value of benefit obligations: Vested. . . . . . . . . . . . . . . $ 94.0 $ 95.2 $ 82.9 Non-vested. . . . . . . . . . . . . 6.3 6.1 3.6 ------ ------ ------ Total . . . . . . . . . . . . . . $100.3 $101.3 $ 86.5 ====== ====== ====== Plan assets at November 30 (principally debt and equity securities) at fair value . . . . . . . . . . . . . $115.4 $119.9 $113.7 Projected benefit obligation at November 30 . . . . . . . . . . . . (125.4) (125.5) (110.8) ------ ------ ------ Funded status at November 30. . . . . . . (10.0) (5.6) 2.9 Unrecognized transition asset . . . . . . (1.5) (1.7) (2.0) Unrecognized prior service costs. . . . . 9.6 12.4 12.1 Unrecognized net gain . . . . . . . . . . (11.1) (20.6) (26.1) ------ ------ ------- Accrued pension costs at December 31. . . $(13.0) $(15.5) $(13.1) ====== ====== =======
Year Ended December 31, 1994 1993 1992
Actuarial Assumptions: Discount rate . . . . . . . . . . 8.0-8.5 % 7.0-7.75% 8.0-8.5 % Annual salary increase rate . . . 5.0 % 5.0 % 6.0 % Long-term rate of return. . . . . 8.0-8.5 % 8.0-8.5 % 8.0-8.5 %
Retirement and Voluntary Separation Plans: In January 1992, the Board of Directors approved an early retirement plan and a voluntary separation program. The voluntary early retirement plan was offered to all vested participants of the Company's defined benefit pension plan who reached the age of 55 with 10 or more years of service on or before May 1, 1992. Certain pension plan improvements were made including a waiver of the actuarial reduction factors for early retirement and a cash incentive payable as a monthly supplement up to 60 months or a lump sum payment. Of the 111 employees eligible for the early retirement option, 71, representing 6% of the Company's work force, elected to retire on or before the May 1, 1992, deadline. Another 29 employees, with 10 or more years of service, elected to participate in the voluntary separation program. In addition, 61 employees received Merger-related severance benefits. The actuarial cost, based on plan provisions for early retirement and voluntary separation programs, and Merger- related severance benefits, was approximately $3.9 million of which $1.8 million was included in the pension liability at December 31, 1992. The actuarial cost was considered in purchase accounting for the Merger (See Note 1).
Postretirement: Western Resources adopted the provisions of Statement of Financial Accounting Standards No. 106 (SFAS 106) in the first quarter of 1993. This statement requires the accrual of postretirement benefits other than pensions, primarily medical benefits costs, during the years an employee provides service.
Based on actuarial projections and adoption of the transition method of implementation which allows a 20-year amortization of the accumulated benefit obligation, the annual expense to be allocated to the Company under SFAS 106 was approximately $3.8 million in 1994 and $3.4 million in 1993. The Company's total obligation to be allocated from Western Resources was approximately $25.3 million and $23.9 million at December 31, 1994 and 1993, respectively. To mitigate the impact of SFAS 106 expense, Western Resources implemented programs to reduce health care costs. In addition, the KCC issued an order permitting the initial deferral of SFAS 106 expense. To mitigate the impact SFAS 106 expense will have on rate increases, Western Resources will include in the future computation of SFAS 106 expense allocated to the Company for computation of cost of service and expense recognition, the actual SFAS 106 expense and an income stream generated from corporate-owned life insurance policies (COLI) purchased in 1993 and 1992. To the extent SFAS 106 expense exceeds income from the COLI program, this excess will be deferred (as allowed by FASB Emerging Issues Task Force Issue No. 92-12) and offset by income generated through the deferral period by the COLI program. Should the income stream generated by the COLI program not be sufficient to offset the deferred SFAS 106 expense, the KCC order allows recovery of such deficit through the ratemaking process by the Company.
Prior to the adoption of SFAS 106 the Company's policy was to recognize expenses as claims were paid. The costs of benefits were $0.8 million for the nine months ended December 31, 1992 and $0.2 million for the three months ended March 31, 1992.
The following table summarizes the status of the Company's postretirement plans for financial statement purposes and the related amount included in the balance sheet:
December 31, 1994 1993 (Dollars in Millions) Reconciliation of Funded Status: Actuarial present value of postretirement benefit obligations: Retirees. . . . . . . . . . . . . . . . . . . $ 12.9 $ 12.4 Active employees fully eligible . . . . . . . 3.0 2.5 Active employees not fully eligible . . . . . 9.4 9.0 Unrecognized prior service cost . . . . . . . (3.2) (.1) Unrecognized transition obligation. . . . . . (19.3) (20.4) Unrecognized net gain (loss). . . . . . . . . .9 (1.7) ------ ------ Balance sheet liability . . . . . . . . . . . . . $ 3.7 $ 1.7 ====== ======
Year Ended December 31, 1994 1993 Assumptions: Discount rate. . . . . . . . . . . . . . . . . 8.0-8.5 % 7.75% Annual compensation increase rate. . . . . . . 5.0 % 5.0 % Expected rate of return. . . . . . . . . . . . 8.5 % 8.5 %
For measurement purposes, an annual health care cost growth rate of 12% was assumed for 1994, decreasing 1% per year to 5% by 2001 and thereafter. The health care cost trend rate has a significant effect on the projected benefit obligation. Increasing the trend rate by 1% each year would increase the present value of the accumulated projected benefit obligation by $.3 million and the aggregate of the service and interest cost components by $26,000.
Savings Plans: Effective January 1, 1995, the Company's 401(k) savings plans were merged with Western Resources savings plans. Prior to the merger of the savings plans, funds of the plans were deposited with a trustee and invested at each employee's option in one or more investment funds, including a Western Resources common stock fund. The Company's contributions were $1.8 million for 1994, $2.0 million for 1993, $1.7 million for the nine months ended December 31, 1992, and $0.2 million for the three months ended March 31, 1992.
9. INCOME TAXES
The Company adopted Statement of Financial Accounting Standards No. 96 (SFAS 96) in 1987. This statement required the Company to establish deferred tax assets and liabilities, as appropriate, for all temporary differences, and to adjust deferred tax balances to reflect changes in tax rates expected to be in effect during the periods the temporary differences reverse. SFAS 96 was superseded by SFAS 109 issued in February 1992 and the Company adopted the provisions of that standard prospectively in the first quarter of 1992. The accounting for SFAS 109 is substantially the same as SFAS 96.
In accordance with various rate orders received from the KCC, the Company has not yet collected through rates the amounts necessary to pay a significant portion of the net deferred income tax liabilities. As management believes it is probable that the net future increases in income taxes payable will be recovered from customers through future rates, it has recorded a deferred asset for these amounts. These assets are also a temporary difference for which deferred income tax liabilities have been provided. Accordingly, the adoption of SFAS 109 did not have a material effect on the Company's results of operations.
At December 31, 1994, the Company has alternative minimum tax credits generated prior to April 1, 1992, which carryforward without expiration, of $41.2 million which may be used to offset future regular tax to the extent the regular tax exceeds the alternative minimum tax. These credits have been applied in determining the Company's net deferred income tax liability and corresponding deferred future income taxes at December 31, 1994.
Beginning April 1, 1992, the Company is part of the consolidated income tax return of Western Resources. However, the Company determines its income tax provisions on a separate company basis.
Deferred income taxes result from temporary differences between the financial statement and tax basis of the Company's assets and liabilities. The sources of these differences and their cumulative tax effects are as follows: =========== =========== ===========
10. LEGAL PROCEEDINGS
The Company is involved in various legal and environmental proceedings. Management believes that adequate provision has been made within the financial statements for these matters and accordingly believes their ultimate dispositions will not have a material adverse effect upon the financial position or results of operations of the Company.
11. FAIR VALUE OF FINANCIAL INSTRUMENTS
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value as set forth in Statement of Financial Accounting Standards No. 107:
Cash and Cash Equivalents- The carrying amount approximates the fair value because of the short- term maturity of these investments. Decommissioning Trust- The fair value of the decommissioning trust is based on quoted market prices at December 31, 1994 and 1993. Variable-rate Debt- The carrying amount approximates the fair value because of the short- term variable rates of these debt instruments. Fixed-rate Debt- The fair value of the fixed-rate debt is based on the sum of the estimated value of each issue taking into consideration the coupon rate, maturity, and redemption provisions of each issue.
The estimated fair values of the Company's financial instruments are as follows:
13. QUARTERLY FINANCIAL STATISTICS (Unaudited) (Dollars in Thousands)
The amounts in the table are unaudited but, in the opinion of management, contain all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation of the results of such periods. The business of the Company is seasonal in nature and, in the opinion of management, comparisons between the quarters of a year do not give a true indication of overall trends and changes in operations.
14. RELATED PARTY TRANSACTIONS
Subsequent to the Merger, the cash management function, including cash receipts and disbursements, for KG&E has been assumed by Western Resources. As a result, the proceeds of cash collections, including short-term borrowings, less disbursements related to KG&E transactions have been recorded by the Companies through an intercompany account which, at December 31, 1994, resulted in a net advance by KG&E to Western Resources of $64.4 million. Certain of the Company's operating expenses have been allocated from Western Resources. These expenses are allocated, depending on the nature of the expense, based on allocation studies, net investment, number of customers, and/or other appropriate allocators. Management believes such allocation procedures are reasonable. During 1994, the Company declared a dividend to Western Resources of $125 million.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
There were no disagreements with accountants on accounting and financial disclosure. Information relating to a change in accountants is incorporated by reference from the Company's Current Report on Form 8-K dated March 8, 1993.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Western Resources, Inc. owns 100 percent of the Company's outstanding common stock. A Director Business Experience Since 1988 and Other Continuously Name Age Directorships Other Than The Company Since
Kent R. Brown 49 Chairman of the Board (since June 1992), 1992 President and Chief Executive Officer (since March 1992), and prior to that Group Vice President Directorships Bank IV Wichita
Robert T. Crain 69 Owner, Crain Realty, Co., Fort Scott, 1992(b) (a) Kansas Directorships Citizens National Bank Ft. Scott Industries, Inc.
Anderson E. 61 President, Jackson Mortuary, Wichita, 1994 Jackson Kansas
Donald A. 61 President, Maupintour, Inc., Lawrence, 1992(b) Johnston Kansas (Escorted Tours and Travel) (a) Directorships Commerce Bank, Lawrence Maupintour, Inc.
Steven L. 49 Executive Vice President and Chief 1992 Kitchen Financial Officer, Western Resources, Inc.
Glenn L. 69 Retired Vice President - Nuclear of the 1992(b) Koester Company
James J. Noone 74 Attorney and retired Administrative Judge 1992(b) (a) for the District Court of Sedgwick County, Kansas
Marilyn B. 45 President (since October 1993) and prior 1994 Pauly to that Executive Vice President, Bank IV Wichita, Wichita, Kansas Directorships Farmers Mutual Alliance Insurance Company A Director Business Experience Since 1988 and Other Continuously Name Age Directorships Other Than The Company Since
Newton C. Smith 73 Physician and Surgeon, Arkansas City, 1992(b) Kansas
Richard D. Smith 61 President, Range Oil Company 1993 Directorships Bank IV Kansas
(a) Member of the Audit Committee of which Mr. Johnston is Chairman. The Audit Committee has responsibility for the investigation and review of the financial affairs of the Company and its relations with independent accountants. (b) Mr. Crain, Mr. Johnston, Mr. Koester, Mr. Noone, and Mr. Newton Smith were directors of the former Kansas Gas & Electric Company since 1981, 1980, 1986, 1986, and 1985, respectively.
Outside Directors are paid $3,750 per quarter retainer and are paid an attendance fee of $600 for Directors' meetings ($300 if attending by phone). A committee attendance fee of $800 is paid to the outside Director Audit Committee Chairman, and $500 to other outside Committee members. All outside Directors are reimbursed mileage and expenses while attending Directors' and Committee Meetings.
During 1994, the Board of Directors met seven times and the Audit Committee met two times. Each director attended at least 75% of the total number of Board and Committee meetings held while he/she served as a director or a member of the committee, except Mr. Richard D. Smith who attended 71% of such meetings.
Other information required by Item 10 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
ITEM 11. EXECUTIVE COMPENSATION
Information required by Item 11 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Information required by Item 12 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Information required by Item 13 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
The following financial statements are included herein under Item 8.
FINANCIAL STATEMENTS
Balance Sheets, December 31, 1994 and 1993 Statements of Income for the year ended December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Cash Flows for the year ended December 31, 1994 and 1993 (Successor), the period March 31 to December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Taxes for the year ended December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Capitalization, December 31, 1994 and 1993 Statements of Common Stock Equity for the year ended December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Notes to Financial Statements
REPORTS ON FORM 8-K
None
EXHIBIT INDEX
All exhibits marked "I" are incorporated herein by reference.
Description
2(a) Agreement and Plan of Merger (Filed as Exhibit 2 to Form 10-K I for the year ended December 31, 1990, File No. 1-7324)
2(b) Amendment No. 1 to Agreement and Plan of Merger (Filed as I Exhibit 2 to Form 10-K for the year ended December 31, 1990, File No. 1-7324)
3(a) Articles of Incorporation (Filed as Exhibit 3(a) to Form 10-K I for the year ended December 31, 1992, File No. 1-7324)
3(b) Certificate of Merger of Kansas Gas and Electric Company into I KCA Corporation (Filed as Exhibit 3(b) to Form 10-K for the year ended December 31, 1992, File No. 1-7324)
3(c) By-laws as amended (Filed as Exhibit 3(c) to Form 10-K I for the year ended December 31, 1992, File No. 1-7324)
4(c)1 Mortgage and Deed of Trust, dated as of April 1, 1940 to I Guaranty Trust Company of New York (now Morgan Guaranty Trust Company of New York) and Henry A. Theis (to whom W. A. Spooner is successor), Trustees, as supplemented by thirty-eight Supplemental Indentures, dated as of June 1, 1942, March 1, 1948, December 1, 1949, June 1, 1952, October 1, 1953, March 1, 1955, February 1, 1956, January 1, 1961, May 1, 1966, March 1, 1970, May 1, 1971, March 1, 1972, May 31, 1973, July 1, 1975, December 1, 1975, September 1, 1976, March 1, 1977, May 1, 1977, August 1, 1977, March 15, 1978, January 1, 1979, April 1, 1980, July 1, 1980, August 1, 1980, June 1, 1981, December 1, 1981, May 1, 1982, March 15, 1984, September 1, 1984 (Twenty-ninth and Thirtieth), February 1, 1985, April 15, 1986, June 1, 1991 March 31, 1992, December 17, 1992, August 24, 1993, January 15, 1994 and March 1, 1994, (Filed, respectively, as Exhibit A-1 to Form U-1, File No. 70-23; Exhibits 7(b) and 7(c), File No. 2-7405; Exhibit 7(d), File No. 2-8242; Exhibit 4(c), File No. 2-9626; Exhibit 4(c), File No. 2-10465; Exhibit 4(c), File No. 2-12228; Exhibit 4(c), File No. 2-15851; Exhibit 2(b)-1, File No. 2-24680; Exhibit 2(c), File No. 2-36170; Exhibits 2(c) and 2(d), File No. 2-39975; Exhibit 2(d), File No. 2-43053; Exhibit 4(c)2 to Form 10-K, for December 31, 1989, File No. 1-7324; Exhibit 2(c), File No. 2-53765; Exhibit 2(e), File No. 2-55488; Exhibit 2(c), File No. 2-57013; Exhibit 2(c), File No. 2-58180; Exhibit 4(c)3 to Form 10-K for December 31, 1989, File No. 1-7324; Exhibit 2(e), File No. 2-60089; Exhibit 2(c), File No. 2-60777; Exhibit 2(g), File No. 2-64521; Exhibit 2(h), File No. 2-66758; Exhibits 2(d) and 2(e), File No. 2-69620; Exhibits 4(d) and 4(e), File No. 2-75634; Exhibit 4(d), File No. 2-78944; Exhibit 4(d), File No. 2-87532; Exhibits 4(c)4, 4(c)5 and 4(c)6 to Form 10-K for December 31, 1989, File No. 1-7324; Exhibits 4(c)2 and 4(c)3 to Form 10-K for
Description
December 31, 1992, File No. 1-7324; Exhibit 4(b) to Form S-3, File No. 33-50075; Exhibits 4(c)2 and 4(c)3 to Form 10-K for December 31, 1993, File No. 1-7324)
4(c)2 Thirty-ninth Supplemental Indenture dated as of April 15, 1994, to the Company's Mortgage and Deed of Trust (Filed electronically)
Instruments defining the rights of holders of other long-term debt not required to be filed as exhibits will be furnished to the Commission upon request.
10(a)1 Severance Agreement (Filed as Exhibit 10(a)1 to Form 10-K for the I year ended December 31, 1990, File No. 1-7324)
10(a)2 Severance Agreement (Filed as Exhibit 10(a)2 to Form 10-K for the I year ended December 31, 1990, File No. 1-7324)
10(a)3 Severance Agreement (Filed as Exhibit 10(a)3 to Form 10-K for the I year ended December 31, 1990, File No. 1-7324)
10(b) La Cygne 2 Lease (Filed as Exhibit 10(a) to Form 10-K for the year I ended December 31, 1988, File No. 1-7324)
10(b)1 Amendment No. 3 to La Cygne 2 Lease Agreement dated as of September I 29, 1992 (Filed as Exhibit 10(b)1 to Form 10-K for the year ended December 31, 1992, File No. 1-7324)
10(c) Outside Directors' Deferred Compensation Plan (Filed as Exhibit I 10(c) to the Form 10-K for the year ended December 31, 1993, File No. 1-7324)
12 Computation of Ratio of Consolidated Earnings to Fixed Charges. (Filed electronically)
16 Letter re Change in Certifying Accountant (Filed as Exhibit 16 to I the Current Report on Form 8-K dated March 8, 1993)
23(a) Consent of Independent Public Accountants, Arthur Andersen LLP (Filed electronically)
23(b) Consent of Independent Public Accountants, Deloitte & Touche LLP (Filed electronically)
SIGNATURE
Pursuant to the requirements of Sections 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
KANSAS GAS AND ELECTRIC COMPANY
March 29, 1995 By KENT R. BROWN Kent R. Brown, Chairman of the Board, President and Chief Executive Officer


ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
FINANCIAL CONDITION
The results of operations for the years ended December 31, 1994 and 1993, and the nine months ended December 31, 1992, included herein, refer to the Company following the merger with Western Resources, Inc. (formerly The Kansas Power and Light Company) through its wholly-owned subsidiary, KCA Corporation, on March 31, 1992 (the Merger) (see Note 1).
Pro forma results of operations for the twelve months ended December 31, 1992 presented herein, give effect to the Merger as if it occurred on January 1, 1992 and were derived by combining the historical information for the three month period ended March 31, 1992 and the nine month period ended December 31, 1992. Additional information relating to changes between years is provided in the Notes to Financial Statements.
GENERAL: The Company had net income of $104.5 million for 1994 compared to net income of $108.1 million in 1993. The decrease in net income is primarily due to increases in income taxes as a result of the completion of the accelerated amortization of certain deferred income tax reserves and the receipt of death benefit proceeds from corporate-owned life insurance policies in the third quarter of 1993. As of December 31, 1993, the Company had fully amortized the deferred income tax reserves related to the allowance for funds used during construction capitalized for Wolf Creek Generating Station (Wolf Creek). The completion of the amortization of these deferred income tax reserves increased income tax expense and thereby reduced net income by approximately $12 million in 1994, and in the future will reduce net income by this same amount each year.
LIQUIDITY AND CAPITAL RESOURCES: The Company's liquidity is a function of its ongoing construction program, designed to improve facilities which provide electric service and meet future customer service requirements.
During 1994, construction expenditures for the Company's electric system were approximately $69 million and nuclear fuel expenditures were approximately $21 million. It is projected that adequate capacity margins will be maintained through the turn of the century. The construction program is focused on providing service to new customers and improving present electric facilities.
Capital expenditures for 1995 through 1997 are anticipated to be as follows:
Electric Nuclear Fuel (Dollars in Thousands) 1995. . . . . . . . . . $53,961 $ 21,400 1996. . . . . . . . . . 47,388 8,100 1997. . . . . . . . . . 42,453 24,000
These expenditures are estimates prepared for planning purposes and are subject to revisions from time to time.
The Company's net cash flows to capital expenditures exceeded 100 percent for 1994 and during the last five years has also averaged in excess of 100 percent. The Company anticipates all of its cash requirements for capital expenditures through 1997 will be provided from net cash flows. The Company also has $16 million of bonds maturing through 1999 which will be provided from internal and external sources available under then existing financial conditions.
During 1994, the Company continued to take advantage of favorable long- term interest rates by refinancing long-term debt issues. The embedded cost of long-term debt was 7.3% at December 31, 1994, a decrease from 7.7% at December 31, 1993.
On January 20, 1994, the Company issued $100 million of First Mortgage Bonds, 6.20% Series due January 15, 2006. The net proceeds were used to reduce short-term debt.
On February, 17, 1994, the Company refinanced the City of La Cygne, Kansas, 5 3/4% Pollution Control Revenue Refunding Bonds Series 1973, $13,980,000 principal amount, with 5.10% Pollution Control Revenue Refunding Bonds Series 1994, $13,982,500 principal amount, due 2023.
On April 28, 1994, three series of Market-Adjusted Tax Exempt Securities totalling $46.4 million were sold on behalf of the Company at a rate of 2.95% for the initial auction period. The interest rates are being reset periodically via an auction process. As of December 31, 1994, the rate on these bonds was 4.10%. The net proceeds from the new issues, together with available cash, were used to refund three series of Pollution Control Bonds totalling $46.4 million bearing interest rates between 5 7/8% and 6.8%.
On November 1, 1994, the Company terminated a long-term agreement which contained provisions for the sale of accounts receivable and unbilled revenues, and phase-in revenues (see Note 6).
In 1986, the Company purchased corporate-owned life insurance policies (COLI) on certain of its employees. The annual cash outflow for the premiums on these policies from 1992 through 1994 was approximately $27 million. See Note 2 of the Notes to Financial Statements for additional information on the accumulated cash surrender value. The borrowings are expected to produce annual cash inflows, net of expenses, through the remaining life of the policies. Borrowings against the policies will be repaid from death proceeds.
The Company's short-term financing requirements are satisfied, as needed, through short-term bank loans and borrowings under other unsecured lines of credit maintained with banks. At December 31, 1994, short-term borrowings amounted to $50 million compared to $155.8 million at December 31, 1993. The decrease is primarily the result of the issuance of the $100 million of bonds on January 20, 1994 (see Note 5).
The KG&E common and preferred stock was redeemed in connection with the Merger, leaving 1,000 shares of common stock held by Western Resources. The debt structure of the Company and available sources of funds were not affected by the Merger.
The Company's capital structure at December 31, 1994, was 64 percent common stock equity and 36 percent long-term debt. The capital structure at December 31, 1994, including short-term debt was 62 percent common stock equity and 38 percent debt. As of December 31, 1994, the Company's bonds were rated "A3" by Moody's Investors Service, "A-" by Standard & Poor's Ratings Group, and "A-" by Fitch Investors Service.
RESULTS OF OPERATIONS
The following is an explanation of significant variations from prior year results in revenues, operating expenses, other income and deductions, and interest charges. Additional information relating to changes between years is provided in the Notes to Financial Statements.
REVENUES
The operating revenues of the Company are based on sales volumes and rates authorized by the Kansas Corporation Commission (KCC) and the Federal Energy Regulatory Commission (FERC). Rates charged for the sale and delivery of electricity are designed to recover the cost of service and allow investors a fair rate of return. Future electric sales will continue to be affected by weather conditions, competition from other generating sources, competing fuel sources, customer conservation efforts and the overall economy of the Company's service area.
The KCC order approving the Merger provided a moratorium on increases, with certain exceptions, in the Company's electric rates until August 1995. The KCC ordered refunds totalling $32 million to the combined companies' (Western Resources and the Company) customers to share with customers the Merger-related cost savings achieved during the moratorium period. Refunds of approximately $4.9 (Company's portion) million were made in April 1992 and December 1993 and the remaining refund of approximately $8.7 million (Company's portion) was made in September 1994 (see Note 1).
On March 26, 1992, in connection with the Merger, the KCC approved the elimination of the Energy Cost Adjustment Clause (ECA) for most retail customers of the Company effective April 1, 1992. The fuel costs are now included in base rates and were established at a level intended by the KCC to equal the projected average cost of fuel through August 1995. Any increase or decrease in fuel costs from the projected average will impact the Company's earnings.
1994 Compared to 1993: Total operating revenues for 1994 of $619.9 million increased less than one percent from revenues of $617.0 million for 1993. The increase can be attributed to higher revenues in all retail customer classes. While residential sales remained virtually unchanged, commercial and industrial sales increased over two percent during 1994. Partially offsetting these increases was a 21 percent decrease in wholesale and interchange sales as a result of higher than normal sales in 1993 to other utilities while their generating units were down due to the flooding of 1993.
1993 Compared to 1992: Total operating revenues increased $62.7 million or 11 percent in 1993 compared to 1992 pro forma revenues. The increase is due to the return of near normal temperatures during 1993 compared to unusually mild winter and summer temperatures in 1992. All customer classes experienced increased sales volumes during 1993. The number of cooling degree days recorded for the city of Wichita were 1,546 for 1993, a 23 percent increase from 1992. Contributing to the increase in wholesale sales were sales to neighboring utilities to meet peak demand periods while those utilities' units were down as a result of the summer flooding.
Partially offsetting these increases in revenues was the amortization of the Merger-related refund.
OPERATING EXPENSES
1994 Compared to 1993: Total operating expenses for 1994 of $470.9 million increased slightly from total operating expenses of $469.6 million for 1993. Federal and state income taxes increased $13.5 million and maintenance expense increased three percent primarily as a result of the major boiler overhaul of the Company's coal fired La Cygne 1 generating station.
The increase in income tax expense was due to the completion at December 31, 1993, of the accelerated amortization of deferred income tax reserves related to the allowance for borrowed funds used during construction capitalized for Wolf Creek. The completion of the amortization of these deferred income tax reserves increased income tax expense and thereby reduced net income by approximately $12 million in 1994, and in the future will reduce net income by this same amount each year.
Partially offsetting the increases in total operating expenses were lower fuel costs, due to decreased electric generation during 1994, and lower other operations expense.
1993 Compared to 1992: Total operating expenses increased $45.5 million or 11 percent in 1993 compared to 1992. Fuel and purchased power expenses increased $21.4 million or 23 percent primarily due to increased generation resulting from increased customer demand for electricity during the summer peak season. Federal and state income taxes increased $28.6 million primarily as a result of higher net income. General taxes increased $4.8 million primarily due to an increase in plant, the property tax assessment ratio, and higher mill levies.
Partially offsetting these increases in total operating expenses was a decrease in other operations expense of $10.1 million primarily as a result of merger-related savings for the entire year of 1993 and reduced net lease expense for La Cygne 2 resulting from refinancing of the secured facility bonds (see Note 7) compared to pro forma operating expenses of 1992.
OTHER INCOME AND DEDUCTIONS: Other income and deductions, net of taxes, decreased significantly in 1994 compared to 1993 primarily as a result of increased interest expense on higher COLI borrowings. Interest on COLI borrowings increased $9.1 million in 1994 compared to 1993. Also contributing to the decrease was the receipt of death benefit proceeds from COLI policies in the third quarter of 1993.
Other income and deductions, net of taxes, increased slightly in 1993 compared to 1992 due to the increased cash surrender values of COLI policies and the receipt of death benefit proceeds. Partially offsetting these increases was higher interest expense on COLI borrowings.
INTEREST CHARGES: Interest charges decreased 12 percent in 1994 compared to 1993 primarily as a result of the refinancing of higher cost fixed-rate debt. Also accounting for the decrease was the impact of increased COLI borrowings which reduce the need for other long-term debt and thereby reduced interest expense. COLI interest is reflected in Other Income and Deductions on the Income Statement. The Company's embedded cost of long-term debt decreased to 7.3% at December 31, 1994 compared to 7.7% and 7.8% at December 31, 1993 and 1992, respectively.
Interest charges decreased $12.4 million in 1993 compared to 1992 as the Company continued to take advantage of lower interest rates on variable-rate and fixed-rate debt by retiring and refinancing higher cost debt.
MERGER IMPLEMENTATION: In accordance with the KCC Merger order, amortization of the acquisition adjustment will commence August 1995. The amortization will amount to approximately $20 million (pre-tax) per year for 40 years. Western Resources and the Company (combined companies) can recover the amortization of the acquisition adjustment through cost savings under a sharing mechanism approved by the KCC as described in Note 1 of the Notes to the Financial Statements. While the combined companies have achieved savings from the Merger, there is no assurance that the savings achieved will be sufficient to, or the cost savings sharing mechanism will operate as to, fully offset the amortization of the acquisition adjustment.
OTHER INFORMATION
INFLATION: Under the ratemaking procedures prescribed by the regulatory commissions to which the Company is subject, only the original cost of plant is recoverable in revenues as depreciation. Therefore, because of inflation, present and future depreciation provisions are inadequate for purposes of maintaining the purchasing power invested by common shareholders and the related cash flows are inadequate for replacing property. The impact of this ratemaking process on common shareholders is mitigated to the extent depreciable property is financed with debt that can be repaid with dollars of less purchasing power. While the Company has experienced relatively low inflation in the recent past, the cumulative effect of inflation on operating costs may require the Company to seek regulatory rate relief to recover these higher costs.
ENVIRONMENTAL: The Company has taken a proactive position with respect to the potential environmental liability associated with former manufactured gas sites and has an agreement with the Kansas Department of Health and Environment (KDHE) to systematically evaluate these sites (see Note 3).
Although the Company currently has no Phase I affected units under the Clean Air Act of 1990, the Company has applied for an early substitution permit to bring the co-owned La Cygne Station under the Phase I guidelines. The oxides of nitrogen (NOx) and air toxic limits, which were not set in law, will be specified in future Environmental Protection Agency (EPA) regulations. The EPA's proposed NOx regulations were ruled invalid by the U.S. Court of Appeals for the District of Columbia Circuit in November 1994, and until such time as the EPA resubmits new proposed regulations, the Company will be unable to determine its compliance options or related compliance costs (see Note 3).
COMPETITION: As a regulated utility, the Company currently has limited direct competition for retail electric service in its certified service area. However, there is competition, based largely on price, from the generation, or potential generation, of electricity by large commercial and industrial customers, and independent power producers.
The 1992 Energy Policy Act (Act) requires increased efficiency of energy usage and has effected the way electricity is marketed. The Act also provides for increased competition in the wholesale electric market by permitting the FERC to order third party access to utilities' transmission systems and by liberalizing the rules for ownership of generating facilities. As part of the Merger, the Company agreed to open access of its transmission system for wholesale transactions. During 1994, wholesale revenues represented less than seven percent of the Company's total revenues.
Operating in this competitive environment could place pressure on utility profit margins and credit quality. Wholesale and industrial customers may threaten to pursue cogeneration, self-generation, retail wheeling, municipalization or relocation to other service territories in an attempt to obtain reduced energy costs. Increasing competition has resulted in credit rating agencies applying more stringent guidelines when making utility credit rating determinations.
The Company is providing reduced electric rates for industrial expansion projects and economic development projects in an effort to maintain and increase electric load. In 1994, The Boeing Company announced it would develop its 777 jetliner in Wichita and Cessna Aircraft Company announced it would build a production plant in Independence, Kansas along with expanding its Wichita facilities, with an addition of 2,000 jobs.
In order to retain its current electric load, the Company has and will continue to negotiate with some of its larger industrial customers, who are able to develop cogeneration facilities, for long term contracts although some negotiated rates may result in reduced margins for the Company. During 1996, the Company will lose a major industrial customer to cogeneration resulting in a reduction to pre-tax earnings of approximately $7 to $8 million. This customer's decision to develop its own cogeneration project was based partially on factors other than energy cost.
ITEM 8.


ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
TABLE OF CONTENTS PAGE
Report of Independent Public Accountants 21
Financial Statements:
Balance Sheets, December 31, 1994 and 1993 23 Statements of Income for the year ended December 31, 1994 24 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Cash Flows for the years ended December 31, 1994 25 and 1993 (Successor), the period March 31 to December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Taxes for the years ended December 31, 1994 26 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Capitalization, December 31, 1994 and 1993 27 Statements of Common Stock Equity for the years ended 28 December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Notes to Financial Statements 29
SCHEDULES OMITTED
The following schedules are omitted because of the absence of the conditions under which they are required or the information is included in the financial statements and schedules presented:
I, II, III, IV, and V.
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors of Kansas Gas and Electric Company:
We have audited the accompanying balance sheets and statements of capitalization of Kansas Gas and Electric Company (a wholly-owned subsidiary of Western Resources, Inc.) as of December 31, 1994 and 1993, and the related statements of income, cash flows, taxes, and common stock equity for the years then ended. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audits to obtain reasonable assurance whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Kansas Gas and Electric Company as of December 31, 1994 and 1993, and the results of its operations and its cash flows for the years then ended in conformity with generally accepted accounting principles.
As explained in Note 8 to the financial statements, effective January 1, 1993, the Company changed its method of accounting for postretirement benefits.
ARTHUR ANDERSEN LLP
Kansas City, Missouri, January 25, 1995
INDEPENDENT AUDITORS' REPORT
Kansas Gas and Electric Company:
We have audited the 1992 financial statements of Kansas Gas and Electric Company (a wholly-owned subsidiary of Western Resources, Inc.) listed in the accompanying table of contents. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
In our opinion, such financial statements present fairly, in all material respects, the results of the Company's operations and its cash flows for the periods indicated in conformity with generally accepted accounting principles.
DELOITTE & TOUCHE LLP
Kansas City, Missouri January 29, 1993
KANSAS GAS AND ELECTRIC COMPANY NOTES TO FINANCIAL STATEMENTS
1. ACQUISITION AND MERGER
On March 31, 1992, Western Resources, Inc. (formerly The Kansas Power and Light Company) (Western Resources) through its wholly-owned subsidiary KCA Corporation (KCA), acquired all of the outstanding common and preferred stock of Kansas Gas and Electric Company (KG&E) for $454 million in cash and 23,479,380 shares of Western Resources common stock (the Merger). Western Resources also paid $20 million in costs to complete the Merger. The total cost of the acquisition to Western Resources was $1.066 billion. Simultaneously, KCA and KG&E merged and adopted the name of Kansas Gas and Electric Company. The Merger was accounted for as a purchase. For income tax purposes the tax basis of the Company's assets was not changed by the Merger. In the accompanying statements, KG&E prior to the Merger is labeled as the "Predecessor" and after the Merger as the "Successor". Throughout the notes to financial statements, the "Company, KG&E" refers to both Predecessor and Successor.
As Western Resources acquired 100% of the common and preferred stock of KG&E, the Company recorded an acquisition premium of $490 million on the balance sheet for the difference in purchase price and book value and increased common stock equity to reflect the new cost basis of Western Resources' investment in the Company. This acquisition premium and related income tax requirement of $311 million under Statement of Financial Accounting Standards No. 109 (SFAS 109) have been classified as plant acquisition adjustment in electric plant in service on the balance sheets. Under the provisions of the order of the Kansas Corporation Commission (KCC), the acquisition premium is recorded as an acquisition adjustment and not allocated to the other assets and liabilities of the Company.
The pro forma information for the year ended December 31, 1992 in the accompanying financial statements gives effect to the Merger as if it occurred on January 1, 1992, and was derived by combining the historical information for the three month period ended March 31, 1992 and the nine month period ended December 31, 1992. No purchase accounting adjustments were made for periods prior to the Merger in determining pro forma amounts, other than the elimination of preferred dividends, because such adjustments would be immaterial. This pro forma information is not necessarily indicative of the results of operations that would have occurred had the Merger been consummated on January 1, 1992, nor is it necessarily indicative of future operating results or financial position.
In the November 1991 KCC order approving the Merger, a mechanism was approved to share equally between the shareholders and ratepayers the cost savings generated by the Merger in excess of the revenue requirement needed to allow recovery of the amortization of a portion of the acquisition adjustment, including income tax, calculated on the basis of a purchase price of KG&E's common stock at $29.50 per share. The order provides an amortization period for the acquisition adjustment of 40 years commencing in August 1995, at which time the full amount of cost savings is expected to have been implemented. Merger savings will be measured by application of an inflation index to certain pre-merger operating and maintenance costs at the time of the next Kansas rate case. While Western Resources and the Company (combined companies) have achieved savings from the Merger, there is no assurance that the savings achieved will be sufficient to, or the cost savings sharing
mechanism will operate as to fully offset the amortization of the acquisition adjustment. The order further provides a moratorium on increases, with certain exceptions, in the Company's Kansas electric rates until August 1995. The KCC ordered refunds totalling $32 million to the combined companies' customers to share with customers the Merger-related cost savings achieved during the moratorium period. Refunds of approximately $4.9 (Company's share) million for the Company were made in April 1992 and December 1993 and the remaining refund of approximately $8.7 (Company's share )million was made in September 1994.
The KCC order approving the Merger required the legal reorganization of the Company so that it was no longer held as a separate subsidiary after January 1, 1995, unless good cause was shown why such separate existence should be maintained. The Securities and Exchange Commission order relating to the Merger granted Western Resources an exemption under the Public Utility Holding Company Act (PUHCA) until January 1, 1995. Western Resources has been granted regulatory approval from the KCC which eliminates the requirement for a combination. As a result of the sales of Western Resources' Missouri Properties, Western Resources is now exempt from regulation as a holding company under Section 3(a)(1) of the PUHCA.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
General: The financial statements of KG&E include, through March 31, 1992, its 80% owned subsidiary, CIC Systems, Inc. (CIC). In April 1992, the Company disposed of its 80% interest in CIC. KG&E owns 47 percent of Wolf Creek Nuclear Operating Corporation (WCNOC), the operating company for Wolf Creek Generating Station (Wolf Creek). The Company records its proportionate share of all transactions of WCNOC as it does other jointly-owned facilities. The accounting policies of the Company are in accordance with generally accepted accounting principles as applied to regulated public utilities. The accounting and rates of the Company are subject to requirements of the KCC and the Federal Energy Regulatory Commission (FERC).
Utility Plant: Utility plant (including plant acquisition adjustment) is stated at cost. For constructed plant, cost includes contracted services, direct labor and materials, indirect charges for engineering, supervision, general and administrative costs, and an allowance for funds used during construction (AFUDC). The AFUDC rate was 4.07% for 1994, 4.41% for 1993, 6.51% for the nine months ended December 31, 1992, and 6.70% for the three months ended March 31, 1992. The cost of additions to utility plant and replacement units of property is capitalized. Maintenance costs and replacement of minor items of property are charged to expense as incurred. When units of depreciable property are retired, they are removed from the plant accounts and the original cost plus removal charges less salvage are charged to accumulated depreciation.
Depreciation: Depreciation is provided on the straight-line method based on estimated useful lives of property. Composite provisions for book depreciation approximated 2.7% during 1994, 2.9% during 1993, 2.9% during the nine months ended December 31, 1992, and 3.0% during the three months ended March 31, 1992 of the average original cost of depreciable property.
Cash and Cash Equivalents: For purposes of the Statements of Cash Flows, cash and cash equivalents include cash on hand and highly liquid collateralized debt instruments purchased with maturities of three months or less.
Income Taxes: Income tax expense includes provisions for income taxes currently payable and deferred income taxes calculated in conformance with income tax laws, regulatory orders and Statement of Financial Accounting Standards No. 109 (SFAS 109) (see Note 9).
Investment tax credits previously deferred are being amortized to income over the life of the property which gave rise to the credits.
Revenues: Operating revenues include amounts actually billed for services rendered and an accrual of estimated unbilled revenues. Unbilled revenues represent the estimated amount customers will be billed for service provided from the time meters were last read to the end of the accounting period. Unbilled revenues of $21.4 and $22.3 million at December 31, 1994 and 1993, respectively, are recorded as a component of accounts receivable on the balance sheets. At December 31, 1993, certain amounts of unbilled revenues were sold (see Note 6).
The Company had reserves for doubtful accounts receivable of $1.9 and $3.0 million at December 31, 1994 and 1993, respectively.
Fuel Costs: The cost of nuclear fuel in process of refinement, conversion, enrichment, and fabrication is recorded as an asset at original cost and is amortized to expense based upon the quantity of heat produced for the generation of electricity. The accumulated amortization of nuclear fuel in the reactor at December 31, 1994 and 1993, was $13.6 and $17.4 million, respectively.
Cash Surrender Value of Life Insurance Contracts: The following amounts related to corporate-owned life insurance contracts (COLI), primarily with one highly rated major insurance company, are recorded on the balance sheets:
1994 1993 (Dollars in Millions) Cash surrender value of contracts. . . $320.6 $269.0 Borrowings against contracts . . . . . 311.2 (269.0) ------ ------ COLI (net) . . . . . . . . . . . . $ 9.4 $ 0.0 ====== ====== The COLI borrowings will be repaid upon receipt of proceeds from death benefits under contracts. The Company recognizes increases in the cash surrender value of contracts, resulting from premiums and investment earnings on a tax free basis, and the tax deductible interest on the COLI borrowings in Corporate-owned Life Insurance (net) on the Statements of Income. Interest expense included in corporate-owned life insurance (net) on the statements of income was $21.0 million for 1994, $11.9 million for 1993, $5.3 million for the nine months ended December 31, 1992, and $1.9 million for the three months ended March 31, 1992.
Reclassifications: Certain amounts in prior years have been reclassified to conform with classifications used in the current year presentation.
3. COMMITMENTS AND CONTINGENCIES
Manufactured Gas Sites: The Company was previously associated with six former manufactured gas sites which contain coal tar and other potentially harmful materials. The Company and the Kansas Department of Health and Environment (KDHE) conducted preliminary assessments of these sites at minimal cost. The results of the preliminary investigations determined the Company does not have a connection to two of the sites.
The Company and KDHE entered into a consent agreement governing all future work at the four remaining sites. The terms of the consent agreement will allow the Company to investigate these sites and set remediation priorities based upon the results of the investigations and risk analysis. The prioritized sites will be investigated over a 10 year period. The agreement will allow the Company to set mutual objectives with the KDHE in order to expedite effective response activities and to control costs and environmental impact. The Company is aware of other utilities in Region VII of the EPA (Kansas, Missouri, Nebraska, and Iowa) which have incurred remediation costs for such sites ranging between $500,000 and $10 million, depending on the site and that the KCC has permitted another Kansas utility to recover its remediation costs through rates. To the extent that such remediation costs are not recovered through rates, the costs could be material to the Company's financial position or results of operations depending on the degree of remediation and number of years over which the remediation must be completed.
Spent Nuclear Fuel Disposal: Under the Nuclear Waste Policy Act of 1982, the U.S. Department of Energy (DOE) is responsible for the ultimate storage and disposal of spent nuclear fuel removed from nuclear reactors. Under a contract with the DOE for disposal of spent nuclear fuel, the Company pays a quarterly fee to DOE of one mill per kilowatthour on net nuclear generation. These fees are included as part of nuclear fuel expense and amounted to $3.8 million for 1994, $3.5 million for 1993, $1.6 million for the nine months ended December 31, 1992, and $.5 million for the three months ended March 31, 1992.
The Company along with the other co-owners of Wolf Creek are among 14 companies that filed a lawsuit on June 20, 1994, seeking an interpretation of the DOE's obligation to begin accepting spent nuclear fuel for disposal in 1998. The Federal Nuclear Waste Policy Act requires DOE ultimately to accept and dispose of nuclear utilities' spent fuel. The DOE has filed a motion to have this case dismissed. The issue to be decided in this case is whether DOE must begin accepting spent fuel in 1998 or at a future date. Wolf Creek contains an on-site spent fuel storage facility which, under current regulatory guidelines, provides space for the storage of spent fuel through the year 2006 while still maintaining full core off-load capability. The Company believes adequate additional storage space can be obtained as necessary.
Decommissioning: On June 9, 1994, the KCC issued an order approving the decommissioning costs of the 1993 Wolf Creek Decommissioning Cost Study which estimates the Company's share of Wolf Creek decommissioning costs, under the immediate dismantlement method, to be approximately $595 million primarily during the period from 2025 through 2033, or approximately $174 million in 1993 dollars. These costs were calculated using an assumed inflation rate of 3.45% over the remaining service life, in 1993, of 32 years.
Decommissioning costs are being charged to operating expenses in accordance with the KCC order. Electric rates charged to customers provide for recovery of these decommissioning costs over the life of Wolf Creek. Amounts so expensed ($3.5 million in 1994 increasing annually to $5.5 million in 2024) and earnings on trust fund assets are deposited in an external trust fund. The assumed return on trust assets is 5.9%.
The Company's investment in the decommissioning fund, including reinvested earnings was $16.9 million and $13.2 million at December 31, 1994 and December 31, 1993, respectively. These amounts are reflected in Decommissioning Trust, and the related liability is included in Deferred Credits and Other Liabilities, Other, on the Balance Sheets.
The Company carries $118 million in premature decommissioning insurance. The insurance coverage has several restrictions. One of these is that it can only be used if Wolf Creek incurs an accident exceeding $500 million in expenses to safely stabilize the reactor, to decontaminate the reactor and reactor station site in accordance with a plan approved by the Nuclear Regulatory Commission (NRC), and to pay for on-site property damages. If the amount designated as decommissioning insurance is needed to implement the NRC-approved plan for stabilization and decontamination, it would not be available for decommissioning purposes.
Nuclear Insurance: The Price-Anderson Act limits the combined public liability of the owners of nuclear power plants to $8.9 billion for a single nuclear incident. The Wolf Creek owners (Owners) have purchased the maximum available private insurance of $200 million and the balance is provided by an assessment plan mandated by the NRC. Under this plan, the Owners are jointly and severally subject to a retrospective assessment of up to $79.3 million ($37.3 million, Company's share) in the event there is a major nuclear incident involving any of the nation's licensed reactors. This assessment is subject to an inflation adjustment based on the Consumer Price Index and applicable premium taxes. There is a limitation of $10 million ($4.7 million, Company's share) in retrospective assessments per incident per year.
The Owners carry decontamination liability, premature decommissioning liability, and property damage insurance for Wolf Creek totalling approximately $2.8 billion ($1.3 billion, Company's share). This insurance is provided by a combination of "nuclear insurance pools" ($500 million) and Nuclear Electric Insurance Limited (NEIL) ($2.3 billion). In the event of an accident, insurance proceeds must first be used for reactor stabilization and site decontamination. The Company's share of any remaining proceeds can be used for property damage up to $1.2 billion (Company's share) and premature decommissioning costs up to $118 million (Company's share) in excess of funds previously collected for decommissioning (as discussed under "Decommissioning").
The Owners also carry additional insurance with NEIL to cover costs of replacement power and other extra expenses incurred during a prolonged outage resulting from accidental property damage at Wolf Creek. If losses incurred at any of the nuclear plants insured under the NEIL policies exceed premiums, reserves, and other NEIL resources, the Company may be subject to retrospective assessments of approximately $13 million per year.
Although the Company maintains various insurance policies to provide coverage for potential losses or liabilities resulting from an accident or extended outage, the Company's insurance coverage may not be adequate to cover the costs that could result from a major accident or extended outage at Wolf Creek. Any substantial losses not covered by insurance, to the extent not recoverable through rates, would have a material adverse effect on the Company's financial position and results of operations.
Clean Air Act: The Clean Air Act Amendments of 1990 (the Act) require a two-phase reduction in sulfur dioxide and oxides of nitrogen (NOx) emissions effective in 1995 and 2000 and a probable reduction in toxic emissions. To meet the monitoring and reporting requirements under the acid rain program, the Company installed continuous monitoring and reporting equipment at a total cost of approximately $2.3 million. The Company does not expect additional equipment to reduce sulfur emissions to be necessary under Phase II. Although the Company currently has no Phase I affected units, the owners have applied for an early substitution permit to bring the co-owned La Cygne Station under the Phase I regulations.
The NOx and air toxic limits, which were not set in the law, will be specified in future EPA regulations. The EPA's proposed NOx regulations were ruled invalid by the U.S. Court of Appeals for the District of Columbia Circuit in November 1994, and until such time as the EPA resubmits new proposed regulations, the Company will be unable to determine its compliance options or related compliance costs.
Federal Income Taxes: During 1991, the Internal Revenue Service (IRS) completed an examination of the Company's federal income tax returns for the years 1984 through 1988. In April 1992, the Company received the examination report and upon review filed a written protest in August 1992. In October 1993, the Company received another examination report for the years 1989 and 1990 covering the same issues identified in the previous examination report. Upon review of this report, the Company filed a written protest in November 1993. The most significant proposed adjustments reduce the depreciable basis of certain assets and investment tax credits generated. Management believes there are significant questions regarding the theory, computations, and sampling techniques used by the IRS to arrive at its proposed adjustments, and also believes any additional tax expense incurred or loss of investment tax credits will not be material to the Company's financial position and results of operations. Additional income tax payments, if any, are expected to be offset by investment tax credit carryforwards, alternative minimum tax credit carryforwards, or deferred tax provisions.
Fuel Commitments: To supply a portion of the fuel requirements for its generating plants, the Company has entered into various commitments to obtain nuclear fuel, coal, and natural gas. Some of these contracts contain provisions for price escalation and minimum purchase commitments. At December 31, 1994, WCNOC's nuclear fuel commitments (Company's share) were
approximately $12.6 million for uranium concentrates expiring at various times through 1997, $122.9 million for enrichment expiring at various times through 2014, and $56.5 million for fabrication through 2012. At December 31, 1994, the Company's coal and natural gas contract commitments in 1994 dollars under the remaining term of the contracts are $721 million and $9 million, respectively. The largest coal contract was renegotiated in early 1993 and expires in 2020 with the remaining coal contracts expiring at various times through 2013. The majority of natural gas contracts expire in 1995 with automatic one-year extension provisions. In the normal course of business, additional commitments and spot market purchases will be made to obtain adequate fuel supplies.
Energy Act: As part of the 1992 Energy Policy Act, a special assessment is being collected from utilities for a uranium enrichment decontamination and decommissioning fund. The Company's portion of the assessment for Wolf Creek is approximately $7 million, payable over 15 years. Management expects such costs to be recovered through the ratemaking process.
4. RATE MATTERS AND REGULATION
Elimination of the Energy Cost Adjustment Clause (ECA): On March 26, 1992, in connection with the Merger, the KCC approved the elimination of the ECA for most retail customers effective April 1, 1992. The provisions for fuel costs included in base rates were established at a level intended by the KCC to equal the projected average cost of fuel through August 1995, and to include recovery of costs provided by previously issued orders relating to coal contract settlements and storm damage recovery discussed below. Any increase or decrease in fuel costs from the projected average will impact the Company's earnings.
Rate Stabilization Plan: In 1988, the KCC issued an order requiring that the accrual of phase-in revenues be discontinued effective December 31, 1988. Effective January 1, 1989, the Company began amortizing the phase-in revenue asset on a straight-line basis over 9-1/2 years. At December 31, 1994 approximately $61 million of deferred phase-in revenues remained on the Balance Sheet.
Coal Contract Settlements: In March 1990, the KCC issued an order allowing the Company to defer its share of a 1989 coal contract settlement with the Pittsburg and Midway Coal Mining Company amounting to $22.5 million. This amount was recorded as a deferred charge on the balance sheets. The settlement resulted in the termination of a long-term coal contract. The KCC permitted the Company to recover this settlement as follows: 76% of the settlement plus a return over the remaining term of the terminated contract (through 2002) and 24% to be amortized to expense with a deferred return equivalent to the carrying cost of the asset. Approximately $18 million of this deferral remains on the balance sheet at December 31, 1994.
In February 1991, the Company paid $8.5 million to settle a coal contract lawsuit with AMAX Coal Company and recorded the payment as a deferred charge on the Company's Balance Sheet. In July 1991, the KCC approved the recovery of the settlement plus a return equivalent to the carrying cost of the asset, over the remaining term of the terminated contract (through 1996).
5. SHORT-TERM BORROWINGS
The Company's short-term financing requirements are satisfied through short-term bank loans and uncommitted loan participation agreements. Maximum short-term borrowings outstanding during 1994 and 1993 were $172.3 million on January 4, 1994 and $175.8 million on December 14, 1993. The weighted average interest rates, including fees, were 4.5% for 1994, 3.5% for 1993, 6.4% for the nine months ended December 31, 1992, and 7.1% for the three months ended March 31, 1992.
6. LONG-TERM DEBT
The amount of first mortgage bonds authorized by the KG&E Mortgage and Deed of Trust (Mortgage) dated April 1, 1940, as supplemented, is limited to a maximum of $2 billion. Amounts of additional bonds which may be issued are subject to property, earnings, and certain restrictive provisions of the Mortgage. Electric plant is subject to the lien of the Mortgage except for transportation equipment. Debt discount and expenses are being amortized over the remaining lives of each issue. The improvement and maintenance fund requirements for certain first mortgage bond series can be met by bonding additional property. The sinking fund requirements for certain pollution control series bonds can be met only through the acquisition and retirement of outstanding bonds.
On November 1, 1994, the Company terminated a long-term agreement which contained provisions for the sale of accounts receivable and unbilled revenues (receivables) and phase-in revenues up to a total of $180 million. Amounts related to receivables were accounted for as sales while those related to phase-in revenues were accounted for as collateralized borrowings. At December 31, 1993, outstanding receivables amounting to $56.8 million, were considered sold under the agreement. The weighted average interest rate, including fees, on this agreement was 4.6% for 1994, 3.7% for 1993, 6.6% for the nine months ended December 31, 1992, and 7.9% for the three months ended March 31, 1992.
7. SALE-LEASEBACK OF LA CYGNE 2
In 1987, the Company sold and leased back its 50 percent undivided interest in the La Cygne 2 generating unit. The lease has an initial term of 29 years, with various options to renew the lease or repurchase the 50 percent undivided interest. The Company remains responsible for its share of operation and maintenance costs and other related operating costs of La Cygne 2. The lease is an operating lease for financial reporting purposes.
As permitted under the lease agreement, the Company in 1992 requested the Trustee Lessor to refinance $341.1 million of secured facility bonds of the Trustee and owner of La Cygne 2. The transaction was requested to reduce recurring future net lease expense. In connection with the refinancing on September 29, 1992, a one-time payment of approximately $27 million was made by the Company which has been deferred and is being amortized over the remaining life of the lease and included in operating expense as part of the future lease expense. At December 31, 1994, approximately $24.8 million of this deferral remained on the Balance Sheet.
Future minimum annual lease payments required under the lease agreement are approximately $34.6 million for each year through 1999 and $680 million over the remainder of the lease.
The gain of approximately $322 million realized at the date of the sale has been deferred for financial reporting purposes, and is being amortized over the initial lease term in proportion to the related lease expense. The Company's lease expense, net of amortization of the deferred gain and a one- time payment, was approximately $22.5 million for 1994 and 1993, $20.6 million for the nine months ended December 31, 1992, and $7.5 million for the three months ended March 31, 1992.
8. EMPLOYEE BENEFIT PLANS
Pension: The Company maintains noncontributory defined benefit pension plans covering substantially all employees of the Company prior to the Merger. Pension benefits are based on years of service and the employee's compensation during the five highest paid consecutive years out of ten before retirement. The Company's policy is to fund pension costs accrued, subject to limitations set by the Employee Retirement Income Security Act of 1974 and the Internal Revenue Code.
The following table provides information on the components of pension cost for the Company's pension plans (dollars in millions):
April 1 | Jan.1 to 1994 1993 to Dec.31 | March 31 (Successor)|(Predecessor) Pension Cost: | Service cost . . . . . . . . . . $ 3.7 $ 3.2 $ 2.5 | $ .8 Interest cost on projected | benefit obligation . . . . . . 9.7 9.5 6.7 | 2.1 (Gain) loss on plan assets . . . 2.1 (14.1) (5.8) | (9.0) Net amortization & deferral. . . (11.4) 4.9 (1.0) | 6.7 ------ ------ ------ | ------ Net pension cost . . . . . . . $ 4.1 $ 3.5 $ 2.4 | $ .6 ====== ====== ====== ======
The following table sets forth the plans' actuarial present value and funded status at November 30, 1994 and 1993 (the plan years) and a reconciliation of such status to the December 31, 1994, 1993, and 1992 financial statements (dollars in millions):
1994 1993 1992 Reconciliation of Funded Status: Actuarial present value of benefit obligations: Vested. . . . . . . . . . . . . . . $ 94.0 $ 95.2 $ 82.9 Non-vested. . . . . . . . . . . . . 6.3 6.1 3.6 ------ ------ ------ Total . . . . . . . . . . . . . . $100.3 $101.3 $ 86.5 ====== ====== ====== Plan assets at November 30 (principally debt and equity securities) at fair value . . . . . . . . . . . . . $115.4 $119.9 $113.7 Projected benefit obligation at November 30 . . . . . . . . . . . . (125.4) (125.5) (110.8) ------ ------ ------ Funded status at November 30. . . . . . . (10.0) (5.6) 2.9 Unrecognized transition asset . . . . . . (1.5) (1.7) (2.0) Unrecognized prior service costs. . . . . 9.6 12.4 12.1 Unrecognized net gain . . . . . . . . . . (11.1) (20.6) (26.1) ------ ------ ------- Accrued pension costs at December 31. . . $(13.0) $(15.5) $(13.1) ====== ====== =======
Year Ended December 31, 1994 1993 1992
Actuarial Assumptions: Discount rate . . . . . . . . . . 8.0-8.5 % 7.0-7.75% 8.0-8.5 % Annual salary increase rate . . . 5.0 % 5.0 % 6.0 % Long-term rate of return. . . . . 8.0-8.5 % 8.0-8.5 % 8.0-8.5 %
Retirement and Voluntary Separation Plans: In January 1992, the Board of Directors approved an early retirement plan and a voluntary separation program. The voluntary early retirement plan was offered to all vested participants of the Company's defined benefit pension plan who reached the age of 55 with 10 or more years of service on or before May 1, 1992. Certain pension plan improvements were made including a waiver of the actuarial reduction factors for early retirement and a cash incentive payable as a monthly supplement up to 60 months or a lump sum payment. Of the 111 employees eligible for the early retirement option, 71, representing 6% of the Company's work force, elected to retire on or before the May 1, 1992, deadline. Another 29 employees, with 10 or more years of service, elected to participate in the voluntary separation program. In addition, 61 employees received Merger-related severance benefits. The actuarial cost, based on plan provisions for early retirement and voluntary separation programs, and Merger- related severance benefits, was approximately $3.9 million of which $1.8 million was included in the pension liability at December 31, 1992. The actuarial cost was considered in purchase accounting for the Merger (See Note 1).
Postretirement: Western Resources adopted the provisions of Statement of Financial Accounting Standards No. 106 (SFAS 106) in the first quarter of 1993. This statement requires the accrual of postretirement benefits other than pensions, primarily medical benefits costs, during the years an employee provides service.
Based on actuarial projections and adoption of the transition method of implementation which allows a 20-year amortization of the accumulated benefit obligation, the annual expense to be allocated to the Company under SFAS 106 was approximately $3.8 million in 1994 and $3.4 million in 1993. The Company's total obligation to be allocated from Western Resources was approximately $25.3 million and $23.9 million at December 31, 1994 and 1993, respectively. To mitigate the impact of SFAS 106 expense, Western Resources implemented programs to reduce health care costs. In addition, the KCC issued an order permitting the initial deferral of SFAS 106 expense. To mitigate the impact SFAS 106 expense will have on rate increases, Western Resources will include in the future computation of SFAS 106 expense allocated to the Company for computation of cost of service and expense recognition, the actual SFAS 106 expense and an income stream generated from corporate-owned life insurance policies (COLI) purchased in 1993 and 1992. To the extent SFAS 106 expense exceeds income from the COLI program, this excess will be deferred (as allowed by FASB Emerging Issues Task Force Issue No. 92-12) and offset by income generated through the deferral period by the COLI program. Should the income stream generated by the COLI program not be sufficient to offset the deferred SFAS 106 expense, the KCC order allows recovery of such deficit through the ratemaking process by the Company.
Prior to the adoption of SFAS 106 the Company's policy was to recognize expenses as claims were paid. The costs of benefits were $0.8 million for the nine months ended December 31, 1992 and $0.2 million for the three months ended March 31, 1992.
The following table summarizes the status of the Company's postretirement plans for financial statement purposes and the related amount included in the balance sheet:
December 31, 1994 1993 (Dollars in Millions) Reconciliation of Funded Status: Actuarial present value of postretirement benefit obligations: Retirees. . . . . . . . . . . . . . . . . . . $ 12.9 $ 12.4 Active employees fully eligible . . . . . . . 3.0 2.5 Active employees not fully eligible . . . . . 9.4 9.0 Unrecognized prior service cost . . . . . . . (3.2) (.1) Unrecognized transition obligation. . . . . . (19.3) (20.4) Unrecognized net gain (loss). . . . . . . . . .9 (1.7) ------ ------ Balance sheet liability . . . . . . . . . . . . . $ 3.7 $ 1.7 ====== ======
Year Ended December 31, 1994 1993 Assumptions: Discount rate. . . . . . . . . . . . . . . . . 8.0-8.5 % 7.75% Annual compensation increase rate. . . . . . . 5.0 % 5.0 % Expected rate of return. . . . . . . . . . . . 8.5 % 8.5 %
For measurement purposes, an annual health care cost growth rate of 12% was assumed for 1994, decreasing 1% per year to 5% by 2001 and thereafter. The health care cost trend rate has a significant effect on the projected benefit obligation. Increasing the trend rate by 1% each year would increase the present value of the accumulated projected benefit obligation by $.3 million and the aggregate of the service and interest cost components by $26,000.
Savings Plans: Effective January 1, 1995, the Company's 401(k) savings plans were merged with Western Resources savings plans. Prior to the merger of the savings plans, funds of the plans were deposited with a trustee and invested at each employee's option in one or more investment funds, including a Western Resources common stock fund. The Company's contributions were $1.8 million for 1994, $2.0 million for 1993, $1.7 million for the nine months ended December 31, 1992, and $0.2 million for the three months ended March 31, 1992.
9. INCOME TAXES
The Company adopted Statement of Financial Accounting Standards No. 96 (SFAS 96) in 1987. This statement required the Company to establish deferred tax assets and liabilities, as appropriate, for all temporary differences, and to adjust deferred tax balances to reflect changes in tax rates expected to be in effect during the periods the temporary differences reverse. SFAS 96 was superseded by SFAS 109 issued in February 1992 and the Company adopted the provisions of that standard prospectively in the first quarter of 1992. The accounting for SFAS 109 is substantially the same as SFAS 96.
In accordance with various rate orders received from the KCC, the Company has not yet collected through rates the amounts necessary to pay a significant portion of the net deferred income tax liabilities. As management believes it is probable that the net future increases in income taxes payable will be recovered from customers through future rates, it has recorded a deferred asset for these amounts. These assets are also a temporary difference for which deferred income tax liabilities have been provided. Accordingly, the adoption of SFAS 109 did not have a material effect on the Company's results of operations.
At December 31, 1994, the Company has alternative minimum tax credits generated prior to April 1, 1992, which carryforward without expiration, of $41.2 million which may be used to offset future regular tax to the extent the regular tax exceeds the alternative minimum tax. These credits have been applied in determining the Company's net deferred income tax liability and corresponding deferred future income taxes at December 31, 1994.
Beginning April 1, 1992, the Company is part of the consolidated income tax return of Western Resources. However, the Company determines its income tax provisions on a separate company basis.
Deferred income taxes result from temporary differences between the financial statement and tax basis of the Company's assets and liabilities. The sources of these differences and their cumulative tax effects are as follows: =========== =========== ===========
10. LEGAL PROCEEDINGS
The Company is involved in various legal and environmental proceedings. Management believes that adequate provision has been made within the financial statements for these matters and accordingly believes their ultimate dispositions will not have a material adverse effect upon the financial position or results of operations of the Company.
11. FAIR VALUE OF FINANCIAL INSTRUMENTS
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value as set forth in Statement of Financial Accounting Standards No. 107:
Cash and Cash Equivalents- The carrying amount approximates the fair value because of the short- term maturity of these investments. Decommissioning Trust- The fair value of the decommissioning trust is based on quoted market prices at December 31, 1994 and 1993. Variable-rate Debt- The carrying amount approximates the fair value because of the short- term variable rates of these debt instruments. Fixed-rate Debt- The fair value of the fixed-rate debt is based on the sum of the estimated value of each issue taking into consideration the coupon rate, maturity, and redemption provisions of each issue.
The estimated fair values of the Company's financial instruments are as follows:
13. QUARTERLY FINANCIAL STATISTICS (Unaudited) (Dollars in Thousands)
The amounts in the table are unaudited but, in the opinion of management, contain all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation of the results of such periods. The business of the Company is seasonal in nature and, in the opinion of management, comparisons between the quarters of a year do not give a true indication of overall trends and changes in operations.
14. RELATED PARTY TRANSACTIONS
Subsequent to the Merger, the cash management function, including cash receipts and disbursements, for KG&E has been assumed by Western Resources. As a result, the proceeds of cash collections, including short-term borrowings, less disbursements related to KG&E transactions have been recorded by the Companies through an intercompany account which, at December 31, 1994, resulted in a net advance by KG&E to Western Resources of $64.4 million. Certain of the Company's operating expenses have been allocated from Western Resources. These expenses are allocated, depending on the nature of the expense, based on allocation studies, net investment, number of customers, and/or other appropriate allocators. Management believes such allocation procedures are reasonable. During 1994, the Company declared a dividend to Western Resources of $125 million.
ITEM 9.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
There were no disagreements with accountants on accounting and financial disclosure. Information relating to a change in accountants is incorporated by reference from the Company's Current Report on Form 8-K dated March 8, 1993.
PART III
ITEM 10.



ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Western Resources, Inc. owns 100 percent of the Company's outstanding common stock. A Director Business Experience Since 1988 and Other Continuously Name Age Directorships Other Than The Company Since
Kent R. Brown 49 Chairman of the Board (since June 1992), 1992 President and Chief Executive Officer (since March 1992), and prior to that Group Vice President Directorships Bank IV Wichita
Robert T. Crain 69 Owner, Crain Realty, Co., Fort Scott, 1992(b) (a) Kansas Directorships Citizens National Bank Ft. Scott Industries, Inc.
Anderson E. 61 President, Jackson Mortuary, Wichita, 1994 Jackson Kansas
Donald A. 61 President, Maupintour, Inc., Lawrence, 1992(b) Johnston Kansas (Escorted Tours and Travel) (a) Directorships Commerce Bank, Lawrence Maupintour, Inc.
Steven L. 49 Executive Vice President and Chief 1992 Kitchen Financial Officer, Western Resources, Inc.
Glenn L. 69 Retired Vice President - Nuclear of the 1992(b) Koester Company
James J. Noone 74 Attorney and retired Administrative Judge 1992(b) (a) for the District Court of Sedgwick County, Kansas
Marilyn B. 45 President (since October 1993) and prior 1994 Pauly to that Executive Vice President, Bank IV Wichita, Wichita, Kansas Directorships Farmers Mutual Alliance Insurance Company A Director Business Experience Since 1988 and Other Continuously Name Age Directorships Other Than The Company Since
Newton C. Smith 73 Physician and Surgeon, Arkansas City, 1992(b) Kansas
Richard D. Smith 61 President, Range Oil Company 1993 Directorships Bank IV Kansas
(a) Member of the Audit Committee of which Mr. Johnston is Chairman. The Audit Committee has responsibility for the investigation and review of the financial affairs of the Company and its relations with independent accountants. (b) Mr. Crain, Mr. Johnston, Mr. Koester, Mr. Noone, and Mr. Newton Smith were directors of the former Kansas Gas & Electric Company since 1981, 1980, 1986, 1986, and 1985, respectively.
Outside Directors are paid $3,750 per quarter retainer and are paid an attendance fee of $600 for Directors' meetings ($300 if attending by phone). A committee attendance fee of $800 is paid to the outside Director Audit Committee Chairman, and $500 to other outside Committee members. All outside Directors are reimbursed mileage and expenses while attending Directors' and Committee Meetings.
During 1994, the Board of Directors met seven times and the Audit Committee met two times. Each director attended at least 75% of the total number of Board and Committee meetings held while he/she served as a director or a member of the committee, except Mr. Richard D. Smith who attended 71% of such meetings.
Other information required by Item 10 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
ITEM 11.

ITEM 11. EXECUTIVE COMPENSATION
Information required by Item 11 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
ITEM 12.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Information required by Item 12 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
ITEM 13.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Information required by Item 13 is omitted pursuant to General Instruction J(2)(c) to Form 10-K.
PART IV
ITEM 14.

ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
The following financial statements are included herein under Item 8.
FINANCIAL STATEMENTS
Balance Sheets, December 31, 1994 and 1993 Statements of Income for the year ended December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Cash Flows for the year ended December 31, 1994 and 1993 (Successor), the period March 31 to December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Taxes for the year ended December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Statements of Capitalization, December 31, 1994 and 1993 Statements of Common Stock Equity for the year ended December 31, 1994 and 1993 (Successor), the nine months ended December 31, 1992 (Successor), and the three months ended March 31, 1992 (Predecessor) Notes to Financial Statements
REPORTS ON FORM 8-K
None
EXHIBIT INDEX
All exhibits marked "I" are incorporated herein by reference.
Description
2(a) Agreement and Plan of Merger (Filed as Exhibit 2 to Form 10-K I for the year ended December 31, 1990, File No. 1-7324)
2(b) Amendment No. 1 to Agreement and Plan of Merger (Filed as I Exhibit 2 to Form 10-K for the year ended December 31, 1990, File No. 1-7324)
3(a) Articles of Incorporation (Filed as Exhibit 3(a) to Form 10-K I for the year ended December 31, 1992, File No. 1-7324)
3(b) Certificate of Merger of Kansas Gas and Electric Company into I KCA Corporation (Filed as Exhibit 3(b) to Form 10-K for the year ended December 31, 1992, File No. 1-7324)
3(c) By-laws as amended (Filed as Exhibit 3(c) to Form 10-K I for the year ended December 31, 1992, File No. 1-7324)
4(c)1 Mortgage and Deed of Trust, dated as of April 1, 1940 to I Guaranty Trust Company of New York (now Morgan Guaranty Trust Company of New York) and Henry A. Theis (to whom W. A. Spooner is successor), Trustees, as supplemented by thirty-eight Supplemental Indentures, dated as of June 1, 1942, March 1, 1948, December 1, 1949, June 1, 1952, October 1, 1953, March 1, 1955, February 1, 1956, January 1, 1961, May 1, 1966, March 1, 1970, May 1, 1971, March 1, 1972, May 31, 1973, July 1, 1975, December 1, 1975, September 1, 1976, March 1, 1977, May 1, 1977, August 1, 1977, March 15, 1978, January 1, 1979, April 1, 1980, July 1, 1980, August 1, 1980, June 1, 1981, December 1, 1981, May 1, 1982, March 15, 1984, September 1, 1984 (Twenty-ninth and Thirtieth), February 1, 1985, April 15, 1986, June 1, 1991 March 31, 1992, December 17, 1992, August 24, 1993, January 15, 1994 and March 1, 1994, (Filed, respectively, as Exhibit A-1 to Form U-1, File No. 70-23; Exhibits 7(b) and 7(c), File No. 2-7405; Exhibit 7(d), File No. 2-8242; Exhibit 4(c), File No. 2-9626; Exhibit 4(c), File No. 2-10465; Exhibit 4(c), File No. 2-12228; Exhibit 4(c), File No. 2-15851; Exhibit 2(b)-1, File No. 2-24680; Exhibit 2(c), File No. 2-36170; Exhibits 2(c) and 2(d), File No. 2-39975; Exhibit 2(d), File No. 2-43053; Exhibit 4(c)2 to Form 10-K, for December 31, 1989, File No. 1-7324; Exhibit 2(c), File No. 2-53765; Exhibit 2(e), File No. 2-55488; Exhibit 2(c), File No. 2-57013; Exhibit 2(c), File No. 2-58180; Exhibit 4(c)3 to Form 10-K for December 31, 1989, File No. 1-7324; Exhibit 2(e), File No. 2-60089; Exhibit 2(c), File No. 2-60777; Exhibit 2(g), File No. 2-64521; Exhibit 2(h), File No. 2-66758; Exhibits 2(d) and 2(e), File No. 2-69620; Exhibits 4(d) and 4(e), File No. 2-75634; Exhibit 4(d), File No. 2-78944; Exhibit 4(d), File No. 2-87532; Exhibits 4(c)4, 4(c)5 and 4(c)6 to Form 10-K for December 31, 1989, File No. 1-7324; Exhibits 4(c)2 and 4(c)3 to Form 10-K for
Description
December 31, 1992, File No. 1-7324; Exhibit 4(b) to Form S-3, File No. 33-50075; Exhibits 4(c)2 and 4(c)3 to Form 10-K for December 31, 1993, File No. 1-7324)
4(c)2 Thirty-ninth Supplemental Indenture dated as of April 15, 1994, to the Company's Mortgage and Deed of Trust (Filed electronically)
Instruments defining the rights of holders of other long-term debt not required to be filed as exhibits will be furnished to the Commission upon request.
10(a)1 Severance Agreement (Filed as Exhibit 10(a)1 to Form 10-K for the I year ended December 31, 1990, File No. 1-7324)
10(a)2 Severance Agreement (Filed as Exhibit 10(a)2 to Form 10-K for the I year ended December 31, 1990, File No. 1-7324)
10(a)3 Severance Agreement (Filed as Exhibit 10(a)3 to Form 10-K for the I year ended December 31, 1990, File No. 1-7324)
10(b) La Cygne 2 Lease (Filed as Exhibit 10(a) to Form 10-K for the year I ended December 31, 1988, File No. 1-7324)
10(b)1 Amendment No. 3 to La Cygne 2 Lease Agreement dated as of September I 29, 1992 (Filed as Exhibit 10(b)1 to Form 10-K for the year ended December 31, 1992, File No. 1-7324)
10(c) Outside Directors' Deferred Compensation Plan (Filed as Exhibit I 10(c) to the Form 10-K for the year ended December 31, 1993, File No. 1-7324)
12 Computation of Ratio of Consolidated Earnings to Fixed Charges. (Filed electronically)
16 Letter re Change in Certifying Accountant (Filed as Exhibit 16 to I the Current Report on Form 8-K dated March 8, 1993)
23(a) Consent of Independent Public Accountants, Arthur Andersen LLP (Filed electronically)
23(b) Consent of Independent Public Accountants, Deloitte & Touche LLP (Filed electronically)
SIGNATURE
Pursuant to the requirements of Sections 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
KANSAS GAS AND ELECTRIC COMPANY
March 29, 1995 By KENT R. BROWN Kent R. Brown, Chairman of the Board, President and Chief Executive Officer