Item 1. Business
General
Cambridge Electric Light Company (the Company) is engaged in the genera- tion, transmission and distribution and sale of electricity at retail to approximately 44,900 customers in the city of Cambridge, Massachusetts. The service territory encompasses a seven square mile area with a population of approximately 96,000. In addition, the Company sells power for resale to the Independent System Operator (ISO) - New England (formerly the New England Power Pool that operates a centralized facility to ensure reliability of service and dispatch of economically available generating units throughout New England), the Town of Belmont, Massachusetts (Belmont), and sells steam from its electric generating stations at wholesale to an affiliated company for distribution to customers for space heating and other purposes. In early 1997, the Company received approval to participate as a broker in the purchase and sale of electricity.
The Company, which was organized on January 28, 1886 pursuant to a special act of the legislature of the Commonwealth of Massachusetts, operates under the jurisdiction of the Massachusetts Department of Telecommunications and Energy (DTE), formerly the Massachusetts Department of Public Utilities, which regulates retail rates, accounting, issuance of securities and other matters. In addition, the Company files its wholesale rates with the Federal Energy Regulatory Commission (FERC). The Company is a wholly-owned subsidiary of Commonwealth Energy System (System), which, together with its subsidiaries, is collectively referred to as "the system."
By virtue of its charter, which is unlimited in time, the Company purchas- es, distributes and sells electricity without direct competition in kind from any privately or municipally-owned utility. Alternate sources of energy are available to customers within the service territory, but competition from these sources has not been significant. However, on November 25, 1997, the Governor of Massachusetts signed into law the Electric Industry Restructuring Act that subjects the generation element of traditional electric utility operations to competition, effective March 1, 1998. For further details, refer to the "Industry Restructuring" section of Management's Discussion and Analysis of Results of Operations in Item 7 of this report. In early 1995, the Massachusetts Institute of Technology, one of the Company's largest customers, completed and placed into service a natural gas cogeneration facility which will meet approximately 94% of its power needs. For further information on this facility refer to the "Customer Transition Charge" section discussion which follows.
Of the Company's 1997 retail electric unit sales (83% of total sales), 13% was sold to residential customers, 82% to commercial customers, 5% to indus- trial and 1% to streetlighting and similar types of customers.
Electric Power Supply
The Company owns generating facilities with a total capacity of 112.5 MW, of which 49.5 MW is used for peaking purposes. The Company relies primarily on purchased power to meet its energy requirements.
CAMBRIDGE ELECTRIC LIGHT COMPANY
The Company's non-nuclear generating assets together with capacity entitlements associated with power contracts that are further discussed later in this section are part of an ongoing auction process initiated during 1997 in response to electric industry restructuring legislation enacted in Massa- chusetts in November 1997. The auction process is expected to be completed in 1998. For further information, refer to the "Industry Restructuring" section of Management's Discussion and Analysis of Results of Operations in Item 7 of this report.
Power purchases for the Company and Commonwealth Electric Company (Common- wealth Electric), the other wholly-owned electric distribution subsidiary of the System, are arranged in accordance with their requirements. These arrangements include purchases from Canal Electric Company (Canal Electric), another wholly-owned subsidiary of the System. Canal Electric is a wholesale electric generating company located in Sandwich, Massachusetts and is an important source of purchased power for the Company. These generating facilities are also part of the aforementioned auction. Under long-term con- tracts, system entitlements include one-quarter (141.5 MW) of the capacity and energy of Canal Electric Unit 1 and one-half (275.7 MW) of the capacity and energy of Canal Unit 2. The Company's entitlements in these units are 28.2 MW and 55.0 MW, respectively. The Company also has an equity ownership interest of 2 1/2% in an operating nuclear unit located in New England with a power entitlement of 11.3 MW.
Pursuant to a Capacity Acquisition and Disposition Agreement (CADA), Canal Electric seeks to secure bulk electric power on a single system basis to provide cost savings for the customers of the Company and Commonwealth Electric. The CADA has been accepted for filing as an amendment to Canal's FERC rate schedule and allows Canal to act on behalf of the Company and Commonwealth Electric in the procurement of additional capacity for one or both companies. The CADA is in effect for Seabrook 1 and Phases I and II of Hydro-Quebec. Exchange agreements are in place with these utilities whereby, in certain circumstances, it is possible to exchange capacity so that the mix of power improves the pricing for dispatch for both the seller and the purchaser. Power contracts are in place whereby Canal bills or credits the Company and Commonwealth Electric for the costs or revenues associated with these facilities. The Company and Commonwealth Electric, in turn, have billed or are billing these charges (net of revenues from sales) to their customers through rates subject to DTE approval.
Information relevant to life-of-the-unit contracts with nuclear units that are no longer operating in which the Company has an equity ownership is as follows: Connecticut Maine Yankee Yankee Yankee Atomic (Dollars in thousands)
Equity Ownership (%) 4.50 4.00 2.00 Equity Ownership Balance $5,007 $3,121 $405 Year of Shutdown 1996 1997 1992
For further information on Maine Yankee, Connecticut Yankee and Yankee Atomic, refer to Notes 3(b) and 3(e) in the Company's Notes to Financial Statements filed under Item 8 of this report.
CAMBRIDGE ELECTRIC LIGHT COMPANY
In addition, the Company has entitlements of 19.7 MW and 8.1 MW through Canal's equity ownership in Hydro-Quebec Phase II and joint-ownership in the Seabrook nuclear unit, respectively.
ISO - New England
The Company, together with other electric utility companies in the New England area, is a member of ISO - New England, which was formed in 1971 to provide for the joint planning and operation of electric systems throughout New England.
ISO - New England operates a centralized dispatching facility to ensure reliability of service and to dispatch the most economically available generating units of member companies to fulfill the region's energy require- ments. This concept is accomplished through the use of computers to monitor and forecast load requirements.
The Company and the System's other electric subsidiaries are also members of the Northeast Power Coordinating Council (NPCC), an advisory organization, which includes the major power systems in New England and New York plus the provinces of Ontario and New Brunswick in Canada. The NPCC establishes criteria and standards for reliability and serves as a vehicle for coordina- tion in the planning and operation of these systems.
The reserve requirements used by ISO - New England participants in planning future additions are determined by ISO - New England to meet the reliability criteria recommended by the NPCC. The system estimates that, during the next ten years, reserve requirements so determined will be approxi- mately 20% of peak load.
Energy Mix
The Company's energy mix, including purchased power, was as follows:
1997 1996 1995
Oil 55% 21% 23% Nuclear 11 39 36 Natural gas 30 33 40 Hydro 4 7 1 Total 100% 100% 100%
The Company' energy mix in 1997 reflects the greater availability of the oil-fired Canal Units 1 and 2 as compared to 1996 and 1995 when significant scheduled and unscheduled maintenance resulted in reduced output. The significantly reduced nuclear fuel component in 1997 reflects the permanent shutdown of the Maine and Connecticut Yankee plants. The increase in hydro during 1996 represents an increase in power from Hydro-Quebec.
Rates, Regulation and Legislation
The Company operates under the jurisdiction of the DTE, which regulates retail rates, accounting, issuance of securities and other matters. In addition, the Company files its wholesale rates with the FERC.
CAMBRIDGE ELECTRIC LIGHT COMPANY
(a) Restructuring Legislation
As more fully discussed in the "Industry Restructuring" section of Management's Discussion and Analysis of Results of Operations in Item 7 of this report, the Company began to implement the provisions of the Electric Industry Restructuring Act on March 1, 1998 as signed into law on November 25, 1997 following the Company's filing of its proposed restructuring plan with the DTE on November 19, 1997. A modified plan was approved by the DTE on February 27, 1998 prior to implementation on March 1, 1998.
(b) Wholesale Rate Proceedings
The Company currently provides power supply and transmission services to its FERC-jurisdictional wholesale customer, the Municipal Light Department of the Town of Belmont, Massachusetts (Belmont). Belmont has been a "partial requirements" customer since 1986 receiving fully bundled service for most of its capacity and energy requirements from the Company, while the remainder of their power supply requirements is provided by the New York Power Authority (NYPA). The NYPA power supply is wheeled by the Company over its borders in accordance with the provisions set forth in its Firm Transmission Tariff. Since April 1993, Belmont has taken power supply service pursuant to a FERC approved Net Requirements Power Supply Agreement.
In 1993, the Company and Belmont began negotiations for a new transmission service agreement. The nogotiations were not successful. On June 29, 1994, the Company filed for FERC approval of a new transmission service agreement with Belmont. The FERC accepted the rates effective January 25, 1995, subject to refund. At the same time, an investigation was opened by the FERC to determine the reasonableness of both the existing transmission tariff rates to Belmont and the proposed transmission service agreement with Belmont. Both Belmont and FERC staff intervened in the investigation. The Company filed its case with the FERC on October 25, 1994 and evidentiary hearings were held in March 1995.
An Initial Decision (ID) of the Presiding Administrative Law Judge was issued on September 14, 1995. In the ID, the Administrative Law Judge found that the Company's existing transmission tariff rates were just and reason- able. The Administrative Law Judge identified a number of revisions to the filed transmission service agreement which effectively reduced the rates to Belmont. In October 1995, the parties filed briefs on exceptions to the Administrative Law Judge's ID. The Company awaits final FERC action on this investigation.
On March 29, 1995, the FERC issued two notices of proposed rulemaking concerning open access transmission and stranded costs. The FERC's notices proposed to remove impediments to competition in the wholesale bulk power marketplace and to bring more efficient, lower-cost power to electric consum- ers. On March 29, 1996, the Company filed Transmission Tariffs that imple- mented the FERC's requirements for non-discriminatory open access transmission for both point-to-point and network service. The tariffs were accepted on May 17, 1996 to be effective on May 28, 1996, but the rates are subject to an investigation initiated by the FERC itself. A settlement with the FERC regarding this investigation was filed on February 6, 1997.
CAMBRIDGE ELECTRIC LIGHT COMPANY
On April 24, 1996, the FERC issued Order No. 888, a set of three interre- lated rules resolving the above rulemakings. The FERC required all public utilities that own, control or operate transmission facilities in interstate commerce to have on file wholesale open access transmission tariffs that conform to the FERC pro-forma tariff contained in Order No. 888. On July 9, 1996, the Company and Commonwealth Electric filed tariffs that conform to the FERC's pro-forma tariffs. On November 13, 1996, the FERC accepted the non- rate terms and conditions of these tariffs effective July 9, 1996, subject to a revision of one section dealing with the scheduling of services. On March 4, 1997, the FERC issued Order No. 888-A which required revisions to the tariffs filed in compliance with Order No. 888. The Company and Commonwealth Electric both filed their revised tariffs on July 14, 1997. On November 25, 1997, the FERC issued Order No. 888-B requiring minor changes that did not require an additional filing.
On December 31, 1996, the Company and Commonwealth Electric filed market- based power sales tariffs with the FERC with the intent to make wholesale power sales at fully negotiated rates. FERC approved the tariffs on February 27, 1997. In addition, the Companies requested and received authorization to participate as brokers in the sale and purchase of electricity.
(c) Cost Recovery
Rate Schedule Prior to March 1, 1998, the Company had Fuel Charge rate schedules that generally allowed for current recovery, from retail customers, of fuel used in electric production, purchased power and transmission costs. These schedules required a quarterly computation and DTE approval of a Fuel Charge decimal based upon forecasts of fuel, purchased power, transmission costs and billed unit sales for each period. To the extent that collections under the rate schedules did not match actual costs for that period, an appropriate adjustment was reflected in the calculation of the next subsequent calendar quarter decimal. The FC was eliminated on March 1, 1998.
Unbundled Rates The Company has restructured its operations to provide customers with unbundled rates that include a ten percent rate reduction as of March 1, 1998 and the opportunity to purchase generation supply on the competitive market pursuant to the electric industry restructuring enacted in November 1997. Delivery rates are composed of distribution charges, transition charges (to collect transition costs) and transmission charges. Electricity supply services include optional standard offer service and default service. Distribution charges consist of customer demand and energy charges as appropriate to recover distribution costs, including costs formerly recovered under its CC, and is based on the separation of distribution and transmission facilities. Transmission charges are itemized separately and are subject to the Company's Transmission Cost Adjustment. Transition charges are designed to recover on a reconciling basis all of the Company's stranded costs.
Purchased Power The Company has long-term contracts for the purchase of electricity from various sources. Generally, these contracts are for fixed periods and required that the Company pay a demand charge for its capacity entitlement and an energy charge to cover the cost of fuel. The Company collected a portion of the capacity-related purchased power costs associated
CAMBRIDGE ELECTRIC LIGHT COMPANY
with certain long-term power and transmission agreements through base rates as approved by the DTE.
Prior to March 1, 1998, revenues collected through base rates were generally designed to reimburse the Company for all costs of operation other than fuel, the energy portion of purchased power, transmission and C&LM costs while providing a fair return on capital invested in the business. However, as a result of a DTE-mandated recovery mechanism for these costs described above, the Company experienced a revenue excess or shortfall when unit sales and/or the costs recoverable in base rates varied from test-period levels. The issue, which had a significant impact on the Company's net income, was addressed in a settlement agreement approved by the DTE in May 1995 that permitted deferral of up to $2 million annually for these capacity-related purchased power costs. There were no deferrals prior to March 1, 1998.
Conservation and Load Management Programs The Company has implemented a variety of cost-effective C&LM programs that are designed to reduce future energy use by its customers. In 1993, the DTE began allowing the recovery by the Company of its "lost base revenues" from customers as a rate component employed by the DTE to encourage effective implementation of C&LM programs. These and other C&LM costs were recovered through a Conservation Charge decimal. The KWH savings that were realized as a result of the successful implementation of C&LM programs served as the basis for determining lost base revenues. Pursuant to the Restructuring Act, the Company has agreed to mandatory charges per KWH to fund energy efficiency and demand-side management activities.
Customer Transition Charge In September 1995, the DTE issued a ruling largely approving four rate tariffs, including a Customer Transition Charge (CTC), that were filed by the Company on March 15, 1995. The CTC was intended to protect remaining customers from paying certain stranded costs that were incurred in the event that the Company's largest customers discontinued full service, yet still remain connected for back-up and other services. These costs included long-term power contracts entered into to meet projected energy requirements, investments in substations, underground and overhead lines and current and future decommissioning costs associated with nuclear plants. This ruling is believed to be the first retail stranded cost charge approved nationally and follows the DTE restructuring order which endorsed, in princi- ple, the recovery of stranded costs.
Through the CTC, the Company recovered 75% of net stranded costs as calculated in its proposal. The Company's other rates include a Supplemental Service Rate, a Standby Service Rate and a Maintenance Service Rate each of which were approved with only minor changes. By its terms, the CTC will terminate as of March 1, 1998, which is the retail access date established by the Massachusetts Legislature in its Electric Industry Restructuring Act.
The Massachusetts Institute of Technology (MIT) appealed the DTE's ruling approving the CTC to the Massachusetts Supreme Judicial Court (the SJC), contending, in part, that the DTE lacked authority to approve the CTC, the DTE's ruling was not supported by subsidiary findings, imposition of the CTC on MIT constitutes inequitable retroactive ratemaking, and the CTC violates the Public Utility Regulatory Policies Act (PURPA). On September 18, 1997, the SJC announced its decision remanding the matter to the DTE for further
CAMBRIDGE ELECTRIC LIGHT COMPANY
consideration. The SJC did find that recovery of prudent and verifiable stranded costs by utility companies is in the public interest and consistent with PURPA. However, the SJC stated that the insufficiencies of the DTE's subsidiary findings precluded the SJC from undertaking a meaningful review of the DTE's calculations that formed the basis of the customer transition charge. Among the issues that the SJC directed the DTE to consider further are: the methodology for calculation of stranded costs, why 75% of stranded costs were allocated to MIT rather than 100%, the prudence of the stranded costs incurred by the Company, and whether the Company took the necessary mitigation efforts to reduce stranded costs. The DTE is in the process of determining whether to take additional evidence in the remand or to rely on the record and pleadings already filed. At this time, management is unable to predict the outcome of this proceeding.
In an earlier legal proceeding involving the CTC, on August 27, 1996, the United States District Court for the District of Massachusetts (District Court) granted the motions for summary judgement of the Company and the DTE and dismissed the complaint filed by MIT. In its complaint, MIT had alleged that the CTC approved by the DTE and implemented by the Company violated PURPA. In dismissing MIT's complaint, the District Court found that MIT's complaint involved an allegation relating to the DPU's application of PURPA, which is not within the District Court's jurisdiction.
Competition
Prior to March 1, 1998, the Company developed and implemented strategies that dealt with the increasingly competitive environment then facing the electric business. The inherently high cost of providing energy services in the Northeast had placed the region at a competitive disadvantage as more customers began to explore alternative energy supply options. Pursuant to preliminary electric industry restructuring rules issued in late 1996, the DTE proposed to implement programs under which utility and non-utility generators could sell electricity to customers of other utilities without regard to previously closed franchise service areas. The DTE initially began an inquiry into incentive ratemaking in 1994. The Company had developed innovative pricing mechanisms designed to retain existing customers, add new retail and wholesale customers and expand beyond current markets.
On February 6, 1997, due to the dramatically changing nature of the electric and gas industries, the system announced the consolidation of management personnel of the Company and affiliates Commonwealth Electric, Commonwealth Gas, COM/Energy Services Company effective on that date. COM/Electric and COM/Gas continue to operate under their existing company names. The consolidation process for these companies involved the merging of similar functions and activities to eliminate duplication in order to create the most efficient and cost-effective operation possible.
Construction and Financing
Information concerning the Company's construction and financing programs is contained in Note 3(a) of the Notes to Financial Statements filed under Item 8 of this report.
CAMBRIDGE ELECTRIC LIGHT COMPANY
Employees
The Company has 142 regular employees, 104 employees (73%) are represented by the Utility Workers' Union of America, A.F.L.-C.I.O. Upon the expiration of the existing collective bargaining agreement on September 1, 1998, a new agreement, which has already been ratified, will become effective through March 1, 2001. Employee relations have generally been satisfactory.
Item 2.
Item 2. Properties
The Company owns and operates two steam generating plants and two gas turbine units located in Cambridge with a total capability of 112.5 MW together with an integrated system of distribution lines and substations.
At December 31, 1997, the Company's electric transmission and distribution system consisted of 93 pole miles of overhead lines, 714 cable miles of underground line, 233 substations and 45,420 active customer meters.
Item 3.
Item 3. Legal Proceedings
The Company is an intervenor in an appeal at the Massachusetts Supreme Judicial Court (SJC) filed by MIT of a decision by the DTE approving a customer transition charge that allows the Company to recover certain stranded costs. For additional information refer to "Cost Recovery" section in Item 1 of this report.
CAMBRIDGE ELECTRIC LIGHT COMPANY
PART II.
Item 5.
Item 5. Market for the Registrant's Common Stock and Related Stockholder Matters
(a) Principal Market
Not applicable. The Company is a wholly-owned subsidiary of Common- wealth Energy System.
(b) Number of Stockholders at December 31, 1997
One
(c) Frequency and Amount of Dividends Declared in 1997 and 1996
1997 1996 Per Share Per Share Declaration Date Amount Declaration Date Amount
April 25, 1997 $ 1.70 January 24, 1996 $4.00 October 27, 1997 2.50 April 29, 1996 0.75 December 22, 1997 4.00 November 04, 1996 5.20 $ 8.20 $9.95
Reference is made to Note 7 of the Notes to Financial Statements filed under Item 8 of this report for the restriction against the payment of cash dividends.
(d) Future dividends may vary depending on the Company's earnings and capital requirements as well as financial and other conditions existing at that time.
CAMBRIDGE ELECTRIC LIGHT COMPANY
Item 7.
Item 7. Management's Discussion and Analysis of Results of Operations
The following is a discussion of certain significant factors which have affected operating revenues, expenses and net income during the periods included in the accompanying Statements of Income and is presented to facili- tate an understanding of the results of operations. This discussion should be read in conjunction with the Notes to Financial Statements filed under Item 8
Item 8. Financial Statements and Supplementary Data
The Company's financial statements required by this item are filed herewith on pages 19 through 39 of this report.
Item 9.
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
CAMBRIDGE ELECTRIC LIGHT COMPANY
Item 8. Financial Statements and Supplementary Data
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors of Cambridge Electric Light Company:
We have audited the accompanying balance sheets of CAMBRIDGE ELECTRIC LIGHT COMPANY (a Massachusetts corporation and wholly-owned subsidiary of Commonwealth Energy System) as of December 31, 1997 and 1996, and the related statements of income, retained earnings and cash flows for each of the three years in the period ended December 31, 1997. These financial statements and schedules referred to below are the responsibility of the Company's manage- ment. Our responsibility is to express an opinion on these financial state- ments and schedules based on our audits.
We conducted our audits 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 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 Cambridge Electric Light Company as of December 31, 1997 and 1996, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1997, in conformity with generally accepted accounting princi- ples.
Our audits were made for the purpose of forming an opinion on the basic financial statements taken as a whole. The schedules listed in the index to financial statements and schedules are presented for purposes of complying with the Securities and Exchange Commission's rules and are not part of the basic financial statements. These schedules have been subjected to the auditing procedures applied in the audits of the basic financial statements and, in our opinion, fairly state, in all material respects, the financial data required to be set forth therein in relation to the basic financial statements taken as a whole.
ARTHUR ANDERSEN LLP
Boston, Massachusetts February 19, 1998 (except with respect to certain matters discussed in Note 2, as to which the date is March 2, 1998).
CAMBRIDGE ELECTRIC LIGHT COMPANY INDEX TO FINANCIAL STATEMENTS AND SCHEDULES
PART II.
FINANCIAL STATEMENTS
Balance Sheets at December 31, 1997 and 1996
Statements of Income for the Years Ended December 31, 1997, 1996 and 1995
Statements of Retained Earnings for the Years Ended December 31, 1997, 1996 and 1995
Statements of Cash Flows for the Years Ended December 31, 1997, 1996 and 1995
Notes to Financial Statements
PART IV.
SCHEDULES
I Investments in, Equity in Earnings of, and Dividends Received From Related Parties for the Years Ended December 31, 1997, 1996 and 1995
II Valuation and Qualifying Accounts for the Years Ended December 31, 1997, 1996 and 1995
SCHEDULES OMITTED
All other schedules are not submitted because they are not applicable or not required or because the required information is included in the financial statements or notes thereto.
Financial statements of 50% or less owned companies accounted for by the equity method have been omitted because they do not, considered individ- ually, constitute a significant subsidiary.
CAMBRIDGE ELECTRIC LIGHT COMPANY BALANCE SHEETS DECEMBER 31, 1997 AND 1996 ASSETS
1997 1996 (Dollars in thousands)
PROPERTY, PLANT AND EQUIPMENT, at original cost $163 914 $161 331 Less - Accumulated depreciation 63 706 61 499 100 208 99 832 Add - Construction work in progress 757 546 100 965 100 378
INVESTMENTS Equity in nuclear electric power companies 9 849 9 403 Other 5 5 9 854 9 408
CURRENT ASSETS Cash 521 143 Accounts receivable - Affiliated companies 2 743 1 452 Customers, less reserves of $297 in 1997 and $482 in 1996 12 483 11 285 Unbilled revenues 3 047 2 751 Inventories, at average cost - Materials and supplies 540 468 Electric production fuel oil 936 1 101 Prepaid taxes - Income 1 192 968 Property 1 697 1 704 Other 501 454 23 660 20 326
DEFERRED CHARGES Regulatory assets 70 466 42 781 Other 2 176 2 258 72 642 45 039
$207 121 $175 151
The accompanying notes are an integral part of these financial statements.
CAMBRIDGE ELECTRIC LIGHT COMPANY BALANCE SHEETS DECEMBER 31, 1997 AND 1996 CAPITALIZATION AND LIABILITIES
1997 1996 (Dollars in thousands) CAPITALIZATION Common Equity - Common stock, $25 par value - Authorized and outstanding - 346,600 shares in 1997 and 1996, wholly-owned by Commonwealth Energy System (Parent) $ 8 665 $ 8 665 Amounts paid in excess of par value 27 953 27 953 Retained earnings 11 607 9 233 48 225 45 851 Long-term debt, including premiums, less current sinking fund requirements and maturing debt 17 402 17 503 65 627 63 354 CURRENT LIABILITIES Interim Financing - Notes payable to banks 19 000 18 725 Advances from affiliates 11 290 5 065 Maturing long-term debt - 4 260 30 290 28 050 Other Current Liabilities - Current sinking fund requirements 100 100 Accounts payable - Affiliated companies 4 144 4 429 Other 8 076 8 216 Accrued local property and other taxes 1 706 1 705 Accrued interest 460 475 Other 3 830 3 738 18 316 18 663 48 606 46 713 DEFERRED CREDITS Accumulated deferred income taxes 15 135 14 355 Yankee Atomic purchased power contract 2 749 3 466 Connecticut Yankee purchased power contract 28 566 35 879 Maine Yankee purchased power contract 34 908 - Unamortized investment tax credits and other 11 530 11 384 92 888 65 084 COMMITMENTS AND CONTINGENCIES
$207 121 $175 151
The accompanying notes are an integral part of these financial statements.
CAMBRIDGE ELECTRIC LIGHT COMPANY STATEMENTS OF INCOME FOR THE YEARS ENDED DECEMBER 31, 1997, 1996 AND 1995
1997 1996 1995 (Dollars in thousands)
ELECTRIC OPERATING REVENUES $131 327 $119 105 $122 303
OPERATING EXPENSES Fuel used in electric production 4 322 3 427 2 895 Electricity purchased for resale 77 879 68 673 69 415 Transmission 5 121 6 177 6 861 Other operation 23 599 20 757 20 617 Maintenance 2 749 3 064 3 404 Depreciation 4 335 4 254 4 127 Taxes - Income 2 591 2 683 2 725 Local property 3 060 3 041 3 017 Payroll and other 885 822 835 124 541 112 898 113 896
OPERATING INCOME 6 786 6 207 8 407
OTHER INCOME 1 774 2 242 1 309
INCOME BEFORE INTEREST CHARGES 8 560 8 449 9 716
INTEREST CHARGES Long-term debt 1 560 2 238 3 776 Other interest charges 1 815 1 157 638 Allowance for borrowed funds used during construction (31) (66) (136) 3 344 3 329 4 278
NET INCOME $ 5 216 $ 5 120 $ 5 438
The accompanying notes are an integral part of these financial statements.
CAMBRIDGE ELECTRIC LIGHT COMPANY STATEMENTS OF RETAINED EARNINGS FOR THE YEARS ENDED DECEMBER 31, 1997, 1996 AND 1995
1997 1996 1995 (Dollars in thousands)
Balance at beginning of year $ 9 233 $ 7 561 $ 7 166 Add (Deduct): Net income 5 216 5 120 5 438 Cash dividends on common stock (2 842) (3 448) (5 043) Balance at end of year $11 607 $ 9 233 $ 7 561
The accompanying notes are an integral part of these financial statements.
CAMBRIDGE ELECTRIC LIGHT COMPANY STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, 1997, 1996 AND 1995
1997 1996 1995 (Dollars in thousands)
OPERATING ACTIVITIES Net income $ 5 216 $ 5 120 $ 5 438 Effects of noncash items - Depreciation and amortization 4 335 4 254 4 258 Deferred income taxes (448) (628) 1 067 Investment tax credits (92) (93) (94) Earnings from corporate joint ventures (1 119) (1 006) (1 111) Dividends from corporate joint ventures 673 827 1 051 Change in working capital, exclusive of cash and interim financing - Accounts receivable and unbilled revenues (2 785) 178 (1 543) Income taxes (224) (1 698) 55 Accounts payable and other (294) 829 331 Deferred postretirement benefits and pension costs (676) (225) (503) All other operating items 1 399 2 356 109 Net cash provided by operating activities 5 985 9 914 9 058
INVESTING ACTIVITIES Additions to property, plant and equipment (exclusive of AFUDC) (4 873) (5 024) (6 229) Allowance for borrowed funds used during construction (31) (66) (136) Net cash used for investing activities (4 904) (5 090) (6 365)
FINANCING ACTIVITIES Payment of dividends (2 842) (3 448) (5 043) Proceeds from short-term borrowings, net 275 16 050 500 Proceeds from affiliate borrowings 6 225 2 640 1 875 Long-term debt issue refunded (4 260) (20 000) - Retirement of long-term debt through sinking funds (101) (162) (162) Net cash used for financing activities (703) (4 920) (2 830) Change in cash 378 (96) (137) Cash at beginning of period 143 239 376 Cash at end of period $ 521 $ 143 $ 239
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION Interest paid (net of capitalized amounts) $ 3 371 $ 3 796 $ 3 934 Income taxes paid $ 2 319 $ 4 015 $ 2 061
The accompanying notes are an integral part of these financial statements.
CAMBRIDGE ELECTRIC LIGHT COMPANY NOTES TO FINANCIAL STATEMENTS
(1) General Information
Cambridge Electric Light Company (the Company) is a wholly-owned subsid- iary of Commonwealth Energy System (the System). The System is the parent company and, together with its subsidiaries, is collectively referred to as "the system." The System is an exempt public utility holding company under the provisions of the Public Utility Holding Company Act of 1935 with invest- ments in four operating public utility companies located in central, eastern and southeastern Massachusetts and several non-regulated companies.
The Company's operations are involved in the production, distribution and sale of electricity to approximately 44,500 customers in the city of Cam- bridge, Massachusetts. The service territory encompasses a seven square-mile area with a population of approximately 96,000. In addition, the Company sells power for resale to the New England Power Pool (NEPOOL) and the Town of Belmont, Massachusetts (Belmont), and sells steam from its electric generating stations at wholesale to an affiliated company for distribution to customers for space heating and other purposes.
The Company has 142 regular employees, 104 (73%) of whom are represented by a single collective bargaining unit with a contract that expires on September 1, 1998. Upon expiration of that contract, a new contract, which has already been ratified, will take effect through March 1, 2001. Employee relations have generally been satisfactory.
(2) Significant Accounting Policies
(a) Principles of Accounting
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Certain prior year amounts are reclassified from time to time to conform with the presentation used in the current year's financial statements.
(b) Regulatory Assets and Liabilities
The Company is regulated as to rates, accounting and other matters by various authorities including the Federal Energy Regulatory Commission (FERC) and the Massachusetts Department of Telecommunications and Energy (DTE), formerly the Massachusetts Department of Public Utilities (DPU).
Based on the current regulatory framework, the Company accounts for the economic effects of regulation in accordance with the provisions of Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regulation." The Company has established various regula- tory assets in cases where the DTE and/or the FERC have permitted or are expected to permit recovery of specific costs over time. Similarly, the regulatory liabilities established by the Company are required to be refunded to customers over time. In the event the criteria for applying SFAS No. 71 are
CAMBRIDGE ELECTRIC LIGHT COMPANY
no longer met, the accounting impact would be an extraordinary, non-cash charge to operations of an amount that could be material. Criteria that give rise to the discontinuance of SFAS No. 71 include: 1) increasing competition that restricts the Company's ability to establish prices to recover specific costs, and 2) a significant change in the current manner in which rates are set by regulators from cost based regulation to another form of regulation. These criteria are reviewed on a regular basis to ensure the continuing application of SFAS No. 71 is appropriate. Based on the current evaluation of the various factors and conditions that are expected to impact future cost recovery, the Company believes that its regulatory assets including those related to generation, are probable of future recovery.
As a result of electric industry restructuring, the Company discontinued application of accounting principles applied to rate-regulated enterprises for its investment in electric generation facilities effective March 1, 1998. The Company will not be required to write-off any of its generation-related assets including regulatory assets. These assets will be retained on the balance sheet because the legislation and DTE's plan for electric industry restructur- ing specifically provide for their recovery through a non-bypassable transi- tion charge.
Effective January 1, 1996, the Company adopted SFAS No. 121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of." SFAS No. 121 imposes stricter criteria for regulatory assets by requiring that such assets be probable of future recovery at each balance sheet date. SFAS No. 121 did not have an impact on the Company's financial position upon adoption.
The principal regulatory assets included in deferred charges at December 31, 1997 and 1996 were as follows:
1997 1996 (Dollars in thousands)
Yankee Atomic unrecovered plant and decommissioning costs $ 2 749 $ 3 466 Connecticut Yankee unrecovered plant and decommissioning costs 28 566 35 879 Maine Yankee unrecovered plant and decommissioning costs 34 908 - Postretirement benefits costs including pensions 3 596 2 988 Other 647 448 $70 466 $42 781
The regulatory liabilities, reflected in the accompanying Balance Sheets and related to deferred income taxes, were $3 million and $3.2 million at December 31, 1997 and 1996, respectively.
As of December 31, 1997, $66.6 million of the Company's regulatory assets and all of its regulatory liabilities are reflected in rates charged to customers over a weighted average period of approximately 10 years.
In November 1997, the Commonwealth of Massachusetts enacted a comprehen- sive electric utility industry restructuring bill. On November 19, 1997 the
CAMBRIDGE ELECTRIC LIGHT COMPANY
System filed a restructuring plan with the DTE. The plan, approved by the DTE on February 27, 1998, describes the process by which Commonwealth Electric and Cambridge Electric will, beginning March 1, 1998, initiate a ten percent rate reduction for all customer classes and allow customers to choose their energy supplier. As part of the plan, the DTE authorized the recovery of certain strandable costs. The legislation gives the DTE the authority to determine the amount of strandable costs that will be eligible for recovery. Costs that will qualify as strandable costs and be eligible for recovery include, but are not limited to, certain above market costs associated with generating facilities, costs associated with long-term commitments to purchase power at above market prices from independent power producers and regulatory assets and associated liabilities related to the generation portion of the electric business.
The cost of transitioning to competition will be mitigated, in part, through the divestiture of the system's non-nuclear generating assets in an auction process that is expected to be completed in 1998. Any net proceeds in excess of book value received from the divestiture of these assets will be used to mitigate stranded costs.
The system's ability to recover its stranded costs will depend on several factors, including the aggregate amount of stranded costs the system will be allowed to recover and the market price of electricity. Management believes that the system will recover its stranded costs. A change in any of the above listed factors or in the current legislation could affect the recovery of stranded costs and may result in a loss to the system. For additional information relating to industry restructuring, see the "Electric Industry Restructuring" section under Management's Discussion and Analysis of Results of Operations.
(c) Transactions with Affiliates
Transactions between the Company and other system companies include purchases and sales of electricity, including purchases from Canal Electric Company (Canal), an affiliate wholesale electric generating company. Other Canal transactions include costs relating to the abandonment of Seabrook 2 and the recovery of a portion of Seabrook 1 pre-commercial operation costs. In addition, payments for management, accounting, data processing and other services are made to an affiliate, COM/Energy Services Company. Transactions with other system companies are subject to review by the DTE.
The Company's operating expenses include the following major intercompany transactions for the periods indicated:
Purchased Power Purchased Power and Transmission Period Ended Purchased Power and Transmission From Canal December 31, Canal Units Seabrook 1 as Agent (Dollars in thousands)
1997 $15 772 $ 7 825 $ 2 358 1996 11 302 7 932 2 786 1995 10 148 6 973 1 465
CAMBRIDGE ELECTRIC LIGHT COMPANY
The costs for the Canal and Seabrook 1 units are included in the long-term obligation table listed in Note 3(b). In addition, the Company purchased natural gas from an affiliate, Commonwealth Gas Company, totaling $245,000, $621,000 and $1,969,000 in 1997, 1996 and 1995, respectively.
(d) Operating Revenues
Customers are billed for their use of electricity on a cycle basis throughout the month. To reflect revenues in the proper period, the estimated amount of unbilled sales revenue is recorded each month.
The Company is generally permitted to bill customers currently for costs associated with purchased power and transmission, fuel used in electric production and conservation and load management (C&LM) costs through adjust- ment clauses. Amounts recoverable under the adjustment clauses are subject to review and adjustment by the DTE. The amount of such costs incurred by the Company but not yet reflected in customers' bills is recorded as unbilled revenues.
(e) Depreciation
Depreciation is provided using the straight-line method at rates intended to amortize the original cost and the estimated cost of removal less salvage of properties over their estimated economic lives. The average composite depreciation rate was 2.68% in 1997, 2.69% in 1996 and 2.72% in 1995.
(f) Maintenance
Expenditures for repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expense. Additions, replacements and renewals of property considered to be units of property are charged to the appropriate plant accounts. Upon retirement, accumulated depreciation is charged with the original cost of property units and the cost of removal less salvage.
(g) Allowance for Funds Used During Construction
Under applicable rate-making practices, the Company is permitted to include an allowance for funds used during construction (AFUDC) as an element of its depreciable property costs. This allowance is based on the amount of construction work in progress that is not included in the rate base on which the Company earns a return. An amount equal to the AFUDC capitalized in the current period is reflected in the accompanying Statements of Income.
While AFUDC does not provide funds currently, these amounts are recover- able in revenues over the service life of the constructed property. The amount of AFUDC recorded was at a weighted average rate of 6% in 1997, 6.25% in 1996 and 7.75% in 1995.
(3) Commitments and Contingencies
(a) Financing and Construction Programs
The Company is engaged in a continuous construction program presently estimated at $24.8 million for the five-year period 1998 through 2002. Of
CAMBRIDGE ELECTRIC LIGHT COMPANY
that amount, $7 million is estimated for 1998. The program is subject to periodic review and revision because of factors such as changes in business conditions, rates of customer growth, effects of inflation, maintenance of reliable and safe service, equipment delivery schedules, licensing delays, availability and cost of capital and environmental factors. The Company expects to finance these expenditures on an interim basis with internally generated funds and short-term borrowings which are ultimately expected to be repaid with the proceeds from sales of long-term debt and equity securities.
(b) Power Contracts
The Company has long-term contracts for the purchase of electricity from various sources. Generally, these contracts are for fixed periods and require payment of a demand charge for the capacity entitlement and an energy charge to cover the cost of fuel. Information relative to these contracts is as follows: Range of Contract Expiration Entitlement Cost Dates % MW 1997 1996 1995 (Dollars in thousands) Type of Unit Cogenerating 2011 17.2 24.5 $15 804 $14 589 $14 680 Oil 2002-2009 (a) 85.6 15 794 11 301 10 148 Nuclear 2012-2026 (b) 8.1 11 670 12 089 10 922 Total 118.2 $43 268 $37 979 $35 750
(a) Includes entitlements in Canal Unit 1 (5%) and Canal Unit 2 (10%).
(b) Includes entitlements in Seabrook 1 (0.7%) and Vermont Yankee (2.5%) nuclear power plants. The estimated cost to decommission Vermont Yankee is $385.9 million in current dollars. The Company's share of this liability (approximately $8.7 million), less its share of the market value of the assets held in a decommissioning trust (approximately $4.4 million), is approximately $4.3 million at December 31, 1997.
Pertinent information with respect to life-of-the-unit contracts with nuclear units no longer operating in which the Company has an equity ownership is as follows: Connecticut Maine Yankee Yankee Yankee Atomic (Dollars in thousands)
Equity Ownership (%) 4.50 4.00 4.50 Plant Entitlement (%) 4.50 3.59 2.50 Contract Expiration Date 2007 2008 2000 Year of Shutdown 1996 1997 1992 1995 Actual Cost ($) 9 498 7 376 2 023 1996 Actual Cost ($) 9 259 6 511 2 260 1997 Actual Cost ($) 5 760 8 928 2 238 Decommissioning cost estimate (100%) ($) 437 270 360 046 137 428 Company's decommissioning cost ($) 19 677 13 859 6 184 Market value of assets (100%) ($) 209 448 199 457 134 143 Company's market value of assets ($) 9 425 7 161 6 036
CAMBRIDGE ELECTRIC LIGHT COMPANY
Based upon regulatory precedent, the operators of the Yankee units believe they will be permitted to continue to collect from power purchasers (including the Company) decommissioning costs, unrecovered plant investment and other costs associated with the permanent closure of these plants over the remaining period of each plant's operating license. The Company does not believe that the ultimate outcome of the early closing of these plants will have a material adverse effect on its operations and believes that recovery of these FERC- approved costs would continue to be allowed in its rates at the retail level.
Costs pursuant to these contracts are included in electricity purchased for resale in the accompanying Statements of Income and are recoverable in revenue. The Company pays its share of decommissioning expense to each of the operators of the nuclear facilities as a cost of electricity purchased for resale.
The estimated aggregate obligations under the life-of-the-unit contracts for capacity from the operating Yankee Nuclear Unit and other long-term purchased power obligations, including the Canal and Seabrook 1 units, in effect for the five years subsequent to 1997 are as follows:
Long-Term Equity-Owned Purchased Nuclear Units Power Total (Dollars in thousands)
1998 $4 957 $40 726 $45 683 1999 5 001 39 504 44 505 2000 4 311 40 339 44 650 2001 4 806 41 265 46 071 2002 4 996 43 036 48 032
Due to changing conditions within the nuclear industry, it is possible that the remaining operating nuclear plant in which the Company has an equity ownership interest could be shutdown prior to the expiration of that unit's operating license.
In addition, the Company incurred costs for purchases from ISO - New England of $15,143,000, $10,973,000 and $14,185,000 in 1997, 1996 and 1995, respectively.
The costs associated with these power contract obligations are a signifi- cant component of the Company's stranded costs that are included in the Company's restructuring plan approved by the DTE.
(c) Price-Anderson Act
Under the Price-Anderson Act (the Act), owners of nuclear power plants have the benefit of approximately $8.9 billion of public liability coverage that would compensate the public for valid bodily injury and property loss on a no fault basis in the event of an accident at a commercial nuclear power plant. Under the provisions of the Act, each nuclear reactor with an operat- ing license can be assessed up to $79.3 million per nuclear incident with a maximum assessment of $10 million per incident within one calendar year. Nuclear plant owners have initiated insurance programs designed to help cover liability claims relating to property damage, decontamination,
CAMBRIDGE ELECTRIC LIGHT COMPANY
replacement power and business interruption costs for participating utilities arising from a nuclear incident.
The Company has an equity ownership interest in four nuclear generating facilities. The operators of these units maintain nuclear insurance coverage (on behalf of the owners of the facilities) with Nuclear Electric Insurance Limited (NEIL II) and the combined American Nuclear Insurers/Mutual Atomic Energy Liability Underwriters (ANI). NEIL II provides $2.25 billion of property, boiler, machinery and decontamination insurance coverage, including accidental premature decommissioning insurance in the amount of the shortfall in the Decommissioning Trust Fund, in excess of the underlying $500 million policy. All companies insured with NEIL are subject to retroactive assess- ments if losses exceed the accumulated funds available. ANI provides $500 million of "all risk" property damage, boiler, machinery and decontamination insurance. An additional $200 million of primary financial protection cover- age is provided for off-site bodily injury or property damage caused by a nuclear incident. ANI also provides secondary financial protection liability insurance which currently provides $8.7 billion of retrospective insurance premium benefits in accordance with the provisions of the Act. Additional coverage ($200 million) provided by ANI includes tort liability protection arising out of radiation injury claims by nuclear workers and injury or property damage caused by the transportation or shipment of nuclear materials or waste.
Based on its various ownership interests in the four nuclear generating facilities, the Company's retrospective premium could be as high as $1.3 million annually or a cumulative total of $12.3 million, exclusive of the effect of inflation indexing (at five-year intervals) and a 5% surcharge ($4 million) in the event that total public liability claims from a nuclear incident exceed the funds available to pay such claims.
(d) Guarantee Agreement
In connection with its investment in Maine Yankee Atomic Power Company, the Company has guaranteed its pro-rata portion of that company's nuclear fuel financing. At December 31, 1997, the Company's portion amounted to $2,680,000.
(e) Environmental Matters
The Company is subject to laws and regulations administered by federal, state and local authorities relating to the quality of the environment. These laws and regulations affect, among other things, the siting and operation of electric generating and transmission facilities and can require the installa- tion of expensive air and water pollution control equipment. These regula- tions have had an impact on the Company's operations in the past and could have an impact on future operations, capital costs and construction schedules of major facilities; however, the generation facilities are likely to be sold at auction in 1998 pursuant to the restructuring plan approved by the DTE.
(4) Income Taxes
For financial reporting purposes, the Company provides federal and state income taxes on a separate-return basis. However, for federal income tax purposes, the Company's taxable income and deductions are included in the
CAMBRIDGE ELECTRIC LIGHT COMPANY
consolidated income tax return of the System and it makes tax payments or receives refunds on the basis of its tax attributes in the tax return in accordance with applicable regulations.
The following is a summary of the Company's provisions for income taxes for the years ended December 31, 1997, 1996 and 1995:
1997 1996 1995 (Dollars in thousands) Federal Current $ 2 574 $ 2 861 $ 1 397 Deferred (287) (582) 991 Investment tax credits (91) (93) (94) 2 196 2 186 2 294 State Current 556 543 355 Deferred (48) (21) 174 508 522 529 2 704 2 708 2 823 Amortization of regulatory liability relating to deferred income taxes (113) (25) (98) $ 2 591 $ 2 683 $ 2 725
Deferred tax liabilities and assets are determined based on the difference between the financial statement and tax bases of assets and liabilities using enacted tax rates in effect in the year in which the differences are expected to reverse.
Accumulated deferred income taxes consisted of the following in 1997 and 1996: 1997 1996 (Dollars in thousands) Liabilities Property-related $17 309 $16 661 All other 1 710 1 947 19 019 18 608 Assets Investment tax credits 1 134 1 193 Pension plan 810 789 Regulatory liability 1 039 1 112 All other 2 339 1 563 5 322 4 657 Accumulated deferred income taxes, net $13 697 $13 951
The net year-end deferred income tax liability above includes a current deferred tax liability of $1,438,000 in 1997 which is included in accrued income taxes in the accompanying Balance Sheets and is net of a current deferred tax asset of $404,000 in 1996 which is included in other deferred charges in the accompanying Balance Sheets.
The total income tax provision set forth previously represents 33% in 1997, 34% in 1996 and 33% in 1995 of income before such taxes. The following
CAMBRIDGE ELECTRIC LIGHT COMPANY
table reconciles the statutory federal income tax rate to these percentages:
1997 1996 1995 (Dollars in thousands) Federal statutory rate 35% 35% 35%
Federal income tax expense at statutory levels $2 732 $2 731 $2 857 Increase (Decrease) from statutory levels: State tax net of federal tax benefit 331 339 343 Tax versus book depreciation 66 83 2 Amortization of excess deferred reserves (113) (25) (98) Amortization of investment tax credits (91) (93) (94) Reversals of capitalized expenses (13) (13) (14) Dividend received deduction (274) (246) (272) Other (47) (93) 1 $2 591 $2 683 $ 2 725
Effective federal income tax rate 33% 34% 33%
(5) Employee Benefit Plans
(a) Pension
The Company has a noncontributory pension plan covering substantially all regular employees who have attained the age of 21 and have completed one year of service. Pension benefits are based on an employee's years of service and compensation. The Company makes monthly contributions to the plan consistent with the funding requirements of the Employee Retirement Income Security Act of 1974.
Components of pension expense and related assumptions to develop pension expense were as follows:
1997 1996 1995 (Dollars in thousands)
Service cost $ 534 $ 538 $ 484 Interest cost 1 871 1 921 1 924 Return on plan assets - (gain)/loss (5 103) (3 899) (5 388) Net amortization and deferral 3 145 2 080 3 672 Total pension expense 447 640 692 Transfers from affiliated companies, net 503 441 439 Less: Amounts capitalized and deferred 723 299 243 Net pension expense $ 227 $ 782 $ 888
Discount rate 7.50% 7.25% 8.50% Assumed rate of return 8.75 8.75 9.00 Rate of increase in future compensation 4.25 4.25 5.00
Pension expense reflects the use of the projected unit credit method which is also the actuarial cost method used in determining future funding of the plan. The Company, in accordance with current ratemaking, is deferring the difference between pension contribution, which is reflected in base rates, and
CAMBRIDGE ELECTRIC LIGHT COMPANY
pension expense. The funded status of the Company's pension plan (using a measurement date of December 31) is as follows:
1997 1996 (Dollars in thousands) Accumulated benefit obligation: Vested $ (26 002) $ (20 583) Nonvested (3 326) (2 131) $ (29 328) $ (22 714)
Projected benefit obligation $ (31 860) $ (26 690) Plan assets at fair market value 32 325 29 027 Projected benefit obligation greater than plan assets 465 2 337 Unamortized transition obligation 551 688 Unrecognized prior service cost 954 1 074 Unrecognized gain (4 289) (5 971) Accrued pension liability $ (2 319) $ (1 872)
The following actuarial assumptions were used in determining the plan's year-end funded status: 1997 1996
Discount rate 7.00% 7.50% Rate of increase in future compensation 3.75 4.25
Plan assets consist primarily of fixed-income and equity securities. Fluctuations in the fair market value of plan assets will affect pension expense in future years.
(b) Other Postretirement Benefits
Certain employees are eligible for postretirement benefits if they meet specific requirements. These benefits could include health and life insurance coverage and reimbursement of Medicare Part B premiums. Under certain circumstances, eligible employees are required to make contributions for postretirement benefits.
To fund its postretirement benefits, the Company makes contributions to various voluntary employees' beneficiary association (VEBA) trusts that were established pursuant to section 501(c)(9) of the Internal Revenue Code (the Code). The Company also makes contributions to a subaccount of its pension plan pursuant to section 401(h) of the Code to fund a portion of its postre- tirement benefit obligation. The Company contributed approximately $1.1 million, $1.2 million and $1.3 million to these trusts during 1997, 1996 and 1995, respectively.
CAMBRIDGE ELECTRIC LIGHT COMPANY
The net periodic postretirement benefit cost for the years ended December 31, 1997, 1996 and 1995 include the following components and related assumptions:
1997 1996 1995 (Dollars in thousands)
Service cost $ 189 $ 205 $ 164 Interest cost 777 809 817 Return on plan assets (764) (460) (521) Amortization of transition obligation over 20 years 497 498 498 Net amortization and deferral 388 181 337 Total postretirement benefit cost 1 087 1 233 1 295 Transfers from affiliated companies, net 590 555 579 Less: Amounts capitalized and deferred 1 68 458 Net postretirement benefit cost $1 676 $1 720 $1 416
Discount rate 7.50% 7.25% 8.50% Assumed rate of return 8.75 8.75 9.00 Rate of increase in future compensation 4.25 4.25 5.00
The funded status of the Company's postretirement benefit plan using a measurement date of December 31, 1997 and 1996 is as follows:
1997 1996 (Dollars in thousands)
Accumulated postretirement benefit obligation: Retirees $ (8 520) $ (6 052) Fully eligible active plan participants (1 685) (1 422) Other active plan participants (2 670) (3 365) (12 875) (10 839) Plan assets at fair market value 5 195 4 076 Accumulated postretirement benefit obligation greater than plan assets (7 680) (6 763) Unamortized transition obligation 7 463 7 960 Unrecognized gain 217 (1 197) $ - $ -
The following actuarial assumptions were used in determining the plan's estimated accumulated postretirement benefit obligation (APBO) and funded status for 1997 and 1996: 1997 1996
Discount rate 7.00% 7.50% Rate of increase in future compensation 3.75 4.25 Medicare Part B premiums 3.10 9.50 Medical care 6.75 7.00 Dental care 4.50 5.00
The above dental rate remains constant through the year 2007. Rates for Medicare Part B premiums and medical care decrease to 3.1% and 4.5%, respec- tively, by 2007 and remain at that level thereafter. A one percent change in the medical trend rate would have a $136,000 impact on the Company's
CAMBRIDGE ELECTRIC LIGHT COMPANY
annual expense and would change the APBO by approximately $1.5 million.
Plan assets consist primarily of fixed-income and equity securities. Fluctuations in the fair market value of plan assets will affect postretire- ment benefits expense in future years.
Effective with its June 1, 1993 rate order from the DPU, the Company was allowed to recover its SFAS No. 106 expense in base rates over a four-year phase-in period with carrying costs on the deferred balance. At December 31, 1997 and 1996, the Company's deferral amounted to approximately $2 million and $2.1 million, respectively.
(c) Savings Plan
The Company has an Employees Savings Plan that provides for Company contributions equal to contributions by eligible employees of up to four percent of each employee's compensation rate and up to five percent for those employees no longer eligible for postretirement health benefits. The Com- pany's contribution was $302,000 in 1997, $310,000 in 1996 and $317,000 in 1995.
(6) Interim Financing and Long-Term Debt
(a) Notes Payable to Banks
The Company and other system companies maintain both committed and uncommitted lines of credit for the short-term financing of their construction programs and other corporate purposes. As of December 31, 1997, system companies had $145 million of committed lines of credit that will expire at varying intervals in 1998. These lines are normally renewed upon expiration and require annual fees of up to .1875% of the individual line. At December 31, 1997, the system's uncommitted lines of credit totaled $10 million. Interest rates on the Company's outstanding borrowings generally are at an adjusted money market rate and averaged 5.8% and 5.6% in 1997 and 1996, respectively. Notes payable to banks totaled $19,000,000 and $18,725,000 at December 31, 1997 and 1996, respectively.
(b) Advances from Affiliates
Notes payable to the System totaled $7,500,000 and $4,665,000 at December 31, 1997 and 1996, respectively. These notes are written for a term of up to 11 months and 29 days. Interest is at the prime rate and is adjusted for changes in that rate during the term of the notes. The rate averaged 8.5% and 8.3% in 1997 and 1996, respectively.
The Company is a member of the COM/Energy Money Pool (the Pool), an arrangement among the subsidiaries of the System, whereby short-term cash surpluses are used to help meet the short-term borrowing needs of the utility subsidiaries. In general, lenders to the Pool receive a higher rate of return than they otherwise would on such investments, while borrowers pay a lower interest rate than those available from banks. Interest rates on the out- standing borrowings are based on the monthly average rate the Company would otherwise have to pay banks, less one-half the difference between that rate and the monthly average U.S. Treasury Bill weekly auction rate. The borrow- ings are for a period of less than one year and are payable upon demand.
CAMBRIDGE ELECTRIC LIGHT COMPANY
Rates on these borrowings averaged 5.4% and 5.3% in 1997 and 1996, respective- ly. Borrowings from the Pool totaled $3,790,00 and $400,000 at December 31, 1997 and 1996, respectively.
(c) Long-Term Debt Maturities and Retirements
Long-term debt outstanding, exclusive of current maturities, current sinking fund requirements and related premiums, is as follows:
Original Balance December 31, Issue 1997 1996 (Dollars in thousands)
7-Year Notes - 8.04%, due 1999 $10 000 $10 000 $10 000 15-Year Notes - 8.7%, due 2007 5 000 5 000 5 000 30-Year Notes - 7 3/4%, due 2002 5 000 2 400 2 500 $17 400 $17 500
Under the terms of its Indenture of Trust, the Company is required to make periodic sinking fund payments for retirement of outstanding long-term debt. The payments and balances of maturing debt issues for the five years subse- quent to December 31, 1997 are as follows:
Sinking Fund Maturing Year Payments Debt Issues Total (Dollars in thousands)
1998 $100 $ - $ 100 1999 100 10 000 10 100 2000 100 - 100 2001 100 - 100 2002 100 2 000 2 100
(d) Disclosures About Fair Value of Financial Instruments
The fair value of certain financial instruments included in the accompany- ing Balance Sheets as of December 31, 1997 and 1996 is as follows:
1997 1996 (Dollars in thousands)
Carrying Fair Carrying Fair Value Value Value Value
Long-Term Debt $17 502 $18 498 $21 863 $22 787
The carrying amount of cash, notes payable to banks and advances to/from affiliates approximates the fair value because of the short maturity of these financial instruments.
The estimated fair value of long-term debt is based on quoted market prices of the same or similar issues or on the current rates offered for debt with the same remaining maturity. The fair values shown above do not purport to represent the amounts at which those obligations would be settled.
CAMBRIDGE ELECTRIC LIGHT COMPANY
(7) Dividend Restriction
At December 31, 1997 none of retained earnings was restricted against the payment of cash dividends by terms of term loans and note agreements securing long-term debt. As of the same date, retained earnings also included approxi- mately $4,852,000 representing the Company's equity in undistributed earnings of the nuclear companies.
(8) Lease Obligations
The Company leases equipment and office space under arrangements that are classified as operating leases. These lease agreements are for terms of one year or longer. Leases currently in effect contain no provisions that prohibit the Company from entering into future lease agreements or obliga- tions.
Future minimum lease payments, by period and in the aggregate, of noncanc- elable operating leases consisted of the following at December 31, 1997:
Operating Leases (Dollars in thousands)
1998 $ 1 703 1999 1 639 2000 1 479 2001 1 392 2002 1 392 Beyond 2002 4 381 Total future minimum lease payments $11 986
Total rent expense for all operating leases, except those with terms of a month or less, amounted to $1,683,000 in 1997, $1,348,000 in 1996 and $1,374,000 in 1995. There were no contingent rentals and no sublease rentals for the years 1997, 1996 and 1995.
CAMBRIDGE ELECTRIC LIGHT COMPANY
PART V.
Item 14.
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K
(a) 1. Index to Financial Statements
Financial statements and notes thereto of the Company together with the Report of Independent Public Accountants, are filed under Item 8 of this report and listed on the Index to Financial Statements and Schedules (page 20).
(a) 2. Index to Financial Statement Schedules
Filed herewith at page(s) indicated -
Schedule I - Investments in, Equity in Earnings of, and Dividends Received From Related Parties - Years Ended December 31, 1997, 1996 and 1995 (pages 49-51).
Schedule II - Valuation and Qualifying Accounts - Years Ended December 31, 1997, 1996 and 1995 (page 52).
(a) 3. Exhibits: Notes to Exhibits -
a. Unless otherwise designated, the exhibits listed below are incorporat- ed by reference to the appropriate exhibit numbers and the Securities and Exchange Commission file numbers indicated in parentheses.
b. The following is a glossary of Commonwealth Energy System and subsid- iary companies' acronyms that are used throughout the following Exhibit Index:
CES.....................Commonwealth Energy System CE......................Commonwealth Electric Company CEL.....................Cambridge Electric Light Company CEC.....................Canal Electric Company CG......................Commonwealth Gas Company NBGEL...................New Bedford Gas and Edison Light Company
CAMBRIDGE ELECTRIC LIGHT COMPANY
Exhibit Index
Exhibit 3. Articles of incorporation and by-laws.
3.1 Articles of incorporation of CEL (Exhibit 1 to the CEL Form 10-K for 1990, File No.2-7909).
3.2 By-laws of CEL, as amended (Exhibit 2 to the CEL Form 10-K for 1990, File No.2-7909).
Exhibit 4. Instruments defining the rights of security holders; including indentures.
Indenture of Trust or Supplemental Indenture of Trust.
4.1.1 Original Indenture on Form S-1 (April 1949) (Exhibit 7(a), File No. 2-7909). 4.1.2 Third Supplemental on Form 10-K (1984) (Exhibit 1, File No. 2- 7909). 4.1.3 Fourth Supplemental on Form 10-K (1984) (Exhibit 2, File No. 2- 7909). 4.1.4 Sixth Supplemental on Form 10-Q (June 1989) (Exhibit 1, File No. 2-7909). 4.1.5 Seventh Supplemental on Form 10-Q (June 1992) (Exhibit 1, File No. 2-7909).
Exhibit 10. Material Contracts.
10.1 Power Contracts.
10.1.1 Power Contract between CEC and CEL dated December 1, 1965 (Exhibit 13(a)(1) to the CEC Form S-1, File No. 2-30057).
10.1.2 Contract between CEC and NBGEL and CEL, affiliated companies, for the sale for specified amounts of electricity from CEC Unit 2 dated January 12, 1976 (Exhibit 7 to the CES Form 10-K for 1985, File No. 1-7316).
10.1.3 Power Contract, as amended to February 28, 1990, superseding the Power Contract dated September 1, 1986 and amendment dated June 1, 1988, between CEC (seller) and CE and CEL (purchasers) for seller's entire share of the Net Unit Capability of Seabrook 1 and related energy produced and other provisions (Exhibit 1 to the CEC Form 10-Q (March 1990), File No. 2-30057).
10.1.4 Agreement for Joint-Ownership, Construction and Operation of the New Hampshire Nuclear Units (Seabrook) between CE, Public Service Company of New Hampshire (PSNH) and others dated May 1, 1973 and filed by CE as Exhibit 13(N) on Form S-1 dated October 1973, File No. 2-49013, and as amended below:
CAMBRIDGE ELECTRIC LIGHT COMPANY
10.1.4.1 First through Fifth Amendments to 10.1.4 dated May 24, 1974, June 21, 1974, September 25, 1975, October 25, 1974 and January 31, 1975, respectively (Exhibit 13(m) to CE's Form S-1, (November 7, 1975), File No. 2-54995).
10.1.4.2 Sixth through Eleventh Amendments to 10.1.4 dated April 18, 1979, April 18, 1979, April 25, 1979, June 8, 1979, October 11, 1979 and December 15, 1979, respectively (Refiled as Exhibit 1 to the CEC Form 10-K for 1989, File No. 2-30057).
10.1.4.3 Twelfth through Fourteenth Amendments to 10.1.4 dated May 16, 1980, December 31, 1980 and June 1, 1982, respectively (Refiled as Exhibits 1, 2 and 3 to the CE 1992 Form 10-K), File No. 2-7749).
10.1.4.4 Fifteenth and Sixteenth Amendment to 10.1.4 dated April 27, 1984 and June 15, 1984, respectively (Exhibit 1 to the CEC Form 10-Q (June 1984), File No. 2-30057).
10.1.4.5 Seventeenth Amendment to 10.1.4 dated March 8, 1985 (Exhibit 1 to the CEC Form 10-Q (March 1985), File No. 2-30057).
10.1.4.6 Eighteenth Amendment to 10.1.4 dated March 14, 1986 (Exhibit 1 to the CEC Form 10-Q (March 1986), File No. 2-30057).
10.1.4.7 Nineteenth Amendment to 10.1.4 dated May 1, 1986 (Exhibit 1 to the CEC Form 10-Q (June 1986), File No. 2-30057).
10.1.4.8 Twentieth Amendment to 10.1.4 dated September 19, 1986 (Exhibit 1 to the CEC Form 10-K for 1986, File No. 2-30057).
10.1.4.9 Twenty-First Amendment to 10.1.4 dated November 12, 1987 (Exhibit 1 to the CEC Form 10-K for 1989, File No. 2-30057).
10.1.4.10 Twenty-Second Amendment and Settlement Agreement to 10.1.4 both dated January 13, 1989, (Exhibit 4 to the CEC Form 10-K for 1988, File No. 2-30057).
10.1.5 Capacity Acquisition Agreement between CEC, CEL and CE dated September 25, 1980 (Exhibit 1 to the 1991 CEC Form 10-K, File No. 2-30057).
10.1.5.1 Amendment to 10.1.5 as amended and restated June 1, 1993, hence- forth referred to as the Capacity Acquisition and Disposition Agreement, whereby CEC, as agent, in addition to acquiring power may also sell bulk electric power which the Company and/or CE owns or otherwise has the right to sell (Exhibit 1 to CE's Form 10-Q (September 1993), File No. 2-30057).
10.1.6 Power Contract between Yankee Atomic Electric Company and CEL, dated June 30, 1959, as amended April 1, 1975 (Exhibit 1 to the CEL Form 10-K, File No. 2-7909).
CAMBRIDGE ELECTRIC LIGHT COMPANY
10.1.6.1 Second, Third and Fourth Amendments to 10.1.6 as amended October 1, 1980, April 1, 1985 and May 6, 1988, respectively (Exhibit 2 to the CEL Form 10-Q (June 1988), File No. 2-7909).
10.1.6.2 Fifth and Sixth Amendments to 10.1.6 as amended June 26, 1989 and July 1, 1989, respectively (Exhibit 1 to the CEL Form 10-Q (Septem- ber 1989), File No. 2-7909).
10.1.7 Power Contract between Connecticut Yankee Atomic Power Company and CEL dated July 1, 1964 (Exhibit 13-K1 to the CES Form S-1, (April 1967) File No. 2-25597).
10.1.7.1 Additional Power Contract to 10.1.7 providing for extension on the contract term dated April 30, 1984 (Exhibit 5 to the CEL Form 10-Q (June 1984), File No. 2-7909).
10.1.7.2 Second Supplementary Power Contract to 10.1.7 providing for decom- missioning financing dated April 30, 1984 (Exhibit 6 to the CEL Form 10-Q (June 1984), File No. 2-7909).
10.1.8 Power Contract between CEL and Vermont Yankee Nuclear Power Corpo- ration dated February 1, 1968 (Exhibit 3 to the CEL 1984 Form 10-K, File No. 2-7909).
10.1.8.1 First Amendment (Section 7) and Second Amendment (decommissioning financing) to 10.1.8 as amended June 1, 1972 and April 15, 1983, respectively (Exhibits 1 and 2, respectively, to the CEL Form 10-Q (June 1984), File No. 2-7909).
10.1.8.2 Third and Fourth Amendments to 10.1.8 as amended April 1, 1985 and June 1, 1985, respectively (Exhibit 1 and 2 to the CEL Form 10-Q (June 1986) File No. 2-7909).
10.1.8.3 Fifth and Sixth Amendments to 10.1.8 both as amended May 6, 1988 (Exhibit 1 to the CEL Form 10-Q (June 1988), File No. 2-7909).
10.1.8.4 Seventh Amendment to 10.1.8 as amended June 15, 1989 (Exhibit 2 to the CEL Form 10-Q (September 1989), File No. 2-7909).
10.1.8.5 Additional Power Contract between CEL and Vermont Yankee Nuclear Power Corporation providing for decommissioning financing and contract extension dated February 1, 1984 (Refiled as Exhibit 1 to the 1993 CEL Form 10-K, File No. 2-7909).
10.1.9 Power Contract between Maine Yankee Atomic Power Company and CEL dated May 20, 1968 (Exhibit 5 to the CES Form S-7, File No. 2- 38372).
10.1.9.1 First Amendment (decommissioning financing) and Second Amendment (supplementary payments) to 10.1.9 as amended March 1, 1984 and January 1, 1984, respectively (Exhibits 3 and 4 to the CEL Form 10-Q (June 1984), File No. 2-7909).
CAMBRIDGE ELECTRIC LIGHT COMPANY
10.1.9.2 Third Amendment to 10.1.9 as amended October 1, 1984 (Exhibit 1 to the CEL Form 10-Q (September 1984), File No. 2-7909).
10.1.10 Participation Agreement between Maine Electric Power Company and CEL and/or NBGEL for the construction of a 345 KV transmission line between Wiscasset, Maine and Mactaquac, New Brunswick, Canada and for the purchase of base and peaking capacity from the New Bruns- wick Electric Power Commission, dated June 20, 1969 (Exhibit 13 to the CES Form 10-K for 1984, File No. 1-7316).
10.1.10.1 Supplement Amending 10.1.10, as amended June 24, 1970 (Exhibit 8 to the CES Form S-7, Amendment No. 1, File No. 2-38372).
10.1.11 Service Agreement for Non-Firm Transmission Service between Boston Edison Company and CEL dated July 5, 1984 (Exhibit 4 to the CEL 1984 Form 10-K, File No. 2-7909).
10.1.12 Agreement, dated September 1, 1985, With Respect To Amendment of Agreement With Respect To Use Of Quebec Interconnection, dated December 1, 1981, among certain New England Power Pool (NEPOOL) utilities to include Phase II facilities in the definition of "Project" (Exhibit 1 to the CEC Form 10-Q (September 1985), File No. 2-30057).
10.1.12.1 Amendatory Agreement No. 3 to 10.1.12, as amended June 1, 1990 (Exhibit 1 to the CEC Form 10-Q (September 1990), File No. 2- 30057).
10.1.13 Preliminary Quebec Interconnection Support Agreement - Phase II among certain NEPOOL utilities, dated June 1,1984 (Exhibit 6 to the CE Form 10-Q (June 1984), File No. 2-7749).
10.1.13.1 First, Second and Third Amendments to 10.1.13 as amended March 1, 1985, January 1, 1986 and March 1, 1987, respectively (Exhibit 1 to the CEC Form 10-Q (March 1987), File No. 2-30057).
10.1.13.2 Fourth and Eighth Amendments to 10.1.13 as amended July 1, 1987 and August 1, 1988, respectively (Exhibit 3 to the CEC Form 10-Q (September 1988), File No. 2-30057).
10.1.13.3 Fifth, Sixth and Seventh Amendments to 10.1.13 as amended October 15, 1987, December 15, 1987 and March 1, 1988, respectively (Exhib- it 1 to the CEC Form 10-Q (June 1988), File No. 2-30057).
10.1.13.4 Ninth and Tenth Amendments to 10.1.13 as amended November 1, 1988 and January 15, 1989, respectively (Exhibit 2 to the CEC Form 10-K for 1988, File No. 2-30057).
10.1.13.5 Eleventh Amendment to 10.1.13 as amended November 1, 1989 (Exhibit 4 to the CEC Form 10-K for 1989, File No. 2-30057).
10.1.13.6 Twelfth Amendment to 10.1.13 as amended April 1, 1990 (Exhibit 1 to the CEC Form 10-Q (June 1990), File No. 2-30057).
CAMBRIDGE ELECTRIC LIGHT COMPANY
10.1.14 Agreement to Preliminary Quebec Interconnection Support Agreement - Phase II among PSNH, New England Power Company, Boston Edison Company and CEC whereby PSNH assigns a portion of its interests under the original Agreement to the other three parties, dated October 1, 1987 (Exhibit 2 to the CEC 1987 Form 10-K, File No. 2-30057).
10.1.15 Phase II Equity Funding Agreement for New England Hydro-Transmis- sion Electric Company, Inc. (New England Hydro (Massachusetts) between New England Hydro and certain NEPOOL utilities, dated June 1, 1985 (Exhibit 2 to the CEC Form 10-Q (September 1985), File No. 2-30057).
10.1.16 Phase II Equity Funding Agreement for New England Hydro-Transmis- sion Corporation (New Hampshire Hydro) between New Hampshire Hydro and certain NEPOOL utilities, dated June 1, 1985 (Exhibit 3 to the CEC Form 10-Q (September 1985), File No. 2-30057).
10.1.16.1 Amendment No. 1 to 10.1.16 as amended May 1, 1986 (Exhibit 6 to the CEC Form 10-Q (March 1987), File No. 2-30057).
10.1.16.2 Amendment No. 2 to 10.1.16 as amended September 1, 1987 (Exhibit 3 to the CEC Form 10-Q (September 1987), File No. 2-30057).
10.1.17 Phase II Massachusetts Transmission Facilities Support Agreement dated June 1, 1985, refiled as a single agreement incorporating Amendments 1 through 7 dated May 1, 1986 through January 1, 1989, respectively, between New England Hydro-Transmission Electric Company, Inc. (New England Hydro) and certain NEPOOL utilities (Exhibit 2 the CEC Form 10-Q (September 1990), File No. 2-30057).
10.1.18 Phase II New Hampshire Transmission Facilities Support Agreement dated June 1, 1985, refiled as a single agreement incorporating Amendments 1 through 8 dated May 1, 1986 through January 1, 1990, respectively, between New England Hydro-Transmission Corporation (New Hampshire Hydro) and certain NEPOOL utilities (Exhibit 3 to the CEC Form 10-Q (September 1990), File No. 2-30057).
10.1.19 Phase II New England Power AC Facilities Support Agreement between New England Power and certain NEPOOL utilities, dated June 1, 1985 (Exhibit 6 to the CEC Form 10-Q (September 1985), File No. 2-30057).
10.1.19.1 Amendments Nos. 1 and 2 to 10.1.19 as amended May 1, 1986 and February 1, 1987, respectively (Exhibit 5 to the CEC Form 10-Q (March 1987), File No. 2-30057).
10.1.19.2 Amendments Nos. 3 and 4 to 10.1.19 as amended June 1, 1987 and September 1, 1987, respectively (Exhibit 5 to the CEC Form 10-Q (September 1987), File No. 2-30057).
CAMBRIDGE ELECTRIC LIGHT COMPANY
10.1.20 Phase II Boston Edison AC Facilities Support Agreement between Boston Edison Company and certain NEPOOL utilities, dated June 1, 1985 (Exhibit 7 to the CEC Form 10-Q (September 1985), File No. 2-30057).
10.1.20.1 Amendments Nos. 1 and 2 to 10.1.20 as amended May 1, 1986 and February 1, 1987, respectively (Exhibit 2 to the CEC Form 10-Q (March 1987), File No. 2-30057).
10.1.20.2 Amendments Nos. 3 and 4 to 10.1.20 as amended June 1, 1987 and September 1, 1987, respectively (Exhibit 4 to the CEC Form 10-Q (September 1987), File No. 2-30057).
10.1.21 Agreement Authorizing Execution of Phase II Firm Energy Contract among certain NEPOOL utilities to participate in the purchase of power from Hydro Quebec, dated September 1, 1985 (Exhibit 8 to the CEC Form 10-Q (September 1985), File No.2-30057).
10.1.22 System Power Sales Agreement by and between Connecticut Light and Power (CL&P), Western Massachusetts Electric Company (Northeast Utilities companies), as sellers, and CEL, as buyer, of power in excess of firm power customer requirements from the electric systems of the Northeast Utilities companies, dated June 1, 1984, as effective October 25, 1985 (Exhibit 1 to the CEL 1985 Form 10-K, File No. 2-7909).
10.1.23 Power Sale Agreement by and between Altresco Pittsfield, L. P. and the Company for entitlement to the electric capacity and related energy to be produced by a cogeneration facility located in Pitts- field, Massachusetts, dated February 20, 1992 (Exhibit 1 to the CEL Form 10-Q (September 1993), File No. 2-7909).
10.1.23.1 System Exchange Agreement by and among Altresco Pittsfield, L.P., the Company, CE and New England Power Company, dated July 2, 1993 (Exhibit 3 to the CE Form 10-Q (September 1993), File No. 2-7749).
10.2 Other Agreements.
10.2.1 Pension Plan for Employees of Commonwealth Energy System and Subsidiary Companies as amended and restated January 1, 1993 (Exhibit 1 to the CES Form 10-Q (September 1993), File No. 1-7316).
10.2.2 Employees Savings Plan of Commonwealth Energy System and Subsidiary Companies as amended and restated January 1, 1993 (Exhibit 2 to the CES Form 10-Q (September 1993), File No. 1-7316).
10.2.2.1 First Amendment to the Employees Savings Plan of Commonwealth Energy System and Subsidiary Companies, as amended and restated as of January 1, 1993, effective October 1, 1994. (Exhibit 1 to the CES Form S-8 (January 1995), File No. 1-7316).
10.2.2.2 Second Amendment to the Employees Savings Plan of Commonwealth Energy System and Subsidiary Companies, as amended and restated as of January 1, 1993, effective April 1, 1996. (Exhibit 1 to the CES Form 10-K/A Amendment No. 1 (April 30, 1996), File No. 1-7316).
CAMBRIDGE ELECTRIC LIGHT COMPANY
10.2.2.3 Third Amendment to the Employees Savings Plan of Commonwealth Energy System and Subsidiary Companies, as amended and restated as of January 1, 1993, effective January 1, 1997. (Exhibit 1 to the CES Form 10-K/A Amendment No. 1 (April 29, 1997), File No. 1-7316).
10.2.3 NEPOOL Agreement dated September 1, 1971 as amended through August 1, 1977 between NEGEA Service Corporation, as agent for CEL, CEC, NBGEL and various other electric utilities operating in New Eng- land, together with amendments dated August 15, 1978, January 31, 1979 and February 1, 1980 (Exhibit 5(c)13 to the CES Form S-16 (April 1980), File No. 2-64731).
10.2.3.1 Thirteenth Amendment to 10.2.3 dated September 1, 1981 (Exhibit 3 to the CES 1991 Form 10-K, File No. 1-7316).
10.2.3.2 Fourteenth through Twentieth Amendments to 10.2.3 as amended December 1, 1981, June 1, 1982, June 15, 1983, October 1, 1983, August 1, 1985, August 15, 1985 and September 1, 1985, respectively (Exhibit 4 to the CES Form 10-Q (September 1985), File No. 1-7316).
10.2.3.3 Twenty-first Amendment to 10.2.3 as amended to January 1, 1986 (Exhibit 1 to the CES Form 10-Q (March 1986), File No. 1-7316).
10.2.3.4 Twenty-second Amendment to 10.2.3 as amended to January 1, 1986 (Exhibit 1 to the CES Form 10-Q (September 1986), File No. 1-7316).
10.2.3.5 Twenty-third Amendment to 10.2.3 as amended April 30, 1987 (Exhibit 1 to the CES Form 10-Q (June 1987), File No. 1-7316).
10.2.3.6 Twenty-fourth Amendment to 10.2.3 as amended March 1, 1988 (Exhibit 1 to the CES 1987 Form 10-K, File No. 1-7316).
10.2.3.7 Twenty-fifth Amendment to 10.2.3 as amended May 1, 1988 (Exhibit 1 to the CES Form 10-Q (March 1988), File No. 1-7316).
10.2.3.8 Twenty-sixth Amendment to 10.2.3 as amended March 15, 1989 (Exhibit 1 to the CES Form 10-Q (March 1989), File No. 1-7316).
10.2.3.9 Twenty-seventh Amendment to 10.2.3 as amended October 1, 1990 (Exhibit 3 to the CES 1990 Form 10-K, File No. 1-7316).
10.2.3.10 Twenty-Eighth Amendment to 10.2.3 as amended September 15, 1992 (Exhibit 1 to the CES Form 10-Q (September 1994), File No. 1-7316).
10.2.3.11 Twenty-Ninth Amendment to 10.2.3 as amended May 1, 1993 (Exhibit 2 to the CES Form 10-Q (September 1994), File No. 1-7316).
10.2.4 Guarantee Agreement by CEL (as guarantor) and MYA Fuel Company (as initial lender) covering the unconditional guarantee of a portion of the payment obligations of Maine Yankee Atomic Power Company under a loan agreement and note initially between Maine Yankee and MYA Fuel Company (Exhibit 3 to the CEL 1985 Form 10-K, File No. 2-7909).
CAMBRIDGE ELECTRIC LIGHT COMPANY
Exhibit 27. Financial Data Schedule
Filed herewith as Exhibit 1 is the Financial Data Schedule for the twelve months ended December 31, 1997
(b) Reports on Form 8-K
No reports on Form 8-K were filed during the three months ended Decem- ber 31, 1997.
SCHEDULE II
CAMBRIDGE ELECTRIC LIGHT COMPANY VALUATION AND QUALIFYING ACCOUNTS FOR THE YEARS ENDED DECEMBER 31, 1997, 1996 AND 1995 (Dollars in Thousands)
Additions Balance at Provision Deductions Balance Beginning Charged to Accounts End Description of Year Operations Recoveries Written Off of Year
Year Ended December 31, 1997
Allowance for Doubtful Accounts $482 $343 $ 49 $577 $297
Year Ended December 31, 1996
Allowance for Doubtful Accounts $490 $279 $ 51 $338 $482
Year Ended December 31, 1995
Allowance for Doubtful Accounts $471 $327 $101 $409 $490
CAMBRIDGE ELECTRIC LIGHT COMPANY FORM 10-K DECEMBER 31, 1997
SIGNATURES
Pursuant to the requirements of Section 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.
CAMBRIDGE ELECTRIC LIGHT COMPANY (Registrant)
By: WILLIAM G. POIST William G. Poist, Chairman of the Board
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
Principal Executive Officers:
WILLIAM G. POIST March 31, 1998 William G. Poist, Chairman of the Board
R. D. WRIGHT March 31, 1998 Russell D. Wright, Vice Chairman and Chief Executive Officer
DEBORAH A. McLAUGHLIN March 31, 1998 Deborah A. McLaughlin President and Chief Operating Officer
Principal Financial and Accounting Officer:
JAMES D. RAPPOLI March 31, 1998 James D. Rappoli, Financial Vice President and Treasurer
A majority of the Board of Directors:
WILLIAM G. POIST March 31, 1998 William G. Poist, Director
R. D. WRIGHT March 31, 1998 Russell D. Wright, Director
JAMES D. RAPPOLI March 31, 1998 James D. Rappoli, Director
DEBORAH A. McLAUGHLIN March 31, 1998 Deborah A. McLaughlin, Director