Annual Report (Form 10-K), fiscal year 1993

ITEM 1. BUSINESS
Allegheny Power System, Inc. (APS), incorporated in Maryland in 1925, is an electric utility holding company that derives substantially all of its income from the electric utility operations of its direct and indirect subsidiaries (Subsidiaries), Monongahela Power Company (Monongahela), The Potomac Edison Company (Potomac Edison), West Penn Power Company (West Penn), and Allegheny Generating Company (AGC). The properties of the Subsidiaries are located in Maryland, Ohio, Pennsylvania, Virginia, and West Virginia, are interconnected, and are operated as a single integrated electric utility system (System), which is interconnected with all neighboring utility systems. The three electric utility operating Subsidiaries are Monongahela, Potomac Edison, and West Penn (Operating Subsidiaries).
Monongahela, incorporated in Ohio in 1924, operates in northern West Virginia and an adjacent portion of Ohio. It also owns generating capacity in Pennsylvania. Monongahela serves about 340,700 customers in a service area of about 11,900 square miles with a population of about 710,000. The seven largest communities served have populations ranging from 10,900 to 33,900. On December 31, 1993, Monongahela had 1,962 employees. Its service area has navigable waterways and substantial deposits of bituminous coal, glass sand, natural gas, rock salt, and other natural resources. Its service area's principal industries produce coal, chemicals, iron and steel, fabricated products, wood products, and glass. There are two municipal electric distribution systems and two rural electric cooperative associations in its service area. Except for one of the cooperatives, they purchase all of their power from Monongahela.
Potomac Edison, incorporated in Maryland in 1923 and in Virginia in 1974, operates in portions of Maryland, Virginia, and West Virginia. It also owns generating capacity in Pennsylvania. Potomac Edison serves about 354,300 customers in a service area of about 7,300 square miles with a population of about 782,000. The six largest communities served have populations ranging from 11,900 to 40,100. On December 31, 1993, Potomac Edison had 1,152 employees. Its service area is generally rural. Its service area's principal industries produce aluminum, cement, fabricated products, rubber products, sand, stone, and gravel. There are four municipal electric distribution systems in its service area, all of which purchase power from Potomac Edison, and six rural electric cooperatives, one of which purchases power from Potomac Edison. There are also several large federal government installations served by Potomac Edison.
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West Penn, incorporated in Pennsylvania in 1916, operates in southwestern and north and south central Pennsylvania. It also owns generating capacity in West Virginia. West Penn serves about 646,700 customers in a service area of about 9,900 square miles with a population of about 1,399,000. The 10 largest communities served have populations ranging from 11,200 to 38,900. On December 31, 1993, West Penn had 2,043 employees. Its service area has navigable waterways and substantial deposits of bituminous coal, limestone, and other natural resources. Its service area's principal industries produce steel, coal, fabricated products, and glass. There are two municipal electric distribution systems in its service area, which purchase their power requirements from West Penn, and five rural electric cooperative associations, located partly within the area, which purchase virtually all of their power through a pool supplied by West Penn and other nonaffiliated utilities.
AGC, organized in 1981 under the laws of Virginia, is jointly owned by the Operating Subsidiaries as follows: Monongahela, 27%; Potomac Edison, 28%; and West Penn, 45%. AGC has no employees, and its only operating assets are a 40% undivided interest in the Bath County (Virginia) pumped- storage hydroelectric station, which was placed in commercial operation in December 1985, and its connecting transmission facilities. AGC's 840-megawatt (MW) share of capacity of the station is sold to its three parents. The remaining 60% interest in the Bath County Station is owned by Virginia Electric and Power Company (Virginia Power).
APS has no employees. Its officers are employed by Allegheny Power Service Corporation (APSC), a wholly-owned subsidiary of APS. On December 31, 1993, the Subsidiaries and APSC had 6,025 employees.
The Subsidiaries in the past have experienced and in the future may experience some of the more significant problems common to electric utilities in general. These include increases in operating and other expenses, difficulties in obtaining adequate and timely rate relief, restrictions on construction and operation of facilities due to regulatory requirements and environmental and health considerations, including the requirements of the Clean Air Act Amendments of 1990 (CAAA), which among other things, require a substantial annual reduction in utility emissions of sulfur dioxides and nitrogen oxides.
Additional concerns include proposals to restructure and, to some extent, deregulate portions of the industry and increase competition, particularly as a result of the National Energy Policy Act of 1992 (EPACT). EPACT may increase competition by allowing the formation of Exempt Wholesale Generators (EWGs), with the approval of the FERC, and providing mandatory access to the interconnected electric grid for wholesale transactions. It further provides for expansion of the grid where constraints are determined to exist - at the expense of the requestor of such transmission service and provided necessary authority to construct such facilities can be obtained. EPACT permits utility generation facilities to qualify as EWGs and allows sales to nonaffiliated and to affiliated utilities provided state commissions approve such transactions. (See ITEM 1. SALES, ELECTRIC FACILITIES and REGULATION for a further discussion of the impact of EPACT.)
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In an effort to meet the challenges of the new competitive environment in the industry, APS is considering forming a new nonutility subsidiary, subject to regulatory approval, to pursue new business opportunities which have a meaningful relationship to the core utility business. APS would also consider establishing or acquiring its own EWGs, if that is feasible, particularly in view of the possible constraints imposed by regulations under the Public Utility Holding Company Act of 1935 (PUHCA) on nonexempt public utility holding companies such as APS and its Subsidiaries.
Further concerns of the industry include possible restrictions on carbon dioxide emissions, uncertainties in demand due to economic conditions, energy conservation, market competition, weather, and interruptions in fuel supply because of weather and strikes. (See ITEM 1. CONSTRUCTION AND FINANCING, RATE MATTERS, and ENVIRONMENTAL MATTERS for information concerning the effect on the Subsidiaries of the CAAA.)
SALES
In 1993, consolidated kilowatthour (kWh) sales to the Operating Subsidiaries' retail customers increased 3.3% from those of 1992, as a result of increases of 6.5%, 5.2% and 0.3% in residential, commercial and industrial sales, respectively. The increased Kwh sales in 1993 reflect both growth in number of customers and higher use. Consolidated revenues from residential, commercial, and industrial sales increased 11.4%, 9.8%, and 5.6%, respectively, primarily because of several rate increases effective in 1993 as described in ITEM 1. RATE MATTERS, increases in fuel and energy cost adjustment clause revenues, and increased kWh sales. Consolidated kWh sales to and revenues from nonaffiliated utilities decreased 30.2% and 25.5%, respectively, due to increased native load, decreased demand, and price competition.
The System's all-time peak load of 7,153 MW occurred on January 18, 1994. The peak loads in 1993 and 1992 were 6,678 MW and 6,530 MW, respectively. The increased 1994 peak was due in part to record cold temperatures throughout the Operating Subsidiaries' service areas and would have been higher except for voluntary curtailments. The average System load (Yearly Net Power Supply divided by number of hours in the year) was 4,674 megawatthours (MWh) and 4,526 MWh in 1993 and 1992, respectively. More information concerning sales may be found in the statistical sections and ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Consolidated electric operating revenues for 1993 were derived as follows: Pennsylvania, 44.8%; West Virginia, 28.4%; Maryland, 20.2%; Virginia, 5.0%; Ohio, 1.6% (residential, 35.1%; commercial, 18.4%; industrial, 28.9%; nonaffiliated utilities, 14.9%; and other, 2.7%). The following percentages of such revenues were derived from these industries: iron and steel, 6.0%; chemicals, 3.3%; fabricated products, 3.3%; aluminum and other nonferrous metals, 3.2%; coal mines, 3.1%; cement, 1.8%; and all other industries, 8.2%. The coal mine percentage decreased in 1993 principally due to the coal strike. More information concerning the coal strike may be found in ITEM 1. FUEL SUPPLY. Revenues from each of 16 industrial customers exceeded $5 million, including one coal customer of both Monongahela and West Penn with total revenues exceeding $15 million, three steel customers with revenues exceeding $26 million each, and one aluminum customer with revenues exceeding $63 million.
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During 1993, Monongahela's kWh sales to retail customers increased 0.3% as a result of increases of 6.4% and 4.7% in residential and commercial sales, respectively, and a decrease of 4.4% in industrial sales, primarily due to the coal strike and lower sales to one iron and steel customer because of increased use of its own generation. Revenues from such customers increased 9.2%, 7.8% and 0.7%, respectively, and revenues from kWh sales to affiliated and nonaffiliated utilities decreased 7.8%. Monongahela's all- time peak load of 1,667 MW occurred on December 21, 1989. (For a discussion of the coal strike, See ITEM 1. FUEL SUPPLY.)
Monongahela's electric operating revenues were derived as follows: West Virginia, 94.0% and Ohio, 6.0% (residential, 28.8%; commercial, 17.3%; industrial, 29.2%; nonaffiliated utilities, 13.4 %; and other, 11.3%). Revenues from each of five industrial customers exceeded $8 million, including one coal customer with revenues exceeding $13 million and one steel customer with revenues exceeding $26 million. The decreases in the revenues of these customers from 1992 levels were primarily due to the coal strike.
During 1993, Potomac Edison's kWh sales to retail customers increased 6.3% as a result of increases of 8.4%, 7.1%, and 4.3% in residential, commercial, and industrial sales, respectively. Revenues from such customers increased 12.7%, 11.8%, and 11.8%, respectively, and revenues from kWh sales to affiliated and nonaffiliated utilities decreased 23.1%. Potomac Edison's all-time peak load of 2,595 MW occurred on January 19, 1994.
Potomac Edison's electric operating revenues were derived as follows: Maryland, 66.6%; West Virginia, 16.8%; and Virginia 16.6% (residential, 38.5%; commercial, 17.5%; industrial, 24.7%; nonaffiliated utilities, 15.2%; and other, 4.1%). Revenues from one industrial customer, the Eastalco aluminum reduction plant near Frederick, Maryland, amounted to $63.4 million (8.9% of total electric operating revenues). Minimum annual charges to Eastalco under an electric service agreement which continues through March 31, 2000, with automatic extensions thereafter unless terminated on notice by either party, were $19.3 million in 1993. Said agreement may be canceled before the year 2000 upon 90 days notice of a governmental decision resulting in a material modification of the agreement.
During 1993, West Penn's kWh sales to retail customers increased 3.1% as a result of increases of 5.2%, 4.4% and 0.8% in residential, commercial, and industrial sales, respectively. Revenues from residential, commercial, and industrial customers increased 11.5%, 9.6%, and 5.4%, respectively, and revenues from kWh sales to affiliated and nonaffiliated utilities decreased 24.3%. West Penn's all- time peak load of 3,068 MW occurred on January 18, 1994.
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West Penn's electric operating revenues were derived as follows: Pennsylvania, 100% (residential, 33.1%; commercial, 18.0%; industrial, 28.5%; nonaffiliated utilities, 14.1%; and other, 6.3%). Revenues from each of three steel customers exceeded $10 million, including two with revenues exceeding $31 million each.
On average, the Operating Subsidiaries are the lowest or among the lowest cost producers of electricity in their regions and therefore the Operating Subsidiaries' delivered power prices should compete favorably with those of potential alternate suppliers who use cost-based pricing. However, the Operating Subsidiaries are experiencing cost increases due to compliance with the CAAA and purchases from Public Utility Regulatory Policies Act of 1978 (PURPA) projects. (See page 7 for a discussion of PURPA projects, and ITEM 3. LEGAL PROCEEDINGS for a description of litigation and regulatory proceedings concerning PURPA capacity.)
In 1993, the Operating Subsidiaries provided approximately 13.3 billion kWh of energy to nonaffiliated utility companies, of which 1.5 billion kWh were generated by the Subsidiaries and the rest were transmitted from electric systems located primarily to the west. These sales included a long-term transaction under which the Operating Subsidiaries purchased 450 MW of firm capacity and its associated energy from Ohio Edison Company for resale to Potomac Electric Power Company, both nonaffiliated utilities. The transaction began in mid-1987 and will continue through 2005, unless terminated earlier.
Sales to nonaffiliated utility companies vary with the needs of those companies for imported power; the availability of System generating facilities, fuel, and regional transmission facilities; and the availability and price of competitive sources of power. System sales decreased in 1993 relative to 1992 primarily because of continued decreased demand, increased Operating Subsidiaries' native load, coal conservation because of the coal strike, and increased willingness of other suppliers to make sales at lower prices. Further decreases in kWh sales to nonaffiliated utilities are expected in 1994 and beyond. Substantially all of the revenues from kWh sales to nonaffiliated utilities are passed on to retail customers and as a result have little effect on net income.
The Operating Subsidiaries reactivated a peak diversity exchange arrangement with Virginia Power effective June 1993 which continues indefinitely. The Operating Subsidiaries will annually supply Virginia Power with 200 MW during each June, July, and August, in return for which Virginia Power will supply the Operating Subsidiaries with 200 MW during each December, January, and February, at least through February 1997. Thereafter, specific amounts of annual diversity exchanges beyond those currently established are to be mutually determined no less than 34 months prior to each year for which an exchange is to take place. The total number of MWh to be delivered by each to the other over the term of the arrangement is expected to be equal.
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The Operating Subsidiaries and Duquesne Light Company (Duquesne Light) in 1991 entered into an exchange arrangement under which the Operating Subsidiaries will supply Duquesne Light with up to 200 MW for a specified number of weeks, generally during each March, April, May, September, October, and November. In return, Duquesne Light will supply the Operating Subsidiaries with up to 100 MW, generally during each December, January, and February. The total number of MWh delivered by each utility to the other over the term of the arrangement is expected to be the same.
West Penn supplies power to the Borough of Tarentum (Tarentum) using in part leased distribution facilities from Tarentum under a 30 year lease agreement terminating in 1996. In June 1993, Tarentum, which in that year had a load of 6.5 MW and revenues of $1.8 million, notified West Penn of its intention to exercise its option to end the lease agreement. The termination of the lease agreement and resulting transfer and sale of electric facilities will result in Tarentum becoming a municipal customer which will purchase electricity on a wholesale basis from West Penn or another supplier. The sale of electric facilities will require Pennsylvania Public Utility Commission approval.
The System provides wholesale transmission services to applicants under its Federal Energy Regulatory Commission (FERC) approved Standard Transmission Service tariff. The tariff provides that such service is subordinate in priority to native load and reliability requirements of interconnected systems to avoid adverse effects on regional reliability in general and on the reliability of the Operating Subsidiaries' service to their retail and full- requirements wholesale customers in particular. (See ITEM 1. ELECTRIC FACILITIES for a discussion of stress on the System's transmission system.) Transmission services requiring special arrangements or long-term commitments have been and continue to be negotiated through mutually acceptable bilateral agreements. Substantially all of the revenues from transmission service sales are passed on to retail customers and as a result have little effect on net income.
EPACT permits wholesale generators, utility-owned and otherwise, and wholesale consumers to request from System and other owners of bulk power transmission facilities a commitment to supply transmission services. Generators include nonaffiliated utilities and nonutility generators (NUG) of electricity (including classifications of generators known as Independent Power Producers (IPP) and EWGs). Consumers of wholesale power include qualifying nonaffiliated utilities or groups of utilities including the many small electric systems owned by municipalities and rural electric cooperative associations in the service areas of the Operating Subsidiaries. Many of these small systems currently purchase substantially all of their power from the Operating Subsidiaries. Under EPACT, these small systems may now seek an order from the FERC to force the Operating Subsidiaries to wheel power over the System to them from sources outside the System service area. All of the small electric wholesale customers in the Operating Subsidiaries' service areas which might avail themselves of this opportunity produced $42 million of total revenues in 1993.
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Under PURPA, certain municipalities and private developers have installed, are installing or are proposing to install hydroelectric and other generating facilities at various locations in or near the Operating Subsidiaries' service areas with the intent of selling some or all of the electric capacity and energy to the Operating Subsidiaries at rates provided under PURPA and approved by appropriate state commissions. The System's total generation capacity includes 292 MW of on-line PURPA capacity. Payments for PURPA capacity and energy in 1993 totaled approximately $105 million at an average cost to the System of 5.04 cents per kWh. The System projects an additional 180 MW of PURPA capacity to come on-line in future years. In addition, lapsed purchase agreements totaling 203 MW and other PURPA complaints totaling 520 MW (none of which are included in the System's integrated resource plan as of August 20, 1993), are the subject of pending litigation. (See ITEM 3. LEGAL PROCEEDINGS for a description of litigation and regulatory proceedings in Pennsylvania, Maryland, and West Virginia affecting PURPA capacity.) In the future, ratings of the Operating Subsidiaries' first mortgage bonds and preferred stock may be affected by increased concern of rating agencies that purchased power contracts are a risk factor deserving consideration in assessing the credit- worthiness of electric utilities.
ELECTRIC FACILITIES
The following table shows the System's December 31, 1993, generating capacity, based on the maximum monthly normal seasonal operating capacity of each unit. The System-owned capacity totaled 7,991 MW, of which 7,089 MW (88.7%) are coal-fired, 840 MW (10.5%) are pumped-storage, and 62 MW (0.8%) are hydroelectric. The term "pumped-storage" refers to the Bath County station which stores energy for use principally during peak load hours by pumping water from a lower to an upper reservoir, using the most economic available electricity, generally during off-peak hours. During the generating cycle, power is produced by water falling from the upper to the lower reservoir through turbine generators.
The average age of the System-owned coal-fired stations shown below, based on generating capacity at December 31, 1993, was about 23.6 years. In 1993, their average heat rate was 10,020 Btu's/kWh, and their availability factor was 87.0%.
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(a) Excludes 361 MW of West Penn oil-fired capacity, which was placed on cold reserve status as of June 1, 1983. Current plans call for the reactivation of these units within the next five years.
(b) Where more than one year is listed as a commencement date for a particular source, the dates refer to the years in which operations commenced for the different units at that source.
(c) The installation of flue-gas desulfurization equipment (See ITEM 1. ENVIRONMENTAL MATTERS) is expected to reduce the net generating capacity of each unit by about 3%.
(d) Capacity entitlement through percentage ownership of AGC.
(e) The FERC issued an annual license to West Penn for Lake Lynn for 1994. A relicensing application has been filed with the FERC for Lake Lynn and a license with a 30 to 50 year term is expected to be issued in late 1994. Potomac Edison's license for hydroelectric facilities, Dam #4 and Dam #5 will expire in 2003. Potomac Edison has received 30 year licenses, effective January 1994, for the Shenandoah, Warren, Luray and Newport projects.
(f) Nonutility generating capacity available through contractual arrangements pursuant to PURPA.
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SYSTEM MAP
The Allegheny Power System Map (System Map), which has been omitted, provides a broad illustration of the names and approximate locations of the System's major generation and transmission facilities, both existing and under construction, in a five state region which includes portions of Pennsylvania, Ohio, West Virginia, Maryland and Virginia. Additionally, Extra High Voltage substations are displayed. By use of shading, the System Map also provides a general representation of the service areas of Monongahela (portions of West Virginia and Ohio), Potomac Edison (portions of Maryland, Virginia and West Virginia), and West Penn (portions of Pennsylvania).
Power Stations shown on the System Map which appear within the Monongahela service area are Willow Island, Pleasants, Harrison, Rivesville, Albright, and Fort Martin. The single Power Station appearing within the Potomac Edison service area is R. Paul Smith. The Bath County Power Station appears on the map just south of the westernmost portion of Potomac Edison's service area formed by the borders of Virginia and West Virginia. Power Stations appearing within the West Penn service area are Armstrong, Mitchell, Hatfield's Ferry, Springdale and Lake Lynn.
The System Map also depicts transmission facilities which are (i) owned solely by the Operating Subsidiaries; (ii) owned by the Operating Subsidiaries in conjunction with other utilities; or (iii) owned solely by other utilities. The transmission facilities portrayed range in capacity from 138kV to 765kV. Additionally, interconnections with other utilities are displayed.
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The following table sets forth the existing miles of tower and pole transmission and distribution lines and the number of substations of the Subsidiaries as of December 31, 1993:
(a) The System has a total of 5,203 miles of underground distribution lines.
(b) The substations have an aggregate transformer capacity of 37,512,771 kilovoltamperes.
(c) Total Bath County transmission lines, of which AGC owns an undivided 40% interest and Virginia Power owns the remainder.
The System has 11 extra-high-voltage (345 kV and above) (EHV) and 29 lower-voltage interconnections with neighboring utility systems. The interregional EHV transmission system, including System facilities, continues to experience periods of heavy loading in a west-to-east direction. Increases in customer load, power transfers by the Subsidiaries and by nonaffiliated entities, and parallel flows caused by transactions to which the Operating Subsidiaries are not a party, all contribute to the heavy west-to-east power flows. In late 1992 and early 1993, a substantial amount of reactive power sources (shunt capacitors) were added to neighboring eastern utilities' EHV systems. These capacitors complement the capacitors added in 1991 and 1992 on the System and together they serve to increase transfer capability by improving voltage on the transmission system during heavy loading periods.
While the additional capacitors installed by the Subsidiaries' eastern neighbors have enhanced transfer capability, the interregional transmission facilities are still expected periodically to operate up to their reliability limits; therefore, restrictions on transfers may still be necessary at times as was the case in recent years.
Under certain provisions of EPACT, wholesale generators, utility-owned or otherwise, may seek from System and other owners of bulk power transmission facilities a commitment to supply power transmission services, so long as the FERC finds reliability and native load and existing contractual customers are not adversely affected (See discussion under ITEM 1. SALES and REGULATION). Such demand on the System for transmission service may add periodically to heavy power flows on the System's facilities.
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The Operating Subsidiaries have, to date, provided managed contractual access to the System's transmission facilities via the provisions of their Standard Transmission Service tariff, or the terms and conditions of bilateral contracts with purchasers of transmission service.
As a result of EPACT, the FERC is investigating the continued desirability of traditional methods of pricing and providing transmission service. The FERC may choose to maintain existing methods, implement new methodologies which the Operating Subsidiaries and their ratepayers may or may not find to be beneficial, or a combination thereof. The Operating Subsidiaries are participating fully in the FERC proceedings with the principal intent of safeguarding the reliability of the System's transmission facilities, and the rights and interests of its native load customers. The outcome of those deliberations cannot be predicted.
RESEARCH AND DEVELOPMENT
The Operating Subsidiaries spent $4.6 million, $2.7 million, and $2.8 million in 1993, 1992, and 1991, respectively, for research programs. Of these amounts, $3.2 million and $0.6 million were for Electric Power Research Institute (EPRI) dues in 1993 and 1992, respectively. The Operating Subsidiaries plan to spend approximately $7.5 million for research in 1994, with EPRI dues representing $5.9 million of that total.
The Operating Subsidiaries joined EPRI, an industry- sponsored research and development institution, effective October 1, 1992, contingent upon the approval by state commissions of recovery of the dues in rates, which approval was subsequently received in all jurisdictions except Ohio and West Virginia, where the matter is pending. Ongoing participation in EPRI depends upon continued approval by state commissions of recovery of dues in rates. Dues are based on a three-year, new-member ramping formula.
Independent research conducted by the Operating Subsidiaries in 1993, which will be completed or continued in 1994, concentrated on environmental protection, generating unit performance, future generating technologies, delivery systems, and customer-related research.
Two U.S. Department of Energy Clean Coal Technology nitrogen oxide control projects, which the Operating Subsidiaries cofounded, have recently been completed. Based upon the results of one of the projects, retrofitting of low nitrogen oxide cell burners at the Hatfield's Ferry Power Station units has been undertaken at much lower costs than would otherwise have been required.
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Research is also being directed to help address major issues facing the Operating Subsidiaries including electric and magnetic field (EMF) risk, waste disposal, greenhouse gas, client-server information system prospects, renewable resources, fuel cells, new combustion turbines and other cogeneration technologies. In addition, evaluation of technical proposals for business opportunities is also ongoing.
EMF research includes monitoring work done by EPRI, Department of Energy (DOE), the Environmental Protection Agency (EPA) and other government researchers. It also includes monitoring literature, law and litigation, and standards as developed. This research enables the Operating Subsidiaries to evaluate any potential health risks to employees and customers which may exist.
Research activities related to alleged global climate change include monitoring government activity, studying possible joint implementation activities in connection with the Clinton Climate Change Action Plan, and studying demand- side management, electro- technologies and possible joint implementation plans.
The Operating Subsidiaries also made research grants to regional colleges and universities to encourage the development of technical resources related to current and future utility problems.
CONSTRUCTION AND FINANCING
Construction expenditures by the Subsidiaries in 1993 amounted to $574 million and for 1994 and 1995 are expected to aggregate $500 million and $400 million, respectively. In 1993, these expenditures included $240 million for compliance with the CAAA. The 1994 and 1995 estimated expenditures include $161 million and $53 million, respectively, to cover the costs of compliance with the CAAA. (See ITEM 1. ENVIRONMENTAL MATTERS.) Allowance for funds used during construction (AFUDC) (shown below) has been reduced for carrying charges on CAAA expenditures that are being collected through currently approved surcharges or in base rates.
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* Includes allowance for funds used during construction for 1993, 1994 and 1995 of: Monongahela $5.8, $4.1 and $1.9; Potomac Edison $7.1, $5.7 and $2.7; and West Penn $8.6, $12.7 and $6.2.
These construction expenditures include major capital projects at existing generating stations, including the construction of flue-gas desulfurization equipment (scrubbers) at the Harrison Power Station, upgrading distribution lines and substations, and the strengthening of the transmission and subtransmission systems. It is anticipated that the Harrison scrubber project will be completed on schedule and that the final costs will be approximately 24% below the original budget. Primary factors contributing to the reduced cost are: a) the absence of any major construction problems to date; b) financing and material and equipment costs lower than expected; and c) favorable rulings of state commissions allowing the inclusion of carrying costs of construction in rates in lieu of AFUDC. In order to avoid unnecessary and uneconomic additional outages, power station construction and long-range maintenance schedules and the expenditures associated therewith will have to be coordinated over the next several years with outages to meet the in-service dates of the new emission control facilities.
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On a System basis, total expenditures for 1993, 1994, and 1995 include $270 million, $191 million, and $93 million, respectively, for construction of environmental control technology.
The Operating Subsidiaries continue to study ways to reduce or meet future increases in customer demand, including aggressive demand- side management programs, new and efficient electric technologies, construction of various types and sizes of generating units and increasing the efficiency and availability of System generating facilities, reducing company electrical use and transmission and distribution losses, and where feasible and economical, acquisition of reliable long- term capacity from other electric systems and from nonutility developers.
The Operating Subsidiaries are implementing demand-side management activities. Potomac Edison and West Penn are engaged in state commission supported or ordered evaluations of demand-side management programs (See ITEM 1. REGULATION for a further discussion of these programs). Several jurisdictions have adopted mechanisms which provide for recovery of the costs of such activities, some return on the related investment, the associated revenue reductions and a performance incentive, either on a current basis or through deferral to a base rate case.
Current forecasts, which reflect demand-side management efforts and other considerations and assume normal weather conditions, project average annual winter and summer peak load growth rates of 1.47% and 1.28%, respectively, in the period 1994-2004. After giving effect to the reactivation of West Penn capacity in cold reserve (see page 9), peak diversity exchange arrangements described in ITEM 1. SALES above, demand- side management and conservation programs, and the capacity of an anticipated new PURPA plant, the System's integrated resource plan indicates that new System-owned generating capacity will not be required until the year 2000 or beyond. If future customer demand materially exceeds that forecast or anticipated supply-side resources do not become available or demand-side management efforts do not succeed, or under extremely adverse weather conditions, the Operating Subsidiaries may be unable at times to meet all of their customers' requirements for electric service.
In connection with their construction and demand- side management programs, the Operating Subsidiaries must make estimates of the availability and cost of capital as well as the future demands of their customers that are necessarily subject to regional, national, and international developments, changing business conditions, and other factors. The construction of facilities and their cost are affected by laws and regulations, lead times in manufacturing, availability of labor, materials and supplies, inflation, interest rates, and licensing, rate, environmental, and other proceedings before regulatory authorities. As a result, future plans of the Operating Subsidiaries, as well as their projected ownership of future generating stations, are subject to continuing review and substantial change.
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The Subsidiaries have financed their construction programs through internally generated funds, first mortgage bond, debenture, medium-term note and preferred stock issues, pollution control and solid waste disposal notes, instalment loans, long-term lease arrangements, equity investments by APS (or, in the case of AGC, by the Operating Subsidiaries), and, where necessary, interim short-term debt. Effective January 1994, the Operating Subsidiaries also have available a $300 million multi-year credit facility. The future ability of the Subsidiaries to finance their construction programs by these means depends on many factors, including rate levels sufficient to provide internally generated funds and adequate revenues to produce a satisfactory return on the common equity portion of the Subsidiaries' capital structures and to support their issuance of senior and other securities. APS obtains most of the funds for equity investments in the Operating Subsidiaries through the issuance and sale of its common stock publicly and through its Dividend Reinvestment and Stock Purchase Plan and its Employee Stock Ownership and Savings Plan.
In May 1993, Monongahela, Potomac Edison, and West Penn issued $10.68 million, $13.99 million, and $18.04 million, respectively, in solid waste disposal notes to Harrison County, West Virginia. Harrison County in turn issued $24.67 million of 6-1/4% and $18.04 million of 6.3% tax-exempt 30-year solid waste disposal revenue bonds. The Operating Subsidiaries are using the proceeds from the issuance to finance certain solid waste disposal facilities which comprise a portion of the scrubbers located at the Harrison Power Station.
On November 3, 1993, the holders of more than two-thirds of the shares of APS common stock voted to split the common stock by amending the charter to reclassify each share of common stock, par value $2.50, issued or unissued, into two shares of common stock, par value $1.25 each. The stock split became effective on November 4, 1993. All references to APS common stock herein reflect the two-for-one stock split.
On October 14, 1993, APS issued and sold 2,400,000 shares of its common stock in an underwritten offering with net proceeds to APS of $64.1 million, and in 1993 sold 1,364,846 shares of its common stock for $36.1 million through its Dividend Reinvestment and Stock Purchase Plan and its Employee Stock Ownership and Savings Plan.
In October 1993, Potomac Edison and West Penn issued and sold to APS 2,500,000 and 5,000,000 additional shares of each of their common stock, respectively, at a price of $20 per share.
During 1993, the rate for West Penn's 400,000 shares of market auction preferred stock, par value $100 per share, reset approximately every 90 days at 2.62%, 2.55%, 2.595% and 2.7%. The rate set at auction on January 14, 1994, was 2.52%.
In August 1993, Potomac Edison redeemed the remaining $404,600 of 4.70% Series B Preferred Stock outstanding.
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In 1993, the Subsidiaries issued $651.9 million of securities having interest rates between 4.95% and 7.75%, to refund outstanding debt with rates of 7.0% to 9.75%, with an annual after-tax savings in interest cost of almost $9 million. In February 1993, Potomac Edison issued $45 million of 7-3/4%, 30-year first mortgage bonds to refund $25 million, 8-5/8% series due 2007 and $15 million, 8-5/8% series due 2003. In March 1993, West Penn issued $61.5 million of 10-year, 4.95% Pollution Control Revenue Notes to refund $30 million, 9-3/4% series due 2003 and $31.5 million, 9-1/2% series due 2003. In March 1993, AGC issued $50 million of 5- 3/4% medium-term notes due in 1998 to refund $50 million, 8% debentures due in 1997. In March 1993, Potomac Edison issued $75 million of 5-7/8% first mortgage bonds due 2000 to refund $72 million of four series due 1998-2002 with rates ranging from 7% to 8- 3/8%. In April 1993, Monongahela, Potomac Edison and West Penn issued $7.05 million, $8.6 million, and $7.75 million, respectively, in 20-year Pollution Control Revenue Notes to Monongalia County, West Virginia. Monongalia County, in turn issued $23.4 million of 5.95%, 20-year Pollution Control Revenue Bonds to refund $23.4 million of three series due in 2013 with rates ranging from 9.375% to 9.5%. In April 1993, Monongahela issued $65 million of 5-5/8% first mortgage bonds due in 2000 to refund $60 million of three series due 1998-2002 with rates ranging from 7.5% to 8.125%. In June 1993, West Penn issued $102 million of 5-1/2% first mortgage bonds due in 1998 to refund $102 million of three series due 1997-1999 with rates ranging from 7% to 7-7/8%. Also in June 1993, West Penn issued $80 million of 6-3/8% first mortgage bonds due 2003 to refund $75 million of two series due 2001-2002 with rates of 7-5/8% and 8-1/8%. In September 1993, AGC issued $50 million of 5-5/8% debentures due 2003 and $100 million of 6-7/8% debentures due 2023 to refund $50 million, 8-3/4% debentures due 2017 and $100 million, 9-1/8% debentures due 2016.
At December 31, 1993, APS had $67.5 million and Monongahela had $63.1 million outstanding in short-term debt, and AGC had $50.87 million outstanding in commercial paper and notes payable to affiliates, while Potomac Edison and West Penn had short-term investments of $4.6 million and $24.9 million, respectively.
The Subsidiaries' ratios of earnings to fixed charges for the year ended December 31, 1993, were as follows: Monongahela, 3.49; Potomac Edison, 3.34; West Penn, 3.49; and AGC, 2.88.
APS and the Subsidiaries' consolidated capitalization ratios as of December 31, 1993, were: common equity, 46.1%; preferred stock, 6.5%; and long- term debt, 47.4%. APS and the Subsidiaries' long-term objective is to maintain the common equity portion above 45%, reduce the long-term debt portion toward 45%, and maintain the preferred stock ratio for the balance of the capital structure.
In January 1994, the Operating Subsidiaries jointly entered into an aggregate $300 million multi- year credit agreement with eighteen lenders. Each Operating Subsidiary's borrowings under the agreement are limited to its pro rata share of the stock of AGC, which stock was pledged to secure the credit agreement. The Operating Subsidiaries' percentage ownership of AGC and resulting borrowing limitations are: Monongahela 27%, $81,000,000; Potomac Edison 28%, $84,000,000; and West Penn 45%, $135,000,000. The agreement may be used as a supplement to or in lieu of public financings and short-term debt programs.
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During 1994, Monongahela, Potomac Edison and West Penn plan to issue up to $50 million, $75 million, and $105 million, respectively, of new securities, consisting of both debt and preferred and common equity, for general corporate purposes, including their construction programs. In addition, the Operating Subsidiaries may engage in tax-exempt solid waste disposal financings to the extent funds are available to Harrison County from the West Virginia cap allocation. APS plans to fund Operating Subsidiaries' sales of common stock to it through the issuance of short-term debt and the sale of APS' common stock through its Dividend Reinvestment and Stock Purchase Plan and Employee Stock Ownership and Savings Plan.
The Operating Subsidiaries, if economic and market conditions make it desirable, may refund during 1994 up to $550 million of first mortgage bonds, up to $100 million of preferred stock, and up to $78 million of pollution control revenue notes through tender offers or optional redemptions.
FUEL SUPPLY
System-operated stations burned approximately 15.7 million tons of coal in 1993. Of that amount, 67% was cleaned (6.7 million tons) or used in stations equipped with scrubbers (3.9 million tons). Use of desulfurization equipment and cleaning and blending of coal make burning local higher-sulfur coal practical, and in 1993 about 96% of the coal received at System stations came from mines in West Virginia, Pennsylvania, Maryland, and Ohio. The Operating Subsidiaries do not mine or clean any coal. All raw, clean or washed coal is purchased from various suppliers as necessary to meet station requirements.
Long-term arrangements, subject to price change, are in effect and will provide for approximately 12 million tons of coal in 1994. The System depends on short-term arrangements and spot purchases for its remaining requirements. Through the year 1999, the total coal requirements of present System-operated stations are expected to be met with coal acquired under existing contracts or from known suppliers.
The Operating Subsidiaries will meet the requirements of Phase I of the CAAA by installing scrubbers at Harrison Power Station. This will allow the continued use of local, high-sulfur coal there. A long-term contract for the supply of lime for use in the scrubber operation and for fixation of the scrubber byproduct has been negotiated and is expected to be signed in early 1994. It is expected that the use of lime will increase the costs of operating the station.
For each of the years 1989 through 1992, the average cost per ton of coal burned was, respectively, $34.64, $35.97, $36.74 and $36.31. For the year 1993, the cost per ton decreased to $36.19, and in December 1993 the cost per ton was $36.45.
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The labor agreement between the United Mine Workers of America (UMWA) and the Bituminous Coal Operators' Association (BCOA) expired on February 1, 1993. As a result, the UMWA initiated selective strikes against BCOA member companies on February 2, 1993. In late May and early June, numerous mines which serve the Operating Subsidiaries' power stations were closed down to various degrees. The UMWA and BCOA agreed to a new five year contract on December 14, 1993, and mining operations resumed at most mines during the week of December 20, 1993. The Operating Subsidiaries continued to meet customer needs during this approximately seven-month period through the use of existing low cost inventories, additional spot and substitute contract coal purchases, and some conservation measures, primarily at the Harrison Power Station.
The Operating Subsidiaries own coal reserves estimated to contain about 125 million tons of high- sulfur coal recoverable by deep mining. There are no present plans to mine these reserves and, in view of economic conditions now prevailing in the coal market, the Operating Subsidiaries plan to hold the reserves as a long-term resource.
RATE MATTERS
Rate case decisions in Pennsylvania and Maryland were issued for West Penn and Potomac Edison in May and February, 1993.
West Penn
On May 14, 1993, the Pennsylvania Public Utility Commission (PUC) issued an order in West Penn's base rate case effective May 18, 1993, authorizing an increase in revenues of $61.6 million, of which $26.1 million was for recovery of carrying charges (return on investment and taxes) associated with West Penn's CAAA compliance plan through June 30, 1993. West Penn had originally filed for a base rate increase designed to produce $101.4 million. West Penn received all maintenance expenses that it had requested, and a return on equity (ROE) of 11.5%.
West Penn filed a petition on January 12, 1994 with the PUC requesting authorization to accrue post in-service carrying charges on the Harrison scrubbers and to defer related depreciation and operating and maintenance expenses until they are recognized in rates. West Penn cannot predict the outcome of this proceeding.
West Penn plans to file an application with the PUC on or about March 31, 1994, for a base rate increase to recover the remaining carrying charges on investment, depreciation and all operating costs required to comply with Phase I of the CAAA, and other increasing levels of expense. It is expected that the new rates will become effective on or about December 31, 1994. West Penn cannot predict the precise amount to be requested or the outcome of this proceeding.
On February 20, 1992, the Commonwealth Court of Pennsylvania affirmed the PUC's December 13, 1990, decision relating to West Penn's challenge to the PUC's methodology for calculation of ROE. Three industrial customers also appealed to the Commonwealth Court that part of the PUC order which failed to allocate capacity costs of PURPA projects on a demand basis in West Penn's Energy Cost Rate. On June 25, 1992, the Commonwealth Court reversed the PUC's decision on this issue and remanded the case to the PUC for further proceedings. West Penn and other parties have negotiated a settlement on capacity costs of PURPA projects and other demand-related costs in West Penn's Energy Cost Rate, which settlement does not affect West Penn's revenues. The settlement agreement was approved by the PUC and was implemented in 1993.
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Monongahela
On January 18, 1994, Monongahela filed an application with the West Virginia Public Service Commission (West Virginia PSC) for a base rate increase designed to produce $61.3 million in additional annual revenues which includes recovery of the remaining carrying charges on investment, depreciation, and all operating costs required to comply with Phase I of the CAAA, and other increasing levels of expense. It is expected that a decision will be rendered about November 15, 1994, with increases to be effective immediately. Monongahela cannot predict the outcome of this proceeding.
Monongahela filed a petition on January 11, 1994, with the Public Utilities Commission of Ohio (PUCO) requesting authorization to accrue post-in-service carrying charges on the Harrison scrubbers until its investment in such scrubbers is recognized in rates. The petition also requested authorization for Monongahela to defer depreciation, and operating and maintenance expenses, including property taxes (but not including fuel costs) with respect to the scrubbers until the recovery of the deferrals can be addressed in Monongahela's next base rate case or otherwise, as the PUCO may deem appropriate. Monongahela is currently awaiting a decision on this petition. If the petition is approved, Monongahela will file its Ohio base rate case in early 1995.
Potomac Edison
The Maryland Public Service Commission (Maryland PSC) issued a final order in Potomac Edison's base rate case on February 24, 1993, authorizing an annual increase of $11.3 million, effective February 25, 1993, which included CAAA carrying charges through February 28, 1993. The original filing in July of 1992 was designed to produce approximately $23.0 million in additional annual revenues. Subsequent adjustments reduced this request to $17.6 million. Potomac Edison received most of the maintenance expenses that it had requested and a ROE of 11.9%.
On April 30, 1993, Potomac Edison filed with the Virginia State Corporation Commission (SCC) for a rate increase designed to produce $10.0 million in additional annual revenues. The new rates went into effect on September 28, 1993, subject to refund. Hearings have been held and a final SCC decision is expected by April 1994. Potomac Edison cannot predict the outcome of this proceeding.
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On January 14, 1994, Potomac Edison filed an application with the West Virginia PSC for a base rate increase designed to produce $12.2 million in additional annual revenues which includes recovery of the remaining carrying charges on investment, depreciation, and all operating costs required to comply with Phase I of the CAAA, and other increasing levels of expense. It is expected that a decision will be rendered about November 15, 1994, with increases to be effective immediately. Potomac Edison cannot predict the outcome of this proceeding.
On or about April 15, 1994, and June 30, 1994, Potomac Edison plans to file new rate cases in Maryland and Virginia, respectively. The amounts of the requested increases have not yet been determined, but they will include recovery of the remaining carrying charges on investment, depreciation, and all operating costs required to comply with Phase I of the CAAA, and other increasing levels of expense. It is expected that the Maryland decision will be rendered in late 1994, and the Virginia decision in mid-1995. However, in both jurisdictions, it is expected that increases will be effective in late 1994.
Monongahela and Potomac Edison
Pursuant to its order of December 12, 1991, approving Monongahela and Potomac Edison's plan for compliance with Phase I of the CAAA, the West Virginia PSC authorized recovery by Monongahela and Potomac Edison of $5.6 million and $1.4 million, respectively, of carrying charges on Phase I CAAA compliance costs through March 31, 1993, effective July 1, 1993. This brings the annual Phase I CAAA recovery for Monongahela and Potomac Edison to $8.7 million and $2.2 million, respectively. Pursuant to the order, Monongahela and Potomac Edison will submit requests for recovery of carrying charges through March 31, 1994, on Phase I CAAA compliance costs in the annual energy cost review proceedings with any increase to be effective July 1, 1994. The annual values of all CAAA revenues authorized in these proceedings will be removed from this collection process effective when full Phase I CAAA costs are included in base rates as a result of the 1994 rate case filings.
AGC
Through February 29, 1992, AGC's ROE was adjusted annually pursuant to a settlement agreement approved by the FERC. In December 1991, AGC filed for a continuation of the existing ROE of 11.53% and other parties filed to reduce the ROE to 10%. Hearings were completed in June 1992, and a recommendation has been issued by an Administrative Law Judge (ALJ) on December 21, 1993, for an ROE of 10.83%, which the other parties argue should be further adjusted to reflect changes in capital market conditions since the hearings. Exceptions to this recommendation have been filed by all parties for consideration by the full Commission. On January 28, 1994, the Consumer Advocate Division of the West Virginia PSC, Maryland People's Counsel, and Pennsylvania Office of Consumer Advocate filed a joint complaint with the FERC against AGC claiming that both the existing ROE of 11.53% and the ROE recommended by the ALJ of 10.83% are unjust and unreasonable. This new complaint requests an ROE of 8.53% with rates subject to refund beginning April 1, 1994. AGC cannot predict the outcome of these proceedings.
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FERC
West Penn, Potomac Edison, and Monongahela implemented settlement agreements in 1993 covering wholesale rates in effect for their municipal, co-op, and borderline agreement customers subject to the jurisdiction of the FERC. Each included carrying charges for work in progress on the scrubbers at the Harrison Power Station, additional expenses for postretirement benefits other than pensions (see below), and future automatic rate changes resulting from changes to taxes or tax rates (federal, state and local for Monongahela and West Penn, and federal for Potomac Edison). The amounts of the increases and the effective dates for West Penn, Potomac Edison, and Monongahela were $1.6 million on June 15, 1993; $1.5 million on September 15, 1993; and $0.6 million on December 1, 1993, respectively. It is anticipated that additional filings to include recovery of the remaining carrying charges on investment, depreciation, as well as all operating costs required to comply with Phase I of the CAAA, and other increasing levels of expense for each Operating Subsidiary will be made in 1994 with increases to be effective around the end of 1994.
Postretirement Benefits Other Than Pensions (SFAS No. 106)
The Operating Subsidiaries and APSC adopted SFAS No. 106 as of January 1, 1993. This requires all companies to accrue for the cost of postretirement benefits other than pensions (principally health care and life insurance) for the employee and covered dependents during the years that the employee renders the necessary service to receive such benefits. Prior to 1993, medical expenses and life insurance premiums paid by the Operating Subsidiaries and APSC for retired employees and their dependents were recovered in rates on a pay-as-you-go basis.
Recovery of SFAS No. 106 costs has been authorized for retail customers in Maryland effective in February 1993, in Pennsylvania effective in May 1993, and for FERC wholesale customers effective on the rate case effective date described above under ITEM 1. RATE MATTERS, FERC. Regulatory actions have been taken by the PUCO and Virginia PSC, which indicate that substantial recovery is probable. The West Virginia PSC considers recovery of SFAS No. 106 costs on a case- by-case basis and therefore Monongahela and Potomac Edison cannot predict the outcome of such proceedings. Recovery has been requested in rate cases filed in Virginia and West Virginia for which final commission decisions are expected in 1994. Recovery of these costs in Ohio will be requested in the next base rate case which is expected to be filed in early 1995. The Operating Subsidiaries are currently recovering approximately 85% of SFAS No. 106 expenses in rates. This reflects for West Virginia and Ohio only the recovery of the previously authorized pay-as-you-go component. The Operating Subsidiaries have recorded regulatory assets relating to those regulatory jurisdictions where full recovery of SFAS No. 106 level of expenses has not yet been granted recovery in rates. The Operating Subsidiaries do not anticipate that SFAS No. 106 will have a substantial effect on consolidated net income.
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ENVIRONMENTAL MATTERS
The operations of the Subsidiaries are subject to regulation as to air and water quality, hazardous and solid waste disposal, and other environmental matters by various federal, state, and local authorities.
Meeting known environmental standards is estimated to cost the Subsidiaries about $361 million in capital expenditures over the next three years, including $254 million for compliance with Phase I of the CAAA, described below, and initial cost for anticipated compliance with Phase II. The full costs of compliance with Phase II cannot be estimated at this time, but may be substantial. Additional legislation or regulatory control requirements, if enacted, may well require modifying, supplementing, or replacing equipment at existing stations at substantial additional cost.
Air Standards
The Operating Subsidiaries meet applicable standards as to particulates and opacity at major stations with high-efficiency electrostatic precipitators, cleaned coal, flue-gas conditioning, and, at times, reduction of output. From time to time minor excursions of opacity normal to fossil fuel operations are experienced and are accommodated by the regulatory process. In February 1994, three notices of violation were received by the Operating Subsidiaries from the West Virginia Division of Environmental Protection (WVDEP) regarding opacity excursions for three power stations in West Virginia. The Operating Subsidiaries are working with the WVDEP to resolve the alleged violations. It is not anticipated that the alleged violations will result in substantial penalties. At the major stations (other than Mitchell Unit No. 3 and Pleasants, which have scrubbers), the Operating Subsidiaries meet current emission standards as to sulfur dioxide by using low-sulfur coal, by purchasing cleaned coal to lower the sulfur content, or by blending low-sulfur with higher sulfur coal.
The CAAA, among other things, require an annual reduction in total utility emissions within the United States of 10 million tons of sulfur dioxide and two million tons of nitrogen oxides from 1980 emission levels, to be completed in two phases, Phase I and Phase II. Five coal-fired System plants are affected in Phase I and the remaining five coal-fired plants and any coal-fired plants or units reactivated in the future will be affected in Phase II. Installation of scrubbers at the Harrison Power Station is the strategy undertaken by the Operating Subsidiaries to meet the required sulfur dioxide emission reductions for Phase I (1995). Continuing studies will determine the compliance strategy for Phase II (2000). It is expected that burner modifications at all power stations will satisfy the nitrogen oxide emission reduction requirements for the acid rain (Title IV) provisions of the CAAA. Additional post-combustion controls may be mandated in Maryland and Pennsylvania for ozone nonattainment (Title I) reasons. Continuous emission monitoring equipment has been installed on all Phase I units and is being installed on Phase II units. Studies to evaluate cost effective options to comply with Phase II of the CAAA, including those which may be available from the use of Operating Subsidiaries' banked emission allowances and from the emission allowance trading market, are continuing.
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In an effort to introduce market forces into pollution control, the CAAA created sulfur dioxide emission allowances. An allowance is defined as an authorization for an owner to emit one ton of sulfur dioxide into the atmosphere during or following a specified calendar year. Subject to regulatory limitations, allowances (including bonus and extension allowances) not used by an owner for its own compliance may be sold or "banked" for future use or sale. Through an industry allowance pooling agreement, the Operating Subsidiaries will receive a total of approximately 570,000 bonus and extension allowances during Phase I. These allowances are in addition to the Table A allowances of approximately 356,000 per year.
As a result of EPA's 1993 auctioning of a number of Table A allowances retained from each utility's annual allotment, approximately 16,000 allowances were sold for the Operating Subsidiaries. Such auctions will be held every year for the foreseeable future and allowances sold thereby will result in a prorational allocation of revenues back to the Operating Subsidiaries. If some allowances offered at auction remain unsold, the balance will also be prorationally rebated to the utilities which contributed them. The proceeds from these auctions are expected to be relatively minimal and the Operating Subsidiaries plan to credit these proceeds against the capital cost of emission compliance activities, subject to regulatory approval. Other allowance trading activities may be undertaken by the Operating Subsidiaries once certain tax questions are answered and once studies to determine Phase II compliance strategy are completed.
In 1989, the West Virginia Air Pollution Control Commission approved the construction of a cogeneration facility in the vicinity of Rivesville, West Virginia. Emissions impact modeling for that facility raised concerns about the compliance status of Monongahela's Rivesville Station with the National Ambient Air Quality Standards (NAAQS) for sulfur dioxide. Pursuant to a consent order, Monongahela agreed to collect on- site meteorological data and conduct additional dispersion modeling in order to demonstrate compliance. The modeling study and a compliance strategy recommending construction of a new "good engineering practices" (GEP) stack was submitted to the WVDEP in June 1993. Costs associated with the GEP stack are approximately $7 million. Monongahela is awaiting action by the WVDEP.
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Under an EPA-approved consent order with Pennsylvania, West Penn completed construction of a GEP stack at the Armstrong Station in 1982 at a cost of over $13 million with the expectation that EPA's reclassification of Armstrong County to "attainment status" under NAAQS for sulfur dioxide would follow. As a result of the 1985 revision of its stack height rules, EPA refused to reclassify the area to attainment status. West Penn appealed the EPA's decision. In 1988, the U. S. Court of Appeals for the Third Circuit dismissed West Penn's appeal for lack of jurisdiction, stating that West Penn's request for reconsideration before EPA made EPA's denial a non-final agency action. West Penn's request for reconsideration before EPA remains pending. West Penn cannot predict the outcome of this proceeding.
Water Standards
Under the National Pollutant Discharge Elimination System (NPDES) permitting procedures, permits for all System-owned stations are in place. However, in proposed NPDES renewal permits for some stations which are currently being sought, some conditions are being appealed through the regulatory process since the Operating Subsidiaries believe the effluent limitations being applied are overly stringent. The Operating Subsidiaries continue to work with the appropriate state agencies to resolve these issues. In the meantime, the existing permits remain in effect during the appeal process.
The EPA and states are now implementing stormwater runoff regulations for controlling discharges from industrial and municipal sources as well as construction sites. Stormwater discharges have been identified and included in NPDES renewals, but controls have not yet been required. Since the current round of permit renewals began in 1993, monitoring requirements have been imposed, with pollution reduction plans and additional control of some discharges anticipated.
Pursuant to the National Groundwater Protection Strategy, which supplements existing West Virginia groundwater protection policy, West Virginia has adopted a Groundwater Protection Act. This law establishes a statewide antidegradation policy which could require the Operating Subsidiaries to undertake reconstruction of existing landfills and surface impoundments as well as groundwater remediation, and may affect herbicide use for right-of-way maintenance in West Virginia. Groundwater protection standards were approved and implemented in 1993 (based on EPA drinking water criteria) which established compliance limits which cannot be exceeded. The Operating Subsidiaries anticipate that some facilities will not be able to meet the new compliance limits. Variance requests and requests for stays of implementation have been made for all affected facilities. However, variance rules have not yet been promulgated and action on the requests has not been taken. Therefore, it is not possible to predict the difficulty and costs associated with obtaining variances. If variances are not granted, costs may be incurred by the Operating Subsidiaries for groundwater remediation. Such costs, if any, cannot be predicted at this time.
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The Pennsylvania Department of Environmental Resources (PADER) developed a Groundwater Quality Protection Strategy which established a goal of nondegradation of groundwater quality. However, the strategy recognizes that there are technical and economic limitations to immediately achieving the goal and further recognizes that some groundwaters need greater protection than others. The PADER is beginning to implement the strategy by promulgating changes to the existing rules that heretofore did not consider the nondegradation goal. The full extent of the impact of the strategy on the Operating Subsidiaries cannot be anticipated at this time.
In 1993, two notices of violation were received by the Operating Subsidiaries from the WVDEP regarding excursions above limits contained in NPDES permits for discharge of leachate from fly ash landfills in West Virginia. One violation notice was withdrawn by the state agency and the other was resolved without payment of substantial penalty. On January 27, 1994 and February 9, 1994, the Operating Subsidiaries received two separate notices of violation from PADER regarding excursions above limits contained in the NPDES permit for discharge of leachate from Hatfield's Ferry Power Station fly ash landfill. One violation notice was resolved without payment of substantial penalty. The Operating Subsidiaries are working with the PADER to resolve the other alleged violation. It is not anticipated that the alleged violation will result in substantial penalties.
Hazardous and Solid Wastes
Pursuant to the Resource Conservation and Recovery Act of 1976 and the Hazardous and Solid Waste Management Amendments of 1984 (RCRA), EPA regulates the disposal of hazardous and solid waste materials. Pennsylvania, West Virginia, Maryland, Ohio, and Virginia have also enacted hazardous and solid waste management legislation.
With the installation of the scrubbers at the Harrison Power Station, approximately 2.8 million tons per year of scrubber sludge, consisting principally of limestone and ash, will be generated and disposed of in a disposal facility owned and operated by the Operating Subsidiaries. The expected capacity of the site is 30 years. Pleasants Power Station processes its scrubber sludge using a wet-fixation and slurry system, with the treated sludge disposed of in a properly permitted sludge pond. Mitchell and Harrison Power Stations process their scrubber sludge by a dry-fixation process with the stabilized sludge disposed of in a properly permitted landfill. Coal combustion byproducts from all other facilities are either sold for beneficial reuse or landfilled in properly permitted and currently adequate disposal facilities owned and operated by the Operating Subsidiaries. The Operating Subsidiaries are in the process of permitting additional capacity to meet future disposal needs.
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Costs are being incurred as the Operating Subsidiaries progress with implementation of both West Virginia's and Pennsylvania's 1992 solid waste regulatory changes. A predominant portion of the costs are attributable to two major factors: 1) liner systems for new disposal sites and the expansion portion of existing disposal sites, and 2) the assessment of groundwater impacts via monitoring wells. Because past operating practices, while in compliance with then existing regulations, may not meet the current criteria, as measured by new standards, it is possible that groundwater remediation may be required at some of the Operating Subsidiaries' facilities. In addition, under West Virginia's Solid Waste Rules, it is possible that certain active disposal sites may have to be retrofitted with liner systems to address potential groundwater degradation. The draft permit renewal from WVDEP for the currently active disposal site at Albright Power Station requires, on a portion of the site, retrofitting with a new liner system with possible removal of already placed coal combustion byproducts. The Operating Subsidiaries are working to have this proposed permit condition removed; however if it is not, it is anticipated that this condition will be appealed.
EPA regulations on the burning of hazardous waste in utility boilers are expected to be amended in 1994 making the practice cost prohibitive for the Operating Subsidiaries. Until such time as the regulations are amended, the Operating Subsidiaries will continue to minimize their hazardous waste and to burn small quantities of hazardous waste generated in accordance with EPA boiler and industrial furnace disposal rules. Once such regulations are amended, the low volume wastes will be disposed of in incinerators or landfills which are owned by third parties. None of the Operating Subsidiaries are required to obtain hazardous waste treatment, storage or disposal permits under RCRA. With a continued effort to reduce hazardous waste, disposal costs and potential environmental liability should be minimized.
Potomac Edison has received a notice from the Maryland Department of the Environment (MDE) regarding a remediation ordered under Maryland law at a facility previously owned by Potomac Edison. The MDE has identified Potomac Edison as a potentially responsible party under Maryland law. Remediation is currently being implemented by the current owner of the facility in Frederick, Maryland. It is not anticipated that Potomac Edison's share of remediation costs, if any, will be substantial.
Emerging Environmental Issues
Title I of the CAAA establishes an ozone transport region consisting of 11 northeast states including Maryland and Pennsylvania. Sources within the region will be required to reduce nitrogen oxide emissions, a precursor of ozone, to a level conducive to attainment of the ambient ozone standard. The first step for Title I compliance will result in the installation of low nitrogen oxide burners and potentially overfire air at all Pennsylvania and Maryland stations by 1995. This is compatible with Title IV nitrogen oxide reduction requirements. Modeling studies being conducted by the states will determine if a second step of reductions will be necessary which could require installation of post- combustion control technologies.
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Title III of the CAAA requires EPA to conduct studies of toxic air pollutants from utility plants to determine if emission controls are necessary. EPA's reports are expected to be submitted to Congress in late 1995.
The impact of Titles I and III on the Operating Subsidiaries is unknown at this time.
Both the CWA and the RCRA are expected to be reauthorized in 1994. It is anticipated that coal combustion byproducts will continue to be regulated as nonhazardous waste, minimizing the Operating Subsidiaries' disposal costs.
An additional issue which could impact the Operating Subsidiaries and which is undergoing intense study, is the effect, if any, of electric and magnetic fields. The financial impact of this issue on the Operating Subsidiaries, if any, cannot be assessed at this time.
In connection with President Clinton's Climate Change Action Plan concerning greenhouse gases, the Operating Subsidiaries expressed by letter to the DOE in August 1993, their willingness to work with the DOE on implementing voluntary, cost-effective courses of action that reduce or avoid emission of greenhouse gases. Such courses of action must take into account the unique circumstances of each participating company, such as growth requirements, fuel mix and other circumstances. Furthermore, they must be consistent with the Operating Subsidiaries' integrated resource planning process and must not have an adverse effect on competitive position in terms of costs and rates or be unacceptable to their regulators. Some 63 other utility systems submitted similar letters.
REGULATION
APS and the Subsidiaries are subject to the broad jurisdiction of the Securities and Exchange Commission (SEC) under the Public Utility Holding Company Act of 1935 (PUHCA). APS is also subject to the jurisdiction of the Maryland PSC as to certain of its activities. The Subsidiaries are regulated as to substantially all of their operations by regulatory commissions in the states in which they operate and also by the DOE and the FERC. In addition, they are subject to numerous other city, county, state, and federal laws, regulations, and rules.
EPACT became law on October 24, 1992. This broad legislation, among other things, amends PUHCA to permit utilities subject to PUHCA to compete in the wholesale generation business with other wholesale generators which it exempts from PUHCA; to ease restrictions on financing for that purpose; and to permit investment in foreign utilities. EPACT also amends the Federal Power Act to permit the FERC to order, under specified circumstances, access to transmission systems (including those of the System) so long as it would not unreasonably impair reliability nor adversely affect its existing wholesale, retail and transmission customers. It also amends PURPA to encourage states to study and regulate various matters, including the capital structures of EWGs, integrated resource planning, and the amount of purchased power that electric utilities should have in their generation mix. EPACT also sets forth waste disposal standards, new nuclear licensing procedures, and contains provisions promoting alternate transportation fuels, research on environmental issues, and increased energy from renewables (See discussion of EPACT in ITEM 1. BUSINESS, SALES and ELECTRIC FACILITIES).
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Pursuant to the requirements of Section 712 of EPACT, the Maryland, Ohio, Pennsylvania, Virginia, and West Virginia commissions issued orders regarding four broad economic and regulatory policy issues related to the purchase of wholesale power. All of the commissions decided to evaluate these issues on a case- by-case basis or within their existing regulatory framework, instead of establishing generic standards.
On January 24, 1994, the Maryland PSC issued an order which instituted a proceeding for the purpose of determining whether to implement standards which, under EPACT, a state commission must consider in order to encourage integrated resource planning and investments in conservation and energy efficiency by electric utilities. The order provides for the filing of initial and reply comments and for a hearing on May 3, 1994. Potomac Edison intervened and will be submitting comments in this proceeding.
Under EPACT, the FERC has initiated several proceedings, one of the most significant being the request for comments on transmission pricing, including pricing as it may apply to parallel power flows. The Operating Subsidiaries have developed and submitted a pricing philosophy intended to meet certain goals, including reliable operation of the transmission system and protection of native load customers, while promoting accurate price signals and offering third- party transmission service at the lowest reasonable rates. Other FERC initiatives included the issuance of guidelines governing open access transmission requests and rules governing the establishment of Regional Transmission Groups.
The Operating Subsidiaries founded and continue to participate in, along with other utilities, an organization whose primary purpose is to develop a mutually acceptable method of resolving the inequities imposed on transmission network owners by parallel power flows.
The SEC has also issued regulations and proposed regulations to implement EPACT, including the integration of EPACT with PUCHA and the effect of EPACT on nonexempt PUCHA companies such as APS and its Subsidiaries.
In July 1993, the PUC directed the Bureau of Conservation, Economics and Energy Planning to develop competitive bidding regulations to replace, at least in part, the existing state PURPA regulations. In November 1993, West Penn filed a petition with the PUC requesting an Order that, pending the revision and replacement of the existing state PURPA regulations, any proceedings or orders regarding purchase by West Penn of capacity from a qualifying facility under PURPA shall be based on competitive bidding. The Office of Consumer Advocate, the Office of Small Business Advocate, the West Penn Power Industrial Intervenors, and West Penn's two largest industrial customers have intervened in support of West Penn's position. Several PURPA developers and a group purporting to represent PURPA interests have filed in opposition to certain parts of the petition. West Penn cannot predict the outcome of this proceeding.
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On October 8, 1993, the West Virginia PSC issued proposed regulations concerning bidding procedures for capacity additions for electric utilities and invited comment by December 7, 1993. A number of interested parties, including Monongahela and Potomac Edison, filed comments. The West Virginia PSC has taken no further action since the filing of comments.
On December 17, 1992, the PUCO issued proposed rules concerning competitive bidding for supply-side resources, transmission access for winning bidders and incentives for the recovery of the cost of purchased power. The PUCO invited comments by March 3, 1993 and reply comments by March 24, 1993. A number of interested parties, including Monongahela, submitted comments. The PUCO has taken no further action following the filing of comments.
Maryland and Virginia have not mandated compulsory competitive bidding at this date.
The Omnibus Budget Reconciliation Act of 1993 increased the marginal corporate income tax rate from 34% to 35%, retroactive to January 1, 1993. As a result, the Operating Subsidiaries' income tax expense for 1993 increased by about $3 million.
On June 13, 1990, the Maryland PSC began an investigation to determine whether Potomac Edison's methodology for calculating avoided costs under PURPA is appropriate. On October 11, 1991, the Maryland PSC incorporated this review of avoided costs into a collaborative process already formed between its Staff, the Maryland Department of Natural Resources, Potomac Edison, Eastalco Aluminum, the Maryland Energy Administration, and the Office of People's Counsel. Although the group's primary mission was to avoid litigation by working cooperatively to develop demand- side management programs, the issue of avoided costs was addressed because avoided costs are needed for determining the cost-effectiveness of programs. These negotiations culminated in a Settlement Agreement which was signed by the six parties and filed with the Maryland PSC on October 14, 1993. The Hearing Examiner issued a proposed order accepting the Settlement Agreement on November 17, 1993. The proposed order became final on December 17, 1993, thereby concluding this proceeding.
In October 1990, the PUC ordered Pennsylvania's major electric utilities, including West Penn, to file programs for demand-side management designed to reduce customer demand for electricity and to reduce the need for additional generating capacity. The PUC's order proposed that the affected utilities receive full recovery of the costs of approved programs, as well as financial incentives for implementing such programs, including recovery of lost revenues. West Penn filed its proposed programs with the PUC. On December 13, 1993, the PUC entered an order which provides for the recovery of program costs either through a surcharge or deferral to a base rate case; the recovery of revenues lost due to the implementation of demand-side management programs through a base rate case; and the award of incentives for good program performance or the assessment of penalties for poor performance. Two parties to this proceeding have petitioned the PUC for reconsideration and clarification and the Pennsylvania Industrial Energy Coalition has filed an appeal with the Commonwealth Court of Pennsylvania. West Penn cannot predict the final outcome of this proceeding.
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During 1993, Potomac Edison continued its participation in the Collaborative Process for demand- side management in Maryland with the Maryland PSC Staff, Office of People's Counsel, the Department of Natural Resources, Maryland Energy Administration, and Potomac Edison's largest industrial customer. Potomac Edison received the Maryland PSC's approval to implement a Commercial and Industrial Lighting Rebate Program as of July 1, 1993. Through December 31, 1993 Potomac Edison had received applications for $7.5 million in rebates related to the commercial lighting program. Program costs, including rebates and lost revenues, are deferred and are to be recovered through an energy conservation surcharge over a five-year period.
ITEM 2.



ITEM 2. PROPERTIES
Substantially all of the properties of the Operating Subsidiaries are held subject to the lien securing each company's first mortgage bonds and, in many cases, subject to certain reservations, minor encumbrances, and title defects which do not materially interfere with their use. Some properties are also subject to a second lien securing certain solid waste disposal and pollution control notes. The indenture under which AGC's unsecured debentures and medium-term notes are issued, prohibits AGC, with certain limited exceptions, from incurring or permitting liens to exist on any of its properties or assets unless the debentures and medium-term notes are contemporaneously secured equally and ratably with all other indebtedness secured by such lien. Transmission and distribution lines, in substantial part, some substations and switching stations, and some ancillary facilities at power stations are on lands of others, in some cases by sufferance, but in most instances pursuant to leases, easements, permits or other arrangements, many of which have not been recorded and some of which are not evidenced by formal grants. In some cases no examination of titles has been made as to lands on which transmission and distribution lines and substations are located. Each of the Operating Subsidiaries possesses the power of eminent domain with respect to its public utility operations. (See also ITEM 1. BUSINESS and SYSTEM MAP.)
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ITEM 3.

ITEM 3. LEGAL PROCEEDINGS
In 1979, National Steel Corporation (National Steel) filed suit against certain Subsidiaries in the Circuit Court of Hancock County, West Virginia, alleging damages of approximately $7.9 million as a result of an order issued by the West Virginia PSC requiring curtailment of the plaintiff's use of electric power during the United Mine Workers' strike of 1977-8. A jury verdict in favor of the defendants was rendered in June 1991. National Steel has filed a motion for a new trial, which is still pending before the Circuit Court of Hancock County. The Subsidiaries believe the motion is without merit; however, they cannot predict the outcome of this case.
In 1987, West Penn entered into separate agreements with developers of four PURPA projects: Milesburg (43 MW), Burgettstown (80 MW), Shannopin (80 MW) and Point Marion (2 MW). The agreements provided for the purchase of each project's power over 30 years or more at rates generally approximating West Penn's avoided costs at the time the agreements were negotiated, as defined by PURPA. Yearly capacity payments under the four agreements would total in excess of $50 million. Each agreement was subject to prior PUC approval of the pass-through to West Penn's customers of the total cost incurred under each agreement, on a current basis. In 1987 and 1988, West Penn filed a separate petition with the PUC for each agreement requesting an appropriate PUC order, and various parties intervened. Since that time, all four agreements have been, in varying degrees, the subject of complex and continuing regulatory and judicial proceedings. During 1993, West Penn entered into a settlement agreement with Point Marion and that project has been terminated.
On November 24, 1993, the Pennsylvania Supreme Court issued a per curiam opinion regarding the Milesburg project which upheld the decision of the Commonwealth Court concerning the time frame for the calculation of avoided cost and upheld the decision that the PUC had the authority under PURPA to revise and reinstate a lapsed power purchase contract. West Penn is considering its options as a result of this ruling, including a petition for certiorari to the United States Supreme Court.
On December 30, 1993, the Pennsylvania Supreme Court issued a per curiam opinion regarding the Shannopin project which upheld the decision of the Commonwealth Court affirming the PUC's authority under PURPA to revise voluntarily negotiated power purchase contracts. West Penn is considering its options as a result of this ruling, including a petition for certiorari to the United States Supreme Court. As of December 31, 1993, petitions for allowance of an appeal of the decision of the Pennsylvania Commonwealth Court on the Burgettstown project were pending before the Pennsylvania Supreme Court. West Penn cannot predict the outcome of these proceedings.
On October 28, 1993, South River Power Partners, L.P. ("South River") filed a complaint against West Penn with the PUC. The complaint seeks to require West Penn to purchase 240 MW from a proposed coal-fired PURPA project which South River proposes to build in Fayette County, Pennsylvania. South River's proposed initial price for this power would be over $0.09 per kWh. West Penn is opposing this complaint as the power is not needed and the price is in excess of avoided cost. The Pennsylvania Consumer Advocate, the Small Business Advocate, the PUC Trial Staff and various industrial customers have also intervened in opposition to the complaint. West Penn cannot predict the outcome of this proceeding.
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Two previously reported complaints had been filed with the West Virginia PSC by developers of cogeneration projects in Marshall and Barbour Counties, West Virginia to require Monongahela and Potomac Edison to purchase capacity from the projects. These two cases were consolidated. The West Virginia PSC on March 5, 1993, found that: Monongahela had no need for additional capacity; Potomac Edison will need new combustion turbine generating capacity beginning in 1996; and Potomac Edison's avoided cost estimate, which is substantially below the costs sought by the developers of the projects, is reasonable. The developers have asked the West Virginia PSC to consider issues not resolved in the March 5, 1993 order. On June 25, 1993 the West Virginia PSC found that Potomac Edison had a PURPA obligation to purchase power from qualifying facilities properly interconnected to the System in Monongahela's service territory and ordered negotiations by Monongahela and Potomac Edison with the two PURPA developers. On August 9, 1993, the West Virginia PSC deconsolidated the two cases. Following the West Virginia Supreme Court's denial of a petition for review of this order, both developers requested the start of negotiations. Monongahela and Potomac Edison cannot predict the outcome of these proceedings.
On November 16, 1992, Potomac Edison and the developer of a proposed cogeneration project located in Cumberland, Maryland, requested that the Maryland PSC approve an amendment to a previously approved agreement for the sale of 180 MW of capacity and associated energy from the project to Potomac Edison. The amendment provides for the relocation of the proposed project within the Cumberland area; a delay of one year in the project's earliest in-service date to October 1, 1996, without increase in the initial capacity rate (which otherwise escalates annually at one-half the rate of actual inflation); and other changes consistent with the site and in-service date modifications. The Maryland PSC commenced an investigation of the amendment in December 1992. After hearings, the parties reached a settlement which was approved by the Maryland PSC on March 17, 1993. The settlement agreement resulted in a further delay of the project's in-service date to October 1, 1999, modified the initial capacity rate with only a slight escalation, and provided that Potomac Edison would pay, and recover from customers by a surcharge, a portion of the project's costs resulting from the delay. On December 22, 1993, the Maryland PSC approved the surcharge and these costs are being recovered from customers effective January 1, 1994.
As previously reported, effective March 1, 1989, West Virginia enacted a new method for calculating the Business and Occupation Tax (B & O Tax) on electricity generated in that state, which disproportionately increased the B & O Tax on shipments of electricity to other states. In 1989, West Penn, the Pennsylvania Consumer Advocate, and several West Penn industrial customers filed a joint complaint in the Circuit Court of Kanawha County, West Virginia seeking to have the B & O Tax declared illegal and unconstitutional on the grounds that it violates the Interstate Commerce Clause and the Equal Protection Clause of the federal Constitution and certain provisions of federal law that bar the states from imposing or assessing taxes on the generation or transmission of electricity that discriminate against out-of-state entities. In 1991, West Penn amended the complaint to include a 1990 increase in the rate of the B & O Tax. The trial was held in July 1993 and briefs have been filed. West Penn cannot predict the outcome of this litigation.
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As of January 1994, Monongahela has been named as a defendant along with multiple other defendants in 1,429 pending asbestos cases involving multiple plaintiffs and Monongahela, Potomac Edison and West Penn have been named as defendants along with multiple defendants in an additional 626 cases by multiple plaintiffs. Because these cases are filed by "shot- gun" complaints naming many plaintiffs and many defendants, it is presently impossible to determine the actual number of claims against the Operating Subsidiaries. However, based on past experience and data available to date, it is estimated that less than 600 cases actually involve claims against any or all of the Operating Subsidiaries. All complaints allege that the plaintiffs sustained unspecified injuries resulting from claimed exposure to asbestos in various generating plants and other industrial facilities operated by the various defendants, although all plaintiffs do not claim exposure at facilities operated by all defendants. All plaintiffs claiming exposure at Subsidiary-operated stations were employed by third- party contractors, with the exception of three who claim to have been employees of Monongahela. Each plaintiff generally seeks compensatory and punitive damages against all defendants in amounts of up to $1 million and $3 million, respectively; in those cases that include a spousal claim for loss of consortium, damages are generally sought against all defendants in an amount of up to $1 million for the loss of consortium claim. Therefore, because of the multiple defendants, the Operating Subsidiaries believe potential liability of the Operating Subsidiaries is a very small percentage of the total amount of the damages sought. A total of 94 cases have been previously settled by Monongahela for an amount substantially less than the anticipated cost of defense. While the Operating Subsidiaries believe that all of these cases are without merit, they cannot predict the outcome of these cases or whether other cases will be filed.
On March 4, 1994, the Operating Subsidiaries received notice that the EPA had identified them as potentially responsible parties ("PRPs") under the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended ("CERCLA"), with respect to the Jack's Creek/Sitkin Smelting Superfund Site ("Site"). The Operating Subsidiaries are among some 880 PRPs that have been identified at the Site. EPA is planning to issue a Proposed Plan and Record of Decision in September 1994 delineating the remedy selected for the Site. At this time it is not possible to determine what liability, if any, the Operating Subsidiaries may have regarding the Site.
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In 1970, the Operating Subsidiaries filed with the Federal Power Commission (FPC) an application for a license to build a 1,000-MW energy-storage facility near Davis, West Virginia. In 1977, FPC issued a license for the project, but various parties, including the State of West Virginia and the U.S. Department of Interior, filed appeals, which are now pending before the U.S. Court of Appeals for the District of Columbia. The U.S. Army Corps of Engineers (Corps) denied a dredge and fill permit for the project, which decision was appealed. The U.S. District Court for the District of Columbia decided that the Corps had no jurisdiction in the matter. The Corps filed an appeal with the U.S. Court of Appeals for the District of Columbia. In 1987, the appellate Court decided that the Corps did have jurisdiction and remanded the case to the U.S. District Court for further consideration of the Corps' denial of the permit. The U. S. Supreme Court refused to review that decision. In 1988, the U.S. District Court reversed the Corps' denial of the dredge and fill permit. The District Court's decision, which has now been appealed, found, among other things, that the Operating Subsidiaries were denied an opportunity to review and comment upon written materials and other communications used by the Corps in making its decision, and as a result the Court remanded the matter to the Corps for further proceedings. Negotiations are ongoing to settle this matter. The Operating Subsidiaries cannot predict the outcome of these proceedings.
ITEM 4.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
The holders of 46,537,924 shares of common stock of APS voted at a special meeting held on November 3, 1993 to amend APS' charter to reclassify each share of common stock, par value $2.50 per share, issued or unissued, into two shares of common stock, par value $1.25 each. The holder of 259,451 shares voted against the proposal and the holders of 296,598 shares abstained. The charter amendment became effective at the close of business on November 4, 1993. The amount of APS' stated capital was not changed as a result of the amendment.
The holder of the common stock of Monongahela on December 13, 1993, waived the holding of a meeting and consented in writing to the amendment of its Charter to reflect the redemption of 50,000 shares of $9.64 series cumulative preferred stock.
No other company submitted matters to a vote of shareholders during the fourth quarter.
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Executive Officers of the Registrants
The names of the executive officers of each company, their ages, the positions they hold and their business experience during the past five years appears below:
(a) All officers and directors are elected annually.
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(a) All officers and directors are elected annually.
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(a) All officers and directors are elected annually.
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PART II
ITEM 5.

ITEM 5. MARKET FOR THE REGISTRANTS' COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
APS.
AYP is the trading symbol of the common stock of APS on the New York, Chicago, and Pacific Stock Exchanges. The stock is also traded on the Amsterdam (Netherlands) and other stock exchanges. As of December 31, 1993, there were 63,396 holders of record of APS' common stock.
The tables below show the dividends paid and the high and low sale prices of the common stock for the periods indicated:
The high and low prices in 1994 were 26-1/2 and 24-1/8 through February 3. The last reported sale on that date was at 25.
Monongahela, Potomac Edison, and West Penn. The information required by this Item is not applicable as all the common stock of these Subsidiaries is held by APS.
AGC. The information required by this Item is not applicable as all the common stock of AGC is held by Monongahela, Potomac Edison, and West Penn.
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ITEM 6.

ITEM 6. SELECTED FINANCIAL DATA
Page No.
APS D-1 Monongahela D-3 Potomac D-5 West Penn D-7 AGC D-9
D-1
D-2
(a) Reflects a two-for-one common stock split effective November 4, 1993. (b) Capability available through contractual arrangements with nonutility generators. (c) Preliminary.
D-3
D-3
(a) Capability available through contractual arrangements with nonutility generators.
D-5
D-6
D-7
D-8
(a) Capability available through contractual arrangements with nonutility generators.
D-9
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ITEM 7.

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Page No.
APS M-1 Monongahela M-9 Potomac M-18 West Penn M-27 AGC M-36
M-1 APS MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
CONSOLIDATED NET INCOME Earnings per share were $1.88 in 1993 and were $1.83 and $1.80 in 1992 and 1991. Consolidated net income was $215.8 million, $203.5 million, and $194.0 million. The increase in consolidated net income in 1993 resulted primarily from kWh sales and retail rate increases. The increase in 1992 resulted primarily from retail rate increases. These revenue increases, in both years, were offset in part by higher expenses. All per share amounts have been adjusted to reflect the November 4, 1993, two-for-one stock split (See Note F to the consolidated financial statements).
SALES AND REVENUES KWh sales to and revenues from residential, commercial, and industrial customers are shown on page D-2. Such kWh sales increased 3.3% and 1.5% in 1993 and 1992, respectively. The increases in revenues from sales to residential, commercial, and industrial customers resulted from the following: Increase from Prior Year 1993 1992 (Millions of Dollars) Increased kWh sales $ 46.6 $ 9.1 Fuel and energy cost adjustment clauses (a) 57.0 37.9 Rate increases (b): Pennsylvania 25.2 5.8 Maryland 12.7 11.7 West Virginia 5.3 12.4 Virginia 2.5 1.8 Ohio 2.1 1.7 47.8 33.4 Other 6.2 .1 $157.6 $80.5 (a) Changes in revenues from fuel and energy cost adjustment clauses have little effect on consolidated net income. (b) See ITEM 1. RATE MATTERS for further information on rate changes.
The increased kWh sales to residential and commercial customers in 1993 reflect both growth in number of customers and higher use. While 1993 heating degree days showed only a slight increase over 1992, and were approximately normal, cooling degree days increased 69% over 1992 and were 25% over normal, contributing to the 1993 kWh sales increases. The subsidiaries experienced a mild winter in the first quarter of 1992 followed by a much cooler than normal summer and early fall. As a result, weather had a negative impact on 1992 sales to retail customers.
M -2
KWh sales to industrial customers increased .3% in 1993 and 2.9% in 1992. The relatively flat industrial sales growth in 1993 followed record industrial sales in 1992 which occurred in almost all industrial groups. One particular group, coal mines staffed by union personnel, recorded reduced usage because of selective work stoppages by the United Mine Workers of America (UMWA) for most of the year prior to the settling of the dispute in December 1993.
KWh sales to and revenues from nonaffiliated utilities are comprised of the following items: 1993 1992 1991 KWh sales (in billions): From subsidiaries' generation 1.2 3.2 5.8 From purchased power 11.2 14.6 12.4 12.4 17.8 18.2 Revenues (in millions): From subsidiaries' generation $ 28.5 $ 91.7 $158.5 From sales of purchased power 318.2 373.8 366.5 $346.7 $465.5 $525.0
Decreased sales to nonaffiliated utilities resulted primarily from decreased demand and continuing price competition. Sales supplied by subsidiaries' generation in 1993 decreased to less than 15% of 1988 levels because of continuing growth of kWh sales to retail customers, which reduces the amount available for sale, and because other suppliers were willing or able to make the sales at lower prices. A significant factor affecting the subsidiaries' ability to compete in the market for sales to nonaffiliated utilities has been the approximate 290% increase (from about 67 cents per MWh to $2.60 per MWh) in taxes on generation in West Virginia since March 1989--a significant cost not experienced by utilities not generating in West Virginia. Further decreases in these sales are anticipated in 1994 before leveling off. About 95% of the aggregate benefits from sales to nonaffiliated utilities is passed on to retail customers and has little effect on consolidated net income.
The decrease in other revenues in 1993 resulted from an agreement with the Federal Energy Regulatory Commission to record in 1993 about $14 million of revenues as sales to nonaffiliated utilities. Similar transactions were recorded as other revenues in prior years.
M -3 OPERATING EXPENSES Fuel expenses decreased 4% in 1993 and 6% in 1992. Both decreases were primarily due to decreases in kWh generated. The 1992 decrease also included a 1% decrease in average coal prices. Fuel expenses are primarily subject to deferred power cost accounting procedures, as described in Note A to the consolidated financial statements, with the result that changes in fuel expenses have little effect on consolidated net income.
"Purchased power and exchanges, net" represents power purchases from and exchanges with other utilities and qualified facilities under the Public Utility Regulatory Policies Act of 1978 (PURPA) and is comprised of the following items: 1993 1992 1991 (Millions of Dollars) Purchased power: For resale to other utilities $280.9 $344.0 $332.7 From PURPA generation 105.2 94.0 68.9 Other 33.8 12.7 29.0 Total power purchased 419.9 450.7 430.6 Power exchanges, net (2.5) .7 (1.4) $417.4 $451.4 $429.2
The amount of power purchased from other utilities for use by subsidiaries and for resale to other utilities depends upon the availability of the subsidiaries' generating equipment, transmission capacity, and fuel, and their cost of generation and the cost of operations of other utilities from which such purchases are made. The primary reason for the fluctuations in purchases for resale to other utilities is described under SALES AND REVENUES above. The cost of power purchased for use by the subsidiaries, including power from PURPA generation, is mostly recovered from customers currently through the regular fuel and energy cost recovery procedures followed by the subsidiaries' regulatory commissions and is primarily subject to deferred power cost procedures with the result that changes in such costs have little effect on consolidated net income. The increases in purchases from PURPA generation reflect additional generation from new PURPA projects. The 1993 increase in other purchased power reflects efforts to conserve coal during the UMWA dispute.
The increase in other operation expense for 1993 and 1992 resulted primarily from increases in employee benefit costs and salaries and wages. The Financial Accounting Standards Board's (FASB) standard, SFAS No. 106, increased 1993 postretirement benefit expense by approximately $5 million. The subsidiaries are currently recovering approximately 85% of SFAS No. 106 expenses in rates and will be requesting recovery of substantially all of the remainder in 1994 rate cases. During 1992, the subsidiaries implemented significant changes to their benefits plans, including cost caps, in an effort to both control and reduce employee benefits costs. The cost caps provide for future postretirement medical benefit costs to be capped at two times 1993 levels. Because 1993 medical costs were more than actuarially projected, SFAS No. 106 costs for 1994 are expected to be approximately 20% greater than 1993 amounts.
M-4
Another FASB standard, SFAS No. 112, "Employers' Accounting for Postemployment Benefits", effective in 1994, requires companies to accrue for other postemployment benefits such as disability benefits, health care benefits for disabled employees, severance pay, and workers' compensation claims. The subsidiaries currently accrue for workers' compensation claims and the estimated liability for the other benefits is not expected to be material.
Maintenance expenses represent costs incurred to maintain the power stations, the transmission and distribution (T&D) system, and general plant, and reflect routine maintenance of equipment and rights-of-way as well as planned major repairs and unplanned expenditures, primarily from forced outages at the power stations and periodic storm damage on the T&D system. Maintenance expense in 1993 includes the effects of an ice storm and blizzard in March 1993. The subsidiaries are also experiencing, and expect to continue to experience, increased expenditures due to the aging of their power stations. Variations in maintenance expense result primarily from unplanned events and planned major projects, which vary in timing and magnitude depending upon the length of time equipment has been in service without a major overhaul, the amount of work found necessary when the equipment is dismantled, and outage requirements to comply with the Clean Air Act Amendments of 1990 (CAAA).
Depreciation expense increases resulted primarily from additions to electric plant. Because of the increased levels of capital expenditures as a result of the CAAA (see Note I to the consolidated financial statements) and the replacement of aging equipment at the subsidiaries' power stations, depreciation expense is expected to increase significantly over the next few years.
Taxes other than income increased $4 million in 1993 primarily due to increases in gross receipts taxes resulting from higher revenues from retail customers ($5 million) and increased property taxes ($2 million). These increases were offset by decreased West Virginia Business and Occupation taxes (B&O taxes) due to decreased generation in that state. The 1992 increase resulted from increased property taxes ($4 million), increases in gross receipts taxes ($3 million), and increased capital stock taxes ($2 million), offset by decreased B&O taxes ($2 million).
The net increase of $13 million in federal and state income taxes in 1993 resulted primarily from an increase in income before taxes ($9 million), and an increase in the tax rate due to the Revenue Reconciliation Act of 1993 ($3 million). The net decrease in 1992 of $4 million resulted primarily from plant removal and certain bond refinancing cost tax deductions for which deferred taxes were not provided. Note B to the consolidated financial statements provides a further analysis of income tax expenses.
M-5
The combined increase of $4 million in allowances for funds used during construction (AFUDC) in 1993 reflects increased construction expenditures including those associated with the CAAA, net of CAAA amounts included in rate base and earning a cash return. Future levels of AFUDC can be expected to increase slightly with increasing levels of CAAA expenditures until late 1994 upon substantial completion of Phase I of the CAAA compliance program. Fluctuations in other income, net, were individually insignificant. Other interest expense reflects changes in the levels of short-term debt maintained by the companies.
The decrease in dividends on preferred stock of subsidiaries reflects the 1992 redemption of three series totaling $25 million with dividend rates of 9.4% to 9.64% and the 1993 redemption of an additional $2 million of 4.7% to $7.16 series, offset by the 1992 sale of $40 million of market auction preferred stock with an average dividend rate of 2.6%.
LIQUIDITY AND CAPITAL RESOURCES
SEC regulations define "liquidity" as "the ability of an enterprise to generate adequate amounts of cash to meet the enterprise's need for cash". System companies need cash for operating expenses, the payment of interest and dividends, retirement of debt and certain preferred stocks, and for their construction programs. To meet these needs, the companies have used internally generated funds and external financings, such as the sale of common and preferred stock, debt instruments, instalment loans, and lease arrangements. The timing and amount of external financings depend primarily upon economic and financial market conditions, the companies' cash needs, and capitalization ratio objectives. The availability and cost of external financing depend upon the financial health of the companies seeking those funds.
CAPITAL REQUIREMENTS
Construction expenditures for 1993 were $574 million and for 1994 and 1995 are estimated at $500 million and $400 million, respectively. These estimates include $161 million and $53 million, respectively, for substantial completion of the program of complying with Phase I of the CAAA discussed under ITEM 1. ENVIRONMENTAL MATTERS. It is anticipated that the Harrison Scrubber Project will be completed on schedule (late 1994) and that the final cost will be approximately 24% below the original budget. Primary factors contributing to the reduced cost include: 1) the absence of any major construction problems to date; 2) financing and material and equipment costs lower than expected; and 3) favorable rulings of state commissions allowing the inclusion of carrying costs of construction in rates in lieu of AFUDC. Construction expenditures through the year 2000 may include substantial amounts for
M-6
compliance with both Phase I and Phase II of the CAAA. The subsidiaries are estimating amounts of approximately $1.4 billion, which includes $482 million expended through 1993, depending upon the strategy eventually selected for complying with Phase II. The mere possibility of new legislation which restricts or discourages carbon dioxide emissions, either through taxation or caps, further complicates the CAAA Phase II planning process. The remaining amount of this CAAA construction estimate, together with normal construction activity assures that continuing external financings will be required. In addition, the subsidiaries have additional capital requirements of an annual preferred stock sinking fund ($1.2 million) and debt maturities (see Note G to the consolidated financial statements).
INTERNAL CASH FLOWS
Internal generation of cash, consisting of cash flows from operations reduced by dividends, increased to $270 million in 1993. Regulatory commission orders received in Maryland, Pennsylvania, Virginia, and West Virginia provide for current cash recovery of the carrying costs of CAAA expenditures in rates, albeit with various amounts of lag. Based upon the authorizations received and requested and new rate cases planned in 1994, internal generation of cash can be expected to increase.
The increase in other investments reflects the 1993 cash surrender values for secured benefit plans and a related prepayment. Materials and supplies, primarily fuel, constituted a significant source of cash in 1993 ($54 million). The five-year National Bituminous Coal Wage Agreement terminated on February 1, 1993. Coal inventories (fuel) as of December 31, 1992, were increased over 1991 amounts to provide an increased coal supply in the event of a strike. The union chose a strategy of selective shutdowns including mines that accounted for approximately 60% of the subsidiaries' regular coal supply. The union signed a new five-year contract in December 1993. System coal inventory, which declined during the dispute, and which is somewhat lower than the seasonal norm, is considered adequate.
FINANCINGS
In October 1993, the Company issued 2,400,000 shares of its common stock for $64.1 million. Also during 1993, the Company issued 1,364,846 shares of common stock under its Dividend Reinvestment and Stock Purchase Plan (DRISP), and Employee Stock Ownership and Savings Plan (ESOP) for $36.1 million. During 1993 the subsidiaries issued $43 million of 6.25% to 6.3% tax-exempt solid waste disposal notes to Harrison County, West Virginia, and refunded an aggregate of $634 million of debt securities having interest rates of 7% to 9.75% through the issuance of $652 million of securities having interest rates of 4.95% to 7.75%. The costs
M-7
associated with the debt redemptions are being amortized over the life of the new bonds. Due to the significant number of refinancings which have occurred over the past two years, this balance is now about $44 million. Reduced future interest expense will more than offset these expenses.
Short-term debt is used to meet temporary cash needs until the timing is considered appropriate to issue long-term securities. Short-term debt increased from $11.2 million in 1992 to $130.6 million in 1993. The subsidiaries canceled or postponed approximately $152 million of debt and equity financings in 1993 due to favorable short-term alternatives. In 1992, the Company and its subsidiaries established an internal money pool whereby surplus funds of the Company and certain subsidiaries may be borrowed on a short-term basis by the Company's subsidiaries. This has contributed to the decrease in the 1993 temporary cash investment amounts. Allegheny Generating Company in 1992 replaced its $65.7 million of commercial paper with $50.9 million of money pool borrowings and $2.4 million of four-year, 6.05%-6.10% medium-term notes. Allegheny Generating Company has available an established program to replace money pool borrowings with medium-term notes or commercial paper.
At December 31, 1993, unused lines of credit with banks were $149 million. In addition, a multi-year credit program was established in January 1994, which provides that the subsidiaries may borrow on a standby revolving credit basis up to $300 million. After the initial three-year term, the program agreement provides that the maturity date may be extended in one-year increments. The borrowings have the support of a long-term credit facility. During 1994, the subsidiaries plan to issue about $230 million of new securities, consisting of both debt and equity issues and, if economic and market conditions make it desirable, may refinance up to $728 million of first mortgage bonds, preferred stock, and pollution control revenue notes. The subsidiaries may also engage in additional Harrison County tax-exempt solid waste disposal financings to the extent that funds are available. The Company plans to fund the subsidiaries' sale of common stock through the issuance of short-term debt and DRISP/ESOP common stock sales.
The subsidiaries anticipate that they will be able to meet their future cash needs through internal cash generation and external financings as they have in the past and possibly through alternative financing procedures.
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ENVIRONMENTAL MATTERS AND OTHER CONTINGENCIES
In the normal course of business, the subsidiaries are subject to various contingencies and uncertainties relating to their operations and construction programs, including cost recovery in the regulatory process, laws, regulations and uncertainties related to environmental matters, and legal actions. Contingencies and uncertainties related to the CAAA are discussed above and under Note I to the consolidated financial statements.
All of the state jurisdictions in which the subsidiaries operate have enacted hazardous and solid waste management legislation. While the subsidiaries do not have significant hazardous waste concerns, solid wastes, such as fly ash and other coal by-products generated from power stations, must be disposed in accordance with the state requirements. The subsidiaries are incurring various costs, which are recoverable in rates, to comply with these and other environmental matters. The level of future expenditures for environmental matters is impossible to determine with any degree of certainty. It is management's opinion that the ultimate costs will not have a material effect on the financial position of the subsidiaries.
As of January 1994, Monongahela has been named as a defendant along with multiple other defendants in 1,429 pending asbestos cases involving multiple plaintiffs and Monongahela, Potomac Edison, and West Penn have been named as defendants along with multiple defendants in an additional 626 cases by multiple plaintiffs. Because these cases are filed by "shotgun" complaints naming many plaintiffs and many defendants, it is presently impossible to determine the actual number of claims against the subsidiaries. However, based on past experience and data available to date, it is estimated that less than 600 cases actually involve claims against any or all of the subsidiaries. All complaints allege that the plaintiffs sustained unspecified injuries resulting from claimed exposure to asbestos in various generating plants and other industrial facilities operated by the various defendants, although all plaintiffs do not claim exposure at facilities operated by all defendants. All plaintiffs claiming exposure at subsidiary-operated stations were employed by third-party contractors, with the exception of three who claim to have been employees of Monongahela. Each plaintiff generally seeks compensatory and punitive damages against all defendants in amounts of up to $1 million and $3 million, respectively; in those cases that include a spousal claim for loss of consortium, damages are generally sought against all defendants in an amount of up to $1 million for the loss of consortium claim. Therefore, because of the multiple defendants, the subsidiaries believe potential liability of the subsidiaries is a very small percentage of the total amount of the damages sought. A total of 94 cases have been previously settled by Monongahela for an amount substantially less than the anticipated cost of defense. While the subsidiaries believe that all of these cases are without merit, they cannot predict the outcome of these cases or whether other cases will be filed.
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Monongahela
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Net Income Net income was $61.7 million, $58.3 million, and $54.1 million in 1993, 1992, and 1991, respectively. The increase in net income in 1993 resulted primarily from kWh sales and retail rate increases. The increase in 1992 resulted primarily from retail rate increases. These revenue increases, in both years, were offset in part by higher expenses.
Sales and Revenues KWh sales to and revenues from residential, commercial, and industrial customers are shown on pages D-3 and D-4 Such kWh sales increased .3% in 1993 and decreased 1.0% in 1992. The increases in revenues from sales to residential, commercial, and industrial customers resulted from the following:
Increase (Decrease) from Prior Year
1993 1992 (Millions of Dollars)
Increased (decreased) kWh sales $ 6.6 $(5.3) Fuel and energy cost adjustment clauses (a) 11.8 12.3 Rate increases (b): West Virginia 4.1 12.1 Ohio 2.1 1.6 6.2 13.7
Other .2 (1.3) $24.8 $19.4
(a) Changes in revenues from fuel and energy cost adjustment clauses have little effect on net income.
(b) Reflects a surcharge in West Virginia for recovery of carrying charges on expenditures to comply with the Clean Air Act Amendments of 1990 (CAAA), designed to produce $3.1 million on an annual basis effective on July 1, 1992, which was increased to $8.7 million on an annual basis effective on July 1, 1993, and a rate increase in Ohio, designed to produce $3.3 million on an annual basis, which became effective on July 21, 1992.
The increased kWh sales to residential and commercial customers in 1993 reflect both growth in number of customers and higher use. While 1993 heating degree days showed only a slight increase over 1992, and were only 6% above normal, cooling degree days increased 54% over 1992, contributing to the 1993 kWh sales increases. The Company experienced a mild winter in the first quarter of 1992 followed by a much cooler than normal summer and early fall. As a result, weather had a negative impact on 1992 sales to retail customers.
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KWh sales to industrial customers decreased 4.4% in 1993 and .7% in 1992. The 1993 decrease was primarily due to continuing declines in sales to coal and primary metals customers. Coal mines staffed by union personnel, recorded reduced usage because of selective work stoppages by the United Mine Workers of America (UMWA) for most of the year prior to the settling of the dispute in December 1993. Lower sales to primary metals customers was due in part to one iron and steel customer's increased use of its own generation.
KWh sales to and revenues from nonaffiliated utilities are comprised of the following items:
1993 1992 1991 KWh sales (in billions): From Company generation .3 1.0 1.8 From purchased power 2.8 3.6 3.1 3.1 4.6 4.9
Revenues (in millions): From Company generation $ 8.4 $ 26.7 $ 48.5 From sales of purchased power 77.6 92.9 91.5 $86.0 $119.6 $140.0
Decreased sales to nonaffiliated utilities resulted primarily from decreased demand and continuing price competition. Sales supplied by the Company's generation in 1993 decreased to less than 15% of 1988 levels because of growth of kWh sales to retail customers, which reduces the amount available for sale, and because other suppliers were willing or able to make the sales at lower prices. A significant factor affecting the Company's ability to compete in the market for sales to nonaffiliated utilities has been the approximate 290% increase (from about 67 cents per MWh to $2.60 per MWH) in taxes on generation in West Virginia since March 1989 - a significant cost not experienced by utilities not generating in West Virginia. Further decreases in these sales are anticipated in 1994 before leveling off.
The increase in other revenues in 1993 and 1992 resulted from continued increases in sales of capacity, energy, and spinning reserve to other affiliated companies because of additional capacity and energy available from new PURPA projects in both years. This increase was offset in part in 1993 by an agreement with the Federal Energy Regulatory Commission to record in 1993 about $3 million of revenues as sales to nonaffiliated utilities. Similar transactions were recorded as other revenues in prior years. About 90% of the aggregate benefits from sales to affiliated and nonaffiliated utilities is passed on to retail customers and has little effect on net income.
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Operating Expenses
Fuel expenses decreased 3% in 1993 and 9% in 1992. Both decreases were primarily due to decreases in kWh generated. Fuel expenses are primarily subject to deferred power cost accounting procedures, as described in Note A to the financial statements, with the result that changes in fuel expenses have little effect on net income.
"Purchased power and exchanges, net" represents power purchases from and exchanges with nonaffiliated utilities and qualified facilities under the Public Utility Regulatory Policies Act of 1978 (PURPA), capacity charges paid to AGC, and other transactions with affiliates made pursuant to a power supply agreement whereby each company uses the most economical generation available in the System at any given time, and is comprised of the following items:
1993 1992 1991 (Millions of Dollars) Nonaffiliated transactions: Purchased power: For resale to other utilities $ 68.6 $ 85.5 $ 83.0 From PURPA generation 55.7 37.4 13.2 Other 8.1 3.1 7.2 Power exchanges, net (.6) .3 (.5) Affiliated transactions: AGC capacity charges 23.3 24.2 25.1 Energy and spinning reserve charges .5 2.8 5.3 $155.6 $153.3 $133.3
The amount of power purchased from nonaffiliated utilities for use by the Company and for resale to nonaffiliated utilities depends upon the availability of the Company's generating equipment, transmission capacity, and fuel, and its cost of generation and the cost of operations of nonaffiliated utilities from which such purchases are made. The primary reason for the fluctuations in purchases for resale to nonaffiliated utilities is described under Sales and Revenues above. The cost of power and capacity purchased for use by the Company, including power from PURPA generation and affiliated transactions, is mostly recovered from customers currently through the regular fuel and energy cost recovery procedures followed by the Company's regulatory commissions and is primarily subject to deferred power cost procedures with the result that changes in such costs have little effect on net income. The increases in purchases from PURPA generation reflects additional generation from new PURPA projects. The 1993 increase in other purchased power reflects efforts to conserve coal during the UMWA dispute. Energy and spinning reserve charges decreased in 1993 and 1992 primarily because of additional generation available from new PURPA projects.
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The increase in other operation expense for 1993 and 1992 resulted primarily from increases in salaries and wages and employee benefit costs. The Financial Accounting Standards Board's (FASB) standard, SFAS No. 106, will increase future employee benefit costs for postretirement benefit expenses. The Company is currently recovering approximately 50% of SFAS No. 106 expenses in rates and will be requesting recovery of the remainder in 1994 and early 1995 rate cases. This reflects for West Virginia and Ohio only the recovery of the previously authorized pay-as-you-go component. During 1992, the Company implemented significant changes to its benefits plans, including cost caps, in an effort to both control and reduce employee benefits costs. The cost caps provide for future postretirement medical benefit costs to be capped at two times 1993 levels. Because 1993 medical costs were more than actuarially projected, SFAS No. 106 costs for 1994 are expected to be approximately 25% greater than 1993 amounts.
Another FASB standard, SFAS No. 112, "Employers' Accounting for Postemployment Benefits", effective in 1994, requires companies to accrue for other post- employment benefits such as disability benefits, health care benefits for disabled employees, severance pay, and workers' compensation claims. The Company currently accrues for workers' compensation claims and the estimated liability for the other benefits is not expected to be material.
Maintenance expenses represent costs incurred to maintain the power stations, the transmission and distribution (T&D) system, and general plant, and reflect routine maintenance of equipment and rights-of-way as well as planned major repairs and unplanned expenditures, primarily from forced outages at the power stations and periodic storm damage on the T&D system. The Company is also experiencing, and expects to continue to experience, increased expenditures due to the aging of its power stations. Variations in maintenance expense result primarily from unplanned events and planned major projects, which vary in timing and magnitude depending upon the length of time equipment has been in service without a major overhaul, the amount of work found necessary when the equipment is dismantled, and outage requirements to comply with the CAAA.
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Depreciation expense increases resulted primarily from additions to electric plant. Because of the increased levels of capital expenditures as a result of the CAAA (see Note J to the financial statements) and the replacement of aging equipment at the Company's power stations, depreciation expense is expected to increase significantly over the next few years.
Taxes other than income increased $1 million in 1993 primarily due to increases in gross receipts taxes resulting from higher revenues from retail customers ($1 million) and increased property taxes ($1 million), offset by decreased West Virginia Business and Occupation taxes (B&O taxes) ($1 million) due to decreased generation in that state. The 1992 decrease resulted from decreased B&O taxes ($2 million) and prior period B&O tax adjustments ($2 million), offset somewhat by increases in gross receipts and property taxes ($2 million).
The net increase of $6 million in federal and state income taxes in 1993 resulted primarily from an increase in income before taxes ($4 million), and an increase in the tax rate due to the Revenue Reconciliation Act of 1993 ($1 million). The net decrease in 1992 of $3 million resulted primarily from plant removal and certain bond refinancing cost tax deductions for which deferred taxes were not provided. Note B to the financial statements provides a further analysis of income tax expenses.
The combined increase of $2 million in allowances for funds used during construction (AFUDC) in 1993 reflects increased construction expenditures primarily associated with the CAAA, net of CAAA amounts included in rate base and earning a cash return. Future levels of AFUDC can be expected to decrease as the Company completes its Phase I compliance program. The decrease in other income, net, in 1993 resulted primarily from the Company's share of decreases in the earnings of AGC (see Note D to the financial statements). Other fluctuations in other income, net, were individually insignificant. Other interest expense reflects changes in the level of short-term debt maintained by the Company.
Liquidity and Capital Resources SEC regulations define "liquidity" as "the ability of an enterprise to generate adequate amounts of cash to meet the enterprise's need for cash". The Company needs cash for operating expenses, the payment of interest and dividends, retirement of debt, and for its construction program. To meet these needs, the Company has used
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internally generated funds and external financings, such as the sale of common and preferred stock, debt instruments, instalment loans, and lease arrangements. The timing and amount of external financings depend primarily upon economic and financial market conditions, the Company's cash needs, and capitalization ratio objectives. The availability and cost of external financing depend upon the financial health of the companies seeking those funds.
Capital Requirements Construction expenditures for 1993 were $141 million and for 1994 and 1995 are estimated at $103 million and $83 million, respectively. These estimates include $39 million and $10 million, respectively, for substantial completion of the program of complying with Phase I of the CAAA. It is anticipated that the Harrison Scrubber Project will be completed on schedule (late 1994) and that the final cost will be approximately 24% below the original budget. Primary factors contributing to the reduced cost include: 1) the absence of any major construction problems to date; 2) financing and material and equipment costs lower than expected; and 3) favorable rulings of state commissions allowing the inclusion of carrying costs of construction in rates in lieu of AFUDC. Construction expenditures through the year 2000 may include substantial amounts for compliance with both Phase I and Phase II of the CAAA. The Company is estimating amounts of approximately $400 million, which includes $122 million expended through 1993, depending upon the strategy eventually selected for complying with Phase II. The mere possibility of new legislation which restricts or discourages carbon dioxide emissions, either through taxation or caps, further complicates the CAAA Phase II planning process. The remaining amount of this CAAA construction estimate, together with normal construction activity assures that continuing external financings will be required. In addition, the Company has additional capital requirements of debt maturities (see Note H to the financial statements).
Internal Cash Flows Internal generation of cash, consisting of cash flows from operations reduced by dividends, was about $69 million for 1993. A regulatory commission order has been received in West Virginia authorizing procedures to provide for current cash recovery of the carrying costs of CAAA expenditures in rates, albeit with a certain amount of lag. Based upon the authorization received and new rate cases planned in 1994 and early 1995, internal generation of cash can be expected to increase.
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Materials and supplies, primarily fuel, constituted a significant source of cash in 1993 ($13 million). The five- year National Bituminous Coal Wage Agreement terminated on February 1, 1993. Coal inventories (fuel) as of December 31, 1992, were increased over 1991 amounts to provide an increased coal supply in the event of a strike. The union chose a strategy of selective shutdowns including mines that accounted for approximately 60% of the System's regular coal supply. The union signed a new five-year contract in December 1993. System coal inventory, which declined during the dispute, and which is somewhat lower than the seasonal norm, is considered adequate.
Financings During 1993 the Company issued $10.68 million of 6.25% tax-exempt solid waste disposal notes to Harrison County, West Virginia, and refunded an aggregate of $67 million of debt securities having interest rates of 7.5% to 9.5% through the issuance of $72 million of securities having interest rates of 5.625% to 5.95%. The costs associated with the debt redemptions are being amortized over the life of the new bonds. Due to the significant number of refinancings which have occurred over the past two years, this balance is now about $12 million. Reduced future interest expense will more than offset these expenses.
Short-term debt is used to meet temporary cash needs until the timing is considered appropriate to issue long- term securities. Short-term debt, including notes payable to affiliates under the money pool, increased from $8.0 million in 1992 to $63.1 million in 1993. The Company canceled or postponed approximately $69 million of debt and equity financings in 1993 due to favorable short-term alternatives. In 1992, the Company and its affiliates established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds available.
At December 31, 1993, the Company had SEC authorization to issue up to $100 million of short-term debt. In addition, a multi-year credit program was established in January 1994, which provides that the Company may borrow on a standby revolving credit basis up to $81 million. After the initial three-year term, the program agreement provides that the maturity date may be extended in one-year increments. The borrowings have the support of a long-term credit facility. During 1994, the Company plans to issue about $50 million of new equity securities and, if economic and market conditions make it desirable, may refinance up to $285 million of first
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mortgage bonds, preferred stock, and pollution control revenue notes. The Company may also engage in additional Harrison County tax-exempt solid waste disposal financings to the extent that funds are available.
The Company anticipates that it will be able to meet its future cash needs through internal cash generation and external financings as it has in the past and possibly through alternative financing procedures.
Environmental Matters and Other Contingencies In the normal course of business, the Company is subject to various contingencies and uncertainties relating to its operations and construction programs, including cost recovery in the regulatory process, laws, regulations and uncertainties related to environmental matters, and legal actions. Contingencies and uncertainties related to the CAAA are discussed above and under Note J to the financial statements.
All of the state jurisdictions in which the Company operates have enacted hazardous and solid waste management legislation. While the Company does not have significant hazardous waste concerns, solid wastes, such as fly ash and other coal by-products generated from power stations, must be disposed in accordance with the state requirements. The Company is incurring various costs, which are recoverable in rates, to comply with these and other environmental matters. The level of future expenditures for environmental matters is impossible to determine with any degree of certainty. It is management's opinion that the ultimate costs will not have a material effect on the financial position of the Company.
As of January 1994, the Company has been named as a defendant along with multiple other defendants in 1,429 pending asbestos cases involving multiple plaintiffs and the Company and its affiliates have been named as defendants along with multiple defendants in an additional 626 cases by multiple plaintiffs. Because these cases are filed by "shotgun" complaints naming many plaintiffs and many defendants, it is presently impossible to determine the actual number of claims against the Company and its affiliates. However, based on past experience and data available to date, it is estimated that less than 600 cases actually involve claims against the
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Company or its affiliates. All complaints allege that the plaintiffs sustained unspecified injuries resulting from claimed exposure to asbestos in various generating plants and other industrial facilities operated by the various defendants, although all plaintiffs do not claim exposure at facilities operated by all defendants. All plaintiffs claiming exposure at System-operated stations were employed by third-party contractors, with the exception of three who claim to have been employees of the Company. Each plaintiff generally seeks compensatory and punitive damages against all defendants in amounts of up to $1 million and $3 million, respectively; in those cases that include a spousal claim for loss of consortium, damages are generally sought against all defendants in an amount of up to $1 million for the loss of consortium claim. Therefore, because of the multiple defendants, the Company believes its potential liability is a very small percentage of the total amount of the damages sought. A total of 94 cases have been previously settled by the Company for an amount substantially less than the anticipated cost of defense. While the Company believes that all of these cases are without merit, it cannot predict the outcome of these cases or whether other cases will be filed.
M-18 Potomac
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Net Income
Net income was $73.5 million, $67.5 million, and $58.2 million in 1993, 1992, and 1991, respectively. The increase in net income in 1993 resulted primarily from kWh sales and retail rate increases. The increase in 1992 resulted primarily from retail rate increases. These revenue increases, in both years, were offset in part by higher expenses.
Sales and Revenues
KWh sales to and revenues from residential, commercial, and industrial customers are shown on pages D-5 and D-6. Such kWh sales increased 6.3% and 2.0% in 1993 and 1992, respectively. The increases in revenues from sales to residential, commercial, and industrial customers resulted from the following:
Increase from Prior Year 1993 1992 (Millions of Dollars) Increased kWh sales $24.4 $ 7.7 Fuel and energy cost adjustment clauses (a) 19.1 10.4 Rate increases (b): Maryland 12.7 11.7 Virginia 2.5 1.8 West Virginia 1.1 .3 16.3 13.8 Other 2.9 .2 $62.7 $32.1
(a) Changes in revenues from fuel and energy cost adjustment clauses have little effect on net income.
(b) Reflects a rate increase in Maryland, designed to produce $11.3 million on an annual basis, which became effective on February 25, 1993, and a rate increase in Virginia, designed to produce $10.0 million on an annual basis, which became effective on September 28, 1993, subject to refund. The Maryland surcharge for recovery of carrying charges on Clean Air Act Amendments of 1990 (CAAA) compliance investment of $1.7 million effective on June 4, 1992, which was increased to $3.9 million effective on December 3, 1992, was rolled into base rates effective with the February 1993 increase. Rate increases also include a CAAA surcharge in West Virginia designed to produce $.8 million on an annual basis effective July 1, 1992, which was increased to $2.2 million on an annual basis effective July 1, 1993.
The increased kWh sales to residential and commercial customers in 1993 reflect both higher use and growth in number of customers. While 1993 heating degree days showed only a slight increase over 1992, and were only 7%
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above normal, cooling degree days increased 82% over 1992 and were 12% over normal, contributing to the 1993 kWh sales increases. The Company experienced a normal winter in the first quarter of 1992 followed by a much cooler than normal summer and early fall. As a result, weather had a negative impact on 1992 sales to retail customers.
KWh sales to industrial customers increased 4.3% in 1993 and 2.0% in 1992. The increase in both years occurred in almost all industrial groups, the most significant of which in 1993 was from sales to cement customers.
KWh sales to and revenues from nonaffiliated utilities are comprised of the following items:
1993 1992 1991 KWh sales (in billions): From Company generation .4 1.0 1.8 From purchased power 3.5 4.4 3.8 3.9 5.4 5.6 Revenues (in millions): From Company generation $8.6 $27.5 $47.4 From sales of purchased power 99.5 113.6 114.3 $108.1 $141.1 $161.7
Decreased sales to nonaffiliated utilities resulted primarily from decreased demand and continuing price competition. Sales supplied by the Company's generation in 1993 decreased to less than 15% of 1988 levels because of continuing growth of kWh sales to retail customers, which reduces the amount available for sale, and because other suppliers were willing or able to make the sales at lower prices. A significant factor affecting the Company's ability to compete in the market for sales to nonaffiliated utilities has been the approximate 290% increase (from about 67cents per MWh to $2.60 per MWh) in taxes on generation in West Virginia since March 1989 - a significant cost not experienced by utilities not generating in West Virginia. Further decreases in these sales are anticipated in 1994 before leveling off. About 95% of the aggregate benefits from sales to nonaffiliated utilities is passed on to retail customers and has little effect on net income.
The decrease in other revenues in 1993 resulted from an agreement with the Federal Energy Regulatory Commission to record in 1993 about $4 million of revenues as sales to nonaffiliated utilities. Similar transactions were recorded as other revenues in prior years.
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Operating Expenses Fuel expenses decreased 4% in 1993 and 6% in 1992. Both decreases were primarily due to decreases in kWh generated. The 1992 decrease also included a 1% decrease in average coal prices. Fuel expenses are primarily subject to deferred power cost accounting procedures, as described in Note A to the financial statements, with the result that changes in fuel expenses have little effect on net income.
"Purchased power and exchanges, net" represents power purchases from and exchanges with nonaffiliated utilities, capacity charges paid to AGC, and other transactions with affiliates made pursuant to a power supply agreement whereby each company uses the most economical generation available in the System at any given time, and is comprised of the following items:
1993 1992 1991 (Millions of Dollars) Nonaffiliated transactions: Purchased power: For resale to other utilities $87.9 $104.6 $103.7 Other 10.5 3.7 8.9 Power exchanges, net (.8) .2 (.4) Affiliated transactions: AGC capacity charges 28.0 29.6 31.3 Other affiliated capacity charges 28.4 21.9 23.4 Energy and spinning reserve charges 51.1 41.2 37.6 $205.1 $201.2 $204.5
The amount of power purchased from nonaffiliated utilities for use by the Company and for resale to nonaffiliated utilities depends upon the availability of the Company's generating equipment, transmission capacity, and fuel, and its cost of generation and the cost of operations of nonaffiliated utilities from which such purchases are made. The primary reason for the fluctuations in purchases for resale to nonaffiliated utilities is described under Sales and Revenues above. The cost of power purchased from nonaffiliates for use by the Company and affiliated energy and spinning reserve charges are mostly recovered from customers currently through the regular fuel and energy cost recovery procedures followed by the Company's regulatory commissions and is primarily subject to deferred power cost procedures with the result that changes in such costs have little effect on net income. The 1993 increase in other purchased power reflects efforts to conserve coal because of selective work stoppages by the United Mine Workers of America for most of the year.
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While the Company does not currently purchase generation from qualified facilities under the Public Utility Regulatory Policies Act of 1978 (PURPA), several projects have been proposed, and an agreement has been reached with one facility to commence purchasing generation in 1999. This project and others may significantly increase the cost of power purchases passed on to customers. The increase in affiliated capacity and energy and spinning reserve charges in 1993 was due to growth of kWh sales to retail customers and an increase in affiliated energy available because of energy purchased by an affiliate from new PURPA projects in 1992 and 1993.
The increase in other operation expense for 1993 and 1992 resulted primarily from increases in employee benefit costs and salaries and wages. The Financial Accounting Standards Board's (FASB) standard, SFAS No. 106, increased 1993 postretirement benefit expense by approximately $1.5 million. The Company is currently recovering approximately 90% of SFAS No. 106 expenses in rates and will be requesting recovery of the remainder in 1994 rate cases. During 1992, the Company implemented significant changes to its benefits plans, including cost caps, in an effort to both control and reduce employee benefits costs. The cost caps provide for future postretirement medical benefit costs to be capped at two times 1993 levels. Because 1993 medical costs were more than actuarially projected, SFAS No. 106 costs for 1994 are expected to be approximately 25% greater than 1993 amounts.
Another FASB standard, SFAS No. 112, "Employers' Accounting for Postemployment Benefits", effective in 1994, requires companies to accrue for other post- employment benefits such as disability benefits, health care benefits for disabled employees, severance pay, and workers' compensation claims. The Company currently accrues for workers' compensation claims and the estimated liability for the other benefits is not expected to be material.
Maintenance expenses represent costs incurred to maintain the power stations, the transmission and distribution (T&D) system, and general plant, and reflect routine maintenance of equipment and rights-of-way as well as planned major repairs and unplanned expenditures, primarily from forced outages at the power stations and periodic storm damage on the T&D system.
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The Company is also experiencing, and expects to continue to experience, increased expenditures due to the aging of its power stations. Variations in maintenance expense result primarily from unplanned events and planned major projects, which vary in timing and magnitude depending upon the length of time equipment has been in service without a major overhaul, the amount of work found necessary when the equipment is dismantled, and outage requirements to comply with the CAAA.
Depreciation expense increases resulted primarily from additions to electric plant. Because of the increased levels of capital expenditures as a result of the CAAA (see Note J to the financial statements) and the replacement of aging equipment at the Company's power stations, depreciation expense is expected to increase significantly over the next few years.
Taxes other than income increased $1 million in 1993 due to increases in gross receipts taxes resulting from higher revenues from retail customers ($1 million) and increased property taxes ($1 million), offset by decreased West Virginia Business and Occupation taxes due to decreased generation in that state ($1 million). The 1992 increase was due to increased property ($1 million) and gross receipts ($1 million) taxes.
The net increase of $2 million in federal and state income taxes in 1993 resulted primarily from an increase in income before taxes ($3 million) and an increase in the tax rate due to the Revenue Reconciliation Act of 1993 ($1 million), offset by plant removal tax deductions for which deferred taxes were not provided ($1 million). The net increase in 1992 was primarily due to an increase in income before taxes. Note B to the financial statements provides a further analysis of income tax expenses.
The combined increase of $2 million in allowances for funds used during construction (AFUDC) in 1993 reflects increased construction expenditures including those associated with the CAAA, net of CAAA amounts included in rate base and earning a cash return. Future levels of AFUDC can be expected to increase slightly with increasing levels of CAAA expenditures until late 1994 upon substantial completion of Phase I of the CAAA compliance program. The decrease in other income, net in 1993 resulted primarily from the Company's share of decreases in the earnings of AGC (see Note D to the financial statements). Other fluctuations in other income, net, were individually insignificant. Other interest expense reflects changes in the level of short-term debt maintained by the Company.
Liquidity and Capital Resources SEC regulations define "liquidity" as "the ability of an enterprise to generate adequate amounts of cash to meet the enterprise's need for cash". The Company needs cash for operating expenses, the payment of interest and dividends, retirement of debt and certain preferred stock,
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and for its construction program. To meet these needs, the Company has used internally generated funds and external financings, such as the sale of common and preferred stock, debt instruments, instalment loans, and lease arrangements. The timing and amount of external financings depend primarily upon economic and financial market conditions, the Company's cash needs, and capitalization ratio objectives. The availability and cost of external financing depend upon the financial health of the companies seeking those funds.
During 1993, the Company continued its participation in the Collaborative Process for Demand-Side Management in Maryland with the Maryland PSC Staff, Office of People's Counsel, the Department of Natural Resources, Maryland Energy Administration, and the Company's largest industrial customer. The Company received the Maryland PSC's approval to implement a Commercial and Industrial Lighting Rebate Program as of July 1, 1993. Through December 31, 1993, the Company had received applications for $7.5 million in rebates related to the commercial lighting program. Program costs, including rebates and lost revenues, are deferred and are to be recovered through an energy conservation surcharge over a five-year period.
Capital Requirements Construction expenditures for 1993 were $179 million and for 1994 and 1995 are estimated at $136 million and $106 million, respectively. These estimates include $40 million and $10 million, respectively, for substantial completion of the program of complying with Phase I of the CAAA. It is anticipated that the Harrison Scrubber Project will be completed on schedule (late 1994) and that the final cost will be approximately 24% below the original budget. Primary factors contributing to the reduced cost include: 1) the absence of any major construction problems to date; 2) financing and material and equipment costs lower than expected; and 3) favorable rulings of state commissions allowing the inclusion of carrying costs of construction in rates in lieu of AFUDC. Construction expenditures through the year 2000 may include substantial amounts for compliance with both Phase I and Phase II of the CAAA. The Company is estimating amounts of approximately $350 million, which includes $153 million expended through 1993, depending upon the strategy eventually selected for complying with Phase II. The mere possibility of new legislation which restricts or discourages carbon dioxide emissions, either through taxation or caps, further complicates the CAAA Phase II planning process. The remaining amount of this CAAA construction estimate, together with normal construction activity assures that continuing external financings will be required. In addition, the Company has
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additional annual capital requirements of an annual preferred stock sinking fund ($1.2 million) and debt maturities (see Note H to the financial statements).
Internal Cash Flows Internal generation of cash, consisting of cash flows from operations reduced by dividends, increased to $75 million in 1993. Regulatory commission orders received in all of the state jurisdictions and the FERC provide for current cash recovery of the carrying costs of CAAA expenditures in rates, albeit with various amounts of lag. Based upon the authorizations received and new rate cases planned in 1994, internal generation of cash can be expected to increase.
Materials and supplies, primarily fuel, constituted a significant source of cash in 1993 ($14 million). The five-year National Bituminous Coal Wage Agreement terminated on February 1, 1993. Coal inventories (fuel) as of December 31, 1992, were increased over 1991 amounts to provide an increased coal supply in the event of a strike. The union chose a strategy of selective shutdowns including mines that accounted for approximately 60% of the System's regular coal supply. The union signed a new five-year contract in December 1993. System coal inventory, which declined during the dispute, and which is somewhat lower than the seasonal norm, is considered adequate.
Financings During 1993 the Company issued $13.99 million of 6.25% tax-exempt solid waste disposal notes to Harrison County, West Virginia, and refunded an aggregate of $121 million of debt securities having interest rates of 7% to 9.5% through the issuance of $129 million of securities having interest rates of 5.875% to 7.75%. The costs associated with the debt redemptions are being amortized over the life of the new bonds. Due to the significant number of refinancings which have occurred over the past two years, this balance is now about $9 million. Reduced future interest expense will more than offset these expenses.
Short-term debt is used to meet temporary cash needs until the timing is considered appropriate to issue long- term securities. The Company canceled or postponed approximately $36 million of debt financings in 1993 due to favorable short-term alternatives. In 1992, the Company and its affiliates established an internal money pool as a facility to accommodate intercompany short- term borrowing needs, to the extent that certain of the companies have funds available.
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At December 31, 1993, the Company had SEC authorization to issue up to $115 million of short-term debt. In addition, a multi-year credit program was established in January 1994, which provides that the Company may borrow on a standby revolving credit basis up to $84 million. After the initial three-year term, the program agreement provides that the maturity date may be extended in one-year increments. The borrowings have the support of a long-term credit facility. During 1994, the Company plans to issue about $75 million of new debt securities and, if economic and market conditions make it desirable, may refinance up to $231 million of first mortgage bonds, preferred stock, and pollution control revenue notes. The Company may also engage in additional Harrison County tax-exempt solid waste disposal financings to the extent that funds are available.
The Company anticipates that it will be able to meet its future cash needs through internal cash generation and external financings as it has in the past and possibly through alternative financing procedures.
Environmental Matters and Other Contingencies In the normal course of business, the Company is subject to various contingencies and uncertainties relating to its operations and construction programs, including cost recovery in the regulatory process, laws, regulations and uncertainties related to environmental matters, and legal actions. Contingencies and uncertainties related to the CAAA are discussed above and under Note J to the financial statements.
All of the state jurisdictions in which the Company operates have enacted hazardous and solid waste management legislation. While the Company does not have significant hazardous waste concerns, solid wastes, such as fly ash and other coal by-products generated from power stations, must be disposed in accordance with the state requirements. The Company is incurring various costs, which are recoverable in rates, to comply with these and other environmental matters. The level of future expenditures for environmental matters is impossible to determine with any degree of certainty. It is management's opinion that the ultimate costs will not have a material effect on the financial position of the Company.
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As of January 1994, Monongahela Power Company (MP), an affiliated company, has been named as a defendant along with multiple other defendants in 1,429 pending asbestos cases involving multiple plaintiffs and the Company and its affiliates have been named as defendants along with multiple defendants in an additional 626 cases by multiple plaintiffs. Because these cases are filed by "shotgun" complaints naming many plaintiffs and many defendants, it is presently impossible to determine the actual number of claims against the Company and its affiliates. However, based on past experience and data available to date, it is estimated that less than 600 cases actually involve claims against the Company or its affiliates. All complaints allege that the plaintiffs sustained unspecified injuries resulting from claimed exposure to asbestos in various generating plants and other industrial facilities operated by the various defendants, although all plaintiffs do not claim exposure at facilities operated by all defendants. All plaintiffs claiming exposure at System-operated stations were employed by third-party contractors, with the exception of three who claim to have been employees of MP. The Company is joint owner with MP in five generating plants, including four operated by MP in West Virginia. Each plaintiff generally seeks compensatory and punitive damages against all defendants in amounts of up to $1 million and $3 million, respectively; in those cases that include a spousal claim for loss of consortium, damages are generally sought against all defendants in an amount of up to $1 million for the loss of consortium claim. Therefore, because of the multiple defendants, the Company believes its potential liability is a very small percentage of the total amount of the damages sought. A total of 94 cases have been previously settled by MP for an amount substantially less than the anticipated cost of defense. While the Company believes that all of these cases are without merit, it cannot predict the outcome of these cases or whether other cases will be filed.
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West Penn
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Consolidated Net Income
Consolidated net income was $102.1 million, $98.2 million, and $101.2 million in 1993, 1992, and 1991, respectively. The increase in consolidated net income in 1993 resulted primarily from kWh sales and retail rate increases, offset in part by higher expenses. Higher retail revenues in 1992 from a surcharge to recover increases in various state taxes and greater kWh sales were more than offset by higher expenses.
Sales and Revenues
KWh sales to and revenues from residential, commercial, and industrial customers are shown on pages D-7 and D-8. Such kWh sales increased 3.1% and 2.7% in 1993 and 1992, respectively. The increases in revenues from sales to residential, commercial, and industrial customers resulted from the following:
Increase from Prior Year
1993 1992 (Millions of Dollars)
Increased kWh sales $15.5 $ 6.7 Fuel and energy cost adjustment clauses (a) 26.2 15.2 Rate increases (b) 25.2 5.8 Other 3.1 1.3
$70.0 $29.0
(a) Changes in revenues from fuel and energy cost adjustment clauses have little effect on consolidated net income.
(b) Reflects a base rate increase on an annual basis of about $61.6 million in Pennsylvania effective May 18, 1993, including $26.1 million for recovery of carrying charges on Clean Air Act Amendments of 1990 (CAAA) compliance costs, and in 1992 also reflects a surcharge effective August 24, 1991, to recover Pennsylvania tax increases.
The increased kWh sales to residential and commercial customers in 1993 reflect both growth in number of customers and higher use. While 1993 heating degree days remained about the same as 1992, and were only 6% below normal, cooling degree days increased 70% over 1992 and were 46% over normal, contributing to the 1993 kWh sales increases. The Company experienced a mild winter in the first quarter of 1992 followed by a much cooler than normal summer and early fall. As a result, weather had a negative impact on 1992 sales to retail customers.
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KWh sales to industrial customers increased .8% in 1993 and 6.3% in 1992. The relatively flat industrial sales growth in 1993 followed increases in industrial sales in 1992 which occurred in almost all industrial groups. One particular group, coal mines staffed by union personnel, recorded reduced usage because of selective work stoppages by the United Mine Workers of America (UMWA) for most of the year prior to the settling of the dispute in December 1993.
KWh sales to and revenues from nonaffiliated utilities are comprised of the following items:
1993 1992 1991 KWh sales (in billions): From Company generation .4 1.3 2.3 From purchased power 5.0 6.5 5.4
5.4 7.8 7.7
Revenues (in millions): From Company generation $11.5 $37.5 $62.5 From sales of purchased power 141.0 167.2 160.7
$152.5 $204.7 $223.2
Decreased sales to nonaffiliated utilities resulted primarily from decreased demand and continuing price competition. Sales supplied by the Company's generation in 1993 decreased to less than 15% of 1988 levels because of continuing growth of kWh sales to retail customers, which reduces the amount available for sale, and because other suppliers were willing or able to make the sales at lower prices. A significant factor affecting the Company's ability to compete in the market for sales to nonaffiliated utilities has been the approximate 290% increase (from about 67 cents per MWh to $2.60 per MWh) in taxes on generation in West Virginia since March 1989 - a significant cost not experienced by utilities not generating in West Virginia. Further decreases in these sales are anticipated in 1994 before leveling off.
The decrease in other revenues in 1993 and 1992 resulted from continued decreases in sales of energy and spinning reserve to an affiliated company because of additional energy available to it from new PURPA projects commencing in both years. The 1993 decrease was also due in part to an agreement with the Federal Energy Regulatory Commission to record in 1993 about $6 million of revenues as sales to nonaffiliated utilities. Similar transactions were recorded as other revenues in prior years. Most of the aggregate benefits from sales to affiliated and nonaffiliated utilities is passed on to retail customers and has little effect on consolidated net income.
M-29 Operating Expenses
Fuel expenses decreased 4% in each of the years of 1993 and 1992 primarily due to decreases in kWh generated. Fuel expenses are primarily subject to deferred power cost accounting procedures, as described in Note A to the consolidated financial statements, with the result that changes in fuel expenses have little effect on consolidated net income.
"Purchased power and exchanges, net" represents power purchases from and exchanges with nonaffiliated utilities and qualified facilities under the Public Utility Regulatory Policies Act of 1978 (PURPA), capacity charges paid to AGC, and other transactions with affiliates made pursuant to a power supply agreement whereby each company uses the most economical generation available in the System at any given time, and is comprised of the following items:
1993 1992 1991 (Millions of Dollars) Nonaffiliated transactions: Purchased power: For resale to other utilities $124.5 $153.9 $146.0 From PURPA generation 49.6 56.5 55.6 Other 15.2 5.9 12.9 Power exchanges, net (1.2) .3 (.5) Affiliated transactions: AGC capacity charges 42.3 43.5 44.1 Energy and spinning reserve charges 4.7 3.5 3.8 Other affiliated capacity charges .7 .6 .6
$235.8 $264.2 $262.5
The amount of power purchased from nonaffiliated utilities for use by the Company and for resale to nonaffiliated utilities depends upon the availability of the Company's generating equipment, transmission capacity, and fuel, and its cost of generation and the cost of operations of nonaffiliated utilities from which such purchases are made. The primary reason for the fluctuations in purchases for resale to nonaffiliated utilities is described under Sales and Revenues above. The cost of power and capacity purchased for use by the Company, including power from PURPA generation and affiliated transactions, is mostly recovered from customers currently through the regular fuel and energy cost recovery procedures followed by the Company's regulatory commissions and is primarily subject to deferred power cost procedures with the result that changes in such costs have little effect on consolidated net
M-30
income. The decrease in purchases from PURPA generation in 1993 was due to a planned generating outage at one PURPA project. The 1993 increase in other purchased power reflects efforts to conserve coal during the UMWA dispute.
The increase in other operation expense for 1993 and 1992 resulted primarily from increases in salaries and wages and in 1993 also from employee benefit costs. The Financial Accounting Standards Board's (FASB) standard, SFAS No. 106, increased 1993 postretirement benefit expense by approximately $3.1 million. The Company is currently recovering all of SFAS No. 106 expenses in rates. During 1992, the Company implemented significant changes to its benefits plans, including cost caps, in an effort to both control and reduce employee benefits costs. The cost caps provide for future postretirement medical benefit costs to be capped at two times 1993 levels. Because 1993 medical costs were more than actuarially projected, SFAS No. 106 costs for 1994 are expected to be approximately 5% greater than 1993 amounts.
Another FASB standard, SFAS No. 112, "Employers' Accounting for Postemployment Benefits", effective in 1994, requires companies to accrue for other post- employment benefits such as disability benefits, health care benefits for disabled employees, severance pay, and workers' compensation claims. The Company currently accrues for workers' compensation claims and the estimated liability for the other benefits is not expected to be material.
Maintenance expenses represent costs incurred to maintain the power stations, the transmission and distribution (T&D) system, and general plant, and reflect routine maintenance of equipment and rights-of-way as well as planned major repairs and unplanned expenditures, primarily from forced outages at the power stations and periodic storm damage on the T&D system. Maintenance expense in 1993 includes the effects of an ice storm and blizzard in March 1993. The Company is also experiencing, and expects to continue to experience, increased expenditures due to the aging of its power stations. Variations in maintenance expense result primarily from unplanned events and planned major projects, which vary in timing and magnitude depending upon the length of time equipment has been in service without a major overhaul, the amount of work found necessary when the equipment is dismantled, and outage requirements to comply with the CAAA.
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Depreciation expense increases resulted primarily from additions to electric plant and in 1993 also from a change in depreciation rates and net salvage amortization as a result of the May 1993 rate order. Because of the increased levels of capital expenditures as a result of the CAAA (see Note J to the consolidated financial statements) and the replacement of aging equipment at the Company's power stations, depreciation expense is expected to increase significantly over the next few years.
Taxes other than income increased $2 million in 1993 primarily due to increases in gross receipts taxes resulting from higher revenues from retail customers ($3 million) offset in part by decreased West Virginia Business and Occupation taxes (B&O taxes) ($2 million) due to decreased generation in that state. The 1992 increase resulted from increased property and capital stock taxes ($4 million), increased B&O taxes ($1 million), and increases in gross receipts taxes ($1 million).
The net increase of $7 million in federal and state income taxes in 1993 resulted primarily from an increase in income before taxes ($6 million), and an increase in the tax rate due to the Revenue Reconciliation Act of 1993 ($1 million). The net decrease in 1992 of $4 million resulted primarily from a decrease in income before taxes. Note B to the consolidated financial statements provides a further analysis of income tax expenses.
The combined increase of $.3 million in allowances for funds used during construction (AFUDC) in 1993 reflects increased construction expenditures including those associated with the CAAA, net of CAAA amounts included in rate base and earning a cash return. Future levels of AFUDC can be expected to increase slightly with increasing levels of CAAA expenditures until late 1994 upon substantial completion of Phase I of the CAAA compliance program. The decrease in other income, net, in 1993 resulted primarily from the Company's share of decreases in the earnings of AGC (see Note D to the consolidated financial statements). Other fluctuations in other income, net, were individually insignificant. Other interest expense reflects changes in the level of short-term debt maintained by the Company.
Liquidity and Capital Resources SEC regulations define "liquidity" as "the ability of an enterprise to generate adequate amounts of cash to meet the enterprise's need for cash". The Company needs cash for operating expenses, the payment of interest and dividends, retirement of debt, and for its construction program. To meet these needs, the Company has used internally generated funds and external financings, such
M-32
as the sale of common and preferred stock, debt instruments, instalment loans, and lease arrangements. The timing and amount of external financings depend primarily upon economic and financial market conditions, the Company's cash needs, and capitalization ratio objectives. The availability and cost of external financing depend upon the financial health of the companies seeking those funds.
Capital Requirements Construction expenditures for 1993 were $251 million and for 1994 and 1995 are estimated at $258 million and $208 million, respectively. These estimates include $82 million and $33 million, respectively, for substantial completion of the program of complying with Phase I of the CAAA. It is anticipated that the Harrison Scrubber Project will be completed on schedule (late 1994) and that the final cost will be approximately 24% below the original budget. Primary factors contributing to the reduced cost include: 1) the absence of any major construction problems to date; 2) financing and material and equipment costs lower than expected; and 3) favorable ruling of the Pennsylvania PUC allowing the inclusion of carrying costs of construction in rates in lieu of AFUDC. Construction expenditures through the year 2000 may include substantial amounts for compliance with both Phase I and Phase II of the CAAA. The Company is estimating amounts of approximately $700 million, which includes $207 million expended through 1993, depending upon the strategy eventually selected for complying with Phase II. The mere possibility of new legislation which restricts or discourages carbon dioxide emissions, either through taxation or caps, further complicates the CAAA Phase II planning process. The remaining amount of this CAAA construction estimate, together with normal construction activity assures that continuing external financings will be required. In addition, the Company has additional capital requirements of debt maturities (see Note H to the consolidated financial statements).
Internal Cash Flows Internal generation of cash, consisting of cash flows from operations reduced by dividends, increased to $119 million in 1993. A regulatory commission order has been received from the PUC which provides for current cash recovery of the carrying costs of CAAA expenditures in rates, albeit with a certain amount of lag. Based upon the authorization received and a new rate case planned in 1994, internal generation of cash can be expected to increase.
M-33
Materials and supplies, primarily fuel, constituted a significant source of cash in 1993 ($27 million). The five-year National Bituminous Coal Wage Agreement terminated on February 1, 1993. Coal inventories (fuel) as of December 31, 1992, were increased over 1991 amounts to provide an increased coal supply in the event of a strike. The union chose a strategy of selective shutdowns including mines that accounted for approximately 60% of the System's regular coal supply. The union signed a new five-year contract in December 1993. System coal inventory, which declined during the dispute, and which is somewhat lower than the seasonal norm, is considered adequate.
Financings During 1993 the Company issued $18.04 million of 6.30% tax-exempt solid waste disposal notes to Harrison County, West Virginia, and refunded an aggregate of $246 million of debt securities having interest rates of 7% to 9.75% through the issuance of $251 million of securities having interest rates of 4.95% to 6.375%. The costs associated with the debt redemptions are being amortized over the life of the new bonds. Due to the significant number of refinancings which have occurred over the past two years, this balance is now about $12 million. Reduced future interest expense will more than offset these expenses.
Short-term debt is used to meet temporary cash needs until the timing is considered appropriate to issue long- term securities. The Company canceled or postponed approximately $47 million of debt financings in 1993 due to favorable short-term alternatives. In 1992, the Company and its affiliates established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds available.
At December 31, 1993, the Company had SEC authorization to issue up to $170 million of short-term debt. In addition, a multi-year credit program was established in January 1994, which provides that the Company may borrow on a standby revolving credit basis up to $135 million. After the initial three-year term, the program agreement provides that the maturity date may be extended in one-year increments. The borrowings have the support of a long-term credit facility. During 1994, the Company plans to issue about $105 million of new securities, consisting of both debt and equity issues and, if economic and market conditions make it desirable, may refinance up to $212 million of first mortgage bonds, preferred stock, and pollution control revenue notes. The Company may also engage in additional Harrison County tax-exempt solid waste disposal financings to the extent that funds are available.
The Company anticipates that it will be able to meet its future cash needs through internal cash generation and external financings as it has in the past and possibly through alternative financing procedures.
Environmental Matters and Other Contingencies In the normal course of business, the Company is subject to various contingencies and uncertainties relating to its operations and construction program, including cost recovery in the regulatory process, laws, regulations and uncertainties related to environmental matters, and legal actions. Contingencies and uncertainties related to the CAAA are discussed above and under Note J to the consolidated financial statements.
Pennsylvania has enacted hazardous and solid waste management legislation. While the Company does not have significant hazardous waste concerns, solid wastes, such as fly ash and other coal by-products generated from power stations, must be disposed in accordance with the state requirements. The Company is incurring various costs, which are recoverable in rates, to comply with these and other environmental matters. The level of future expenditures for environmental matters is impossible to determine with any degree of certainty. It is management's opinion that the ultimate costs will not have a material effect on the financial position of the Company.
M-35
As of January 1994, Monongahela Power Company (MP), an affiliated company, has been named as a defendant along with multiple other defendants in 1,429 pending asbestos cases involving multiple plaintiffs and the Company and its affiliates have been named as defendants along with multiple defendants in an additional 626 cases by multiple plaintiffs. Because these cases are filed by "shotgun" complaints naming many plaintiffs and many defendants, it is presently impossible to determine the actual number of claims against the Company and its affiliates. However, based on past experience and data available to date, it is estimated that less than 600 cases actually involve claims against the Company or its affiliates. All complaints allege that the plaintiffs sustained unspecified injuries resulting from claimed exposure to asbestos in various generating plants and other industrial facilities operated by the various defendants, although all plaintiffs do not claim exposure at facilities operated by all defendants. All plaintiffs claiming exposure at System- operated stations were employed by third-party contractors, with the exception of three who claim to have been employees of MP. The Company is joint owner with MP in four generating plants, including three operated by MP in West Virginia. Each plaintiff generally seeks compensatory and punitive damages against all defendants in amounts of up to $1 million and $3 million, respectively; in those cases that include a spousal claim for loss of consortium, damages are generally sought against all defendants in an amount of up to $1 million for the loss of consortium claim. Therefore, because of the multiple defendants, the Company believes its potential liability is a very small percentage of the total amount of the damages sought. A total of 94 cases have been previously settled by MP for an amount substantially less than the anticipated cost of defense. While the Company believes that all of these cases are without merit, it cannot predict the outcome of these cases or whether other cases will be filed.
M-36
AGC
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Results of Operations
As described under Liquidity and Capital Resources, revenues are determined under a cost of service formula rate schedule. Therefore, if all other factors remain equal, revenues are expected to decrease each year due to a normal continuing reduction in the Company's net investment in the Bath County station and its connecting transmission facilities upon which the return on investment is determined. Revenues for 1993 and 1992 decreased due to a reduction in interest charges and net investment, and reduced operating expenses which are described below. Additionally, revenues for 1993 and 1992 were reduced by the recording of estimated liabilities for possible refunds pending final Federal Energy Regulatory Commission (FERC) decisions in rate case proceedings (see Liquidity and Capital Resources).
The net investment (primarily net plant less deferred income taxes) decreases to the extent that provisions for depreciation and deferred income taxes exceed net plant additions. The decrease in operating expenses in 1993 resulted from a decrease in federal income taxes due to a decrease in income before taxes ($1.9 million) offset by an increase in the tax rate due to the Revenue Reconciliation Act of 1993 ($.5 million), partially offset by an increase in operation and maintenance expense. The decrease in operating expenses in 1992 resulted primarily from reduced federal income taxes because of a decrease in income before taxes, partially offset by increases in taxes other than income.
The increase in taxes other than income in 1992 was due to increased property taxes.
The decreases in interest on long-term debt in 1993 and 1992 were the combined result of decreases in the average amount of and interest rates on long-term debt outstanding.
Liquidity and Capital Resources
SEC regulations define "liquidity" as "the ability of an enterprise to generate adequate amounts of cash to meet the enterprise's need for cash". The Company's only operating assets are an undivided 40% interest in the Bath County (Virginia) pumped-storage hydroelectric station and its connecting transmission facilities. The Company has no present plans for construction of any other major facilities.
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Pursuant to an agreement, the Parents buy all of the Company's capacity in the station priced under a "cost of service formula" wholesale rate schedule approved by the FERC. Under this arrangement, the Company recovers in revenues all of its operation and maintenance expenses, depreciation, taxes, and a return on its investment.
Through February 29, 1992, the Company's return on equity (ROE) was adjusted annually pursuant to a settlement agreement approved by the FERC. On March 1, 1990, the ROE decreased from 12% to 11.25%, and on March 1, 1991, it was increased to 11.53%. In December 1991, the Company filed for a continuation of the existing ROE of 11.53% and other parties (the Consumer Advocate Division of the Public Service Commission of West Virginia, Maryland People's Counsel, and Pennsylvania Office of Consumer Advocate, collectively referred to as the joint consumer advocates or JCA) filed to reduce the ROE, with any resultant rate decreases subject to refund from March 1, 1992 through May 31, 1993. Hearings were completed in June 1992, and a recommendation was issued by an Administrative Law Judge (ALJ) on December 21, 1993, for an ROE of 10.83%, which the JCA argues should be further adjusted to reflect changes in capital market conditions since the hearings. Exceptions to this recommendation have been filed by all parties for consideration by the full Commission. On January 28, 1994, the JCA filed a joint complaint claiming that both the existing ROE of 11.53% and the ALJ's recommended ROE of 10.83% are unjust and unreasonable. This new complaint requests an ROE of 8.53%, with rates subject to refund beginning April 1, 1994.
In 1993, the Company issued $50 million of 5.75% medium-term notes due 1998, $50 million of 5.625% debentures due 2003, and $100 million of 6.875% debentures due 2023 to refund $50 million 8% debentures due 1997, $50 million 8.75% debentures due 2017, and $100 million 9.125% debentures due 2016. The Company and its affiliates in 1992 established an internal money pool as a facility to accommodate intercompany short- term borrowing needs, to the extent that certain of the companies have funds available.
- 42 -
ITEM 8.


ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Financial Statements
Financial Statement Schedules -
All other schedules are omitted because they are not applicable or the required information is shown in the Financial Statements or Notes thereto.
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors of Allegheny Power System, Inc.
In our opinion, the consolidated financial statements listed in the accompanying index present fairly, in all material respects, the financial position of Allegheny Power System, Inc. and its subsidiaries at December 31, 1993 and 1992, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. 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 of these statements in accordance with generally accepted auditing standards which 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, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for the opinion expressed above.
As discussed in Notes A, B and E to the consolidated financial statements, the Company changed its method of accounting for income taxes and postretirement benefits other than pensions in 1993.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York February 3, 1994
APS
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (These notes are an integral part of the consolidated financial statements.)
NOTE A--SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: The Company and its subsidiaries (companies) are subject to regulation by the Securities and Exchange Commission. The subsidiaries are subject to regulation by various state bodies having jurisdiction and by the Federal Energy Regulatory Commission (FERC). Significant accounting policies of the Company and its subsidiaries are summarized below. CONSOLIDATION: The Company owns all of the outstanding common stock of its subsidiaries. The consolidated financial statements include the accounts of the Company and all subsidiary companies after elimination of intercompany transactions. REVENUES: Customers are billed on a cycle basis, and revenues, including amounts resulting from the application of fuel and energy cost adjustment clauses, are generally recorded when billed. In accordance with ratemaking procedures followed by Monongahela Power Company in West Virginia, revenues include service rendered but unbilled at year end. Certain increases in rates being collected by subsidiaries are subject to final commission approvals, and possible refunds, for which estimated liabilities have been recorded. DEFERRED POWER COSTS, NET: The costs of fuel, purchased power, and certain other costs, and revenues from sales and transmission services to other utilities, are deferred until they are either recovered from or credited to customers under fuel and energy cost recovery procedures. PROPERTY, PLANT, AND EQUIPMENT: Property, plant, and equipment are stated at original cost, less contributions in aid of construction, except for capital leases which are recorded at present value. Cost includes direct labor and material, allowance for funds used during construction (AFUDC) on property for which construction work in progress is not included in rate base, and such indirect costs as administration, maintenance, and depreciation of transportation and construction equipment, and pensions, taxes, and other fringe benefits related to employees engaged in construction. The cost of depreciable property units retired, plus removal costs less salvage, are charged to accumulated depreciation. ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION: AFUDC, an item that does not represent current cash income, is defined in applicable regulatory systems of accounts as including "the net cost for the period of construction of borrowed funds used for construction purposes and a reasonable rate on other funds when so used". AFUDC is recognized as a cost of property, plant, and equipment with offsetting credits to other income and interest charges. Rates used by the subsidiaries for computing AFUDC in 1993, 1992, and 1991 averaged 9.37%, 9.19%, and 8.84%, respectively.
DEPRECIATION AND MAINTENANCE: Provisions for depreciation are determined generally on a straight-line method based on estimated service lives of depreciable properties and amounted to approximately 3.4% of average depreciable property in 1993 and 3.3% in each of the years 1992 and 1991. The cost of maintenance and of certain replacements of property, plant, and equipment is charged principally to operating expenses. INVESTMENTS: The investment in subsidiaries consolidated represents the excess of acquisition cost over book equity (goodwill) prior to 1966. Goodwill is not being amortized because, in management's opinion, there has been no reduction in its value. Other investments primarily represent the cash surrender values and prepayments of purchased life insurance contracts on certain qualifying management employees under an executive life insurance plan and a supplemental executive retirement plan (Secured Benefit Plan). Payment of future premiums will fully fund these benefits. INCOME TAXES: Financial accounting income before income taxes differs from taxable income principally because certain income and deductions for tax purposes are recorded in the financial income statement in another period. Differences between income tax that would be paid if taxes were computed on the basis of financial accounting income instead of taxable income are accounted for substantially in accordance with the accounting procedures followed for ratemaking purposes. Provisions for federal income tax were reduced in previous years by investment credits, and amounts equivalent to such credits were charged to income with concurrent credits to a deferred account, balances in which are being amortized over estimated service lives of the related properties.
POSTRETIREMENT BENEFITS: The subsidiaries have a noncontributory, defined benefit pension plan covering substantially all employees, including officers. Benefits are based on the employee's years of service and compensation. The funding policy is to contribute annually at least the minimum amount required under the Employee Retirement Income Security Act and not more than can be deducted for federal income tax purposes. The subsidiaries also provide partially contributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which comprise the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. The funding plan for these costs is to contribute to Voluntary Employee Beneficiary Association (VEBA) trust funds an amount equal to the annual cost as determined by Statement of Financial Accounting Standards (SFAS) No. 106 (described below). Medical benefits are self-insured; the life insurance plan is paid through insurance premiums. The Financial Accounting Standards Board (FASB) has prescribed the determination of annual pension and other postretirement benefits expenses in SFAS No. 87, "Employers' Accounting for Pensions", and SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions", respectively. Pursuant to SFAS No. 71, "Accounting for the Effects of Certain Types of Regulation", regulatory deferrals of these benefit expenses are recorded for those jurisdictions which reflect as net expense the funding of pensions and cash payment of other benefits in the ratemaking process. TEMPORARY CASH INVESTMENTS: For purposes of the Consolidated Statement of Cash Flows, temporary cash investments with original maturities of three months or less, generally in the form of commercial paper, certificates of deposit, and repurchase agreements, are considered to be the equivalent of cash. The carrying amount of temporary cash investments approximates the fair value because of the short-term maturity of those instruments. ACCOUNTING CHANGES: Effective January 1, 1993, the subsidiaries adopted SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions". This statement requires the costs of providing postretirement benefits, such as medical and life insurance, to be accrued over the applicable employees' service periods. Prior to 1993, medical expenses and life insurance premiums paid for retired employees and their dependents were recorded as expense in the period they were paid. Also effective January 1, 1993, the subsidiaries adopted SFAS No. 109, "Accounting for Income Taxes". This standard mandated a change from the previous income-based deferral approach to a balance sheet-based liability approach for computing deferred income taxes as further described in Note B.
The total provision for income taxes is different than the amount produced by applying the federal income statutory tax rate to financial accounting income before preferred dividends and income taxes, as set forth below:
Federal income tax returns through 1989 have been examined and substantially settled. In adopting SFAS No. 109, the subsidiaries recognized a significant increase in both deferred tax assets and liabilities. At December 31, 1993, the deferred tax assets and liabilities were comprised of the following: (Thousands of Dollars) Deferred tax assets: Unamortized investment tax credit $ 105 289 Unbilled revenue 38 363 Tax interest capitalized 22 236 Contributions in aid of construction 17 176 State tax loss carryback/carryforward 14 560 Other 21 658 219 282 Deferred tax liabilities: Book vs. tax plant basis differences, net 1 051 500 Other 42 122 1 093 622 Total net deferred tax liabilities 874 340 Less portion above included in current liabilities 645 Total long-term net deferred tax liabilities $ 873 695
It is expected that regulatory commissions will allow recovery of the deferred tax liabilities in future years as they are paid, and accordingly, the subsidiaries have recorded regulatory assets for an amount equal to the $562 million increase in deferred tax liabilities. Regulatory liabilities were recorded in an amount equal to the $108 million increase in deferred tax assets to reflect the subsidiaries' obligation to pass such tax benefits on to their customers as the benefits are realized in cash in future years. Based on the provisions in the standard for recording these regulatory assets and liabilities on the balance sheet, there was no effect on consolidated net income resulting from adoption of the standard.
NOTE C--DIVIDEND RESTRICTION: Supplemental indentures relating to most outstanding bonds of subsidiaries contain dividend restrictions under the most restrictive of which $461,539,000 of consolidated retained earnings at December 31, 1993, is not available for cash dividends on their common stocks, except that a portion thereof may be paid as cash dividends where concurrently an equivalent amount of cash is received by a subsidiary as a capital contribution or as the proceeds of the issue and sale of shares of such subsidiary's common stock.
The benefits earned to date and funded status at December 31 using a measurement date of September 30 were as follows:
In determining the actuarial present value of the projected benefit obligation at December 31, 1993, 1992, and 1991, the discount rates used were 7.25%, 7.75%, and 8%, and the rates of increase in future compensation levels were 4.75%, 5.25%, and 5.5%, respectively. The expected long-term rate of return on assets was 9% in each of the years 1993, 1992, and 1991.
NOTE E--POSTRETIREMENT BENEFITS OTHER THAN PENSIONS: The subsidiaries adopted SFAS No. 106 as of January 1, 1993, which requires accrual of postretirement benefits other than pensions (principally health care and life insurance) for the employee and covered dependents during the years the employee renders the necessary service to receive such benefits. Prior to 1993, medical expenses and life insurance premiums paid by the subsidiaries for retired employees and their dependents were recorded in expense in the period in which they were paid and were $6,553,000 and $5,691,000 in 1992 and 1991, respectively. SFAS No. 106 postretirement cost in 1993, a portion of which (about 30%) was charged to plant construction, included the following components: (Thousands of Dollars) Service cost--benefits earned $ 2 000 Interest cost on accumulated postretirement benefit obligation 11 300 Actual return on plan assets (24) Amortization of unrecognized transition obligation 7 300 Other net amortization and deferral 24 SFAS No. 106 postretirement cost 20 600 Regulatory deferral (4 790) Net postretirement cost $15 810
The benefits earned to date and funded status at December 31, 1993, using a measurement date of September 30 were as follows: (Thousands of Dollars) Accumulated postretirement benefit obligation: Retirees $115 019 Fully eligible employees 24 135 Other employees 55 255 Total obligation 194 409 Plan assets at market value in short-term investment fund 4 646 Accumulated postretirement benefit obligation in excess of plan assets 189 763 Less: Unrecognized cumulative net loss from past experience different from that assumed 41 450 Unrecognized transition obligation, being amortized over 20 years beginning January 1, 1993 138 200 Postretirement benefit liability at September 30, 1993 10 113 Fourth quarter 1993 contributions and benefit payments 4 549 Postretirement benefit liability at December 31, 1993 $ 5 564
The unfunded accumulated postretirement benefit obligation (APBO) at January 1, 1993, of $145,500,000 (transition obligation) is being amortized prospectively over 20 years as permitted by the standard. In determining the APBO at January 1 and December 31, 1993, the discount rates used were 8% and 7.25%, the rates of increase in future compensation levels were 5.5% and 4.75%, respectively. For measurement purposes, a health care trend rate of 14% for 1993, declining 1% each year thereafter to 7% in the year 2000 and beyond, and plan provisions which limit future medical and life insurance benefits were assumed. Increasing the assumed health care trend rate by 1% in each year would increase the APBO at December 31, 1993, by $13.4 million and the aggregate of the service and interest cost components of net periodic postretirement benefit cost for 1993 by $1.0 million. Recovery of SFAS No. 106 costs has been authorized for retail customers in Maryland effective in February 1993, in Pennsylvania effective in May 1993, and for the FERC wholesale customers effective in mid-to-late 1993. Regulatory actions have been taken by the Virginia and Ohio regulatory commissions which provide support that substantial recovery is probable. Recovery has been requested in rate cases filed in Virginia and West Virginia for which final commission decisions are expected in 1994. The subsidiaries have recorded regulatory assets at December 31, 1993, of $4.8 million relating to those regulatory jurisdictions where full recovery of SFAS No. 106 level of expenses has not yet been granted recovery in rates, with the result that adoption of SFAS No. 106 has had no effect on consolidated net income.
NOTE F--STOCKHOLDERS' EQUITY: COMMON STOCK: In November 1993, the common shareholders approved a two-for-one split of the Company's common stock which was effective November 4, 1993. The stock split reduced the par value of the common stock from $2.50 per share to $1.25 per share and increased the number of authorized shares of common stock from 130,000,000 to 260,000,000. The number of common stock shares outstanding and per share information for all periods reflect the two-for-one split. PREFERRED STOCK: All of the preferred stock is entitled on voluntary liquidation to its then current call price and on involuntary liquidation to $100 a share. The holders of West Penn Power Company's auction preferred stock are entitled to dividends at a rate determined by an auction held the business day preceding each quarterly dividend payment date. MANDATORILY REDEEMABLE PREFERRED STOCK: The Potomac Edison Company's $7.16 preferred stock is entitled to a cumulative sinking fund sufficient to retire 12,000 shares each year, commencing in 1992, at $100 a share plus accrued dividends. That subsidiary has the noncumulative option in each year to retire up to an additional 12,000 shares at the same price. The estimated fair value of this series of preferred stock at December 31, 1993 and 1992, was $28,566,000 and $28,944,000, respectively, based on quoted market prices. The call price declines in future years. In August 1993, The Potomac Edison Company redeemed the remaining 4,046 outstanding shares of Series B, 4.70% preferred stock.
NOTE G--LONG-TERM DEBT: Maturities for long-term debt for the next five years are: 1994, $26,000,000; 1995, $28,000,000; 1996, $43,575,000; 1997, $48,262,000; and 1998, $185,400,000. Substantially all of the properties of the subsidiaries are held subject to the lien securing each subsidiary's first mortgage bonds. Some properties are also subject to a second lien securing certain pollution control and solid waste disposal notes. Commercial paper borrowings issuable by Allegheny Generating Company are backed by a revolving credit agreement with a group of seven banks which provides for loans of up to $75 million at any one time outstanding through 1997. Each bank has the option to discontinue its loans after 1997 upon three years' prior written notice. Without such notice, the loans are automatically extended for one year. However, to the extent that funds are available from the companies, Allegheny Generating Company borrowings are made through an internal money pool as described in Note H. The estimated fair value of long-term debt at December 31, 1993 and 1992, was $2,129,923,000 and $2,033,103,000, respectively, based on actual market prices or market prices of similar issues.
NOTE H--SHORT-TERM DEBT: To provide interim financing and support for outstanding commercial paper, lines of credit have been established with several banks. The companies have fee arrangements on all of their lines of credit and no compensating balance requirements. At December 31, 1993, unused lines of credit with banks were $149,175,000. In addition to bank lines of credit, in 1992 the companies established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds available. In January 1994, a multi-year credit program was established which provides that the subsidiaries may borrow up to $300 million on a standby revolving credit basis. Short-term debt outstanding at the end of 1993 consisted of notes payable to banks ($75,825,000) and commercial paper ($54,811,000) and at the end of 1992 consisted of a note payable to a bank ($11,205,000). The carrying amount of short-term debt approximates the fair value because of the short-term maturity of those instruments.
NOTE I--COMMITMENTS AND CONTINGENCIES: CONSTRUCTION PROGRAM: The subsidiaries have entered into commitments for their construction programs, for which expenditures are estimated to be $500 million for 1994 and $400 million for 1995. These estimates include expenditures for the program of complying with the Clean Air Act Amendments of 1990 (CAAA) as discussed below. ENVIRONMENTAL MATTERS: The companies are subject to laws, regulations, and uncertainties as to environmental matters discussed under ITEM 1. ENVIRONMENTAL MATTERS. Compliance may require them to incur substantial additional costs to modify or replace existing and proposed equipment and facilities and may affect adversely the lead time, size, and siting of future generating stations, increase the complexity and cost of pollution control equipment, and otherwise add to the cost of future operations. Construction expenditures through the year 2000 will include substantial amounts for compliance with Phase I and Phase II of the CAAA. The subsidiaries are estimating expenditures of approximately $1.4 billion, which includes $482 million expended through 1993, depending on the strategy eventually selected for complying with Phase II. Construction estimates for 1994 and 1995 include $161 million and $53 million, respectively, for the program of complying with the CAAA. In complying with the CAAA, the subsidiaries will face uncertainties, including regulatory administrative interpretations and contingencies, such as potential cost overruns, equipment performance, and cost recovery in rates. LITIGATION: In the normal course of business, the companies become involved in various legal proceedings. The companies do not believe that the ultimate outcome of these proceedings will have a material effect on their financial position.
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors of Monongahela Power Company
In our opinion, the financial statements listed in the accompanying index present fairly, in all material respects, the financial position of Monongahela Power Company (a subsidiary of Allegheny Power System, Inc.) at December 31, 1993 and 1992, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. 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 of these statements in accordance with generally accepted auditing standards which 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, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for the opinion expressed above.
As discussed in Notes A, B and F to the financial statements, the Company changed its method of accounting for income taxes and postretirement benefits other than pensions in 1993.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York February 3, 1994
Preferred Stock (not subject to mandatory redemption): Cumulative preferred stock - par value $100 per share, authorized 1,500,000 shares, outstanding as follows (Note G):
Monongahela NOTES TO FINANCIAL STATEMENTS
(These notes are an integral part of the financial statements.)
Note A - Summary of Significant Accounting Policies: The Company is a wholly-owned subsidiary of Allegheny Power System, Inc. and is a part of the Allegheny Power integrated electric utility system (the System).
The Company is subject to regulation by the Securities and Exchange Commission (SEC), by various state bodies having jurisdiction, and by the Federal Energy Regulatory Commission (FERC). Significant accounting policies of the Company are summarized below.
REVENUES: Customers are billed on a cycle basis, and revenues, including amounts resulting from the application of fuel and energy cost adjustment clauses, are generally recorded when billed. In accordance with ratemaking procedures in West Virginia, revenues include service rendered but unbilled at year end.
DEFERRED POWER COSTS, NET: The costs of fuel, purchased power, and certain other costs, and revenues from sales and transmission services to other utilities, are deferred until they are either recovered from or credited to customers under fuel and energy cost recovery procedures.
PROPERTY, PLANT, AND EQUIPMENT: Property, plant, and equipment, including facilities owned with affiliates in the System, are stated at original cost, less contributions in aid of construction, except for capital leases which are recorded at present value. Cost includes direct labor and material, allowance for funds used during construction (AFUDC) on property for which construction work in progress is not included in rate base, and such indirect costs as administration, maintenance, and depreciation of transportation and construction equipment, and pensions, taxes, and other fringe benefits related to employees engaged in construction.
The cost of depreciable property units retired, plus removal costs less salvage, are charged to accumulated depreciation.
ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION: AFUDC, an item that does not represent current cash income, is defined in applicable regulatory systems of accounts as including "the net cost for the period of construction of borrowed funds used for construction purposes and a reasonable rate on other funds when so used". AFUDC is recognized as a cost of property, plant, and equipment with offsetting credits to other income and interest charges. Rates used for computing AFUDC in 1993, 1992, and 1991 were 8.69%, 8.23%, and 6.17%, respectively. In accordance with FERC guidelines, the 1991 rate was based solely on borrowed funds because the Company's average outstanding short-term debt was greater than the average construction work in progress balance.
DEPRECIATION AND MAINTENANCE: Provisions for depreciation are determined generally on a straight-line method based on estimated service lives of depreciable properties and amounted to approximately 3.8% of average depreciable property in each of the years 1993, 1992, and 1991. The cost of maintenance and of certain replacements of property, plant, and equipment is charged principally to operating expenses.
INCOME TAXES: The Company joins with its parent and affiliates in filing a consolidated federal income tax return. The consolidated tax liability is allocated among the participants generally in proportion to the taxable income of each participant, except that no subsidiary pays tax in excess of its separate return tax liability.
Financial accounting income before income taxes differs from taxable income principally because certain income and deductions for tax purposes are recorded in the financial income statement in another period. Differences between income tax that would be paid if taxes were computed on the basis of financial accounting income instead of taxable income are accounted for substantially in accordance with the accounting procedures followed for ratemaking purposes.
Provisions for federal income tax were reduced in previous years by investment credits, and amounts equivalent to such credits were charged to income with concurrent credits to a deferred account, balances in which are being amortized over estimated service lives of the related properties.
POSTRETIREMENT BENEFITS: The Company participates with affiliated companies in the System in a noncontributory, defined benefit pension plan covering substantially all employees, including officers. Benefits are based on the employee's years of service and compensation. The funding policy is to contribute annually at least the minimum amount required under the Employee Retirement Income Security Act and not more than can be deducted for federal income tax purposes.
The Company also provides partially contributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which comprise the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. The funding plan for these costs is to contribute to Voluntary Employee Beneficiary Association (VEBA) trust funds an amount equal to the annual cost as determined by Statement of Financial Accounting Standards (SFAS) No. 106 (described below). Medical benefits are self-insured; the life insurance plan is paid through insurance premiums.
The Financial Accounting Standards Board (FASB) has prescribed the determination of annual pension and other postretirement benefits expenses in SFAS No. 87, "Employers' Accounting for Pensions", and SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions", respectively. Pursuant to SFAS No. 71, "Accounting for the Effects of Certain Types of Regulation", regulatory deferrals of these benefit expenses are recorded for those jurisdictions which reflect as net expense the funding of pensions and cash payment of other benefits in the ratemaking process.
TEMPORARY CASH INVESTMENTS: For purposes of the Statement of Cash Flows, temporary cash investments with original maturities of three months or less, generally in the form of commercial paper, certificates of deposit, and repurchase agreements, are considered to be the equivalent of cash.
ACCOUNTING CHANGES: Effective January 1, 1993, the Company adopted SFAS No. 106, "Employers' Accounting for Post- retirement Benefits Other Than Pensions". This statement requires the costs of providing postretirement benefits, such as medical and life insurance, to be accrued over the applicable employees' service periods. Prior to 1993, medical expenses and life insurance premiums paid for retired employees and their dependents were recorded as expense in the period they were paid. Also effective January 1, 1993, the Company adopted SFAS No. 109, "Accounting for Income Taxes". This standard mandated a change from the previous income-based deferral approach to a balance sheet-based liability approach for computing deferred income taxes as further described in Note B.
The total provision for income taxes is different than the amount produced by applying the federal income statutory tax rate to financial accounting income before income taxes, as set forth below:
Federal income tax returns through 1989 have been examined and substantially settled.
In adopting SFAS No. 109, the Company recognized a significant increase in both deferred tax assets and liabilities. At December 31, 1993, the deferred tax assets and liabilities were comprised of the following:
(Thousands of Dollars)
Deferred tax assets: Unamortized investment tax credit $18 043 Unbilled revenue 4 181 Tax interest capitalized 2 430 Contributions in aid of construction 2 058 Vacation pay 1 958 Advances for construction 1 601 Other 4 455 34 726
Deferred tax liabilities: Book vs. tax plant basis differences, net 205 829 Other 23 411 229 240
Total net deferred tax liabilities 194 514 Less portion above included in current liabilities 2 048
Total long-term net deferred tax liabilities $192 466
It is expected that regulatory commissions will allow recovery of the deferred tax liabilities in future years as they are paid, and accordingly, the Company has recorded regulatory assets for an amount equal to the $158 million increase in deferred tax liabilities. Regulatory liabilities were recorded in an amount equal to the $19 million increase in deferred tax assets to reflect the Company's obligation to pass such tax benefits on to its customers as the benefits are realized in cash in future years. Based on the provisions in the standard for recording these regulatory assets and liabilities on the balance sheet, there was no effect on net income resulting from adoption of the standard.
Note C - Dividend Restriction:
Supplemental indentures relating to most outstanding bonds of the Company contain dividend restrictions under the most restrictive of which $103,482,000 of retained earnings at December 31, 1993, is not available for cash dividends on common stock, except that a portion thereof may be paid as cash dividends where concurrently an equivalent amount of cash is received by the Company as a capital contribution or as the proceeds of the issue and sale of shares of its common stock.
Note D - Allegheny Generating Company:
The Company owns 27% of the common stock of Allegheny Generating Company (AGC), and affiliates of the Company own the remainder. AGC owns an undivided 40% interest, 840 MW, in the 2,100-MW pumped-storage hydroelectric station in Bath County, Virginia operated by the 60% owner, Virginia Power Company, an unaffiliated utility.
AGC recovers from the Company and its affiliates all of its operation and maintenance expenses, depreciation, taxes, and a return on its investment under a wholesale rate schedule approved by the FERC. Through February 29, 1992, AGC's return on equity (ROE) was adjusted annually pursuant to a settlement agreement approved by the FERC. In December 1991, AGC filed for a continuation of the existing ROE of 11.53% and other parties (the Consumer Advocate Division of the West Virginia PSC, Maryland People's Counsel, and Pennsylvania Office of Consumer Advocate, collectively referred to as the joint consumer advocates or JCA) filed to reduce the ROE, with any resultant rate decreases subject to refund from March 1, 1992 through May 31, 1993. Hearings were completed in June 1992, and a recommendation was issued by an Administrative Law Judge (ALJ) on December 21, 1993, for an ROE of 10.83%, which the JCA argues should be further adjusted to reflect changes in capital market conditions since the hearings. Exceptions to this recommendation have been filed by all parties for consideration by the full Commission. On January 28, 1994, the JCA filed a joint complaint claiming that both the existing ROE of 11.53% and the ALJ's recommended ROE of 10.83% are unjust and unreasonable. This new complaint requests an ROE of 8.53%, with rates subject to refund beginning April 1, 1994.
Following is a summary of financial information for AGC:
The Company's share of the equity in earnings above was $7.3 million, $8.3 million, and $8.9 million for 1993, 1992, and 1991, respectively, and was included in other income, net, on the Statement of Income.
Note E - Pension Benefits: The Company's share of net pension costs under the System's pension plan, a portion of which (about 30%) was charged to plant construction, included the following components:
The benefits earned to date and funded status of the Company's share of the System plan at December 31 using a measurement date of September 30 were as follows:
The foregoing includes the Company's portion of amounts applicable to employees at power stations which are owned jointly with affiliates.
In determining the actuarial present value of the projected benefit obligation at December 31, 1993, 1992, and 1991, the discount rates used were 7.25%, 7.75%, and 8%, and the rates of increase in future compensation levels were 4.75%, 5.25%, and 5.5%, respectively. The expected long-term rate of return on assets was 9% in each of the years 1993, 1992, and 1991.
Note F - Postretirement Benefits Other Than Pensions: The Company adopted SFAS No. 106 as of January 1, 1993, which requires accrual of postretirement benefits other than pensions (principally health care and life insurance) for the employee and covered dependents during the years the employee renders the necessary service to receive such benefits. Prior to 1993, medical expenses and life insurance premiums paid by the Company for retired employees and their dependents were recorded in expense in the period in which they were paid and were $2,390,000 and $2,029,000 in 1992 and 1991, respectively.
SFAS No. 106 postretirement cost in 1993, a portion of which (about 30%) was charged to plant construction, included the following components:
(Thousands of Dollars)
Service cost - benefits earned $ 478 Interest cost on accumulated postretirement benefit obligation 2 819 Actual return on plan assets (5) Amortization of unrecognized transition obligation 1 772 Other net amortization and deferral 5
SFAS No. 106 postretirement cost 5 069 Regulatory deferral (1 981)
Net postretirement cost $3 088
The benefits earned to date and funded status of the Company's share of the System plan at December 31, 1993, using a measurement date of September 30 were as follows:
(Thousands of Dollars)
Accumulated postretirement benefit obligation: Retirees $32 469 Fully eligible employees 4 348 Other employees 14 664
Total obligation 51 481 Plan assets at market value in short-term investment fund 1 230
Accumulated postretirement benefit obligation in excess of plan assets 50 251 Less: Unrecognized cumulative net loss from past experience different from that assumed 14 161 Unrecognized transition obligation, being amortized over 20 years beginning January 1, 1993 34 059
Postretirement benefit liability at September 30, 1993 2 031 Fourth quarter 1993 contributions and benefit payments 997
Postretirement benefit liability at December 31, 1993 $ 1 034
The unfunded accumulated postretirement benefit obligation (APBO) at January 1, 1993, of $35,800,000 (transition obligation), is being amortized prospectively over 20 years as permitted by the standard.
In determining the APBO at January 1 and December 31, 1993, the discount rates used were 8% and 7.25%, and the rates of increase in future compensation levels were 5.5% and 4.75%, respectively. For measurement purposes, a health care trend rate of 14% for 1993, declining 1% each year thereafter to 7% in the year 2000 and beyond, and plan provisions which limit future medical and life insurance benefits were assumed. Increasing the assumed health care trend rate by 1% in each year would increase the APBO at December 31, 1993, by $3.5 million and the aggregate of the service and interest cost components of net periodic postretirement benefit cost for 1993 by $.2 million.
Recovery of SFAS No. 106 costs has been authorized for FERC wholesale customers effective in December 1993. Recovery has been requested in a rate case filed in West Virginia for which a final commission decision is expected in 1994. Regulatory action has been taken by the Ohio regulatory commission which provides support that substantial recovery is probable. The Company has recorded regulatory assets at December 31, 1993, of $2.0 million for West Virginia and Ohio where full recovery of SFAS No. 106 level of expenses has not yet been granted recovery in rates, with the result that adoption of SFAS No. 106 has had no effect on net income.
Note G - Stockholders' Equity: COMMON STOCK AND OTHER PAID-IN CAPITAL: In September 1992, the Company issued and sold to its parent, 800,000 shares of its common stock at $50 per share. Other paid-in capital decreased $4,000 in 1992 as a result of a preferred stock redemption.
PREFERRED STOCK: All of the preferred stock is entitled on voluntary liquidation to its then current call price and on involuntary liquidation to $100 a share.
Note H - Long-Term Debt:
Maturities for long-term debt for the next five years are: 1994 and 1995, none; 1996, $18,500,000; 1997, $15,500,000; and 1998, $20,100,000. Substantially all of the properties of the Company are held subject to the lien securing its first mortgage bonds. Some properties are also subject to a second lien securing certain pollution control and solid waste disposal notes. Certain first mortgage bond series are not redeemable by certain refunding until dates established in the respective supplemental indentures.
In 1993, the Company sold $65 million of 5-5/8% 7-year first mortgage bonds to refund a $10 million 8-1/8% issue due in 1999, a $30 million 7-7/8% issue due in 2002, and a $20 million 7-1/2% issue due in 1998. The Company also issued $7.05 million of 5.95% 20-year Pollution Control Revenue Notes to Monongalia County, West Virginia to refund a $7.05 million 9.5% issue due in 2013.
The estimated fair value of long-term debt at December 31, 1993 and 1992, was $485,713,000 and $461,663,000, respectively, based on actual market prices or market prices of similar issues.
Note I - Short-Term Debt: To provide interim financing and support for outstanding commercial paper, the System companies have established lines of credit with several banks. The Company has SEC authorization for total short-term borrowings of $100 million including money pool borrowings described below. The Company has fee arrangements on all of its lines of credit and no compensating balance requirements. In addition to bank lines of credit, in 1992 the Company and its affiliates established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds available. In January 1994, the Company and its affiliates jointly established an aggregate $300 million multi-year credit program which provides that the Company may borrow up to $81 million on a standby revolving credit basis. Short-term debt outstanding at the end of 1993 consisted of $63.1 million of notes payable to banks and at the end of 1992 consisted of money pool borrowings from affiliates of $8.03 million. The carrying amount of short-term debt approximates the fair value because of the short-term maturity of those instruments.
Note J - Commitments and Contingencies: CONSTRUCTION PROGRAM: The Company has entered into commitments for its construction program, for which expenditures are estimated to be $103 million for 1994 and $83 million for 1995. These estimates include expenditures for the program of complying with the Clean Air Act Amendments of 1990 (CAAA) as discussed below.
ENVIRONMENTAL MATTERS: System companies are subject to laws, regulations, and uncertainties with respect to air and water quality, land use, and other environmental matters. Compliance may require them to incur substantial additional costs to modify or replace existing and proposed equipment and facilities and may affect adversely the lead time, size, and siting of future generating stations, increase the complexity and cost of pollution control equipment, and otherwise add to the cost of future operations.
Construction expenditures through the year 2000 will include substantial amounts for compliance with Phase I and Phase II of the CAAA. The Company is estimating expenditures of approximately $400 million, which includes $122 million expended through 1993, depending on the strategy eventually selected for complying with Phase II. Construction estimates for 1994 and 1995 include $39 million and $10 million, respectively, for the program of complying with the CAAA.
In complying with the CAAA, the Company will face uncertainties, including regulatory administrative interpretations and contingencies, such as potential cost overruns, equipment performance, and cost recovery in rates.
LITIGATION AND OTHER: In the normal course of business, the Company becomes involved in various legal proceedings. The Company does not believe that the ultimate outcome of these proceedings will have a material effect on its financial position.
The Company is guarantor as to 27% of a $75 million revolving credit agreement of AGC, which in 1993 was used by AGC solely as support for its indebtedness for commercial paper outstanding.
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors of The Potomac Edison Company
In our opinion, the financial statements listed in the accompanying index present fairly, in all material respects, the financial position of The Potomac Edison Company (a subsidiary of Allegheny Power System, Inc.) at December 31, 1993 and 1992, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. 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 of these statements in accordance with generally accepted auditing standards which 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, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for the opinion expressed above.
As discussed in Notes A, B and F to the financial statements, the Company changed its method of accounting for income taxes and postretirement benefits other than pensions in 1993.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York February 3, 1994
Potomac
NOTES TO FINANCIAL STATEMENTS (These notes are an integral part of the financial statements.)
Note A - Summary of Significant Accounting Policies:
The Company is a wholly-owned subsidiary of Allegheny Power System, Inc. and is a part of the Allegheny Power integrated electric utility system (the System).
The Company is subject to regulation by the Securities and Exchange Commission (SEC), by various state bodies having jurisdiction, and by the Federal Energy Regulatory Commission (FERC). Significant accounting policies of the Company are summarized below.
REVENUES: Customers are billed on a cycle basis, and revenues, including amounts resulting from the application of fuel and energy cost adjustment clauses, are recorded when billed. Revenues of $63.4 million from one industrial customer, Eastalco Aluminum Company, were 8.9% of total electric operating revenues in 1993. Certain increases in rates being collected by the Company in Virginia are subject to final commission approval, and possible refunds, for which estimated liabilities have been recorded.
DEFERRED POWER COSTS, NET: The costs of fuel, purchased power, and certain other costs, and revenues from sales and transmission services to other utilities, are deferred until they are either recovered from or credited to customers under fuel and energy cost recovery procedures.
PROPERTY, PLANT, AND EQUIPMENT: Property, plant, and equipment, including facilities owned with affiliates in the System, are stated at original cost, less contributions in aid of construction. Cost includes direct labor and material, allowance for funds used during construction (AFUDC) on property for which construction work in progress is not included in rate base, and such indirect costs as administration, maintenance, and depreciation of transportation and construction equipment, and pensions, taxes, and other fringe benefits related to employees engaged in construction.
The cost of depreciable property units retired, plus removal costs less salvage, are charged to accumulated depreciation.
ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION: AFUDC, an item that does not represent current cash income, is defined in applicable regulatory systems of accounts as including "the net cost for the period of construction of borrowed funds used for construction purposes and a reasonable rate on other funds when so used". AFUDC is recognized as a cost of property, plant, and equipment with offsetting credits to other income and interest charges. Rates used for computing AFUDC in 1993, 1992, and 1991 were 9.97%, 9.92%, and 9.93%, respectively. AFUDC is not recorded for construction applicable to the state of Virginia, where construction work in progress is included in rate base.
DEPRECIATION AND MAINTENANCE: Provisions for depreciation are determined generally on a straight-line method based on estimated service lives of depreciable properties and amounted to approximately 3.6% of average depreciable property in each of the years 1993, 1992, and 1991. The cost of maintenance and of certain replacements of property, plant, and equipment is charged principally to operating expenses.
INCOME TAXES: The Company joins with its parent and affiliates in filing a consolidated federal income tax return. The consolidated tax liability is allocated among the participants generally in proportion to the taxable income of each participant, except that no subsidiary pays tax in excess of its separate return tax liability.
Financial accounting income before income taxes differs from taxable income principally because certain income and deductions for tax purposes are recorded in the financial income statement in another period. Differences between income tax that would be paid if taxes were computed on the basis of financial accounting income instead of taxable income are accounted for substantially in accordance with the accounting procedures followed for ratemaking purposes.
Provisions for federal income tax were reduced in previous years by investment credits, and amounts equivalent to such credits were charged to income with concurrent credits to a deferred account, balances in which are being amortized over estimated service lives of the related properties.
POSTRETIREMENT BENEFITS: The Company participates with affiliated companies in the System in a noncontributory, defined benefit pension plan covering substantially all employees, including officers. Benefits are based on the employee's years of service and compensation. The funding policy is to contribute annually at least the minimum amount required under the Employee Retirement Income Security Act and not more than can be deducted for federal income tax purposes.
The Company also provides partially contributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which comprise the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. The funding plan for these costs is to contribute to Voluntary Employee Beneficiary Association (VEBA) trust funds an amount equal to the annual cost as determined by Statement of Financial Accounting Standards (SFAS) No. 106 (described below). Medical benefits are self-insured; the life insurance plan is paid through insurance premiums.
The Financial Accounting Standards Board (FASB) has prescribed the determination of annual pension and other postretirement benefits expenses in SFAS No. 87, "Employers' Accounting for Pensions", and SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions", respectively. Pursuant to SFAS No. 71, "Accounting for the Effects of Certain Types of Regulation", regulatory deferrals of these benefit expenses are recorded for those jurisdictions which reflect as net expense the funding of pensions and cash payment of other benefits in the ratemaking process.
TEMPORARY CASH INVESTMENTS: For purposes of the Statement of Cash Flows, temporary cash investments with original maturities of three months or less, generally in the form of commercial paper, certificates of deposit, and repurchase agreements, are considered to be the equivalent of cash.
ACCOUNTING CHANGES: Effective January 1, 1993, the Company adopted SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions". This statement requires the costs of providing postretirement benefits, such as medical and life insurance, to be accrued over the applicable employees' service periods. Prior to 1993, medical expenses and life insurance premiums paid for retired employees and their dependents were recorded as expense in the period they were paid. Also effective January 1, 1993, the Company adopted SFAS No. 109, "Accounting for Income Taxes". This standard mandated a change from the previous income-based deferral approach to a balance sheet-based liability approach for computing deferred income taxes as further described in Note B.
The total provision for income taxes is less than the amount produced by applying the federal income statutory tax rate to financial accounting income before income taxes, as set forth below:
Federal income tax returns through 1989 have been examined and substantially settled.
In adopting SFAS No. 109, the Company recognized a significant increase in both deferred tax assets and liabilities. At December 31, 1993, the deferred tax assets and liabilities were comprised of the following:
(Thousands of Dollars) Deferred tax assets: Unamortized investment tax credit $17 922 Unbilled revenue 12 556 Contributions in aid of construction 10 530 Tax interest capitalized 9 056 State tax loss carryback/carryforward 5 770 Advances for construction 1 303 Other 3 279
60 416 Deferred tax liabilities: Book vs. tax plant basis differences, net 183 892 Other 10 122
194 014
Total net deferred tax liabilities 133 598 Less portion above included in current liabilities 571
Total long-term net deferred tax liabilities $133 027
It is expected that regulatory commissions will allow recovery of the deferred tax liabilities in future years as they are paid, and accordingly, the Company has recorded regulatory assets for an amount equal to the $74 million increase in deferred tax liabilities. Regulatory liabilities were recorded in an amount equal to the $19 million increase in deferred tax assets to reflect the Company's obligation to pass such tax benefits on to its customers as the benefits are realized in cash in future years. Based on the provisions in the standard for recording these regulatory assets and liabilities on the balance sheet, there was no effect on net income resulting from adoption of the standard.
Note C - Dividend Restriction: Supplemental indentures relating to most outstanding bonds of the Company contain dividend restrictions under the most restrictive of which $103,730,000 of retained earnings at December 31, 1993, is not available for cash dividends on common stock, except that a portion thereof may be paid as cash dividends where concurrently an equivalent amount of cash is received by the Company as a capital contribution or as the proceeds of the issue and sale of shares of its common stock.
Note D - Allegheny Generating Company: The Company owns 28% of the common stock of Allegheny Generating Company (AGC), and affiliates of the Company own the remainder. AGC owns an undivided 40% interest, 840 MW, in the 2,100-MW pumped-storage hydroelectric station in Bath County, Virginia operated by the 60% owner, Virginia Power Company, an unaffiliated utility.
AGC recovers from the Company and its affiliates all of its operation and maintenance expenses, depreciation, taxes, and a return on its investment under a wholesale rate schedule approved by the FERC. Through February
29, 1992, AGC's return on equity (ROE) was adjusted annually pursuant to a settlement agreement approved by the FERC. In December 1991, AGC filed for a continuation of the existing ROE of 11.53% and other parties (the Consumer Advocate Division of the West Virginia PSC, Maryland People's Counsel, and Pennsylvania Office of Consumer Advocate, collectively referred to as the joint consumer advocates or JCA) filed to reduce the ROE, with any resultant rate decreases subject to refund from March 1, 1992 through May 31, 1993. Hearings were completed in June 1992, and a recommendation was issued by an Administrative Law Judge (ALJ) on December 21, 1993, for an ROE of 10.83%, which the JCA argues should be further adjusted to reflect changes in capital market conditions since the hearings. Exceptions to this recommendation have been filed by all parties for consideration by the full Commission. On January 28, 1994, the JCA filed a joint complaint claiming that both the existing ROE of 11.53% and the ALJ's recommended ROE of 10.83% are unjust and unreasonable. This new complaint requests an ROE of 8.53%, with rates subject to refund beginning April 1, 1994.
Following is a summary of financial information for AGC:
The Company's share of the equity in earnings above was $7.6 million, $8.6 million, and $9.2 million for 1993, 1992, and 1991, respectively, and was included in other income, net, on the Statement of Income.
Note E - Pension Benefits: The Company's share of net pension costs under the System's pension plan, a portion of which (about 35%) was charged to plant construction, included the following components:
The benefits earned to date and funded status of the Company's share of the System plan at December 31 using a measurement date of September 30 were as follows:
The foregoing includes the Company's portion of amounts applicable to employees at power stations which are owned jointly with affiliates.
In determining the actuarial present value of the projected benefit obligation at December 31, 1993, 1992, and 1991, the discount rates used were 7.25%, 7.75%, and 8%, and the rates of increase in future compensation levels were 4.75%, 5.25%, and 5.5%, respectively. The expected long- term rate of return on assets was 9% in each of the years 1993, 1992, and 1991.
Note F - Postretirement Benefits Other Than Pensions: The Company adopted SFAS No. 106 as of January 1, 1993, which requires accrual of postretirement benefits other than pensions (principally health care and life insurance) for the employee and covered dependents during the years the employee renders the necessary service to receive such benefits. Prior to 1993, medical expenses and life insurance premiums paid by the Company for retired employees and their dependents were recorded in expense in the period in which they were paid and were $1,790,000 and $1,564,000 in 1992 and 1991, respectively.
SFAS No. 106 postretirement cost in 1993, a portion of which (about 35%) was charged to plant construction, included the following components:
(Thousands of Dollars) Service cost - benefits earned $ 383 Interest cost on accumulated postretirement benefit obligation 3 042 Actual return on plan assets (7) Amortization of unrecognized transition obligation 1 986 Other net amortization and deferral 7 SFAS No. 106 postretirement cost 5 411 Regulatory deferral (846) Net postretirement cost $4 565
The benefits earned to date and funded status of the Company's share of the System plan at December 31, 1993, using a measurement date of September 30 were as follows:
(Thousands of Dollars) Accumulated postretirement benefit obligation: Retirees $35 189 Fully eligible employees 7 741 Other employees 14 635 Total obligation 57 565 Plan assets at market value in short-term investment fund 1 375 Accumulated postretirement benefit obligation in excess of plan assets 56 190 Less: Unrecognized cumulative net loss from past experience different from that assumed 15 695 Unrecognized transition obligation, being amortized over 20 years beginning January 1, 1993 37 995 Postretirement benefit liability at September 30, 1993 2 500 Fourth quarter 1993 contributions and benefit payments 1 132 Postretirement benefit liability at December 31, 1993 $1 368
The unfunded accumulated postretirement benefit obligation (APBO) at January 1, 1993, of $40,000,000 (transition obligation) is being amortized prospectively over 20 years as permitted by the standard.
In determining the APBO at January 1 and December 31, 1993, the discount rates used were 8% and 7.25%, the rates of increase in future compensation levels were 5.5% and 4.75%, respectively. For measurement purposes, a health care trend rate of 14% for 1993, declining 1% each year thereafter to 7% in the year 2000 and beyond, and plan provisions which limit future medical and life insurance benefits were assumed. Increasing the assumed health care trend rate by 1% in each year would increase the APBO at December 31, 1993, by $4.0 million and the aggregate of the service and interest cost components of net periodic postretirement benefit cost for 1993 by $.3 million.
Recovery of SFAS No. 106 costs has been authorized for retail customers in Maryland effective in February 1993 and for the FERC wholesale customers effective in September 1993. Regulatory action has been taken by the Virginia regulatory commission which provides support that substantial recovery is probable. Recovery has been requested in rate cases filed in Virginia and West Virginia for which final commission decisions are expected in 1994. The Company has recorded regulatory assets at December 31, 1993, of $.8 million relating to those regulatory jurisdictions where full recovery of SFAS No. 106 level of expenses has not yet been granted recovery in rates, with the result that adoption of SFAS No. 106 has had no effect on net income.
Note G - Stockholders' Equity: COMMON STOCK AND OTHER PAID-IN CAPITAL The Company issued and sold common stock to its parent, at $20 per share, 2,500,000 shares in October 1993, 4,000,000 shares in September 1992, and 1,250,000 shares in September 1991. Other paid-in capital decreased $2,000 in 1992 as a result of preferred stock transactions.
PREFERRED STOCK: All of the preferred stock is entitled on voluntary liquidation to its then current call price and on involuntary liquidation to $100 a share.
MANDATORILY REDEEMABLE PREFERRED STOCK: The Company's $7.16 preferred stock is entitled to a cumulative sinking fund sufficient to retire 12,000 shares each year, commencing in 1992, at $100 a share plus accrued dividends. The Company has the noncumulative option in each year to retire up to an additional 12,000 shares at the same price. The estimated fair value of this series of preferred stock at December 31, 1993 and 1992, was $28,566,000 and $28,944,000, respectively, based on quoted market prices. The call price declines in future years. In August 1993, the Company redeemed the remaining 4,046 outstanding shares of Series B, 4.70% preferred stock.
Note H - Long-Term Debt: Maturities for long-term debt for the next five years are: 1994, $16,000,000; 1995, none; 1996, $18,700,000; 1997, $800,000; and 1998, $1,800,000. Substantially all of the properties of the Company are held subject to the lien securing its first mortgage bonds. Some properties are also subject to a second lien securing certain pollution control and solid waste disposal notes. Certain first mortgage bond series are not redeemable by certain refunding until dates established in the respective supplemental indentures.
In 1993, the Company sold $45 million of 7-3/4% 30-year first mortgage bonds and $75 million of 5-7/8% 7-year first mortgage bonds to refund a $25 million 8-5/8% issue due in 2007, a $15 million 8-5/8% issue due in 2003, a $20 million 8-3/8% issue due in 2001, a $15 million 7-5/8% issue due in 1999, a $12 million 7-1/2% issue due in 2002, and a $25 million 7% issue due in 1998. The Company also issued $8.6 million of 5.95% 20-year Pollution Control Revenue Notes to Monongalia County, West Virginia to refund an $8.6 million 9.5% issue due in 2013.
The estimated fair value of long-term debt at December 31, 1993 and 1992, was $566,070,000 and $538,211,000, respectively, based on actual market prices or market prices of similar issues.
Note I - Short-Term Financing: To provide interim financing and support for outstanding commercial paper, the System companies have established lines of credit with several banks. The Company has SEC authorization for total short-term borrowings of $115 million, including money pool borrowings described below. The Company has fee arrangements on all of its lines of credit and no compensating balance requirements. In addition to bank lines of credit, in 1992 the Company and its affiliates established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds
available. In January 1994, the Company and its affiliates jointly established an aggregate $300 million multi-year credit program which provides that the Company may borrow up to $84 million on a standby revolving credit basis. There was no short-term debt outstanding at the end of 1993 or 1992. The Company had outstanding at the end of 1993 and 1992, $4.6 million and $38 million, respectively, of notes receivable from affiliates in the money pool.
Note J - Commitments and Contingencies: CONSTRUCTION PROGRAM: The Company has entered into commitments for its construction program, for which expenditures are estimated to be $136 million for 1994 and $106 million for 1995. These estimates include expenditures for the program of complying with the Clean Air Act Amendments of 1990 (CAAA) as discussed below.
ENVIRONMENTAL MATTERS: System companies are subject to laws, regulations, and uncertainties with respect to air and water quality, land use, and other environmental matters. Compliance may require them to incur substantial additional costs to modify or replace existing and proposed equipment and facilities and may affect adversely the lead time, size, and siting of future generating stations, increase the complexity and cost of pollution control equipment, and otherwise add to the cost of future operations.
Construction expenditures through the year 2000 will include substantial amounts for compliance with Phase I and Phase II of the CAAA. The Company is estimating expenditures of approximately $350 million, which includes $153 million expended through 1993, depending on the strategy eventually selected for complying with Phase II. Construction estimates for 1994 and 1995 include $40 million and $10 million, respectively, for the program of complying with the CAAA.
In complying with the CAAA, the Company will face uncertainties, including regulatory administrative interpretations and contingencies, such as potential cost overruns, equipment performance, and cost recovery in rates.
LITIGATION AND OTHER: In the normal course of business, the Company becomes involved in various legal proceedings. The Company does not believe that the ultimate outcome of these proceedings will have a material effect on its financial position.
The Company is guarantor as to 28% of a $75 million revolving credit agreement of AGC, which in 1993 was used by AGC solely as support for its indebtedness for commercial paper outstanding.
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors of West Penn Power Company
In our opinion, the financial statements listed in the accompanying index present fairly, in all material respects, the financial position of West Penn Power Company (a subsidiary of Allegheny Power System, Inc.) at December 31, 1993 and 1992, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. 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 of these statements in accordance with generally accepted auditing standards which 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, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for the opinion expressed above.
As discussed in Notes A, B and F to the financial statements, the Company changed its method of accounting for income taxes and postretirement benefits other than pensions in 1993.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York February 3, 1994
Preferred Stock of the Company (not subject to mandatory redemption): Cumulative preferred stock - par value $100 per share, authorized 3,097,077 shares, outstanding as follows (Note G):
West Penn
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(These notes are an integral part of the consolidated financial statements.)
Note A - Summary of Significant Accounting Policies:
The Company is a wholly-owned subsidiary of Allegheny Power System, Inc. and is a part of the Allegheny Power integrated electric utility system (the System).
The Company is subject to regulation by the Securities and Exchange Commission (SEC), by various state bodies having jurisdiction, and by the Federal Energy Regulatory Commission (FERC). Significant accounting policies of the Company are summarized below.
CONSOLIDATION: The consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries (the companies).
REVENUES: Customers are billed on a cycle basis, and revenues, including amounts resulting from the application of fuel and energy cost adjustment clauses, are recorded when billed.
DEFERRED POWER COSTS, NET: The costs of fuel, purchased power, and certain other costs, and revenues from sales and transmission services to other utilities, are deferred until they are either recovered from or credited to customers under fuel and energy cost recovery procedures.
PROPERTY, PLANT, AND EQUIPMENT: Property, plant, and equipment, including facilities owned with affiliates in the System, are stated at original cost, less contributions in aid of construction, except for capital leases which are recorded at present value. Cost includes direct labor and material, allowance for funds used during construction (AFUDC) on property for which construction work in progress is not included in rate base, and such indirect costs as administration, maintenance, and depreciation of transportation and construction equipment, and pensions, taxes, and other fringe benefits related to employees engaged in construction.
The cost of depreciable property units retired, plus removal costs less salvage, are charged to accumulated depreciation.
ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION: AFUDC, an item that does not represent current cash income, is defined in applicable regulatory systems of accounts as including "the net cost for the period of construction of borrowed funds used for construction purposes and a reasonable rate on other funds when so
used". AFUDC is recognized as a cost of property, plant, and equipment with offsetting credits to other income and interest charges. Rates used for computing AFUDC in 1993, 1992, and 1991 were 9.40%, 9.25%, and 9.46%, respectively.
DEPRECIATION AND MAINTENANCE: Provisions for depreciation are determined generally on a straight-line method based on estimated service lives of depreciable properties and amounted to approximately 3.4%, 3.3%, and 3.2% of average depreciable property in 1993, 1992, and 1991, respectively. The cost of maintenance and of certain replacements of property, plant, and equipment is charged principally to operating expenses.
INCOME TAXES: The companies join with the parent and affiliates in filing a consolidated federal income tax return. The consolidated tax liability is allocated among the participants generally in proportion to the taxable income of each participant, except that no subsidiary pays tax in excess of its separate return tax liability.
Financial accounting income before income taxes differs from taxable income principally because certain income and deductions for tax purposes are recorded in the financial income statement in another period. Differences between income tax that would be paid if taxes were computed on the basis of financial accounting income instead of taxable income are accounted for substantially in accordance with the accounting procedures followed for ratemaking purposes.
Provisions for federal income tax were reduced in previous years by investment credits, and amounts equivalent to such credits were charged to income with concurrent credits to a deferred account, balances in which are being amortized over estimated service lives of the related properties.
POSTRETIREMENT BENEFITS: The Company participates with affiliated companies in the System in a noncontributory, defined benefit pension plan covering substantially all employees, including officers. Benefits are based on the employee's years of service and compensation. The funding policy is to contribute annually at least the minimum amount required under the Employee Retirement Income Security Act and not more than can be deducted for federal income tax purposes.
The Company also provides partially contributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which comprise the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. The funding plan for these costs is to contribute to Voluntary Employee Beneficiary Association (VEBA) trust funds an amount equal to the annual cost as determined by Statement of Financial Accounting Standards (SFAS) No. 106 (described below). Medical benefits are self-insured; the life insurance plan is paid through insurance premiums.
The Financial Accounting Standards Board (FASB) has prescribed the determination of annual pension and other postretirement benefits expenses in SFAS No. 87, "Employers' Accounting for Pensions", and SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions", respectively. Pursuant to SFAS No. 71, "Accounting for the Effects of Certain Types of Regulation", regulatory deferrals of these benefit expenses are recorded for those jurisdictions which reflect as net expense the funding of pensions and cash payment of other benefits in the ratemaking process.
TEMPORARY CASH INVESTMENTS: For purposes of the Consolidated Statement of Cash Flows, temporary cash investments with original maturities of three months or less, generally in the form of commercial paper, certificates of deposit, and repurchase agreements, are considered to be the equivalent of cash. The carrying amount of temporary cash investments approximates the fair value because of the short-term maturity of those instruments.
ACCOUNTING CHANGES: Effective January 1, 1993, the Company adopted SFAS No. 106, "Employers' Accounting for Post- retirement Benefits Other Than Pensions". This statement requires the costs of providing postretirement benefits, such as medical and life insurance, to be accrued over the applicable employees' service periods. Prior to 1993, medical expenses and life insurance premiums paid for retired employees and their dependents were recorded as expense in the period they were paid. Also effective January 1, 1993, the Company adopted SFAS No. 109, "Accounting for Income Taxes". This standard mandated a change from the previous income-based deferral approach to a balance sheet-based liability approach for computing deferred income taxes as further described in Note B.
The total provision for income taxes is less than the amount produced by applying the federal income statutory tax rate to financial accounting income before income taxes, as set forth below:
Federal income tax returns through 1989 have been examined and substantially settled.
In adopting SFAS No. 109, the Company recognized a significant increase in both deferred tax assets and liabilities. At December 31, 1993, the deferred tax assets and liabilities were comprised of the following:
(Thousands of Dollars) Deferred tax assets: Unamortized investment tax credit $40 455 Unbilled revenue 21 626 Tax interest capitalized 10 750 State tax loss carryback/carryforward 8 790 Contributions in aid of construction 4 588 Other 7 416
93 625
Deferred tax liabilities: Book vs. tax plant basis differences, net 507 214 Other 8 437
515 651
Total net deferred tax liabilities 422 026 Add portion above included in current assets 1 974
Total long-term net deferred tax liabilities $424 000
It is expected that regulatory commissions will allow recovery of the deferred tax liabilities in future years as they are paid, and accordingly, the Company has recorded regulatory assets for an amount equal to the $326 million increase in deferred tax liabilities. Regulatory liabilities were recorded in an amount equal to the $41 million increase in deferred tax assets to reflect the Company's obligation to pass such tax benefits on to its customers as the benefits are realized in cash in future years. Based on the provisions in the standard for recording these regulatory assets and liabilities on the balance sheet, there was no effect on consolidated net income resulting from adoption of the standard.
Note C - Dividend Restriction: Supplemental indentures relating to most outstanding bonds of the Company contain dividend restrictions under the most restrictive of which $285,914,000 of consolidated retained earnings at December 31, 1993, is not available for cash dividends on common stock, except that a portion thereof may be paid as cash dividends where concurrently an equivalent amount of cash is received by the Company as a capital contribution or as the proceeds of the issue and sale of shares of its common stock.
Note D - Allegheny Generating Company: The Company owns 45% of the common stock of Allegheny Generating Company (AGC), and affiliates of the Company own the remainder. AGC owns an undivided 40% interest, 840 MW, in the 2,100-MW pumped-storage hydroelectric station in Bath County, Virginia operated by the 60% owner, Virginia Power Company, an unaffiliated utility.
AGC recovers from the Company and its affiliates all of its operation and maintenance expenses, depreciation, taxes, and a return on its investment under a wholesale rate schedule approved by the FERC. Through February
29, 1992, AGC's return on equity (ROE) was adjusted annually pursuant to a settlement agreement approved by the FERC. In December 1991, AGC filed for a continuation of the existing ROE of 11.53% and other parties (the Consumer Advocate Division of the Public Service Commission of West Virginia, Maryland People's Counsel, and Pennsylvania Office of Consumer Advocate, collectively referred to as the joint consumer advocates or JCA) filed to reduce the ROE, with any resultant rate decreases subject to refund from March 1, 1992 through May 31, 1993. Hearings were completed in June 1992, and a recommendation was issued by an Administrative Law Judge (ALJ) on December 21, 1993, for an ROE of 10.83%, which the JCA argues should be further adjusted to reflect changes in capital market conditions since the hearings. Exceptions to this recommendation have been filed by all parties for consideration by the full Commission. On January 28, 1994, the JCA filed a joint complaint claiming that both the existing ROE of 11.53% and the ALJ's recommended ROE of 10.83% are unjust and unreasonable. This new complaint requests an ROE of 8.53%, with rates subject to refund beginning April 1, 1994.
Following is a summary of financial information for AGC:
The Company's share of the equity in earnings above was $12.2 million, $13.8 million, and $14.8 million for 1993, 1992, and 1991, respectively, and was included in other income, net, on the Consolidated Statement of Income.
Note E - Pension Benefits: The Company's share of net pension costs under the System's pension plan, a portion of which (about 25%) was charged to plant construction, included the following components:
The benefits earned to date and funded status of the Company's share of the System plan at December 31 using a measurement date of September 30 were as follows:
The foregoing includes the Company's portion of amounts applicable to employees at power stations which are owned jointly with affiliates.
In determining the actuarial present value of the projected benefit obligation at December 31, 1993, 1992, and 1991, the discount rates used were 7.25%, 7.75%, and 8%, and the rates of increase in future compensation levels were 4.75%, 5.25%, and 5.5%, respectively. The expected long-term rate of return on assets was 9% in each of the years 1993, 1992, and 1991.
Note F - Postretirement Benefits Other Than Pensions:
The Company adopted SFAS No. 106 as of January 1, 1993, which requires accrual of postretirement benefits other than pensions (principally health care and life insurance) for the employee and covered dependents during the years the employee renders the necessary service to receive such benefits. Prior to 1993, medical expenses and life insurance premiums paid by the Company for retired employees and their dependents were recorded in expense in the period in which they were paid and were $1,907,000 and $1,721,000 in 1992 and 1991, respectively.
SFAS No. 106 postretirement cost in 1993, a portion of which (about 25%) was charged to plant construction, included the following components:
(Thousands of Dollars) Service cost - benefits earned $ 939 Interest cost on accumulated postretirement benefit obligation 4 389 Actual return on plan assets (9) Amortization of unrecognized transition obligation 2 817 Other net amortization and deferral 9
SFAS No. 106 postretirement cost 8 145 Regulatory deferral (1 963)
Net postretirement cost $6 182
The benefits earned to date and funded status of the Company's share of the System plan at December 31, 1993, using a measurement date of September 30 were as follows:
(Thousands of Dollars)
Accumulated postretirement benefit obligation: Retirees $35 748 Fully eligible employees 9 030 Other employees 18 378
Total obligation 63 156 Plan assets at market value in short-term investment fund 1 510
Accumulated postretirement benefit obligation in excess of plan assets 61 646 Less: Unrecognized cumulative net loss from past experience different from that assumed 3 362 Unrecognized transition obligation, being amortized over 20 years beginning January 1, 1993 53 746
Postretirement benefit liability at September 30, 1993 4 538 Fourth quarter 1993 contributions and benefit payments 1 960
Postretirement benefit liability at December 31, 1993 $2 578
The unfunded accumulated postretirement benefit obligation (APBO) at January 1, 1993, of $56,600,000 (transition obligation) is being amortized prospectively over 20 years as permitted by the standard.
In determining the APBO at January 1 and December 31, 1993, the discount rates used were 8% and 7.25%, and the rates of increase in future compensation levels were 5.5% and 4.75%, respectively. For measurement purposes, a health care trend rate of 14% for 1993, declining 1% each year thereafter to 7% in the year 2000 and beyond, and plan provisions which limit future medical and life insurance benefits were assumed. Increasing the assumed health care trend rate by 1% in each year would increase the APBO at December 31, 1993, by $4.3 million and the aggregate of the service and interest cost components of net periodic postretirement benefit cost for 1993 by $.4 million.
Recovery of SFAS No. 106 costs has been authorized for retail customers in Pennsylvania effective in May 1993 and for the FERC wholesale customers effective in June 1993. The Company has recorded regulatory assets at December 31, 1993, of $2.0 million relating to SFAS No. 106 costs in Pennsylvania incurred prior to the May rate order, with the result that adoption of SFAS No. 106 has had no effect on consolidated net income. The Company will seek to recover these costs in its next base rate case.
Note G - Stockholders' Equity: COMMON STOCK AND OTHER PAID-IN CAPITAL: The Company issued and sold common stock to its parent, at $20 per share, 5,000,000 shares in October 1993, and 1,750,000 shares in December 1991. Other paid-in capital decreased $145,000 in 1993 and $550,000 in 1992 as a result of the underwriting fees and commissions and miscellaneous expenses associated with the Company's sale of $40 million of preferred stock in 1992.
PREFERRED STOCK: All of the preferred stock is entitled on voluntary liquidation to its then current call price and on involuntary liquidation to $100 per share. The holders of the Company's market auction preferred stock are entitled to dividends at a rate determined by an auction held the business day preceding each quarterly dividend payment date.
Note H - Long-Term Debt: Maturities for long-term debt for the next five years are: 1994, none; 1995, $27,000,000; 1996 and 1997, none; and 1998, $103,500,000. Substantially all of the properties of the Company are held subject to the lien securing its first mortgage bonds. Some properties are also subject to a second lien securing certain pollution control and solid waste disposal notes. Certain first mortgage bond series are not redeemable by certain refunding until dates established in the respective supplemental indentures.
In 1993, the Company sold $102 million of 5-1/2% 5-year first mortgage bonds to refund a $25 million 7% issue due in 1997, a $25 million 7-7/8% issue due in 1999, and a $52 million 7-1/8% issue due in 1998, and sold $80 million of 6-3/8% 10-year first mortgage bonds to refund a $35 million 7-5/8% issue due in 2002 and a $40 million 8-1/8% issue due in 2001. The Company also issued $7.75 million of 5.95% 20-year Pollution Control Revenue Notes to refund a $7.75 million 9-3/8% issue due in 2013, and issued $61.5 million of 10-year 4.95% Pollution Control Revenue Notes to refund a $30 million 9-3/4% series and a $31.5 million 9-1/2% series due in 2003.
The estimated fair value of long-term debt at December 31, 1993 and 1992, was $823,333,000 and $783,379,000, respectively, based on actual market prices or market prices of similar issues.
Note I - Short-Term Financing: To provide interim financing and support for outstanding commercial paper, the System companies have established lines of credit with several banks. The Company has SEC authorization for total short-term borrowings of $170 million, including money pool borrowings described below. The Company has fee arrangements on all of its lines of credit and no compensating balance requirements. In addition to bank lines of credit, in 1992 the Company and its affiliates established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds available. In January 1994, the Company and its affiliates jointly established an aggregate $300 million multi-year credit program which provides that the Company may borrow up to $135 million on a standby revolving credit basis. There was no short-term debt outstanding at the end of 1993 or 1992. The Company had outstanding at the end of 1993 and 1992, $24.9 million and $20.9 million, respectively, of notes receivable from affiliates in the money pool.
Note J - Commitments and Contingencies: CONSTRUCTION PROGRAM: The Company has entered into commitments for its construction program, for which expenditures are estimated to be $258 million for 1994 and $208 million for 1995. These estimates include expenditures for the program of complying with the Clean Air Act Amendments of 1990 (CAAA) as discussed below.
ENVIRONMENTAL MATTERS: System companies are subject to laws, regulations, and uncertainties with respect to air and water quality, land use, and other environmental matters. Compliance may require them to incur substantial additional costs to modify or replace existing and proposed equipment and facilities and may affect adversely the lead time, size, and siting of future generating stations, increase the complexity and cost of pollution control equipment, and otherwise add to the cost of future operations.
Construction expenditures through the year 2000 will include substantial amounts for compliance with Phase I and Phase II of the CAAA. The Company is estimating expenditures of approximately $700 million, which includes $207 million expended through 1993, depending on the strategy eventually selected for complying with Phase II. Construction estimates for 1994 and 1995 include $82 million and $33 million, respectively, for the program of complying with the CAAA.
In complying with the CAAA, the Company will face uncertainties, including regulatory administrative interpretations and contingencies, such as potential cost overruns, equipment performance, and cost recovery in rates.
LITIGATION AND OTHER: In the normal course of business, the Company becomes involved in various legal proceedings. The Company does not believe that the ultimate outcome of these proceedings will have a material effect on its financial position.
The Company is guarantor as to 45% of a $75 million revolving credit agreement of AGC, which in 1993 was used by AGC solely as support for its indebtedness for commercial paper outstanding.
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors of Allegheny Generating Company
In our opinion, the financial statements listed in the accompanying index present fairly, in all material respects, the financial position of Allegheny Generating Company (an Allegheny Power System, Inc. affiliate) at December 31, 1993 and 1992, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1993, in conformity with generally accepted accounting principles. 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 of these statements in accordance with generally accepted auditing standards which 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, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for the opinion expressed above.
As discussed in Notes A and B to the financial statements, the Company changed its method of accounting for income taxes in 1993.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York February 3, 1994
AGC
NOTES TO FINANCIAL STATEMENTS (These notes are an integral part of the financial statements.)
Note A - Summary of Significant Accounting Policies: The Company was incorporated in Virginia in 1981. Its common stock is owned by Monongahela Power Company - 27%, The Potomac Edison Company - 28%, and West Penn Power Company - 45% (the Parents). The Parents are wholly-owned subsidiaries of Allegheny Power System, Inc. and are a part of the Allegheny Power integrated electric utility system. The Company is subject to regulation by the Securities and Exchange Commission (SEC) and by the Federal Energy Regulatory Commission (FERC). Significant accounting policies of the Company are summarized below.
PROPERTY, PLANT, AND EQUIPMENT: Property, plant, and equipment are stated at original cost, and consist of a 40% undivided interest in the Bath County pumped-storage hydroelectric station and its connecting transmission facilities. The cost of depreciable property units retired plus removal costs less salvage are charged to accumulated depreciation.
DEPRECIATION AND MAINTENANCE: Provisions for depreciation are determined on a straight-line method based on estimated service lives of depreciable properties and amounted to approximately 2.1% of average depreciable property in each of the years 1993, 1992, and 1991. The cost of maintenance and of certain replacements of property, plant, and equipment is charged to operating expenses.
INCOME TAXES: The Company joins with its parents and affiliates in filing a consolidated federal income tax return. The consolidated tax liability is allocated among the participants generally in proportion to the taxable income of each participant, except that no subsidiary pays tax in excess of its separate return tax liability.
Financial accounting income before income taxes differs from taxable income principally because certain income and deductions for tax purposes are recorded in the financial income statement in another period. Differences between income tax that would be paid if taxes were computed on the basis of financial accounting income instead of taxable income are deferred.
Prior to 1987, provisions for federal income tax were reduced by investment credits, and amounts equivalent to such credits were charged to income with concurrent credits to a deferred account, balances in which are being amortized over estimated service lives of the related properties.
ACCOUNTING CHANGE: Effective January 1, 1993, the Company adopted Statement of Financial Accounting Standards (SFAS) No. 109, "Accounting for Income Taxes". This standard mandated a change from the previous income-based deferral approach to a balance sheet-based liability approach for computing deferred income taxes.
Note B - Income Taxes: Details of federal income tax provisions are:
In 1993, the total provision for income taxes ($13,262,000) was less than the amount produced by applying the federal income tax statutory rate to financial accounting income before income taxes ($14,155,000), due primarily to amortization of deferred investment credit ($1,316,000).
Federal income tax returns through 1989 have been examined and substantially settled.
The Company adopted SFAS No. 109 as of January 1, 1993, and in doing so recognized a significant increase in both deferred tax assets and liabilities. At December 31, 1993, the deferred tax assets and liabilities were comprised of the following: (Thousands of Dollars) Deferred tax assets Unamortized investment tax credit $ 28 869
Deferred tax liabilities Book vs. tax plant basis differences, net 154 565 Other 152 154 717
Total net deferred tax liabilities $125 848
It is expected the FERC will allow recovery of the deferred tax liabilities in future years as they are paid, and accordingly, the Company has recorded regulatory assets for an amount equal to the $4 million increase in deferred tax liabilities. Regulatory liabilities were recorded in an amount equal to the $29 million increase in deferred tax assets to reflect the Company's obligation to pass such tax benefits on to its customers as the benefits are realized in cash in future years. Based on the provisions in the standard for recording these regulatory assets and liabilities on the balance sheet, there was no effect on net income resulting from adoption of the standard.
Note C - Long-Term Debt: The Company had long-term debt outstanding as follows:
The Company has a revolving credit agreement with a group of seven banks which provides for loans of up to $75 million at any one time outstanding through 1997. Each bank has the option to discontinue its loans after 1997 upon three years' prior written notice. Without such notice, the loans are automatically extended for one year. Amounts borrowed are guaranteed by the Parents in proportion to their equity interest. Interest rates are determined at the time of each borrowing. The revolving credit agreement serves as support for the Company's commercial paper. In addition to bank lines of credit, the Company and its affiliates in 1992 established an internal money pool as a facility to accommodate intercompany short-term borrowing needs, to the extent that certain of the companies have funds available. At the end of 1993, the Company had outstanding $29,500,000 of money pool borrowings from affiliates.
Maturities for long-term debt for the next five years are: 1994, 10,000,000; 1995, $1,000,000; 1996, $6,375,000; 1997, $61,462,000; and 1998, $60,000,000.
The estimated fair value of debentures and medium- term notes at December 31, 1993 and 1992, was $233,445,000 and $249,850,000 respectively, based on actual market prices or market prices of similar issues. The carrying amount of commercial paper and notes payable to affiliates approximates their fair value because of the short maturity of those instruments.
(A) The maximum amount outstanding at any month end during the year. (B) Computed by multiplying the principal amounts of short-term debt by the days outstanding, and dividing the sum of the products by the number of days in the year. (C) Computed by dividing total interest accrued for the year by the average principal amount outstanding for the year. (D) Unsecured promissory notes issued under informal credit arrangements with various banks with terms of 270 days or less. (E) Unsecured bearer promissory notes sold to dealers at a discount with a term of 270 days or less. (F) Classified as long-term debt by Allegheny Generating Company (AGC).
Charges for maintenance and depreciation other than amounts shown in the consolidated statement of income were not material.
Charges for maintenance and depreciation other than amounts shown in the statement of income were not material.
(A) The maximum amount outstanding at any month end during the year. (B) Computed by multiplying the principal amounts of short-term debt by the days outstanding, and dividing the sum of the products by the number of days in the year. (C) Computed by dividing total interest accrued for the year by the average principal amount outstanding for the year. (D) Unsecured promissory notes issued under informal credit arrangements with various banks with terms of 270 days or less. (E) Unsecured bearer promissory notes sold to dealers at a discount with a term of 270 days or less. (F) Internal arrangement for borrowing funds on a short-term basis.
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ITEM 9.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
For APS and the Subsidiaries, none.
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PART III
ITEM 10.



ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANTS
APS, Monongahela, Potomac Edison, West Penn, and AGC. Reference is made to the Executive Officers of the Registrants in Part I of this report. The names, ages, and the business experience during the past five years of the directors of the System companies are set forth below:
(1) See Executive Officers of the Registrants in Part I of this report for further details.
(a) Eleanor Baum. Dean of the Albert Nerken School of Engineering of The Cooper Union for the Advancement of Science and Art. Director of United States Trust Company, Commissioner of the Engineering Manpower Commission, and a fellow of the Institute of Electrical and Electronic Engineers and the Society of Women Engineers. Ms. Baum filed one late report on Form 4 concerning one purchase transaction in 1993.
(b) William L. Bennett. Co-Chairman, Director and Chief Executive Officer of Noel Group, Inc. Formerly, General partner, Discovery Funds, a venture capital affiliate of Rockefeller & Company, Inc. Chairman of the Board of TDX Corporation. Director of Forschner Group, Inc., Global Natural Resources Inc., Lincoln Snacks Company, Simmons Outdoor Corporation and VISX, Inc.
(c) Phillip E. Lint. Retired. Formerly, partner, Price Waterhouse.
(d) Edward H. Malone. Retired. Formerly, Vice President of General Electric Company and Chairman, General Electric Investment Corporation. Director of Fidelity Group of Mutual Funds, General Re Corporation, Mattel, Inc., and Corporate Property Investors, a real estate investment trust.
(e) Frank A. Metz, Jr. Retired. Formerly, Senior Vice President, Finance and Planning, and Director, International Business Machines Corporation. Director of Monsanto Company and Norrell Corporation.
(f) Clarence F. Michalis. Chairman of the Board of Directors of Josiah Macy, Jr. Foundation, a tax-exempt foundation for medical research and education. Director of Schroder Capital Funds Inc.
(g) Steven H. Rice. Business consultant and attorney-at-law. Formerly, President and Chief Operating Officer and Director of The Seamen's Bank for Savings. Director and member of the Investment and Audit Committees of Royal Group, Inc. (The Royal Insurance Companies). Director and Vice Chairman of the Board of The Stamford (CT) Federal Savings Bank.
(h) Gunnar E. Sarsten. President and Chief Operating Officer of Morrison Knudsen Corporation. Formerly, President and Chief Executive Officer of United Engineers & Constructors International, Inc., a subsidiary of the Raytheon Company, and Deputy Chairman of the Third District Federal Reserve Bank in Philadelphia.
(i) Peter L. Shea. Managing director of Hydrocarbon Energy, Inc., a privately owned oil and gas development drilling and production company.
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ITEM 11.

ITEM 11. EXECUTIVE COMPENSATION
During 1993, and for 1992 and 1991, the annual compensation paid by each of the System companies, APS, APSC, Monongahela, Potomac Edison, West Penn, and AGC directly or indirectly for services in all capacities to such companies to their Chief Executive Officer and each of the four most highly paid executive officers of each such company whose cash compensation exceeded $100,000 was as follows:
(a) APS has no paid employees. All salaries and bonuses are paid by APSC.
(b) Bonus amounts are determined and paid in April of the year in which the figure appears and are based upon performance in the prior year.
(c) Amounts constituting less than 10% of the total annual salary and bonus are not disclosed. All officers did receive miscellaneous other items amounting to less than 10% of total annual salary and bonus.
(d) Effective January 1, 1992, the basic group life insurance provided employees was reduced from two times salary during employment, which reduced to one times salary after 5 years in retirement, to a new plan which provides one times salary until retirement and $25,000 thereafter. Executive officers and other senior managers remain under the prior plan. In order to pay for this insurance for these executives, during 1992 insurance was purchased on the lives of each of them. Effective January 1, 1993, APS started to provide funds to pay for the future benefits due under the supplemental retirement plan (Secured Benefit Plan) as described in note (a) on p. 53. To do this, APS purchased, during 1993, life insurance on the lives of the covered executives. The premium costs of both the 1992 and 1993 policies plus a factor for the use of the money are returned to APS at the earlier of (a) death of the insured or (b) the later of age 65 or 10 years from the date of the policy's inception. The figures in this column include the present value of the executives' cash value at retirement attributable to the current year's premium payment for both the Executive Life Insurance and Secured Benefit Plans (based upon the premium, future valued to retirement, using the policy internal rate of return minus the corporation's premium payment), as well as the premium paid for the basic Group Life Insurance program plan and the contribution for the 401(k) plan. For 1993, the figure shown includes amounts representing (a) the aggregate of life insurance premiums and dollar value of the benefit to the executive officer of the remainder of the premium paid on the Group Life Insurance program and the Executive Life Insurance and Secured Benefit Plans and (b) 401(k) contributions as follows: Mr. Bergman $42,392 and $4,497; Mr. Garnett $19,509 and $4,497; Mr. Skrgic $14,181 and $4,497; Ms. Gormley $11,152 and $4,294; and Mr. Jones $8,382 and $4,497, respectively.
(e) These amounts as previously reported did not include the following amounts representing the dollar value of the benefit to the executive officer of the remainder of the premium paid on the Executive Life Insurance Plan: Mr. Bergman $786; Mr. Garnett $210; Mr. Skrgic $218; Ms. Gormley $232; and Mr. Jones $519.
(f) See Executive Officers of the Registrants for other positions held.
(g) Although less than 10% of total annual salary and bonus, Mr. Skrgic received a $15,000 housing allowance in 1993, 1992 and 1991.
(h) The incentive plan was not in effect for these officers in 1991.
(i) Includes $15,000 housing allowance for both 1993 and 1992 and miscellaneous other items totaling $2,423 and $2,457 for 1993 and 1992, respectively.
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Summary Compensation Tables
AGC
Annual Compensation (a)
Name All Other and Compen- Principal sation Position Year Salary($) Bonus($) ($)
(a) AGC has no paid employees.
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DEFINED BENEFIT OR ACTUARIAL PLAN DISCLOSURE
Estimated Name and Capacities Annual Benefits Company in Which Served on Retirement (a)
APS (b) Klaus Bergman, President* $235,270 and Chief Executive Officer (c)
Stanley I. Garnett, II, 112,320 Vice President, Finance (c)
Peter J. Skrgic, 126,000 Vice President (c)
Kenneth M. Jones, 90,004 Vice President and Comptroller (c)
Nancy H. Gormley, 78,404 Vice President (c)
Monongahela Klaus Bergman, $ Chief Executive Officer (c)(d)
Benjamin H. Hayes, 113,364 President
Thomas A. Barlow, 70,788 Vice President
Robert R. Winter, 67,896 Vice President
Richard E. Myers, 67,200 Comptroller
* Elected Chairman of the Board effective January 1, 1994.
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Estimated Name and Capacities Annual Benefits Company in Which Served on Retirement (a)
Potomac Edison Klaus Bergman, $ Chief Executive Officer (c)(d)
Alan J. Noia, 133,200 President
Robert B. Murdock, 80,677 Vice President
James D. Latimer, 75,298 Vice President
Thomas J. Kloc, 68,591 Comptroller
West Penn Klaus Bergman, $ Chief Executive Officer (c)(d)
Jay S. Pifer, 111,463 President
Thomas K. Henderson, 73,127 Vice President
Charles S. Ault, 71,100 Vice President
Charles V. Burkley, 66,442 Comptroller
Allegheny Generating Company No paid employees.
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(a) Assumes present insured benefit plan and salary continue and retirement at age 65 with single life annuity. Under plan provisions, the annual rate of benefits payable at the normal retirement age of 65 are computed by adding (i) 1% of final average pay up to covered compensation times years of service up to 35 years, plus (ii) 1.5% of final average pay in excess of covered compensation times years of service up to 35 years, plus (iii) 1.3% of final average pay times years of service in excess of 35 years. Covered compensation is the average of the maximum taxable Social Security wage bases during the 35 years preceding the member's retirement, except that years before 1959 are not taken into account for purposes of this average. The final average pay benefit is based on the member's average total earnings during the highest-paid 60 consecutive calendar months or, if smaller, the member's highest rate of pay as of any July 1st. Effective July 1, 1993 the maximum amount of any employee's compensation that may be used in these computations is $235,840. The maximum amount will be reduced to $150,000 effective July 1, 1994 as a result of The Omnibus Budget Reconciliation Act of 1993. Benefits for employees retiring between 55 and 62 differ from the foregoing.
Pursuant to a supplemental plan (Secured Benefit Plan), senior executives of Allegheny Power System companies who retire at age 60 or over with 40 or more years of service are entitled to a supplemental retirement benefit in an amount that, together with the benefits under the basic plan and from other employment, will equal 60% of the executive's highest average monthly earnings for any 36 consecutive months. The supplemental benefit is reduced for less than 40 years service and for retirement age from 60 to 55. It is included in the amounts shown where applicable. In order to provide funds to pay such benefits, effective January 1, 1993 the Company purchased insurance on the lives of the plan participants. The Secured Benefit Plan has been designed that if the assumptions made as to mortality experience, policy dividends, and other factors are realized, the Company will recover all premium payments, plus a factor for the use of the Company's money. All executive officers are participants in the Secured Benefit Plan. This does not include benefits from an Employee Stock Ownership and Savings Plan (ESOSP) established as a non-contributory stock ownership plan for all eligible employees effective January 1, 1976, and amended in 1984 to include a savings program. Under the ESOSP for 1993, all eligible employees may elect to have from 2% to 7% of their compensation contributed to the Plan as pre-tax contributions and an additional 1% to 6% as post-tax contributions. Employees direct the investment of these contributions into one or more of five available funds. Each System company matches 50% of the pre-tax contributions up to 6% of compensation with common stock of Allegheny Power System, Inc. Effective January 1, 1993 the maximum amount of any employee's compensation that may be used in these computations is $235,840. Effective January 1, 1994, the amount was reduced to $150,000 as a result of The Omnibus Budget Reconciliation Act of 1993. Employees' interests in the ESOSP vest immediately. Their pre-tax contributions may be withdrawn only upon meeting certain financial hardship requirements or upon termination of employment.
(b) APS has no paid employees. These executives are employees of APSC.
(c) See Executive Officers of the Registrants for other positions held.
(d) The total estimated annual benefits on retirement payable to Mr. Bergman for services in all capacities to APS, APSC and the Subsidiaries is set forth in the table for APS.
Compensation of Directors
In 1993, APS directors who were not officers or employees of System companies received for all services to System companies (a) $16,000 in retainer fees, (b) $800 for each committee meeting attended, except Executive Committee meetings which are $200, and (c) $250 for each Board meeting of each company attended. Under an unfunded deferred compensation plan, a director may elect to defer receipt of all or part of his or her director's fees for succeeding calendar years to be payable with accumulated interest when the director ceases to be such, in equal annual installments, or, upon authorization by the Board of Directors, in a lump sum.
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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
For APS and the Subsidiaries, none.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a)(1)(2) The financial statements and financial statement schedules filed as part of this Report are set forth under ITEM 8. and reference is made to the index on page 42.
(b) APS filed a report on Form 8-K on November 5, 1993 concerning the two-for-one stock split. No other reports on Form 8-K were filed by System companies during the quarter ended December 31, 1993.
(c) Exhibits for APS, Monongahela, Potomac Edison, West Penn, and AGC are listed in the Exhibit Index beginning on page E-1 and are incorporated herein by reference.
Graphics Appendix
Page
System Map . . . . . . . . . . . . . . . . . . . . . . . 10
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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.
ALLEGHENY POWER SYSTEM, INC. By: KLAUS BERGMAN (Klaus Bergman, President and Chief Executive Officer)
Date: February 3, 1994
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.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
STANLEY I. GARNETT, II Vice President, 2/3/94 (Stanley I. Garnett, II) Finance
(iii) Principal Accounting Officer:
KENNETH M. JONES Vice President 2/3/94 (Kenneth M. Jones) and Comptroller
(iv) A Majority of the Directors:
*Eleanor Baum *Frank A. Metz, Jr. *William L. Bennett *Clarence F. Michalis *Klaus Bergman *Steven H. Rice *Phillip E. Lint *Gunnar E. Sarsten *Edward H. Malone *Peter L. Shea
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
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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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
MONONGAHELA POWER COMPANY
By: BENJAMIN H. HAYES (Benjamin H. Hayes, President) Date: February 3, 1994
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. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
CHARLES S. MULLETT Secretary and 2/3/94 (Charles S. Mullett) Treasurer
(iii) Principal Accounting Officer:
RICHARD E. MYERS Comptroller 2/3/94 (Richard E. Myers)
(iv) A Majority of the Directors:
*Eleanor Baum *Edward H. Malone *William L. Bennett *Frank A. Metz, Jr. *Klaus Bergman *Clarence F. Michalis *Stanley I. Garnett, II *Steven H. Rice *Benjamin H. Hayes *Gunnar E. Sarsten *Phillip E. Lint *Peter L. Shea *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
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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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
THE POTOMAC EDISON COMPANY
By: ALAN J. NOIA (Alan J. Noia, President) Date: February 3, 1994
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. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
DALE F. ZIMMERMAN Secretary and 2/3/94 (Dale F. Zimmerman) Treasurer
(iii) Principal Accounting Officer:
THOMAS J. KLOC Comptroller 2/3/94 (THOMAS J. KLOC)
(iv) A Majority of the Directors:
*Eleanor Baum *Frank A. Metz, Jr. *William L. Bennett *Clarence F. Michalis *Klaus Bergman *Alan J. Noia *Stanley I. Garnett, II *Steven H. Rice *Phillip E. Lint *Gunnar E. Sarsten *Edward H. Malone *Peter L. Shea *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
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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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
WEST PENN POWER COMPANY
By: JAY S. PIFER (Jay S. Pifer, President) Date: February 3, 1994
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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
KENNETH D. MOWL Secretary and 2/3/94 (Kenneth D. Mowl) Treasurer
(iii) Principal Accounting Officer:
CHARLES V. BURKLEY Comptroller 2/3/94 (Charles V. Burkley)
(iv) A Majority of the Directors:
*Eleanor Baum *Frank A. Metz, Jr. *William L. Bennett *Clarence F. Michalis *Klaus Bergman *Jay S. Pifer *Stanley I. Garnett, II *Steven H. Rice *Phillip E. Lint *Gunnar E. Sarsten *Edward H. Malone *Peter L. Shea *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
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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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
ALLEGHENY GENERATING COMPANY
By: KLAUS BERGMAN (Klaus Bergman, President and Chief Executive Officer)
Date: February 3, 1994
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. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
NANCY L. CAMPBELL Treasurer and 2/3/94 (Nancy L. Campbell Assistant Secretary
(iii) Principal Accounting Officer:
THOMAS J. KLOC Comptroller 2/3/94 (Thomas J. Kloc)
(iv) A Majority of the Directors:
*Klaus Bergman *Kenneth M. Jones *Stanley I. Garnett, II *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
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CONSENT OF INDEPENDENT ACCOUNTANTS
We hereby consent to the incorporation by reference in the Prospectus constituting part of Allegheny Power System, Inc.'s Registration Statement on Form S-3 (No. 33-36716) relating to the Dividend Reinvestment and Stock Purchase Plan of Allegheny Power System, Inc.; in the Prospectus constituting part of Allegheny Power System, Inc.'s Registration Statement on Form S-3 (No. 33-49791) relating to the common stock shelf registration; in the Prospectus constituting part of Monongahela Power Company's Registration Statement on Form S-3 (No. 33-51301); in the Prospectus constituting part of The Potomac Edison Company's Registration Statement on Form S-3 (No. 33-51305); and in the Prospectus constituting part of West Penn Power Company's Registration Statement on Form S-3 (No. 33-51303); of our reports dated February 3, 1994 included in ITEM 8 of this Form 10-K. We also consent to the references to us under the heading "Experts" in such Prospectuses.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York March 11, 1994
- 62 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned directors of Allegheny Power System, Inc., a Maryland corporation, Monongahela Power Company, an Ohio corporation, The Potomac Edison Company, a Maryland and Virginia corporation, and West Penn Power Company, a Pennsylvania corporation, do hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to Annual Reports on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Companies, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
ELEANOR BAUM FRANK A. METZ, JR. (Eleanor Baum) (Frank A. Metz, Jr.)
WILLIAM L. BENNETT CLARENCE F. MICHALIS (William L. Bennett) (Clarence F. Michalis)
KLAUS BERGMAN STEVEN H. RICE (Klaus Bergman) (Steven H. Rice)
PHILLIP E. LINT GUNNAR E. SARSTEN (Phillip E. Lint) (Gunnar E. Sarsten)
EDWARD H. MALONE PETER L. SHEA (Edward H. Malone) (Peter L. Shea)
- 63 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of The Potomac Edison Company, a Maryland and Virginia corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
ALAN J. NOIA (Alan J. Noia)
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POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of West Penn Power Company, a Pennsylvania corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
JAY S. PIFER (Jay S. Pifer)
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POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of Monongahela Power Company, an Ohio corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
BENJAMIN H. HAYES (Benjamin H. Hayes)
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POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned directors of Allegheny Generating Company, a Virginia corporation, do hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
KLAUS BERGMAN (Klaus Bergman)
KENNETH M. JONES (Kenneth M. Jones)
PETER J. SKRGIC (Peter J. Skrgic)
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POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of Monongahela Power Company, an Ohio corporation, The Potomac Edison Company, a Maryland and Virginia corporation, and West Penn Power Company, a Pennsylvania corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Companies, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
PETER J. SKRGIC (Peter J. Skrgic)
E-1
EXHIBIT INDEX (Rule 601(a))
Allegheny Power System, Inc. Incorporation Documents by Reference
3.1 Charter of the Company, Form 10-Q of the Company as amended (1-267), September 1993, exh. (a)(3) 3.2 By-laws of the Company, Form 10-Q of the Company as amended (1-267), June 1990, exh. (a)(3)
4 Subsidiaries' Indentures described below.
10.1 Directors' Deferred Compensation Plan
10.2 Executive Compensation Plan
10.3 Allegheny Power System Incentive Compensation Plan
10.4 Allegheny Power System Supplemental Executive Retirement Plan
10.5 Executive Life Insurance Program and Collateral Assignment Agreement
10.6 Secured Benefit Plan and Collateral Assignment Agreement
11 Statement re computation of per share earnings:
Clearly determinable from the financial statements contained in Item 8.
21 Subsidiaries of APS:
Name of Company State of Organization
Allegheny Generating Company (a) Virginia Allegheny Power Service Corporation Maryland Monongahela Power Company Ohio The Potomac Edison Company Maryland and Virginia West Penn Power Company Pennsylvania
(a) Owned directly by Monongahela, Potomac Edison, and West Penn.
23 Consent of Independent Accountants See page 61 herein.
24 Powers of Attorney See pages 62-67 herein.
Exhibit 10.1
Election to Defer Receipt of Directors Fees Under the Directors Elective Deferred Fees Plan of Allegheny Power System
Pursuant to Section 4 of the captioned Plan, I hereby elect to defer receipt of ________% of all retainer and attendance fees payable to me on and after January 1, 19__.
I elect to have my deferred account, with accumulated interest, paid as follows, commencing with the 2nd day of January following the termination of my service as a member of the Board of Directors of Allegheny:
In a single lump sum, to be paid within 60 days after such January 2.
In annual installment payments of equal amounts (adjusted for interest credits) over _______ years (at least 3) with such installment payments to be made on January 2 of each year.
In annual installments of equal amounts (adjusted for interest credits) on January 2 of each year, such annual payments to be equal in number to the number of years of service.
In the event of my death prior to receipt of all amounts I have deferred under this Plan, including interest credits, the balance of such deferred funds shall be paid in a lump sum to the following designees who survive me or to my estate in proportion to the percentage shares indicated, and, if I have indicated no designees or if all indicated designees predecease me, entirely to my estate.
Designee Address Percentage Share
Dated: Signature
Exhibit 10.2
CONFIDENTIAL
EXECUTIVE COMPENSATION PLAN
OBJECTIVES
To attract, hold, and motivate executive personnel. Prior approval of the chief executive officer is required for inclusion in the Plan.
QUALIFICATIONS
An employee becomes eligible for inclusion when
1. the employee has held a position with a salary grade of 28 or above for at least one year, is assuming the full responsibility of the position, is achieving satisfactory results and has a salary which exceeds the mid point between the minimum and standard amounts of salary grade 28, or
2. the employee has held the position of operating division manager with a salary grade of 18 or above for at least one year, is assuming the full responsibility of the position, is achieving satis- factory results and has a salary which exceeds the mid point between the minimum and standard amounts of salary grade 28.
COMPENSATION
1. Life insurance
2. Dependent medical insurance
3. Dependent dental insurance
4. Annual physical examination during employment
5. Five weeks vacation, unless length of service would warrant more.* Participants in the Plan are not entitled to pay for accrued vacation (or to vacation in lieu of such pay) in excess of what they would receive if they were not par- ticipants.
*Language clarified. Exhibit 10.2 (Cont'd)
6. Sick pay allowance of one year at full pay and one year at half pay, regardless of length of service.
PROCEDURE
1. The president of each of the operating companies, the Executive Director, Central Services and the APS, Inc. vice presidents shall submit to the chief executive officer the names of all eligible employees or reasons why an employee, otherwise eligible, should not be included, not less than 30 days prior to the employee's eligibility date.
2. The Vice President, Employee and Consumer Relations maintains an official list of employees included in the Executive Compensation Plan for all companies.
January 1, 1987
Exhibit 10.3
ALLEGHENY POWER SYSTEM, INC.
1993 ANNUAL INCENTIVE PLAN
I. PURPOSE OF THE INCENTIVE PLAN
To attract and retain first quality managers in a com- petitive job market and to reward superior performance.
II. ELIGIBILITY
The annual incentive plan is designed to reward participating executives for achieving key goals for the System and for the units for which they are responsible.
A prerequisite for participation in the plan shall be an understanding of and commitment to
-- The System Management Plan and Policies
-- The System's expectation that employees will observe the highest ethical standards in their conduct of System business and stewardship of its property.
Eligibility will be determined by the Management Review Committee upon the recommendation of the CEO from among executives whose responsibilities can affect System performance.
III. AWARDS
Awards will reflect the importance of the participants to the System and the units for which they are responsible.
Awards will be paid for the achievement of specific measurable goals set for the System, including goals set the individual and the units for which he or she is responsible.
The plan's goals will be:
-- Determined and communicated annually
-- A reasonable number for each participant
The types of goals which the Board will set with the help of the Management Review Committee include:
-- Financial performance (return on equity, earnings, dividends)
-- Customer satisfaction (cost, quality, and reliability of service)
-- Cost and environmental consciousness (productivity, efficiency, availability and utilization of equipment) and conservation of resources
-- Safety
-- Development of personnel for management positions, including women and minorities
IV. OVERALL LIMITATIONS ON AWARDS
The Board of Directors shall not authorize any incentivepayment if, in the Board's opinion, the System's financial performance is less than satisfactory from the perspective of its stockholders.
V. PERFORMANCE MEASURES
Each year measures to evaluate participants' performance will be determined. They may vary among participants according to whether their principal responsibilities are to:
-- The System as a whole
-- An Operating Company
-- Bulk Power Supply or Central Services.
Each category of performance measure will carry appropriate weightings as shown on 1993 Participant Performance Schedule. Examples of possible measures include:
For System as a whole
-- Quantity and quality of earnings: return on equity, measured against previous year, authorized return on equity and as appropriate peer companies; financial ratings; capital structure, dividend payout ratios and total return
-- Productivity, cost control, efficient use of equipment, natural resources, and other environmental considerations
-- Quality and reliability of customer service
-- Safety
-- Attainment of reasonable rates and maintenance of competitive position
For Operating Companies
-- Balance for common stock: return on equity
-- Safety
-- Productivity and efficiency: revenues from regular customers, and administrative, operating, and maintenance expenditures
- Per employee, customer, and kwh
- Measured against previous year and peer companies
-- Customer satisfaction (quality of service): outage rates, speedy restoration of service, customer complaints, employee courtesy, conservation and demand- side management programs
-- Cost of service: rate per kwh measured against past period, economic indices, and peer companies
-- Community relations and relations with state and local governments and their agencies
-- Completion of construction projects on time and within budget
-- Adequacy of management development programs
For Bulk Power Supply and Central Services
-- Adequacy of planning and accuracy of forecasts
-- Completion of assignments and projects on time and within budget
-- Availability, efficiency, and reliability of generating units and transmission systems
-- Safety
-- Cost consciousness (avoidance of excessive staffing and waste of work space and receptivity to cost saving techniques)
-- Minimizing adverse effects in the environment
-- User satisfaction
-- Adherence to System Purchasing Policy and success in buying material, equipment, and supplies at the best possible price.
For Individual Performance
-- Initiative
-- Resourcefulness
-- Responsiveness
-- Identifiable results
-- Other
VI. CALCULATION OF AWARDS
Target Incentive Awards and Total Estimated Cost
-- No awards will be paid for any year unless the Board of Directors finds that the System's financial performance is satisfactory from the perspective of its stockholders
-- 100% of a target incentive award will be paid to a participant only if System, Responsibility Unit, and Individual target performance measures are fully achieved
Performance Schedules
-- The Performance Schedule describes ratings and weightings for each performance measure at all levels of performance
-- As soon as practicable each year, Participant Performance Schedules for that year will be issued
Performance Ratings
-- Target performance represents the full and complete attainment of expectations in the performance area; it is rated 1.0
-- Performance that is acceptable but does not fully meet expectations can earn a rating but, of course, less than 1.0
-- Exceeding expectations can result in a performance rating as high as 1.25
-- Unacceptable individual performance will result in no award regardless of System or Unit Performance.
Weightings
-- Weightings will be established each year for System, Unit and Individual performance measures.
Calculation of Award
-- A participant's award, if any, will be determined by multiplying the participant's assigned incentive percentage times his/her rounded total performance rating times his/her salary at the close of the year prior to the year for which the award is to be made.
The Management Review Committee or the Board of Directors,at its discretion, may supplement or decrease any partici-pant's calculated award to reflect extraordinary circumstances provided that it records its reason for doing so.
VII. FORM AND TIMING OF PAYOUT
Calculation of awards will be made as soon as practicable after the close of books for the year measured, but no award will be paid until it has been approved by the Management Review Committee or the Board of Directors, as appropriate.
Payment will be in current cash unless the Management Review Committee or the Board at its discretion provides for deferral.
VIII. TERMINATION AND TRANSFER PROVISIONS
Termination Provisions
-- Awards may at the discretion of the Management Review Committee or the Board be calculated on the basis of a full year's performance and prorated to the number of whole months actually served, except in the case of voluntary termination (other than retirement after the second quarter of the year) or termination by the company (with or without cause), in which case no award is made for year of termination.
Designation of "Unit" in cases of transfer among Operating Companies, Central Services, Bulk Power Supply, and New York
-- Weighting will be based on the number of months participant was in each unit.
IX. PLAN ADMINISTRATION
Administration of the plan is the responsibility of the Management Review Committee of the Board of Directors.
-- The Committee is responsible for review and administration of all Systemwide goals and has final approval over these and other matters involving the plan, including eligibility.
Exhibit 10.4
ALLEGHENY POWER SYSTEM
SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
(Effective July 1, 1990)
ALLEGHENY POWER SYSTEM
SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
1. Purpose of the Plan: The purpose of the Plan, the "Allegheny Power System Supplemental Executive Retirement Plan" (hereinafter referred to as the "Plan") is to provide for the payment of supplemental retirement benefits to or in respect of senior executives of Allegheny Power System companies (hereinafter sometimes referred to as a "Company" or the "Companies") as part of an integrated executive compensation program which is intended to assist the Companies in attracting, motivating and retaining executives of superior ability, industry, and loyalty.
2. Eligibility to Participate in the Plan: Each employee of a Company who was a participant in the Predecessor Plan or who on or after the Effective Date is assigned 1990 salary grade 28 or higher shall be a participant in the Plan.
3. Definitions: A. Average Compensation - shall mean 12 times the highest average monthly earnings (including overtime and other salary payments actually earned, whether or not payment thereof is deferred) for any 36 consecutive months.
B. Committee - shall mean the Finance Committee of the Board of Directors of Allegheny Power System, Inc. C. Effective Date - shall mean July 1, 1990. D. Participant - shall mean an employee who meets the eligibility requirements of Section 2. Retired Participant shall mean a Participant who has retired from service after at least 10 years of service with one or more Companies and on or after his/her 55th birthday. E. Plan Year - shall mean the 12-month period on which the fiscal records of the Plan are kept, which is now the period from July 1st to June 30th. F. Predecessor Plan - shall mean the Allegheny Power System Supplemental Executive Retirement Plans effective July 1, 1982 and July 1, 1988. G. Supplemental Retirement Benefit Reduction - shall mean the retirement benefit payable to the Participant under the Allegheny Power System Retirement Plan excluding any increases in this benefit which become effective after the Participant has retired. H. Years of Service - shall mean the Participant's Years of Service, and fractional parts thereof, as computed under the terms of the Allegheny Power System Retirement Plan.
4. Supplemental Retirement Benefits: A. Eligibility for Benefits - A Participant shall be eligible for a benefit from this Plan only (a) if he/she has at least 10 Years of Service with one or more of the Companies and (b) on or after his/her 55th birthday: provided that, if a Participant is discharged from employment for cause or terminates employment with the Companies prior to retirement under the Allegheny Power System Retirement Plan for any reason whatsoever, other than death, such eligibility will terminate and no benefit shall be payable to such Participant from this Plan. A Participant who dies in active employment on or after his/her 55th birthday shall be deemed to have retired one day before his/her death.
B. Amount of Benefits - (1) Subject to paragraph (2) of this Subsection, an eligible Participant will be entitled to receive a supplemental retirement benefit under this Plan equal to his/her Average Compensation multiplied by the sum of: (a) 2% times his/her number of Years of Service up to 25 years, (b) 1% times his/her number of Years of Service from 25 to 30 years, and (c) 1/2% times his/her number of Years of Service from 30 to 40 years less (x) such Participant's Supplemental Retirement Benefit Reduction and (y) 2% per year for each year that a Participant retires prior to his/her 60th birthday. (2) The supplemental retirement benefits contemplated by paragraph (1) of this Subsection shall be payable only to the extent such benefits, together with (i) all retirement benefits payable to the Participant by reason of employment with another employer (other than a benefit payable under the Federal Social Security Act) converted to the same form as the benefit paid under this Plan by using the actuarial equivalence factors of the Allegheny Power System Retirement Plan and (ii) the retirement benefit payable to the Participant under the Allegheny Power System Retirement Plan excluding any increases in this benefit which become effective after the Participant has retired do not exceed sixty percent (60%) of his/her Average Compensation, less 2% per year for each year the Participant retires prior to his/her 60th birthday. C. Form and Time of Payment - A benefit payable under this Plan shall be paid in such form as the Participant shall elect from those available, and at the same time as the retirement benefit payable to the Retired Participant, under the Allegheny Power System Retirement Plan. If the Benefit payable under this Plan is paid other than as a life annuity, the amount of the benefit when paid in such other form shall be determined by using the actuarial equivalence factors of the Allegheny Power System Retirement Plan.
5. Vesting: A Participant shall have no vested interest in the Plan until he/she becomes eligible to receive benefits under Section 4A. In the event such eligible Participant is discharged from employment for cause or terminates employment, other than by death or retirement under the Allegheny Power System Retirement Plan, any such interest which may have vested shall be discontinued and forfeited.
6. Funding: The Plan shall be unfunded. Benefits of a Participant shall be paid from the general assets of the Company employing the Participant at the time of his/her retirement and a Participant shall have no interest in any such assets under the terms of this Plan until he/she becomes a Retired Participant. An eligible Participant shall be an unsecured creditor of the Company as to the payment of any benefit under this plan.
7. Administration and Governing Law: This Plan will be administered by and under the direction of the Committee. The Committee shall adopt, and may from time to time modify or amend, such rules and guidelines consistent herewith as it may deem necessary or appropriate for carrying out the provisions and purposes of the Plan, which, upon their adoption and so long as in effect, shall be deemed a part hereof to the same extent as if set forth in the Plan (hereinafter referred to as the "Rules and Guidelines"). Any interpretation and construction by the Committee of any provision of, and the determination of any question arising under, the Plan or the Rules and Guidelines shall be final, conclusive, and binding upon the Participant, his/her surviving spouse and all other persons. The provisions of the Plan shall be construed, administered, and enforced according to and governed by the laws of the United States and the State of New York.
8. Entire Agreement: This Plan shall not be deemed to constitute a contract between any Company and any employee or other person in the employ of any Company, nor shall anything herein contained be deemed to give any employee or other person in the employ of any Company any right to be retained in the employ of any Company or to interfere with the right of any Company to discharge any employee or such other person at any time and to treat an employee without regard to the effect which such treatment might have upon such employee as a Participant in the Plan.
9. Non-Assignability: Neither a Participant, nor his beneficiary or any other person, shall have any right to commute, sell, assign, transfer, or otherwise convey the right to receive any payments hereunder; which payments and the right thereto are expressly declared to be nonassignable and nontransferable. In the event of any attempted assignment or transfer, the Companies shall have no further liability hereunder. Nor shall any payments be subject to attachment, garnishment, or execution, or be transferable by operation of law in the event of bankruptcy or insolvency, except to the extent otherwise provided by applicable law.
10. Termination or Amendment: This Plan may be terminated as to any Company at any time and amended from time to time by the Board of Directors of that Company; provided that neither termination nor amendment of the Plan may reduce or terminate any benefit to or in respect of a Participant eligible to receive benefits under Section 4A.
Exhibit 10.5
AGREEMENT EXECUTIVE LIFE INSURANCE PROGRAM AND COLLATERAL ASSIGNMENT
THIS AGREEMENT is entered into this day of , 19 , by and between Allegheny Power System, Inc., (hereinafter called "the Employer" in Part I or "Assignee" in Part II), and (hereinafter called "the Employee").
WHEREAS the Employee is currently a valued employee and Executive of Employer; Whereas the Employer wishes to assist the Employee with his (or her) personal life insurance program and the Employee desires to accept such assistance; and
WHEREAS in consideration of the Assignee agreeing to pay all of the premiums, the Owner agrees to grant the Assignee a security for the recovery of the Assignee's premium outlay.
NOW, THEREFORE for value received, the Employer and the Employee agree as follows:
PART I - Individual Life Insurance Agreement
A. Description of Policy - Policy Ownership In furtherance of the purposes of the Agreement, The Employee will purchase and own a certain policy of life insurance on his own life, being Policy No. issued by Security Life of Denver Insurance Company. Said policy is hereinafter called "the Policy" and said life insurance company is hereinafter called "the Insurer". The Employee's ownership of the Policy shall be subject to all the terms and conditions set forth in this Agreement.
B. Payment of Premiums The Employer shall pay the entire annual premium for the Policy directly to the Insurer.
C. Collateral Assignment and Possession of Policy To secure repayment of premiums paid by the Employer provided for in Section B, above, Part II of this Agreement includes an assignment of the policy or the Employee's interest therein (hereinafter called "Collateral Assignment") and provides for the transfer of possession of the Policy to the Employer during the term specified in Part II of this Agreement. Except as provided in or as otherwise consistent with the provisions of this Agreement, the Employer covenants that it will not exercise its rights under the Collateral Assignment provisions of this Agreement in such a manner as to defeat the rights of the Employee or the policy beneficiary under this Agreement. Specifically, the Employer covenants that it will not surrender the Policy unless Part I of the Agreement has terminated as provided in Section F and there has been a default in Employee's obligation under Section G of this Part I. The Employer shall have possession of the Policy during the period that the Employer makes premium payments and until all such payments are repaid. The Employer shall make the Policy available to the Insurer in order to make any change desired by the Employee as to the designation of beneficiary or the selection of a settlement option, subject, however, to the Collateral Assignment provisions hereof.
D. Beneficiary Designation and Payment of Policy Proceeds The Employee shall be entitled to a death benefit from the Policy equal to one (1) times his base salary, excluding bonuses, until his retirement. At retirement, his death benefit shall increase to two (2) times salary for the next 12 months, then shall decrease by 20% of final salary each year until the earlier of the fifth anniversary of retirement or age 70, at which time it will be one (1) times salary.
The Employee shall have the right to name the Policy beneficiary. However, in the event of the Employee's death, the Employer shall have an interest in the Policy proceeds equal to the total Policy proceeds in excess of the amount due to the Employee pursuant to this Section above.
E. Procedure at Employee's Death Upon the death of the Employee while the policy and this Agreement are in force and subject to the provisions of Parts I and II hereof, the Employer shall promptly take all necessary steps, including rendering of such assistance as may reasonably be required by the Employee's beneficiary, to obtain payment from the Insurer of the amounts payable under the Policy to the respective parties, as provided under Section D, above.
F. Termination of Agreement Part I of this Agreement shall terminate when the first of any of the following events occur: 1. Termination of the Employee's employment with the Employer prior to retirement; 2. The later of the Employee's actual retirement or ten years from the date of issuance of the Policy; 3. Performance of the Agreement's terms following the death of the Employee; 4. Failure by the Employer, for any reason, to make the premium contributions required under Section B of this Agreement;
G. Disposition of Policy Upon Termination of Agreement Upon the termination of Part I of this Agreement for any reason other than Section above, the Employee shall have a thirty (30) day option to satisfy the Collateral Assignment regarding the policy held by the Employer in accordance with the terms of this Paragraph G. The amount necessary to satisfy such Collateral Assignment shall be an amount equal to the total premium payments made, from time to time, greater than the amount of cash value under the Policy and, at the option of the Employee, either shall be paid directly by the Employee or through the Employer's collection from the cash value under the policy.
If the Policy shall then be encumbered by assignment, policy loan, or other means which have been the result of the Employer's actions, the Employer shall either remove such encumbrance, or reduce the amount necessary to satisfy the Collateral Assignment by the total amount of indebtedness outstanding against the Policy. If the Employee exercises his option to satisfy the Collateral Assignment, the Employer shall execute all necessary documents required by the Insurer to remove and satisfy the Collateral Assignment outstanding on the Policy. If the Employee does not exercise his option to satisfy the Collateral Assignment outstanding on the Policy, the Employee shall execute all documents necessary to transfer ownership of the Policy to the Employer. Such Transfer shall constitute satisfaction of any obligation the Employee has to the Employer with respect to this Agreement. The Employer shall then pay to the Employee the amount, if any, by which the cash surrender value of the Policy exceeds the amount necessary to satisfy the Collateral Assignment.
H. Employee's Right to Assign His/Her Interest The Employee shall have the right to transfer his/her entire interest in the Policy (other than rights assigned to the Employer pursuant to this Agreement and subject to the obligations of any outstanding Collateral Assignment). If the Employee makes such a transfer, all his/her rights shall be vested in the Transferee and the Employee shall have no further interest in the Policy and Agreement. Any assignee shall be subject to all obligations of the Employee under both Parts I and II of this Agreement.
I. Insurer's Obligations The Insurer is not party to this Agreement. It is understood by the parties hereto that in issuing such Policy of insurance, the Insurer shall have no liability except as set forth in the Policy and except as set forth in any assignment of the Policy filed at its Home Office and in Section J of this Agreement. Except as set forth in Section J, the Insurer shall not be bound to inquire into, or take notice of, any of the covenants herein contained as to the Policy of insurance or as to application of proceeds of such Policy. Upon the death of the Insured and payment of the proceeds in accordance with Section J of this Agreement, the insurer shall be discharged of all liability.
J. Claims Procedure The following claims procedure shall apply to the Policy and the Executive Life Insurance Program:
1. Filing of a claim for benefits. The Employee or the beneficiary of the Policy shall make a claim for the benefits provided under the Policy in the manner provided in the Policy. 2. Claim denial. With respect to a claim for benefits under said Policy, the Insurer shall be the entity which reviews and makes decisions on claim denials according to the terms of the Policy. 3. Notification to claimant of decision. If a claim is wholly or partially denied, notice of the decision, meeting the requirements of Section J4, following shall be furnished to the claimant within a reasonable period of time after a claim has been filed. 4. Content of notice. The Insurer shall provide, to any claimant who is denied a claim for benefits, written notice setting forth in a manner calculated to be understood by the claimant, the following: a. The specific reason or reasons for the denial; b. Specific reference to pertinent Policy provisions or provisions of this Agreement on which the denial is based; c. A description of any additional material or information necessary for the claimant to perfect the claim and an explanation of which such material or information is necessary; and d. An explanation of this Agreement's claim review procedure, as set forth in Sections J5 and J6.
5. Review procedure. The purpose of the review procedure set forth in this subsection and subsection 6, following, is to provide a method by which a claimant under the Policy may have a reasonable opportunity to appeal a denial of claim for a full and fair review. To accomplish that purpose, the claimant or his/her duly authorized representative: a. May request a review upon written application to the Insurer; b. May review the Policy; and c. May submit issues and comments in writing.
A claimant, (or his/her duly authorized representative), shall request a review by filing a written application of review at any time within sixty (60) days after receipt by the claimant of written notice of the denial of the claim.
6. Decision on review. A decision on review of a denial of a claim shall be made in the following matter; a. The decision on review shall be made by the Insurer which may, at its discretion, hold a hearing on the denied claim. The Insurer shall make its decision promptly, unless special circumstances (such as the need to hold a hearing) require an extension of time for processing, in which case a decision shall be rendered as soon as possible, but not later than on hundred twenty (120) days after receipt of the request for review. b. The decision on review shall be in writing and shall include specific reasons for the decision, written in a manner calculated to be understood by the claimant, and specific references to the pertinent Policy provision or provision of this Agreement on which the decision is based.
Notwithstanding any provision of the Agreement or the Policy, no Employee, assignee or beneficiary may commence any action in any court regarding the Policy prior to pursuing all rights of an Employee under this Section J.
PART II - Assignment of Life Insurance Policy as Collateral
A. For value received and in specific consideration of the premium payments made by the Employer as set forth in Section B of Part I hereof, the Employee hereby assigns, transfers and sets over to the Employer (herein in this Part II called the "Assignee"), its successors and assigns, the Policy issued by the Insurer upon the life of Employee and all claims, options, privileges, rights, titles and interest therein and thereunder (except as provided in Paragraph C hereof), subject to all terms and conditions of the Policy and to all superior liens, if any, which the Insurer may have against the Policy. The Employee by this instrument agrees and the Assignee by the acceptance of this assignment agrees to the conditions and provisions herein set forth.
B. It is expressly agreed that, without detracting from the generality of the foregoing, the following specific rights are included in this Agreement and Collateral Assignment and inure to the Assignee by virtue hereof: 1. The sole right to collect from the Insurer the net proceeds of the Policy in excess of the proceeds due the Employee under Part I, Section D when it becomes a claim by death or maturity; 2. The sole right to surrender the Policy and receive the surrender value thereof at any time provided by the terms of the Policy and at such other times as the Insurer may allow; 3. The sole right to obtain one or more loans or advances on the policy, either from the Insurer or, at any time, from other persons, and to pledge or assign the Policy as security for such loans or advances; 4. The sole right to collect and receive all distributions or share of surplus, dividend deposits or additions to he Policy now or hereafter made or apportioned thereto, and to exercise any and all options contained in the Policy with respect thereto; provided, that unless and until the Assignee shall notify the Insurer in writing to the contrary, the distributions or share of surplus, dividend deposits and additions shall continue on the Policy in force at the time of this assignment; and 5. The sole right to exercise all nonforfeiture rights permitted by the terms of the Policy or allowed by the Insurer and to receive all benefits and advantages derived therefrom.
C. It is expressly agreed that the following specific rights, so long as the Policy has not been surrendered, are reserved and excluded from this Agreement and Collateral Assignment and do not pass by virtue hereof: 1. The right to designate and change the beneficiary; 2. The right to elect any optional mode of settlement permitted by the Policy or allowed by the Insurer;
provided, however, that the reservation of these rights shall in no way impair the right of the Assignee to surrender the Policy completely with all its incidents or impair any other right of the Assignee hereunder, and any designation or change of beneficiary or election of a mode of settlement shall be made subject to this Agreement and Collateral Assignment and to the rights of the Assignee hereunder.
D. This Collateral Assignment is made and the Policy is to be held as collateral security for any and all liabilities of the Employee to the Assignee arising under this Agreement (all of which liabilities secured to or to become secured are herein called "Liabilities"). It is expressly agreed that all sums received by the Assignee hereunder either in event of death of the Insured, the maturity or surrender of the Policy, the obtaining of a loan or advance on the Policy, or otherwise, shall first be applied to the payment of the liability for premiums paid by the Assignee on the Policy.
E. The Assignee covenants and agrees with the Employee as follows: 1. That any balance of sums, if any, received hereunder from the Insurer remaining after payment of the existing Liabilities, matured or unmatured, shall be paid by the Assignee to the persons entitled thereto under the terms of the policy had this Collateral Assignment not been executed: 2. That the Assignee will not exercise either the right to surrender the Policy or the right to obtain policy loans from the Insurer, until there has been either default in any of the Liabilities pursuant to this Agreement or termination of Part I of said Agreement as therein provided; and
3. That the Assignee will, upon request, forward without reasonable delay to the Insurer the Policy for endorsement of any designation or change of beneficiary or any election of an optional mode of settlement.
F. The Employee declares that no proceedings in bankruptcy are pending against him/her and that his/her property is not subject to any assignment for the benefit of creditors.
PART III - Provisions Applicable to Parts I an II A. Amendments Amendments may be added to this Agreement by a written agreement signed by each of the parties and attached hereto.
B. Choice of Law This agreement shall be subject to, and construed according to, the laws of the State of . C. A Binding Agreement This Agreement shall bind the Employer and the Employer's successors and assigns, the Employee and his/her heirs, executors, administrators, and assigns, and any Policy beneficiary. D. Provision The Employer and the Employee agree that if any provision of this Agreement is determined to be invalid or unenforceable, in whole or part, then all remaining provisions of this Agreement and, to the extent valid or enforceable, the provision in question shall remain valid, binding and fully enforceable as if the invalid or unenforceable provisions, to the extent necessary, was not a part of this Agreement.
IN WITNESS WHEREOF, parties hereto have executed this Agreement, including the provisions regarding Collateral Assignment, on the day and year first above written.
Witness Employee
Address
Employer (Title)
Exhibit 10.6 AGREEMENT SECURED BENEFIT PLAN AND COLLATERAL ASSIGNMENT
THIS AGREEMENT is entered into this _____ day of __________, 1992 by and between Allegheny Power Service Corporation (hereinafter called the "Employer" in Part I or "Assignee" in Part II), and ___________________________ (hereinafter called the "Employee").
WHEREAS the Employee is currently a valued employee and Executive of Employer; WHEREAS the Employer wishes to assist the Employee with his (or her) personal future financial program and the Employee desires to accept such assistance; and
WHEREAS in consideration of the Employer agreeing to pay all of the premiums, the Employee agrees to grant the Employer security for the recovery of the Employer's premium outlay and the excess, if any, over the amounts due the Employee under Part I of this Agreement.
NOW, THEREFORE, for value received, the Employer and the Employee agree as follows:
Part I - Individual Life Insurance Agreement
A. Description of Policy - Policy Ownership
In furtherance of the purposes of the Agreement, the Employee will purchase and own a certain policy of life insurance on his own life, being Policy No. _____, issued by Pacific Mutual Life Insurance Co. Said policy is hereinafter called the "Policy" and said life insurance company is hereinafter called the "Insurer". The Employee's ownership of the Policy shall be subject to all the terms and conditions set forth in this Agreement.
B. Payment of Premiums The Employer shall pay the entire annual premium for the Policy directly to the Insurer.
C. Collateral Assignment and Possession of Policy To secure repayment of premiums paid by and amounts due to the Employer provided for in Section B, above, and Sections D and E, below, Part II of this Agreement includes an assignment of the policy or the Employee's interest therein (hereinafter called "Collateral Assignment") and provides for the transfer of possession of the policy, and the right to receive from the carrier and possess billings and policy statements, to the Employer during the term specified in Part II of this Agreement. Except as provided in or as otherwise consistent with the provisions of this Agreement, the Employer covenants that it will not exercise its rights under the Collateral Assignment provisions of this Agreement in such a manner as to defeat the rights of the Employee or the policy beneficiary under this Agreement. Specifically, the Employer covenants that it will not surrender the Policy unless Part I of the Agreement has terminated as provided in Section G and there has been a default in Employee's obligation under Section H of this Part I. The Employer shall have possession of the Policy during the period that the Employer makes premium payments and until all amounts due the Employer are repaid. The Employer shall make the Policy available to the Insurer in order to make any change desired by the Employee as to the designation of beneficiary or the selection of a settlement option, subject, however, to the provisions of this Agreement and the Collateral Assignment.
D. Beneficiary Designation and Payment of Policy Proceeds The Employee shall be entitled to a death benefit from the Policy in the amount required to provide an annuity equal to (under then current annuity settlement rates from the Insurer) the supplemental retirement benefit that would be provided under Sections 4A and 4B of the Allegheny Power System Supplemental Executive Retirement Plan effective July 1, 1990, attached hereto as Appendix I, excluding the provision in Section 4A that states, "...provided that, if a Participant is discharged from employment for cause or terminates employment with the Companies prior to retirement under the Allegheny Power System Retirement Plan for any reason whatsoever, other than death, such eligibility will terminate and no benefit shall be payable to such Participant from this Plan."
The Employer shall be the sole beneficiary of the policy until such time as the Employee has at least 10 years of service and is at least 55 years old. After that time and while this Agreement is in force, the following shall occur:
1. the beneficiary of the Employee's death benefit shall be the employee's spouse;
2. in the event of the Employee's death, the Employer shall be entitled to Policy proceeds equal to the total Policy proceeds in excess of the amount due to the Employee pursuant to this Section, above; and
3. if the employee is not married, he/she is entitled to no death benefit while this agreement is in force.
E. Policy Cash Values The Employee shall be entitled to cash values of the Policy in excess of the premiums paid by the Employer pursuant to Section B, Above, but not to exceed the death benefits to which he/she is entitled under Section D, above. If the Employee is not married, he/she shall be entitled to cash values determined as if he/she were married.
The Employer shall be entitled to Policy cash values in excess of the amount due to the Employee under this Section, above.
F. Procedure at Employee's Death Upon the death of the Employee while the Policy and this Agreement are in force and subject to the provisions of Parts I and II hereof, the Employer shall promptly take all necessary steps, including rendering of such assistance as may reasonably be required, to obtain payment from the Insurer of the amounts payable under the Policy to the respective parties, as provided under Section D, above.
G. Termination of Agreement Part I of this Agreement shall terminate when the first of any of the following events occur: 1. Termination of the Employee's employment with the Employer prior to retirement; 2. The later of the Employee's actual retirement or ten years from the date of issuance of the policy; 3. Performance of the Agreement's terms following the death of the Employee; 4. Failure by the Employer, for any reason, to make the premium contributions required under Section B of this Agreement.
H. Disposition of Policy Upon Termination of Agreement Upon the termination of Part I of this Agreement for any reason other than Section G3 above, the Employee shall have a thirty (30) day option to satisfy the Collateral Assignment regarding the policy held by the Employer in accordance with the terms of this Paragraph H. The amount necessary to satisfy such Collateral Assignment shall be an amount equal to the total premium payments made by the Employer, plus any excess amounts as determined in Section E, above, but no greater than the amount of cash value under the Policy and, at the option of the Employee, either shall be paid directly by the Employee or through the Employer's collection from the cash value of the Policy.
If the Policy shall then be encumbered by assignment, policy loan, or other means which have been the result of the Employer's actions, the Employer shall either remove such encumbrance, or reduce the amount necessary to satisfy the Collateral Assignment by the total amount of indebtedness outstanding against the Policy. If the Employee exercises his option to satisfy the Collateral Assignment, the Employer shall execute all necessary documents required by the Insurer to remove and satisfy the Collateral Assignment outstanding on the Policy. If the Employee does not exercise his option to satisfy the Collateral Assignment outstanding on the Policy, the Employee shall execute all documents necessary to transfer ownership of the Policy to the Employer. Such transfer shall constitute satisfaction of any obligation the Employee has to the Employer with respect to this Agreement. The Employer shall then pay to the Employee the amount, if any, by which the cash surrender value of the Policy exceeds the amount necessary to satisfy the Collateral Assignment.
I. Employee's Right to Assign His/Her Interest Employee agrees not to sell, assign, surrender or otherwise terminate the policy while this Agreement is in effect without the consent of the Employer.
J. Insurer's Obligations The Insurer is not a party to this Agreement. It is understood by the parties hereto that in issuing such Policy of insurance, the Insurer shall have no liability except as set forth in the Policy and except as set forth in any assignment of the Policy filed at it Home Office and in Section K of this Agreement. Except as set forth in Section K, the Insurer shall not be bound to inquire into, or take notice of, any of the covenants herein contained as to the Policy of insurance or as to application of proceeds of such policy. Upon the death of the Insured and payment of the proceeds in accordance with Section K of this Agreement, the Insurer shall be discharged of all liability.
K. Claims Procedure The following claims procedure shall apply to the Policy and the Secured Benefit Plan:
1. Filing of a claim for benefits. The Employee or the Beneficiary shall make a claim for the benefits provided under the policy in the manner provided in the Policy.
2. Claim denial. With respect to a claim for benefits under said Policy, the Insurer shall be the entity which reviews and makes decisions on claim denials according to the terms of the Policy.
3. Notification to claimant of decision. If a claim is wholly or partially denied, notice of the decision, meeting the requirements of Section K4, following, shall be furnished to the claimant within a reasonable period of time after a claim has been filed.
4. Content of notice. The insurer shall provide, to any claimant who is denied a claim for benefits, written notice setting forth in a manner calculated to be understood by the claimant, the following:
a. The specific reason or reasons for the denial; b. Specific reference to pertinent Policy provisions or provisions of this Agreement on which the denial is based; c. A description of any additional material or information necessary for the claimant to perfect the claim and an explanation of why such material or information is necessary; and d. An explanation of this Agreement's claim review procedure, as set forth in Sections K5 and K6.
5. Review procedure. The purpose of the review procedure set forth in this subsection and subsection 6, following, is to provide a method by which a claimant under the Policy may have a reasonable opportunity to appeal a denial of claim for a full and fair review. To accomplish that purpose, the claimant or his/her duly authorized representative: a. May request a review upon written application to the Insurer; b. May review the Policy; and c. May submit issues and comments in writing.
A claimant, (or his/her duly authorized representative), shall request a review by filing a written application of review at any time within sixty (60) days after receipt by the claimant of written notice of the denial of the claim.
6. Decision on review. A decision on review of a denial of a claim shall be made in the following matter: a. The decision on review shall be made by the Insurer which may, at its discretion, hold a hearing on the denied claim. The Insurer shall make its decision promptly, unless special circumstances (such as the need to hold a hearing) require an extension of time for processing, in which case a decision shall be rendered as soon as possible, but not later than one hundred twenty (120) days after receipt of the request for review. b. The decision on review shall be in writing and shall include specific reasons for the decision, written in a manner calculated to be understood by the claimant, and specific references to the pertinent Policy provision or provision of this Agreement on which the decision is based.
Notwithstanding any provision of the Agreement or the Policy, no Employee, assignee or beneficiary may commence any action in any court regarding the Policy prior to pursuing all rights of an Employee under this Section K. END OF PART I
Part II - Assignment of Life Insurance Policy as Collateral
A. For value received and in specific consideration of the premium payments made by the Employer as set forth in Section B of Part I hereof, the Employee hereby assigns, transfers and sets over to the Employer (herein this Part II called the "Assignee"), its successors and assigns, the Policy issued by the Insurer upon the life of Employee and all claims, options, privileges, rights, titles and interest therein and thereunder (except as provided in Paragraph C hereof), subject to all terms and conditions of the Policy and to all superior liens, if any, which the Insurer may have against the Policy. The Employee by this instrument agrees and the Assignee by the acceptance of this Assignment agrees to the conditions and provisions herein set forth.
B. It is expressly agreed that, without detracting from the generality of the foregoing, the following specific rights are included in this Agreement and Collateral Assignment and inure to the Assignee by virtue hereof:
1. The sole right to collect from the Insurer the net proceeds of the Policy in excess of the proceeds due the Employee under Part I, Section D, when it becomes a claim by death or maturity;
2. The sole right to surrender the Policy and receive the surrender value thereof at any time provided by the terms of the Policy and at such other times as the Insurer may allow;
3. The sole right to obtain one or more loans or advances on the policy, either from the Insurer or, at any time, from other persons, and to pledge or assign the Policy as security for such loans or advances;
4. The sole right to exercise all nonforfeiture rights permitted by the terms of the Policy or allowed by the Insurer and to receive all benefits and advantages derived therefrom;
5. The sole right to direct investment of cash values as provided under the insurance contract, and to make changes and transfers in such fund allocations.
C. It is expressly agreed that the following specific rights, so long as the Policy has not been surrendered, are reserved and excluded from this Collateral Assignment and do not pass by virtue hereof:
1. The right to designate and change the beneficiary;
2. The right to elect any optional mode of settlement permitted by the Policy or allowed by the Insurer;
provided, however, that the reservation of these rights shall in no way impair the right of the Assignee to surrender the Policy completely with all its incidents or impair any other right of the Assignee hereunder, and any designation or change of beneficiary or election of a mode of settlement shall be made subject to this Agreement and Collateral Assignment and to the rights of the Assignee hereunder.
D. This Collateral Assignment is made, and the Policy is to be held as collateral security for, any and all liabilities of the Employee to the Assignee arising under this Agreement (all of which liabilities secured or to become secured are herein called "Liabilities"). It is expressly agreed that all sums received by the Assignee hereunder either in the event of death of the Insured, the maturity or surrender of the Policy, the obtaining of a loan or advance on the Policy, or otherwise, shall first be applied to the payment of the liability for premiums paid by the Assignee on the Policy and other amounts due to Assignee under Part I of this Agreement.
E. The Assignee covenants and agrees with the Employee as follows:
1. That any balance of sums, if any, received hereunder from the Insurer remaining after payment of the existing Liabilities, matured or unmatured, shall be paid by the Assignee to the persons entitled thereto under the terms of the policy had this Collateral Assignment not be executed;
2. That the Assignee will not exercise either the right to surrender the Policy or the right to obtain policy loans from the Insurer, until there has been either default in any of the Liabilities pursuant to this Agreement or termination of part I of said Agreement as therein provided; and
3. That the Assignee will, upon request, forward without unreasonable delay to the Insurer the Policy for endorsement of any designation or change of beneficiary or any election of an optional mode of settlement.
F. The Employee declares that no proceedings in bankruptcy are pending against, him/her and that his/her property is not subject to any assignment for the benefit of creditors.
Part III - Provisions Applicable to Parts I and II
A. Amendments Amendments may be added to this Agreement by a written agreement signed by each of the parties and attached hereto.
B. Choice of Law This Agreement shall be subject to, and construed according to, the laws of the State of Maryland.
C. Binding Agreement This Agreement shall bind the Employer and the Employer's successors and assigns, the Employee and his/her heirs, executors, administrators, and assigns, and any Policy beneficiary.
D. Validity of Provisions The Employer and the Employee agree that if any provision of this Agreement is determined to be invalid or unenforceable, in whole or part, then all remaining provisions of the Agreement and, to the extent valid or enforceable, the provision in question shall remain valid, binding and fully enforceable as if the invalid or unenforceable provisions, to the extent necessary, was not a part of this Agreement.
IN WITNESS WHEREOF, parties hereto have executed this Agreement, including the provisions regarding Collateral Assignment, on the day and year first above written.
________________________ __________________________ Witness Employee ____________________________ _____________________________ Address Allegheny Power Service Corporation By: ____________________________ Richard J. Gagliardi Vice President
E-2 Monongahela Power Company Incorporation Documents by Reference
3.1 Charter of the Company, as amended Form S-3, 33-51301, exh. 4(a)
3.2 Code of Regulations, Form 10-Q of the Company as amended (1-268-2), September 1993, exh. (a)(3)
4 Indenture, dated as S 2-5819, exh. 7(f) of August 1, 1945, S 2-8782, exh. 7(f) (1) and certain S 2-8881, exh. 7(b) Supplemental S 2-9355, exh.4(h) (1) Indentures of the S 2-9979, exh. 4(h)(1) Company defining S 2-10548, exh. 4(b) rights of security S 2-14763, exh. 2(b) (i) holders.* S 2-24404, exh. 2(c); S 2-26806, exh. 4(d); Forms 8-K of the Company (1-268-2) dated August 8, 1989, November 21, 1991, June 4, 1992, July 15, 1992, September 1, 1992 and April 29, 1993
* There are omitted the Supplemental Indentures which do no more than subject property to the lien of the above Indentures since they are not considered constituent instruments defining the rights of the holders of the securities. The Company agrees to furnish the Commission on its request with copies of such Supplemental Indentures.
12 Computation of ratio of earnings to fixed charges
21 Subsidiaries: Monongahela Power Company has a 27% equity ownership in Allegheny Generating Company, incorporated in Virginia; and a 25% equity ownership in Allegheny Pittsburgh Coal Company, incorporated in Pennsylvania.
23 Consent of Independent Accountants See page 61 herein.
24 Powers of Attorney See pages 62-67 herein.
E-3
The Potomac Edison Company
Incorporation Documents by Reference
3.1 Charter of the Company, Form 10-Q of the Company as amended (1-3376-2), September 1993, exh. (a)3
3.2 By-laws of the Company, Form 10-Q of the Company as amended (1-3376-2), June 1990, exh. (a)3
4 Indenture, dated as of S 2-5473, exh. 7(b); Form October 1, 1944, and S-3, 33-51305, exh. 4(d) certain Supplemental Forms 8-K of the Company (1- Indentures of the 33-76-2) dated June 14, 1989, Company defining rights June 25, 1990, August 21, Company defining rights 1991, December 11, 1991, of security holders* December 15, 1992, February 17, 1993 and March 30, 1993
* There are omitted the Supplemental Indentures which do no more than subject property to the lien of the above Indentures since they are not considered constituent instruments defining the rights of the holders of the securities. The Company agrees to furnish the Commission on its request with copies of such Supplemental Indentures.
12 Computation of ratio of earnings to fixed charges
21 Subsidiaries: The Potomac Edison Company has a 28% equity ownership in Allegheny Generating Company, incorporated in Virginia and a 25% equity ownership in Allegheny Pittsburgh Coal Company, incorporated in Pennsylvania.
23 Consent of Independent See page 61 herein. Accountants
24 Powers of Attorney See pages 62-67 herein.
E-4
West Penn Power Company Incorporation Documents by Reference
3.1 Charter of the Company, Form S-3, 33-51303, exh. 4(a) as amended
3.2 By-laws of the Company, Form 8-K of the Company as amended (1-255-2), dated June 9, 1993, exh. (a)(3)
4 Indenture, dated as of S-3, 33-51303, exh. 4(d) March 1, 1916, and certain S 2-1835, exh. B(1), B(6) Supplemental Indentures of S 2-4099, exh. B(6), B(7) the Company defining rights S 2-4322, exh. B(5) of security holders.* S 2-5362, exh. B(2), B(5) S 2-7422, exh. 7(c), 7(i) S 2-7840, exh. 7(d), 7(k) S 2-8782, exh. 7(e) (1) S 2-9477, exh. 4(c), 4(d) S 2-10802, exh. 4(b), 4(c) S 2-13400, exh. 2(c), 2(d) Form 10-Q of the Company (1-255-2), June 1980, exh. D Forms 8-K of the Company (1-255-2) dated June 1989, February 1991, December 1991, August 13, 1993, September 15, 1992, June 9, 1993 and June
* There are omitted the Supplemental Indentures which do no more than subject property to the lien of the above Indentures since they are not considered constituent instruments defining the rights of the holders of the securities. The Company agrees to furnish the Commission on its request with copies of such Supplemental Indentures.
12 Computation of ratio of earnings to fixed charges
21 Subsidiaries: West Penn Power Company has a 45% equity ownership in Allegheny Generating Company, incorporated in Virginia; a 50% equity ownership in Allegheny Pittsburgh Coal Company, incorporated in Pennsylvania; and a 100% equity ownership in West Virginia Power and Transmission Company, incorporated in West Virginia, which owns a 100% equity ownership in West Penn West Virginia Water Power Company, incorporated in Pennsylvania.
23 Consent of Independent See page 61 herein. Accountants
24 Powers of Attorney See pages 62-67 herein.
E-5
Allegheny Generating Company
Documents
3.1(a) Charter of the Company, as amended*
3.1(b) Certificate of Amendment to Charter, effective July 14, 1989.**
3.2 By-laws of the Company, as amended*
4 Indenture, dated as of December 1, 1986, and Supplemental Indenture, dated as of December 15, 1988, of the Company defining rights of security holders.***
10.1 APS Power Agreement-Bath County Pumped Storage Project, as amended, dated as of August 14, 1981, among Monongahela Power Company, West Penn Power Company, and The Potomac Edison Company and Allegheny Generating Company.*
10.2 Operating Agreement, dated as of June 17, 1981, among Virginia Electric and Power Company, Allegheny Generating Company, Monongahela Power Company, West Penn Power Company and The Potomac Edison Company.*
10.3 Equity Agreement, dated June 17, 1981, between and among Allegheny Generating Company, Monongahela Power Company, West Penn Power Company and The Potomac Edison Company.*
10.4 United States of America Before The Federal Energy Regulatory Commission, Allegheny Generating Company, Docket No. ER84-504-000, Settlement Agreement effective October 1, 1985.*
12 Computation of ratio of earnings to fixed charges
23 Consent of Independent See page 61 herein. Accountants
24 Powers of Attorney See pages 62-67 herein.
* Incorporated by reference to the designated exhibit to AGC's registration statement on Form 10, File No. 0-14688.
** Incorporated by reference to Form 10-Q of the Company (0-14688) for June 1989, exh. (a).
*** Incorporated by reference to Forms 8-K of the Company (0-14688) for December 1986, exh. 4(A), and December 1988, exh. 4.1.


ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
For APS and the Subsidiaries, none.
PART IV
ITEM 14.

ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a)(1)(2) The financial statements and financial statement schedules filed as part of this Report are set forth under ITEM 8. and reference is made to the index on page 42.
(b) APS filed a report on Form 8-K on November 5, 1993 concerning the two-for-one stock split. No other reports on Form 8-K were filed by System companies during the quarter ended December 31, 1993.
(c) Exhibits for APS, Monongahela, Potomac Edison, West Penn, and AGC are listed in the Exhibit Index beginning on page E-1 and are incorporated herein by reference.
Graphics Appendix
Page
System Map . . . . . . . . . . . . . . . . . . . . . . . 10
- 56 -
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.
ALLEGHENY POWER SYSTEM, INC. By: KLAUS BERGMAN (Klaus Bergman, President and Chief Executive Officer)
Date: February 3, 1994
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.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
STANLEY I. GARNETT, II Vice President, 2/3/94 (Stanley I. Garnett, II) Finance
(iii) Principal Accounting Officer:
KENNETH M. JONES Vice President 2/3/94 (Kenneth M. Jones) and Comptroller
(iv) A Majority of the Directors:
*Eleanor Baum *Frank A. Metz, Jr. *William L. Bennett *Clarence F. Michalis *Klaus Bergman *Steven H. Rice *Phillip E. Lint *Gunnar E. Sarsten *Edward H. Malone *Peter L. Shea
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
- 57 -
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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
MONONGAHELA POWER COMPANY
By: BENJAMIN H. HAYES (Benjamin H. Hayes, President) Date: February 3, 1994
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. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
CHARLES S. MULLETT Secretary and 2/3/94 (Charles S. Mullett) Treasurer
(iii) Principal Accounting Officer:
RICHARD E. MYERS Comptroller 2/3/94 (Richard E. Myers)
(iv) A Majority of the Directors:
*Eleanor Baum *Edward H. Malone *William L. Bennett *Frank A. Metz, Jr. *Klaus Bergman *Clarence F. Michalis *Stanley I. Garnett, II *Steven H. Rice *Benjamin H. Hayes *Gunnar E. Sarsten *Phillip E. Lint *Peter L. Shea *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
- 58 -
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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
THE POTOMAC EDISON COMPANY
By: ALAN J. NOIA (Alan J. Noia, President) Date: February 3, 1994
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. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
DALE F. ZIMMERMAN Secretary and 2/3/94 (Dale F. Zimmerman) Treasurer
(iii) Principal Accounting Officer:
THOMAS J. KLOC Comptroller 2/3/94 (THOMAS J. KLOC)
(iv) A Majority of the Directors:
*Eleanor Baum *Frank A. Metz, Jr. *William L. Bennett *Clarence F. Michalis *Klaus Bergman *Alan J. Noia *Stanley I. Garnett, II *Steven H. Rice *Phillip E. Lint *Gunnar E. Sarsten *Edward H. Malone *Peter L. Shea *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
- 59 -
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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
WEST PENN POWER COMPANY
By: JAY S. PIFER (Jay S. Pifer, President) Date: February 3, 1994
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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
KENNETH D. MOWL Secretary and 2/3/94 (Kenneth D. Mowl) Treasurer
(iii) Principal Accounting Officer:
CHARLES V. BURKLEY Comptroller 2/3/94 (Charles V. Burkley)
(iv) A Majority of the Directors:
*Eleanor Baum *Frank A. Metz, Jr. *William L. Bennett *Clarence F. Michalis *Klaus Bergman *Jay S. Pifer *Stanley I. Garnett, II *Steven H. Rice *Phillip E. Lint *Gunnar E. Sarsten *Edward H. Malone *Peter L. Shea *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
- 60 -
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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
ALLEGHENY GENERATING COMPANY
By: KLAUS BERGMAN (Klaus Bergman, President and Chief Executive Officer)
Date: February 3, 1994
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. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.
Signature Title Date
(i) Principal Executive Officer:
Chairman of 2/3/94 of the Board, KLAUS BERGMAN President, Chief (Klaus Bergman) Executive Officer, and Director
(ii) Principal Financial Officer:
NANCY L. CAMPBELL Treasurer and 2/3/94 (Nancy L. Campbell Assistant Secretary
(iii) Principal Accounting Officer:
THOMAS J. KLOC Comptroller 2/3/94 (Thomas J. Kloc)
(iv) A Majority of the Directors:
*Klaus Bergman *Kenneth M. Jones *Stanley I. Garnett, II *Peter J. Skrgic
*By: NANCY H. GORMLEY 2/3/94 (Nancy H. Gormley)
- 61 -
CONSENT OF INDEPENDENT ACCOUNTANTS
We hereby consent to the incorporation by reference in the Prospectus constituting part of Allegheny Power System, Inc.'s Registration Statement on Form S-3 (No. 33-36716) relating to the Dividend Reinvestment and Stock Purchase Plan of Allegheny Power System, Inc.; in the Prospectus constituting part of Allegheny Power System, Inc.'s Registration Statement on Form S-3 (No. 33-49791) relating to the common stock shelf registration; in the Prospectus constituting part of Monongahela Power Company's Registration Statement on Form S-3 (No. 33-51301); in the Prospectus constituting part of The Potomac Edison Company's Registration Statement on Form S-3 (No. 33-51305); and in the Prospectus constituting part of West Penn Power Company's Registration Statement on Form S-3 (No. 33-51303); of our reports dated February 3, 1994 included in ITEM 8 of this Form 10-K. We also consent to the references to us under the heading "Experts" in such Prospectuses.
PRICE WATERHOUSE PRICE WATERHOUSE
New York, New York March 11, 1994
- 62 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned directors of Allegheny Power System, Inc., a Maryland corporation, Monongahela Power Company, an Ohio corporation, The Potomac Edison Company, a Maryland and Virginia corporation, and West Penn Power Company, a Pennsylvania corporation, do hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to Annual Reports on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Companies, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
ELEANOR BAUM FRANK A. METZ, JR. (Eleanor Baum) (Frank A. Metz, Jr.)
WILLIAM L. BENNETT CLARENCE F. MICHALIS (William L. Bennett) (Clarence F. Michalis)
KLAUS BERGMAN STEVEN H. RICE (Klaus Bergman) (Steven H. Rice)
PHILLIP E. LINT GUNNAR E. SARSTEN (Phillip E. Lint) (Gunnar E. Sarsten)
EDWARD H. MALONE PETER L. SHEA (Edward H. Malone) (Peter L. Shea)
- 63 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of The Potomac Edison Company, a Maryland and Virginia corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
ALAN J. NOIA (Alan J. Noia)
- 64 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of West Penn Power Company, a Pennsylvania corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
JAY S. PIFER (Jay S. Pifer)
- 65 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of Monongahela Power Company, an Ohio corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
BENJAMIN H. HAYES (Benjamin H. Hayes)
- 66 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned directors of Allegheny Generating Company, a Virginia corporation, do hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Company, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
KLAUS BERGMAN (Klaus Bergman)
KENNETH M. JONES (Kenneth M. Jones)
PETER J. SKRGIC (Peter J. Skrgic)
- 67 -
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS THAT the undersigned director of Monongahela Power Company, an Ohio corporation, The Potomac Edison Company, a Maryland and Virginia corporation, and West Penn Power Company, a Pennsylvania corporation, does hereby constitute and appoint NANCY H. GORMLEY and STANLEY I. GARNETT, II and each of them a true and lawful attorney in his or her name, place and stead, in any and all capacities, to sign his or her name to the Annual Report on Form 10-K for the year ended December 31, 1993 under the Securities Exchange Act of 1934, as amended, and to any and all amendments, of said Companies, and to cause the same to be filed with the Securities and Exchange Commission, granting unto said attorneys and each of them full power and authority to do and perform any act and thing necessary and proper to be done in the premises, as fully and to all intents and purposes as the undersigned could do if personally present, and the undersigned hereby ratifies and confirms all that said attorneys or any one of them shall lawfully do or cause to be done by virtue hereof.
Dated: February 3, 1994
PETER J. SKRGIC (Peter J. Skrgic)
E-1
EXHIBIT INDEX (Rule 601(a))
Allegheny Power System, Inc. Incorporation Documents by Reference
3.1 Charter of the Company, Form 10-Q of the Company as amended (1-267), September 1993, exh. (a)(3) 3.2 By-laws of the Company, Form 10-Q of the Company as amended (1-267), June 1990, exh. (a)(3)
4 Subsidiaries' Indentures described below.
10.1 Directors' Deferred Compensation Plan
10.2 Executive Compensation Plan
10.3 Allegheny Power System Incentive Compensation Plan
10.4 Allegheny Power System Supplemental Executive Retirement Plan
10.5 Executive Life Insurance Program and Collateral Assignment Agreement
10.6 Secured Benefit Plan and Collateral Assignment Agreement
11 Statement re computation of per share earnings:
Clearly determinable from the financial statements contained in Item 8.
21 Subsidiaries of APS:
Name of Company State of Organization
Allegheny Generating Company (a) Virginia Allegheny Power Service Corporation Maryland Monongahela Power Company Ohio The Potomac Edison Company Maryland and Virginia West Penn Power Company Pennsylvania
(a) Owned directly by Monongahela, Potomac Edison, and West Penn.
23 Consent of Independent Accountants See page 61 herein.
24 Powers of Attorney See pages 62-67 herein.
Exhibit 10.1
Election to Defer Receipt of Directors Fees Under the Directors Elective Deferred Fees Plan of Allegheny Power System
Pursuant to Section 4 of the captioned Plan, I hereby elect to defer receipt of ________% of all retainer and attendance fees payable to me on and after January 1, 19__.
I elect to have my deferred account, with accumulated interest, paid as follows, commencing with the 2nd day of January following the termination of my service as a member of the Board of Directors of Allegheny:
In a single lump sum, to be paid within 60 days after such January 2.
In annual installment payments of equal amounts (adjusted for interest credits) over _______ years (at least 3) with such installment payments to be made on January 2 of each year.
In annual installments of equal amounts (adjusted for interest credits) on January 2 of each year, such annual payments to be equal in number to the number of years of service.
In the event of my death prior to receipt of all amounts I have deferred under this Plan, including interest credits, the balance of such deferred funds shall be paid in a lump sum to the following designees who survive me or to my estate in proportion to the percentage shares indicated, and, if I have indicated no designees or if all indicated designees predecease me, entirely to my estate.
Designee Address Percentage Share
Dated: Signature
Exhibit 10.2
CONFIDENTIAL
EXECUTIVE COMPENSATION PLAN
OBJECTIVES
To attract, hold, and motivate executive personnel. Prior approval of the chief executive officer is required for inclusion in the Plan.
QUALIFICATIONS
An employee becomes eligible for inclusion when
1. the employee has held a position with a salary grade of 28 or above for at least one year, is assuming the full responsibility of the position, is achieving satisfactory results and has a salary which exceeds the mid point between the minimum and standard amounts of salary grade 28, or
2. the employee has held the position of operating division manager with a salary grade of 18 or above for at least one year, is assuming the full responsibility of the position, is achieving satis- factory results and has a salary which exceeds the mid point between the minimum and standard amounts of salary grade 28.
COMPENSATION
1. Life insurance
2. Dependent medical insurance
3. Dependent dental insurance
4. Annual physical examination during employment
5. Five weeks vacation, unless length of service would warrant more.* Participants in the Plan are not entitled to pay for accrued vacation (or to vacation in lieu of such pay) in excess of what they would receive if they were not par- ticipants.
*Language clarified. Exhibit 10.2 (Cont'd)
6. Sick pay allowance of one year at full pay and one year at half pay, regardless of length of service.
PROCEDURE
1. The president of each of the operating companies, the Executive Director, Central Services and the APS, Inc. vice presidents shall submit to the chief executive officer the names of all eligible employees or reasons why an employee, otherwise eligible, should not be included, not less than 30 days prior to the employee's eligibility date.
2. The Vice President, Employee and Consumer Relations maintains an official list of employees included in the Executive Compensation Plan for all companies.
January 1, 1987
Exhibit 10.3
ALLEGHENY POWER SYSTEM, INC.
1993 ANNUAL INCENTIVE PLAN
I. PURPOSE OF THE INCENTIVE PLAN
To attract and retain first quality managers in a com- petitive job market and to reward superior performance.
II. ELIGIBILITY
The annual incentive plan is designed to reward participating executives for achieving key goals for the System and for the units for which they are responsible.
A prerequisite for participation in the plan shall be an understanding of and commitment to
-- The System Management Plan and Policies
-- The System's expectation that employees will observe the highest ethical standards in their conduct of System business and stewardship of its property.
Eligibility will be determined by the Management Review Committee upon the recommendation of the CEO from among executives whose responsibilities can affect System performance.
III. AWARDS
Awards will reflect the importance of the participants to the System and the units for which they are responsible.
Awards will be paid for the achievement of specific measurable goals set for the System, including goals set the individual and the units for which he or she is responsible.
The plan's goals will be:
-- Determined and communicated annually
-- A reasonable number for each participant
The types of goals which the Board will set with the help of the Management Review Committee include:
-- Financial performance (return on equity, earnings, dividends)
-- Customer satisfaction (cost, quality, and reliability of service)
-- Cost and environmental consciousness (productivity, efficiency, availability and utilization of equipment) and conservation of resources
-- Safety
-- Development of personnel for management positions, including women and minorities
IV. OVERALL LIMITATIONS ON AWARDS
The Board of Directors shall not authorize any incentivepayment if, in the Board's opinion, the System's financial performance is less than satisfactory from the perspective of its stockholders.
V. PERFORMANCE MEASURES
Each year measures to evaluate participants' performance will be determined. They may vary among participants according to whether their principal responsibilities are to:
-- The System as a whole
-- An Operating Company
-- Bulk Power Supply or Central Services.
Each category of performance measure will carry appropriate weightings as shown on 1993 Participant Performance Schedule. Examples of possible measures include:
For System as a whole
-- Quantity and quality of earnings: return on equity, measured against previous year, authorized return on equity and as appropriate peer companies; financial ratings; capital structure, dividend payout ratios and total return
-- Productivity, cost control, efficient use of equipment, natural resources, and other environmental considerations
-- Quality and reliability of customer service
-- Safety
-- Attainment of reasonable rates and maintenance of competitive position
For Operating Companies
-- Balance for common stock: return on equity
-- Safety
-- Productivity and efficiency: revenues from regular customers, and administrative, operating, and maintenance expenditures
- Per employee, customer, and kwh
- Measured against previous year and peer companies
-- Customer satisfaction (quality of service): outage rates, speedy restoration of service, customer complaints, employee courtesy, conservation and demand- side management programs
-- Cost of service: rate per kwh measured against past period, economic indices, and peer companies
-- Community relations and relations with state and local governments and their agencies
-- Completion of construction projects on time and within budget
-- Adequacy of management development programs
For Bulk Power Supply and Central Services
-- Adequacy of planning and accuracy of forecasts
-- Completion of assignments and projects on time and within budget
-- Availability, efficiency, and reliability of generating units and transmission systems
-- Safety
-- Cost consciousness (avoidance of excessive staffing and waste of work space and receptivity to cost saving techniques)
-- Minimizing adverse effects in the environment
-- User satisfaction
-- Adherence to System Purchasing Policy and success in buying material, equipment, and supplies at the best possible price.
For Individual Performance
-- Initiative
-- Resourcefulness
-- Responsiveness
-- Identifiable results
-- Other
VI. CALCULATION OF AWARDS
Target Incentive Awards and Total Estimated Cost
-- No awards will be paid for any year unless the Board of Directors finds that the System's financial performance is satisfactory from the perspective of its stockholders
-- 100% of a target incentive award will be paid to a participant only if System, Responsibility Unit, and Individual target performance measures are fully achieved
Performance Schedules
-- The Performance Schedule describes ratings and weightings for each performance measure at all levels of performance
-- As soon as practicable each year, Participant Performance Schedules for that year will be issued
Performance Ratings
-- Target performance represents the full and complete attainment of expectations in the performance area; it is rated 1.0
-- Performance that is acceptable but does not fully meet expectations can earn a rating but, of course, less than 1.0
-- Exceeding expectations can result in a performance rating as high as 1.25
-- Unacceptable individual performance will result in no award regardless of System or Unit Performance.
Weightings
-- Weightings will be established each year for System, Unit and Individual performance measures.
Calculation of Award
-- A participant's award, if any, will be determined by multiplying the participant's assigned incentive percentage times his/her rounded total performance rating times his/her salary at the close of the year prior to the year for which the award is to be made.
The Management Review Committee or the Board of Directors,at its discretion, may supplement or decrease any partici-pant's calculated award to reflect extraordinary circumstances provided that it records its reason for doing so.
VII. FORM AND TIMING OF PAYOUT
Calculation of awards will be made as soon as practicable after the close of books for the year measured, but no award will be paid until it has been approved by the Management Review Committee or the Board of Directors, as appropriate.
Payment will be in current cash unless the Management Review Committee or the Board at its discretion provides for deferral.
VIII. TERMINATION AND TRANSFER PROVISIONS
Termination Provisions
-- Awards may at the discretion of the Management Review Committee or the Board be calculated on the basis of a full year's performance and prorated to the number of whole months actually served, except in the case of voluntary termination (other than retirement after the second quarter of the year) or termination by the company (with or without cause), in which case no award is made for year of termination.
Designation of "Unit" in cases of transfer among Operating Companies, Central Services, Bulk Power Supply, and New York
-- Weighting will be based on the number of months participant was in each unit.
IX. PLAN ADMINISTRATION
Administration of the plan is the responsibility of the Management Review Committee of the Board of Directors.
-- The Committee is responsible for review and administration of all Systemwide goals and has final approval over these and other matters involving the plan, including eligibility.
Exhibit 10.4
ALLEGHENY POWER SYSTEM
SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
(Effective July 1, 1990)
ALLEGHENY POWER SYSTEM
SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
1. Purpose of the Plan: The purpose of the Plan, the "Allegheny Power System Supplemental Executive Retirement Plan" (hereinafter referred to as the "Plan") is to provide for the payment of supplemental retirement benefits to or in respect of senior executives of Allegheny Power System companies (hereinafter sometimes referred to as a "Company" or the "Companies") as part of an integrated executive compensation program which is intended to assist the Companies in attracting, motivating and retaining executives of superior ability, industry, and loyalty.
2. Eligibility to Participate in the Plan: Each employee of a Company who was a participant in the Predecessor Plan or who on or after the Effective Date is assigned 1990 salary grade 28 or higher shall be a participant in the Plan.
3. Definitions: A. Average Compensation - shall mean 12 times the highest average monthly earnings (including overtime and other salary payments actually earned, whether or not payment thereof is deferred) for any 36 consecutive months.
B. Committee - shall mean the Finance Committee of the Board of Directors of Allegheny Power System, Inc. C. Effective Date - shall mean July 1, 1990. D. Participant - shall mean an employee who meets the eligibility requirements of Section 2. Retired Participant shall mean a Participant who has retired from service after at least 10 years of service with one or more Companies and on or after his/her 55th birthday. E. Plan Year - shall mean the 12-month period on which the fiscal records of the Plan are kept, which is now the period from July 1st to June 30th. F. Predecessor Plan - shall mean the Allegheny Power System Supplemental Executive Retirement Plans effective July 1, 1982 and July 1, 1988. G. Supplemental Retirement Benefit Reduction - shall mean the retirement benefit payable to the Participant under the Allegheny Power System Retirement Plan excluding any increases in this benefit which become effective after the Participant has retired. H. Years of Service - shall mean the Participant's Years of Service, and fractional parts thereof, as computed under the terms of the Allegheny Power System Retirement Plan.
4. Supplemental Retirement Benefits: A. Eligibility for Benefits - A Participant shall be eligible for a benefit from this Plan only (a) if he/she has at least 10 Years of Service with one or more of the Companies and (b) on or after his/her 55th birthday: provided that, if a Participant is discharged from employment for cause or terminates employment with the Companies prior to retirement under the Allegheny Power System Retirement Plan for any reason whatsoever, other than death, such eligibility will terminate and no benefit shall be payable to such Participant from this Plan. A Participant who dies in active employment on or after his/her 55th birthday shall be deemed to have retired one day before his/her death.
B. Amount of Benefits - (1) Subject to paragraph (2) of this Subsection, an eligible Participant will be entitled to receive a supplemental retirement benefit under this Plan equal to his/her Average Compensation multiplied by the sum of: (a) 2% times his/her number of Years of Service up to 25 years, (b) 1% times his/her number of Years of Service from 25 to 30 years, and (c) 1/2% times his/her number of Years of Service from 30 to 40 years less (x) such Participant's Supplemental Retirement Benefit Reduction and (y) 2% per year for each year that a Participant retires prior to his/her 60th birthday. (2) The supplemental retirement benefits contemplated by paragraph (1) of this Subsection shall be payable only to the extent such benefits, together with (i) all retirement benefits payable to the Participant by reason of employment with another employer (other than a benefit payable under the Federal Social Security Act) converted to the same form as the benefit paid under this Plan by using the actuarial equivalence factors of the Allegheny Power System Retirement Plan and (ii) the retirement benefit payable to the Participant under the Allegheny Power System Retirement Plan excluding any increases in this benefit which become effective after the Participant has retired do not exceed sixty percent (60%) of his/her Average Compensation, less 2% per year for each year the Participant retires prior to his/her 60th birthday. C. Form and Time of Payment - A benefit payable under this Plan shall be paid in such form as the Participant shall elect from those available, and at the same time as the retirement benefit payable to the Retired Participant, under the Allegheny Power System Retirement Plan. If the Benefit payable under this Plan is paid other than as a life annuity, the amount of the benefit when paid in such other form shall be determined by using the actuarial equivalence factors of the Allegheny Power System Retirement Plan.
5. Vesting: A Participant shall have no vested interest in the Plan until he/she becomes eligible to receive benefits under Section 4A. In the event such eligible Participant is discharged from employment for cause or terminates employment, other than by death or retirement under the Allegheny Power System Retirement Plan, any such interest which may have vested shall be discontinued and forfeited.
6. Funding: The Plan shall be unfunded. Benefits of a Participant shall be paid from the general assets of the Company employing the Participant at the time of his/her retirement and a Participant shall have no interest in any such assets under the terms of this Plan until he/she becomes a Retired Participant. An eligible Participant shall be an unsecured creditor of the Company as to the payment of any benefit under this plan.
7. Administration and Governing Law: This Plan will be administered by and under the direction of the Committee. The Committee shall adopt, and may from time to time modify or amend, such rules and guidelines consistent herewith as it may deem necessary or appropriate for carrying out the provisions and purposes of the Plan, which, upon their adoption and so long as in effect, shall be deemed a part hereof to the same extent as if set forth in the Plan (hereinafter referred to as the "Rules and Guidelines"). Any interpretation and construction by the Committee of any provision of, and the determination of any question arising under, the Plan or the Rules and Guidelines shall be final, conclusive, and binding upon the Participant, his/her surviving spouse and all other persons. The provisions of the Plan shall be construed, administered, and enforced according to and governed by the laws of the United States and the State of New York.
8. Entire Agreement: This Plan shall not be deemed to constitute a contract between any Company and any employee or other person in the employ of any Company, nor shall anything herein contained be deemed to give any employee or other person in the employ of any Company any right to be retained in the employ of any Company or to interfere with the right of any Company to discharge any employee or such other person at any time and to treat an employee without regard to the effect which such treatment might have upon such employee as a Participant in the Plan.
9. Non-Assignability: Neither a Participant, nor his beneficiary or any other person, shall have any right to commute, sell, assign, transfer, or otherwise convey the right to receive any payments hereunder; which payments and the right thereto are expressly declared to be nonassignable and nontransferable. In the event of any attempted assignment or transfer, the Companies shall have no further liability hereunder. Nor shall any payments be subject to attachment, garnishment, or execution, or be transferable by operation of law in the event of bankruptcy or insolvency, except to the extent otherwise provided by applicable law.
10. Termination or Amendment: This Plan may be terminated as to any Company at any time and amended from time to time by the Board of Directors of that Company; provided that neither termination nor amendment of the Plan may reduce or terminate any benefit to or in respect of a Participant eligible to receive benefits under Section 4A.
Exhibit 10.5
AGREEMENT EXECUTIVE LIFE INSURANCE PROGRAM AND COLLATERAL ASSIGNMENT
THIS AGREEMENT is entered into this day of , 19 , by and between Allegheny Power System, Inc., (hereinafter called "the Employer" in Part I or "Assignee" in Part II), and (hereinafter called "the Employee").
WHEREAS the Employee is currently a valued employee and Executive of Employer; Whereas the Employer wishes to assist the Employee with his (or her) personal life insurance program and the Employee desires to accept such assistance; and
WHEREAS in consideration of the Assignee agreeing to pay all of the premiums, the Owner agrees to grant the Assignee a security for the recovery of the Assignee's premium outlay.
NOW, THEREFORE for value received, the Employer and the Employee agree as follows:
PART I - Individual Life Insurance Agreement
A. Description of Policy - Policy Ownership In furtherance of the purposes of the Agreement, The Employee will purchase and own a certain policy of life insurance on his own life, being Policy No. issued by Security Life of Denver Insurance Company. Said policy is hereinafter called "the Policy" and said life insurance company is hereinafter called "the Insurer". The Employee's ownership of the Policy shall be subject to all the terms and conditions set forth in this Agreement.
B. Payment of Premiums The Employer shall pay the entire annual premium for the Policy directly to the Insurer.
C. Collateral Assignment and Possession of Policy To secure repayment of premiums paid by the Employer provided for in Section B, above, Part II of this Agreement includes an assignment of the policy or the Employee's interest therein (hereinafter called "Collateral Assignment") and provides for the transfer of possession of the Policy to the Employer during the term specified in Part II of this Agreement. Except as provided in or as otherwise consistent with the provisions of this Agreement, the Employer covenants that it will not exercise its rights under the Collateral Assignment provisions of this Agreement in such a manner as to defeat the rights of the Employee or the policy beneficiary under this Agreement. Specifically, the Employer covenants that it will not surrender the Policy unless Part I of the Agreement has terminated as provided in Section F and there has been a default in Employee's obligation under Section G of this Part I. The Employer shall have possession of the Policy during the period that the Employer makes premium payments and until all such payments are repaid. The Employer shall make the Policy available to the Insurer in order to make any change desired by the Employee as to the designation of beneficiary or the selection of a settlement option, subject, however, to the Collateral Assignment provisions hereof.
D. Beneficiary Designation and Payment of Policy Proceeds The Employee shall be entitled to a death benefit from the Policy equal to one (1) times his base salary, excluding bonuses, until his retirement. At retirement, his death benefit shall increase to two (2) times salary for the next 12 months, then shall decrease by 20% of final salary each year until the earlier of the fifth anniversary of retirement or age 70, at which time it will be one (1) times salary.
The Employee shall have the right to name the Policy beneficiary. However, in the event of the Employee's death, the Employer shall have an interest in the Policy proceeds equal to the total Policy proceeds in excess of the amount due to the Employee pursuant to this Section above.
E. Procedure at Employee's Death Upon the death of the Employee while the policy and this Agreement are in force and subject to the provisions of Parts I and II hereof, the Employer shall promptly take all necessary steps, including rendering of such assistance as may reasonably be required by the Employee's beneficiary, to obtain payment from the Insurer of the amounts payable under the Policy to the respective parties, as provided under Section D, above.
F. Termination of Agreement Part I of this Agreement shall terminate when the first of any of the following events occur: 1. Termination of the Employee's employment with the Employer prior to retirement; 2. The later of the Employee's actual retirement or ten years from the date of issuance of the Policy; 3. Performance of the Agreement's terms following the death of the Employee; 4. Failure by the Employer, for any reason, to make the premium contributions required under Section B of this Agreement;
G. Disposition of Policy Upon Termination of Agreement Upon the termination of Part I of this Agreement for any reason other than Section above, the Employee shall have a thirty (30) day option to satisfy the Collateral Assignment regarding the policy held by the Employer in accordance with the terms of this Paragraph G. The amount necessary to satisfy such Collateral Assignment shall be an amount equal to the total premium payments made, from time to time, greater than the amount of cash value under the Policy and, at the option of the Employee, either shall be paid directly by the Employee or through the Employer's collection from the cash value under the policy.
If the Policy shall then be encumbered by assignment, policy loan, or other means which have been the result of the Employer's actions, the Employer shall either remove such encumbrance, or reduce the amount necessary to satisfy the Collateral Assignment by the total amount of indebtedness outstanding against the Policy. If the Employee exercises his option to satisfy the Collateral Assignment, the Employer shall execute all necessary documents required by the Insurer to remove and satisfy the Collateral Assignment outstanding on the Policy. If the Employee does not exercise his option to satisfy the Collateral Assignment outstanding on the Policy, the Employee shall execute all documents necessary to transfer ownership of the Policy to the Employer. Such Transfer shall constitute satisfaction of any obligation the Employee has to the Employer with respect to this Agreement. The Employer shall then pay to the Employee the amount, if any, by which the cash surrender value of the Policy exceeds the amount necessary to satisfy the Collateral Assignment.
H. Employee's Right to Assign His/Her Interest The Employee shall have the right to transfer his/her entire interest in the Policy (other than rights assigned to the Employer pursuant to this Agreement and subject to the obligations of any outstanding Collateral Assignment). If the Employee makes such a transfer, all his/her rights shall be vested in the Transferee and the Employee shall have no further interest in the Policy and Agreement. Any assignee shall be subject to all obligations of the Employee under both Parts I and II of this Agreement.
I. Insurer's Obligations The Insurer is not party to this Agreement. It is understood by the parties hereto that in issuing such Policy of insurance, the Insurer shall have no liability except as set forth in the Policy and except as set forth in any assignment of the Policy filed at its Home Office and in Section J of this Agreement. Except as set forth in Section J, the Insurer shall not be bound to inquire into, or take notice of, any of the covenants herein contained as to the Policy of insurance or as to application of proceeds of such Policy. Upon the death of the Insured and payment of the proceeds in accordance with Section J of this Agreement, the insurer shall be discharged of all liability.
J. Claims Procedure The following claims procedure shall apply to the Policy and the Executive Life Insurance Program:
1. Filing of a claim for benefits. The Employee or the beneficiary of the Policy shall make a claim for the benefits provided under the Policy in the manner provided in the Policy. 2. Claim denial. With respect to a claim for benefits under said Policy, the Insurer shall be the entity which reviews and makes decisions on claim denials according to the terms of the Policy. 3. Notification to claimant of decision. If a claim is wholly or partially denied, notice of the decision, meeting the requirements of Section J4, following shall be furnished to the claimant within a reasonable period of time after a claim has been filed. 4. Content of notice. The Insurer shall provide, to any claimant who is denied a claim for benefits, written notice setting forth in a manner calculated to be understood by the claimant, the following: a. The specific reason or reasons for the denial; b. Specific reference to pertinent Policy provisions or provisions of this Agreement on which the denial is based; c. A description of any additional material or information necessary for the claimant to perfect the claim and an explanation of which such material or information is necessary; and d. An explanation of this Agreement's claim review procedure, as set forth in Sections J5 and J6.
5. Review procedure. The purpose of the review procedure set forth in this subsection and subsection 6, following, is to provide a method by which a claimant under the Policy may have a reasonable opportunity to appeal a denial of claim for a full and fair review. To accomplish that purpose, the claimant or his/her duly authorized representative: a. May request a review upon written application to the Insurer; b. May review the Policy; and c. May submit issues and comments in writing.
A claimant, (or his/her duly authorized representative), shall request a review by filing a written application of review at any time within sixty (60) days after receipt by the claimant of written notice of the denial of the claim.
6. Decision on review. A decision on review of a denial of a claim shall be made in the following matter; a. The decision on review shall be made by the Insurer which may, at its discretion, hold a hearing on the denied claim. The Insurer shall make its decision promptly, unless special circumstances (such as the need to hold a hearing) require an extension of time for processing, in which case a decision shall be rendered as soon as possible, but not later than on hundred twenty (120) days after receipt of the request for review. b. The decision on review shall be in writing and shall include specific reasons for the decision, written in a manner calculated to be understood by the claimant, and specific references to the pertinent Policy provision or provision of this Agreement on which the decision is based.
Notwithstanding any provision of the Agreement or the Policy, no Employee, assignee or beneficiary may commence any action in any court regarding the Policy prior to pursuing all rights of an Employee under this Section J.
PART II - Assignment of Life Insurance Policy as Collateral
A. For value received and in specific consideration of the premium payments made by the Employer as set forth in Section B of Part I hereof, the Employee hereby assigns, transfers and sets over to the Employer (herein in this Part II called the "Assignee"), its successors and assigns, the Policy issued by the Insurer upon the life of Employee and all claims, options, privileges, rights, titles and interest therein and thereunder (except as provided in Paragraph C hereof), subject to all terms and conditions of the Policy and to all superior liens, if any, which the Insurer may have against the Policy. The Employee by this instrument agrees and the Assignee by the acceptance of this assignment agrees to the conditions and provisions herein set forth.
B. It is expressly agreed that, without detracting from the generality of the foregoing, the following specific rights are included in this Agreement and Collateral Assignment and inure to the Assignee by virtue hereof: 1. The sole right to collect from the Insurer the net proceeds of the Policy in excess of the proceeds due the Employee under Part I, Section D when it becomes a claim by death or maturity; 2. The sole right to surrender the Policy and receive the surrender value thereof at any time provided by the terms of the Policy and at such other times as the Insurer may allow; 3. The sole right to obtain one or more loans or advances on the policy, either from the Insurer or, at any time, from other persons, and to pledge or assign the Policy as security for such loans or advances; 4. The sole right to collect and receive all distributions or share of surplus, dividend deposits or additions to he Policy now or hereafter made or apportioned thereto, and to exercise any and all options contained in the Policy with respect thereto; provided, that unless and until the Assignee shall notify the Insurer in writing to the contrary, the distributions or share of surplus, dividend deposits and additions shall continue on the Policy in force at the time of this assignment; and 5. The sole right to exercise all nonforfeiture rights permitted by the terms of the Policy or allowed by the Insurer and to receive all benefits and advantages derived therefrom.
C. It is expressly agreed that the following specific rights, so long as the Policy has not been surrendered, are reserved and excluded from this Agreement and Collateral Assignment and do not pass by virtue hereof: 1. The right to designate and change the beneficiary; 2. The right to elect any optional mode of settlement permitted by the Policy or allowed by the Insurer;
provided, however, that the reservation of these rights shall in no way impair the right of the Assignee to surrender the Policy completely with all its incidents or impair any other right of the Assignee hereunder, and any designation or change of beneficiary or election of a mode of settlement shall be made subject to this Agreement and Collateral Assignment and to the rights of the Assignee hereunder.
D. This Collateral Assignment is made and the Policy is to be held as collateral security for any and all liabilities of the Employee to the Assignee arising under this Agreement (all of which liabilities secured to or to become secured are herein called "Liabilities"). It is expressly agreed that all sums received by the Assignee hereunder either in event of death of the Insured, the maturity or surrender of the Policy, the obtaining of a loan or advance on the Policy, or otherwise, shall first be applied to the payment of the liability for premiums paid by the Assignee on the Policy.
E. The Assignee covenants and agrees with the Employee as follows: 1. That any balance of sums, if any, received hereunder from the Insurer remaining after payment of the existing Liabilities, matured or unmatured, shall be paid by the Assignee to the persons entitled thereto under the terms of the policy had this Collateral Assignment not been executed: 2. That the Assignee will not exercise either the right to surrender the Policy or the right to obtain policy loans from the Insurer, until there has been either default in any of the Liabilities pursuant to this Agreement or termination of Part I of said Agreement as therein provided; and
3. That the Assignee will, upon request, forward without reasonable delay to the Insurer the Policy for endorsement of any designation or change of beneficiary or any election of an optional mode of settlement.
F. The Employee declares that no proceedings in bankruptcy are pending against him/her and that his/her property is not subject to any assignment for the benefit of creditors.
PART III - Provisions Applicable to Parts I an II A. Amendments Amendments may be added to this Agreement by a written agreement signed by each of the parties and attached hereto.
B. Choice of Law This agreement shall be subject to, and construed according to, the laws of the State of . C. A Binding Agreement This Agreement shall bind the Employer and the Employer's successors and assigns, the Employee and his/her heirs, executors, administrators, and assigns, and any Policy beneficiary. D. Provision The Employer and the Employee agree that if any provision of this Agreement is determined to be invalid or unenforceable, in whole or part, then all remaining provisions of this Agreement and, to the extent valid or enforceable, the provision in question shall remain valid, binding and fully enforceable as if the invalid or unenforceable provisions, to the extent necessary, was not a part of this Agreement.
IN WITNESS WHEREOF, parties hereto have executed this Agreement, including the provisions regarding Collateral Assignment, on the day and year first above written.
Witness Employee
Address
Employer (Title)
Exhibit 10.6 AGREEMENT SECURED BENEFIT PLAN AND COLLATERAL ASSIGNMENT
THIS AGREEMENT is entered into this _____ day of __________, 1992 by and between Allegheny Power Service Corporation (hereinafter called the "Employer" in Part I or "Assignee" in Part II), and ___________________________ (hereinafter called the "Employee").
WHEREAS the Employee is currently a valued employee and Executive of Employer; WHEREAS the Employer wishes to assist the Employee with his (or her) personal future financial program and the Employee desires to accept such assistance; and
WHEREAS in consideration of the Employer agreeing to pay all of the premiums, the Employee agrees to grant the Employer security for the recovery of the Employer's premium outlay and the excess, if any, over the amounts due the Employee under Part I of this Agreement.
NOW, THEREFORE, for value received, the Employer and the Employee agree as follows:
Part I - Individual Life Insurance Agreement
A. Description of Policy - Policy Ownership
In furtherance of the purposes of the Agreement, the Employee will purchase and own a certain policy of life insurance on his own life, being Policy No. _____, issued by Pacific Mutual Life Insurance Co. Said policy is hereinafter called the "Policy" and said life insurance company is hereinafter called the "Insurer". The Employee's ownership of the Policy shall be subject to all the terms and conditions set forth in this Agreement.
B. Payment of Premiums The Employer shall pay the entire annual premium for the Policy directly to the Insurer.
C. Collateral Assignment and Possession of Policy To secure repayment of premiums paid by and amounts due to the Employer provided for in Section B, above, and Sections D and E, below, Part II of this Agreement includes an assignment of the policy or the Employee's interest therein (hereinafter called "Collateral Assignment") and provides for the transfer of possession of the policy, and the right to receive from the carrier and possess billings and policy statements, to the Employer during the term specified in Part II of this Agreement. Except as provided in or as otherwise consistent with the provisions of this Agreement, the Employer covenants that it will not exercise its rights under the Collateral Assignment provisions of this Agreement in such a manner as to defeat the rights of the Employee or the policy beneficiary under this Agreement. Specifically, the Employer covenants that it will not surrender the Policy unless Part I of the Agreement has terminated as provided in Section G and there has been a default in Employee's obligation under Section H of this Part I. The Employer shall have possession of the Policy during the period that the Employer makes premium payments and until all amounts due the Employer are repaid. The Employer shall make the Policy available to the Insurer in order to make any change desired by the Employee as to the designation of beneficiary or the selection of a settlement option, subject, however, to the provisions of this Agreement and the Collateral Assignment.
D. Beneficiary Designation and Payment of Policy Proceeds The Employee shall be entitled to a death benefit from the Policy in the amount required to provide an annuity equal to (under then current annuity settlement rates from the Insurer) the supplemental retirement benefit that would be provided under Sections 4A and 4B of the Allegheny Power System Supplemental Executive Retirement Plan effective July 1, 1990, attached hereto as Appendix I, excluding the provision in Section 4A that states, "...provided that, if a Participant is discharged from employment for cause or terminates employment with the Companies prior to retirement under the Allegheny Power System Retirement Plan for any reason whatsoever, other than death, such eligibility will terminate and no benefit shall be payable to such Participant from this Plan."
The Employer shall be the sole beneficiary of the policy until such time as the Employee has at least 10 years of service and is at least 55 years old. After that time and while this Agreement is in force, the following shall occur:
1. the beneficiary of the Employee's death benefit shall be the employee's spouse;
2. in the event of the Employee's death, the Employer shall be entitled to Policy proceeds equal to the total Policy proceeds in excess of the amount due to the Employee pursuant to this Section, above; and
3. if the employee is not married, he/she is entitled to no death benefit while this agreement is in force.
E. Policy Cash Values The Employee shall be entitled to cash values of the Policy in excess of the premiums paid by the Employer pursuant to Section B, Above, but not to exceed the death benefits to which he/she is entitled under Section D, above. If the Employee is not married, he/she shall be entitled to cash values determined as if he/she were married.
The Employer shall be entitled to Policy cash values in excess of the amount due to the Employee under this Section, above.
F. Procedure at Employee's Death Upon the death of the Employee while the Policy and this Agreement are in force and subject to the provisions of Parts I and II hereof, the Employer shall promptly take all necessary steps, including rendering of such assistance as may reasonably be required, to obtain payment from the Insurer of the amounts payable under the Policy to the respective parties, as provided under Section D, above.
G. Termination of Agreement Part I of this Agreement shall terminate when the first of any of the following events occur: 1. Termination of the Employee's employment with the Employer prior to retirement; 2. The later of the Employee's actual retirement or ten years from the date of issuance of the policy; 3. Performance of the Agreement's terms following the death of the Employee; 4. Failure by the Employer, for any reason, to make the premium contributions required under Section B of this Agreement.
H. Disposition of Policy Upon Termination of Agreement Upon the termination of Part I of this Agreement for any reason other than Section G3 above, the Employee shall have a thirty (30) day option to satisfy the Collateral Assignment regarding the policy held by the Employer in accordance with the terms of this Paragraph H. The amount necessary to satisfy such Collateral Assignment shall be an amount equal to the total premium payments made by the Employer, plus any excess amounts as determined in Section E, above, but no greater than the amount of cash value under the Policy and, at the option of the Employee, either shall be paid directly by the Employee or through the Employer's collection from the cash value of the Policy.
If the Policy shall then be encumbered by assignment, policy loan, or other means which have been the result of the Employer's actions, the Employer shall either remove such encumbrance, or reduce the amount necessary to satisfy the Collateral Assignment by the total amount of indebtedness outstanding against the Policy. If the Employee exercises his option to satisfy the Collateral Assignment, the Employer shall execute all necessary documents required by the Insurer to remove and satisfy the Collateral Assignment outstanding on the Policy. If the Employee does not exercise his option to satisfy the Collateral Assignment outstanding on the Policy, the Employee shall execute all documents necessary to transfer ownership of the Policy to the Employer. Such transfer shall constitute satisfaction of any obligation the Employee has to the Employer with respect to this Agreement. The Employer shall then pay to the Employee the amount, if any, by which the cash surrender value of the Policy exceeds the amount necessary to satisfy the Collateral Assignment.
I. Employee's Right to Assign His/Her Interest Employee agrees not to sell, assign, surrender or otherwise terminate the policy while this Agreement is in effect without the consent of the Employer.
J. Insurer's Obligations The Insurer is not a party to this Agreement. It is understood by the parties hereto that in issuing such Policy of insurance, the Insurer shall have no liability except as set forth in the Policy and except as set forth in any assignment of the Policy filed at it Home Office and in Section K of this Agreement. Except as set forth in Section K, the Insurer shall not be bound to inquire into, or take notice of, any of the covenants herein contained as to the Policy of insurance or as to application of proceeds of such policy. Upon the death of the Insured and payment of the proceeds in accordance with Section K of this Agreement, the Insurer shall be discharged of all liability.
K. Claims Procedure The following claims procedure shall apply to the Policy and the Secured Benefit Plan:
1. Filing of a claim for benefits. The Employee or the Beneficiary shall make a claim for the benefits provided under the policy in the manner provided in the Policy.
2. Claim denial. With respect to a claim for benefits under said Policy, the Insurer shall be the entity which reviews and makes decisions on claim denials according to the terms of the Policy.
3. Notification to claimant of decision. If a claim is wholly or partially denied, notice of the decision, meeting the requirements of Section K4, following, shall be furnished to the claimant within a reasonable period of time after a claim has been filed.
4. Content of notice. The insurer shall provide, to any claimant who is denied a claim for benefits, written notice setting forth in a manner calculated to be understood by the claimant, the following:
a. The specific reason or reasons for the denial; b. Specific reference to pertinent Policy provisions or provisions of this Agreement on which the denial is based; c. A description of any additional material or information necessary for the claimant to perfect the claim and an explanation of why such material or information is necessary; and d. An explanation of this Agreement's claim review procedure, as set forth in Sections K5 and K6.
5. Review procedure. The purpose of the review procedure set forth in this subsection and subsection 6, following, is to provide a method by which a claimant under the Policy may have a reasonable opportunity to appeal a denial of claim for a full and fair review. To accomplish that purpose, the claimant or his/her duly authorized representative: a. May request a review upon written application to the Insurer; b. May review the Policy; and c. May submit issues and comments in writing.
A claimant, (or his/her duly authorized representative), shall request a review by filing a written application of review at any time within sixty (60) days after receipt by the claimant of written notice of the denial of the claim.
6. Decision on review. A decision on review of a denial of a claim shall be made in the following matter: a. The decision on review shall be made by the Insurer which may, at its discretion, hold a hearing on the denied claim. The Insurer shall make its decision promptly, unless special circumstances (such as the need to hold a hearing) require an extension of time for processing, in which case a decision shall be rendered as soon as possible, but not later than one hundred twenty (120) days after receipt of the request for review. b. The decision on review shall be in writing and shall include specific reasons for the decision, written in a manner calculated to be understood by the claimant, and specific references to the pertinent Policy provision or provision of this Agreement on which the decision is based.
Notwithstanding any provision of the Agreement or the Policy, no Employee, assignee or beneficiary may commence any action in any court regarding the Policy prior to pursuing all rights of an Employee under this Section K. END OF PART I
Part II - Assignment of Life Insurance Policy as Collateral
A. For value received and in specific consideration of the premium payments made by the Employer as set forth in Section B of Part I hereof, the Employee hereby assigns, transfers and sets over to the Employer (herein this Part II called the "Assignee"), its successors and assigns, the Policy issued by the Insurer upon the life of Employee and all claims, options, privileges, rights, titles and interest therein and thereunder (except as provided in Paragraph C hereof), subject to all terms and conditions of the Policy and to all superior liens, if any, which the Insurer may have against the Policy. The Employee by this instrument agrees and the Assignee by the acceptance of this Assignment agrees to the conditions and provisions herein set forth.
B. It is expressly agreed that, without detracting from the generality of the foregoing, the following specific rights are included in this Agreement and Collateral Assignment and inure to the Assignee by virtue hereof:
1. The sole right to collect from the Insurer the net proceeds of the Policy in excess of the proceeds due the Employee under Part I, Section D, when it becomes a claim by death or maturity;
2. The sole right to surrender the Policy and receive the surrender value thereof at any time provided by the terms of the Policy and at such other times as the Insurer may allow;
3. The sole right to obtain one or more loans or advances on the policy, either from the Insurer or, at any time, from other persons, and to pledge or assign the Policy as security for such loans or advances;
4. The sole right to exercise all nonforfeiture rights permitted by the terms of the Policy or allowed by the Insurer and to receive all benefits and advantages derived therefrom;
5. The sole right to direct investment of cash values as provided under the insurance contract, and to make changes and transfers in such fund allocations.
C. It is expressly agreed that the following specific rights, so long as the Policy has not been surrendered, are reserved and excluded from this Collateral Assignment and do not pass by virtue hereof:
1. The right to designate and change the beneficiary;
2. The right to elect any optional mode of settlement permitted by the Policy or allowed by the Insurer;
provided, however, that the reservation of these rights shall in no way impair the right of the Assignee to surrender the Policy completely with all its incidents or impair any other right of the Assignee hereunder, and any designation or change of beneficiary or election of a mode of settlement shall be made subject to this Agreement and Collateral Assignment and to the rights of the Assignee hereunder.
D. This Collateral Assignment is made, and the Policy is to be held as collateral security for, any and all liabilities of the Employee to the Assignee arising under this Agreement (all of which liabilities secured or to become secured are herein called "Liabilities"). It is expressly agreed that all sums received by the Assignee hereunder either in the event of death of the Insured, the maturity or surrender of the Policy, the obtaining of a loan or advance on the Policy, or otherwise, shall first be applied to the payment of the liability for premiums paid by the Assignee on the Policy and other amounts due to Assignee under Part I of this Agreement.
E. The Assignee covenants and agrees with the Employee as follows:
1. That any balance of sums, if any, received hereunder from the Insurer remaining after payment of the existing Liabilities, matured or unmatured, shall be paid by the Assignee to the persons entitled thereto under the terms of the policy had this Collateral Assignment not be executed;
2. That the Assignee will not exercise either the right to surrender the Policy or the right to obtain policy loans from the Insurer, until there has been either default in any of the Liabilities pursuant to this Agreement or termination of part I of said Agreement as therein provided; and
3. That the Assignee will, upon request, forward without unreasonable delay to the Insurer the Policy for endorsement of any designation or change of beneficiary or any election of an optional mode of settlement.
F. The Employee declares that no proceedings in bankruptcy are pending against, him/her and that his/her property is not subject to any assignment for the benefit of creditors.
Part III - Provisions Applicable to Parts I and II
A. Amendments Amendments may be added to this Agreement by a written agreement signed by each of the parties and attached hereto.
B. Choice of Law This Agreement shall be subject to, and construed according to, the laws of the State of Maryland.
C. Binding Agreement This Agreement shall bind the Employer and the Employer's successors and assigns, the Employee and his/her heirs, executors, administrators, and assigns, and any Policy beneficiary.
D. Validity of Provisions The Employer and the Employee agree that if any provision of this Agreement is determined to be invalid or unenforceable, in whole or part, then all remaining provisions of the Agreement and, to the extent valid or enforceable, the provision in question shall remain valid, binding and fully enforceable as if the invalid or unenforceable provisions, to the extent necessary, was not a part of this Agreement.
IN WITNESS WHEREOF, parties hereto have executed this Agreement, including the provisions regarding Collateral Assignment, on the day and year first above written.
________________________ __________________________ Witness Employee ____________________________ _____________________________ Address Allegheny Power Service Corporation By: ____________________________ Richard J. Gagliardi Vice President
E-2 Monongahela Power Company Incorporation Documents by Reference
3.1 Charter of the Company, as amended Form S-3, 33-51301, exh. 4(a)
3.2 Code of Regulations, Form 10-Q of the Company as amended (1-268-2), September 1993, exh. (a)(3)
4 Indenture, dated as S 2-5819, exh. 7(f) of August 1, 1945, S 2-8782, exh. 7(f) (1) and certain S 2-8881, exh. 7(b) Supplemental S 2-9355, exh.4(h) (1) Indentures of the S 2-9979, exh. 4(h)(1) Company defining S 2-10548, exh. 4(b) rights of security S 2-14763, exh. 2(b) (i) holders.* S 2-24404, exh. 2(c); S 2-26806, exh. 4(d); Forms 8-K of the Company (1-268-2) dated August 8, 1989, November 21, 1991, June 4, 1992, July 15, 1992, September 1, 1992 and April 29, 1993
* There are omitted the Supplemental Indentures which do no more than subject property to the lien of the above Indentures since they are not considered constituent instruments defining the rights of the holders of the securities. The Company agrees to furnish the Commission on its request with copies of such Supplemental Indentures.
12 Computation of ratio of earnings to fixed charges
21 Subsidiaries: Monongahela Power Company has a 27% equity ownership in Allegheny Generating Company, incorporated in Virginia; and a 25% equity ownership in Allegheny Pittsburgh Coal Company, incorporated in Pennsylvania.
23 Consent of Independent Accountants See page 61 herein.
24 Powers of Attorney See pages 62-67 herein.
E-3
The Potomac Edison Company
Incorporation Documents by Reference
3.1 Charter of the Company, Form 10-Q of the Company as amended (1-3376-2), September 1993, exh. (a)3
3.2 By-laws of the Company, Form 10-Q of the Company as amended (1-3376-2), June 1990, exh. (a)3
4 Indenture, dated as of S 2-5473, exh. 7(b); Form October 1, 1944, and S-3, 33-51305, exh. 4(d) certain Supplemental Forms 8-K of the Company (1- Indentures of the 33-76-2) dated June 14, 1989, Company defining rights June 25, 1990, August 21, Company defining rights 1991, December 11, 1991, of security holders* December 15, 1992, February 17, 1993 and March 30, 1993
* There are omitted the Supplemental Indentures which do no more than subject property to the lien of the above Indentures since they are not considered constituent instruments defining the rights of the holders of the securities. The Company agrees to furnish the Commission on its request with copies of such Supplemental Indentures.
12 Computation of ratio of earnings to fixed charges
21 Subsidiaries: The Potomac Edison Company has a 28% equity ownership in Allegheny Generating Company, incorporated in Virginia and a 25% equity ownership in Allegheny Pittsburgh Coal Company, incorporated in Pennsylvania.
23 Consent of Independent See page 61 herein. Accountants
24 Powers of Attorney See pages 62-67 herein.
E-4
West Penn Power Company Incorporation Documents by Reference
3.1 Charter of the Company, Form S-3, 33-51303, exh. 4(a) as amended
3.2 By-laws of the Company, Form 8-K of the Company as amended (1-255-2), dated June 9, 1993, exh. (a)(3)
4 Indenture, dated as of S-3, 33-51303, exh. 4(d) March 1, 1916, and certain S 2-1835, exh. B(1), B(6) Supplemental Indentures of S 2-4099, exh. B(6), B(7) the Company defining rights S 2-4322, exh. B(5) of security holders.* S 2-5362, exh. B(2), B(5) S 2-7422, exh. 7(c), 7(i) S 2-7840, exh. 7(d), 7(k) S 2-8782, exh. 7(e) (1) S 2-9477, exh. 4(c), 4(d) S 2-10802, exh. 4(b), 4(c) S 2-13400, exh. 2(c), 2(d) Form 10-Q of the Company (1-255-2), June 1980, exh. D Forms 8-K of the Company (1-255-2) dated June 1989, February 1991, December 1991, August 13, 1993, September 15, 1992, June 9, 1993 and June
* There are omitted the Supplemental Indentures which do no more than subject property to the lien of the above Indentures since they are not considered constituent instruments defining the rights of the holders of the securities. The Company agrees to furnish the Commission on its request with copies of such Supplemental Indentures.
12 Computation of ratio of earnings to fixed charges
21 Subsidiaries: West Penn Power Company has a 45% equity ownership in Allegheny Generating Company, incorporated in Virginia; a 50% equity ownership in Allegheny Pittsburgh Coal Company, incorporated in Pennsylvania; and a 100% equity ownership in West Virginia Power and Transmission Company, incorporated in West Virginia, which owns a 100% equity ownership in West Penn West Virginia Water Power Company, incorporated in Pennsylvania.
23 Consent of Independent See page 61 herein. Accountants
24 Powers of Attorney See pages 62-67 herein.
E-5
Allegheny Generating Company
Documents
3.1(a) Charter of the Company, as amended*
3.1(b) Certificate of Amendment to Charter, effective July 14, 1989.**
3.2 By-laws of the Company, as amended*
4 Indenture, dated as of December 1, 1986, and Supplemental Indenture, dated as of December 15, 1988, of the Company defining rights of security holders.***
10.1 APS Power Agreement-Bath County Pumped Storage Project, as amended, dated as of August 14, 1981, among Monongahela Power Company, West Penn Power Company, and The Potomac Edison Company and Allegheny Generating Company.*
10.2 Operating Agreement, dated as of June 17, 1981, among Virginia Electric and Power Company, Allegheny Generating Company, Monongahela Power Company, West Penn Power Company and The Potomac Edison Company.*
10.3 Equity Agreement, dated June 17, 1981, between and among Allegheny Generating Company, Monongahela Power Company, West Penn Power Company and The Potomac Edison Company.*
10.4 United States of America Before The Federal Energy Regulatory Commission, Allegheny Generating Company, Docket No. ER84-504-000, Settlement Agreement effective October 1, 1985.*
12 Computation of ratio of earnings to fixed charges
23 Consent of Independent See page 61 herein. Accountants
24 Powers of Attorney See pages 62-67 herein.
* Incorporated by reference to the designated exhibit to AGC's registration statement on Form 10, File No. 0-14688.
** Incorporated by reference to Form 10-Q of the Company (0-14688) for June 1989, exh. (a).
*** Incorporated by reference to Forms 8-K of the Company (0-14688) for December 1986, exh. 4(A), and December 1988, exh. 4.1.