SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-K [X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended DECEMBER 31, 1996 Registrant; State of Incorporation; IRS Employer COMMISSION FILE NUMBER ADDRESS; AND TELEPHONE NUMBER IDENTIFICATION NO. 1-5532 PORTLAND GENERAL CORPORATION 93-0909442 (an Oregon Corporation) 121 SW Salmon Street Portland, Oregon 97204 (503) 464-8820 1-5532-99 PORTLAND GENERAL ELECTRIC COMPANY 93-0256820 (an Oregon Corporation) 121 SW Salmon Street Portland, Oregon 97204 (503) 464-8000 Securities registered pursuant to Section 12(b) of the Act: <TABLE> <CAPTION> Name of each exchange TITLE OF EACH CLASS ON WHICH REGISTERED <S> <C> Portland General Corporation Common Stock, $3.75 par value per share New York Stock Exchange Pacific Stock Exchange Portland General Electric Company 8.25% Quarterly Income Debt Securities (Junior Subordinated Deferrable Interest Debentures, Series A) New York Stock Exchange Securities registered pursuant to Section 12(g) of the Act: Portland General Corporation None Portland General Electric Company, 7.75% Series, Cumulative Preferred Stock, no par value </TABLE> 1
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [ X ] Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes X No ______. The aggregate market value of Portland General Corporation voting stock held by non-affiliates of the registrant as of February 28, 1997 (based on the last sales price on the New York Stock Exchange as of such date) was $2 billion. The number of shares outstanding of the registrants' common stocks as of February 28, 1997 was: Portland General Corporation 51,391,536 Portland General Electric Company 42,758,877 (owned by Portland General Corporation) DOCUMENT INCORPORATED BY REFERENCE The information required to be included in Part III hereof is incorporated by reference from Portland General Corporation's definitive proxy statement to be filed on or about May 27, 1997. 2
DEFINITIONS The following abbreviations or acronyms used in the text and notes are defined below: <TABLE> <CAPTION> Abbreviations OR ACRONYMS TERM <S> <C> Beaver..............................Beaver Combustion Turbine Plant Bethel..............................Bethel Combustion Turbine Plant Boardman............................Boardman Coal Plant Bonneville Pacific..................Bonneville Pacific Corporation BPA.................................Bonneville Power Administration Centralia...........................Centralia Coal Plant COB.................................California/Oregon Border Colstrip............................Colstrip Units 3 and 4 Coal Plant Coyote Springs......................Coyote Springs Generation Plant CUB.................................Citizen's Utility Board CWL.................................Columbia Willamette Leasing, Inc. DEQ.................................Oregon Department of Environmental Quality EFSC................................Oregon Energy Facility Siting Counsel Enron...............................Enron Corp EPA.................................Environmental Protection Agency FASB................................Financial Accounting Standards Board FERC................................Federal Energy Regulatory Commission Financial Statements................Refers to Financial Statements of Portland General included in Part II, Item 8 of this report. Holdings............................Portland General Holdings, Inc. Intertie............................Pacific Northwest Intertie Transmission Line IOUs................................Investor-Owned Utilities IRS.................................Internal Revenue Service kWh.................................Kilowatt-Hour MMBtu...............................Million British thermal units MW..................................Megawatt MWa.................................Average megawatts MWh.................................Megawatt-hour NRC.................................Nuclear Regulatory Commission NYMEX...............................New York Mercantile Exchange OPUC or the Commission..............Oregon Public Utility Commission Portland General or PGC.............Portland General Corporation PGE or the Company..................Portland General Electric Company PUD.................................Public Utility District Regional Power Act..................Pacific Northwest Electric Power Planning and Conservation Act SFAS................................Statement of Financial Accounting Standards issued by the FASB WPPSS or Supply System..............Washington Public Power Supply System Trojan..............................Trojan Nuclear Plant Tule................................Tule Hub Services Company USDOE...............................United States Department of Energy WAPA................................Western Area Power Authority WNP-3...............................Washington Public Power Supply System Unit 3 Nuclear Project WSCC................................Western Systems Coordinating Council </TABLE> 3
TABLE OF CONTENTS PAGE Definitions................................................................. 3 PART I Item 1. Business..................................................... 5 Portland General Corporation............................... 5 Portland General Electric Company.......................... 5 Portland General Holdings, Inc............................ 16 Item 2. Properties.................................................. 17 Item 3. Legal Proceedings........................................... 19 Item 4. Submission of Matters to a Vote of Security Holders..................................................... 20 Executive Officers of the Registrant........................ 21 PART II Item 5. Market for Registrant's Common Equity and Related Stockholder Matters................................. 22 Item 6. Selected Financial Data..................................... 23 Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations......................... 24 Item 8. Financial Statements and Supplementary Data................. 35 Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure......................... 55 PART III Item 10. Directors and Executive Officers of the Registrant.......... 55 Item 11. Executive Compensation...................................... 55 Item 12. Security Ownership of Certain Beneficial Owners and Management.............................................. 55 Item 13. Certain Relationships and Related Transactions............. 55 PART IV Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K......................................... 55 Signatures................................................................. 57 Exhibit Index.............................................................. 59 Appendix - PGE Financial Information....................................... 65 4
PART I ITEM 1. BUSINESS PORTLAND GENERAL CORPORATION - HOLDING COMPANY GENERAL Portland General Corporation (Portland General or PGC), an electric utility holding company, was organized in December 1985. Portland General Electric Company (PGE or the Company), an electric utility company and Portland General's principal operating subsidiary, accounts for substantially all of Portland General's assets, revenues and net income. Portland General is also the parent company of Portland General Holdings, Inc. (Holdings), which provides organizational separation for Portland General's nonutility businesses (see page 16). Portland General is exempt from regulation under the Public Utility Holding Company Act of 1935, except Section 9(a)(2) thereof relating to the acquisition of securities of other public utility companies. As of December 31, 1996, Portland General and its subsidiaries had 2,649 employees compared to 2,562 and 2,536 at December 31, 1995 and 1994, respectively. PROPOSED MERGER During 1996 Portland General entered into an Amended and Restated Agreement and Plan of Merger (Merger Agreement) with Enron Corp (Enron) and Enron Oregon Corp. (New Enron), a wholly-owned subsidiary of Enron. Under the terms of the Merger Agreement Portland General will merge into New Enron (Merger) and each share of the common stock of Portland General will be converted into one share of the common stock of New Enron. Immediately prior to the consummation of the Merger, Enron will merge into New Enron for the purpose of reincorporating Enron in Oregon (Reincorporation Merger). The Merger Agreement provides that if certain regulatory reforms are enacted, the structure of the transaction contemplated by the Merger Agreement will be revised to eliminate the Reincorporation Merger. The Merger has been approved by both companies' boards of directors, shareholders, and the FERC. However, before the Merger can be completed, approvals and consents must be obtained from the NRC and the OPUC (see Item 7., Management's Discussion and Analysis of Financial Condition and Results of Operations). PORTLAND GENERAL ELECTRIC COMPANY - ELECTRIC UTILITY GENERAL PGE, incorporated in 1930, is an electric utility engaged in the generation, purchase, transmission, distribution, and sale of electricity in the State of Oregon. PGE also sells energy to wholesale customers throughout the western United States. PGE's Oregon service area is 3,170 square miles, including 54 incorporated cities of which Portland and Salem are the largest, within a state-approved service area allocation of 4,070 square miles. PGE estimates that at the end of 1996 its service-area population was approximately 1.4 million, constituting approximately 44% of the state's population. At December 31, 1996 PGE served approximately 668,000 customers. As of December 31, 1996, PGE had 2,587 employees. This compares to 2,533 and 2,502 PGE employees at December 31, 1995 and 1994, respectively. 5
OPERATING REVENUES PGE serves a diverse retail customer base. Residential customers constitute the largest customer class and account for 40% of the retail demand and 44% of retail revenues. Residential demand is highly sensitive to the effects of weather. Commercial customers consume 39% and industrial customers 17% of retail revenues. Since 1994 commercial demand has grown by nearly 10%, making this the Company's most rapidly growing customer class. Despite a 20% increase in sales to high technology customers during 1996, industrial demand decreased nearly 3% in 1996 due to continued production cut backs by both paper manufacturers and metal fabricators. The commercial and industrial classes are not dominated by any single industry. While the 20 largest customers constitute 20% of retail demand, they represent 10 different industrial groups including paper manufacturing, high technology, metal fabrication, transportation equipment, and health services. No single customer represents more than 5% of PGE's retail load. Wholesale revenues continue to make a significant contribution to Company revenues providing over 17% of total operating revenues for 1996. PGE actively markets wholesale power throughout the western United States and has more than tripled its level of sales since 1994. A majority of PGE's wholesale sales were to its traditional customers comprised of IOUs, federal agencies, municipalities and PUDs. However, most of the Company's wholesale growth has come through sales to marketers and brokers, relatively new entrants to the increasingly competitive wholesale electric energy market. These sales are predominantly of a short-term nature. Sustained revenue growth will be more challenging in future periods. During 1996 PGE worked with the OPUC staff and other interested parties to develop a plan that addressed significant savings resulting from lower natural gas and purchased power prices. This resulted in a $55 million annual rate reduction effective December 1, 1996. Also, in a move to position for the future, PGE has launched several experimental programs that allow certain of its largest customers to acquire electricity at market based prices. These programs resulted in annual rate reductions of $15 million. As the electric utility industry moves toward deregulation retail customers will ultimately have the ability to purchase energy from any electric utility or power supplier. Consequently PGE will have to compete with other energy suppliers for customers within its traditionally exclusive service territory. Increased competition is expected to result in lower prices and less revenue per customer. While PGE's participation in the wholesale marketplace has resulted in significant increases in wholesale revenues, primarily from short-term transactions, these revenues are also vulnerable to industry changes. FERC mandated open access to transmission facilities, the advent of NYMEX electricity contracts, and the entrance of power marketers, brokers, and independent power producers has resulted in increased competition, reduced margins and increased risks associated with all transactions, especially the long-term ones. 6
PGE's operating revenues from customers peak during the winter season. The following table summarizes operating revenues and kWh sales for the years ended December 31: <TABLE> <CAPTION> 1996 1995 1994 <S> <C> <C> <C> Operating Revenues (thousands) Residential $ 426,777 $379,485 $360,651 Commercial 345,646 335,607 315,156 Industrial 149,289 153,347 147,347 Public Street Lighting 11,108 11,311 11,205 Tariff Revenues 932,820 879,750 834,359 Accrued (Collected) Revenues (27,142) (2,973) 10,644 Retail 905,678 876,777 845,003 Wholesale 193,726 94,967 105,911 Other 10,427 9,884 8,041 Total Operating Revenues $1,109,831 $981,628 $958,955 Kilowatt-Hours Sold (millions) Residential 7,073 6,622 6,704 Commercial 6,475 6,285 6,142 Industrial 3,909 4,056 3,863 Public Street Lighting 102 102 93 Retail 17,559 17,065 16,802 Wholesale 10,188 3,383 2,701 Total kWh Sold 27,747 20,448 19,503 </TABLE> For additional information on year-to-year revenue trends, see Item 7., Management's Discussion and Analysis of Financial Condition and Results of Operations. REGULATION The OPUC, a three-member commission appointed by the Governor, approves PGE's retail rates and establishes conditions of utility service. The OPUC ensures that prices are fair and equitable and provides PGE an opportunity to earn a fair return on its investment. In addition, the OPUC regulates the issuance of securities and prescribes the system of accounts to be kept by Oregon utilities. PGE is also subject to the jurisdiction of the FERC with regard to the transmission and sale of wholesale electric energy, licensing of hydroelectric projects and certain other matters. Construction of new generating facilities requires a permit from EFSC. The NRC regulates the licensing and decommissioning of nuclear power plants. In 1993 the NRC issued a possession-only license amendment to PGE's Trojan operating license and in early 1996 approved the Trojan Decommissioning Plan. Approval of the Trojan Decommissioning Plan by the NRC and EFSC has allowed PGE to commence decommissioning activities. Trojan will be subject to NRC regulation until Trojan is fully decommissioned, all nuclear fuel is removed from the site and the license is terminated. The Oregon Department of Energy also monitors Trojan. 7
OREGON REGULATORY MATTERS INDUSTRY RESTRUCTURING Historically the OPUC has approached the issues of retail competition on an informal, utility-by-utility basis, rather than through generic, broad-based proceedings. However, in June 1996 the OPUC began an investigation into restructuring the state's electric utility industry by meeting with state utility executives, customers, environmental advocates and other interested parties to discuss how competition in the generation of electric power could be introduced and when to allow customers access to competing power suppliers. Four specific issues were the focus of subsequent meetings: how an electricity distribution company would operate and be regulated; how energy efficiency and other public purpose programs will be offered and funded in a restructured environment; what treatment is appropriate for utility investment in a generating plant that is no longer economic; and whether vertical integration of electrical utilities should be discouraged or prohibited. The OPUC has stated its intent to use these discussions to prepare itself for action on the competitive initiatives that can be implemented under its direct authority and to work with the legislature in assessing proposals for restructuring. The staff of the OPUC has recommended that the commission open a proceeding to develop a policy for the treatment of transition costs for electric utilities. Transition or stranded costs are costs a utility would not recover in a fully competitive environment. The proposed issues to be discussed include: how should a utility's transition costs be determined; what portion of these costs should be recovered from customers; and what types of charges should be used for transition cost recovery. Discussions have begun on an informal basis to sort through issues and establish consensus before moving to a more formal process of written comments and a proposed order. MARGINAL COST In February 1997 the OPUC held a prehearing conference to establish a framework for investigating methods for estimating the marginal cost of service for electric utilities. Marginal costs are the cost of adding an additional customer to a utility system. This investigation was prompted by challenges from the CUB that current methods assign too much cost to the residential customer class. The OPUC anticipates adoption of an order in 1997. Specific marginal cost estimates and rate spread and rate decisions will be made in subsequent rate cases and other proceedings as needed. Retail Price v. Inflation graph comparing PGE retail price (cents per KWh) to Portland CPI: Retail Price CPI 1987 4.93 110.9 1988 4.77 114.7 1989 4.69 120.3 1990 4.57 127.4 1991 4.69 134 1992 4.79 139.9 1993 4.86 144.7 1994 4.97 148.9 1995 5.16 153.2 1996 5.31 158.6 1996 RATE SETTLEMENT During 1996 PGE worked with the OPUC staff and other interested parties to develop a plan for dealing with significant savings which resulted from lower natural gas and power purchase prices. This decision resulted in $55 million in annual rate reductions that began December 1, 1996. The rate reductions will result in an after tax earnings decrease of approximately $32 million for 1997. In addition, the order incorporated $15 million in rate reductions previously approved by the OPUC resulting in total 1997 rate reductions of $70 million. TROJAN INVESTMENT RECOVERY In April 1996 a circuit court judge in Marion County, Oregon found that the OPUC could not authorize PGE to collect a return on its undepreciated investment in Trojan contradicting a November 1994 ruling from the same court. The ruling was the result of an appeal of PGE's 1995 general rate order which granted PGE recovery of, and a return on, 87 percent of its remaining investment in Trojan. The November 1994 ruling, by a different judge of the same court, upheld the Commission's 1993 Declaratory Ruling (DR-10). In DR-10 the OPUC ruled that PGE could recover and earn a return on its undepreciated Trojan investment, provided certain conditions were met. The Commission relied on a 1992 Oregon Department of Justice opinion issued by the Attorney General's office 8
stating that the Commission had the authority to set prices including recovery of and return on investment in plant that is no longer in service. The 1994 ruling was appealed to the Oregon Court of Appeals and stayed pending the appeal of the Commission's March 1995 order. Both PGE and the OPUC have separately appealed the April 1996 ruling which was combined with the appeal of the November 1994 ruling at the Oregon Court of Appeals. For further information regarding the legal challenges to the OPUC's authority to grant recovery for PGE's Trojan investment see Item 3, Legal proceedings. LEAST COST ENERGY PLANNING In August 1996 the OPUC acknowledged PGE's 1995-1997 Integrated Resource Plan (IRP). The OPUC adopted Least Cost Energy Planning for all energy utilities in Oregon with the goal of selecting the mix of options that yields an adequate and reliable supply of energy at the least cost to the utilities and customers. The 1995-1997 IRP reflects: the recognition that the geographic area PGE presently serves no longer defines its customer base; the accelerated pace of technological change; transition of a key fuel, natural gas, to a market commodity; and the development of a vibrant electricity marketplace. The IRP outlines a strategy which emphasizes: (1) the purchase of energy in the marketplace at competitive prices, (2) acquisition of energy efficiency at reduced levels while maintaining market presence and capability for possible future increases when justified, (3) economical use of existing assets and (4) the use of other supply-side actions, including acquisition of renewable resources. RESIDENTIAL EXCHANGE PROGRAM The Regional Power Act (RPA), passed in 1980, attempted to resolve growing power supply and cost inequities between customers of government and publicly owned utilities, who have priority access to the low-cost power from the federal hydroelectric system, and the customers of IOUs. The RPA created the residential exchange program which exists to ensure that all residential and farm customers in the region, the vast majority of which are served by IOUs, receive similar benefits from the publicly funded federal power system. Exchange program benefits are passed directly to residential and farm customers. The exchange benefit for PGE residential and small farm customers totaled $58 million for calendar year 1996. In its 1996 rate case, the BPA initially proposed a $33 million annual reduction in the exchange benefit beginning October 1, 1996. However, recent congressional legislation partially restored the RPA exchange benefit so that the reduction was only $14 million for the BPA's 1997 fiscal year. The amount of future residential exchange benefits is among the subjects of current regional discussions regarding BPA's role in the region. PGE and the BPA have engaged in negotiations about the possibility of a BPA buy out and termination of the exchange program. DECOUPLING An experimental decoupling program adopted by the OPUC set monthly revenue targets associated with retail loads. To the extent weather-adjusted retail revenues exceeded or fell short of target revenues, PGE will refund or collect the difference from customers over an 18-month period. At the end of 1996 PGE's estimated liability to customers was $5 million. The program expired at the end of 1996. ENERGY EFFICIENCY PGE has promoted the efficient use of electricity for over two decades and has invested over $80 million in Demand Side Management (DSM) measures. Current DSM programs provide a range of services to all classes of PGE customers. These programs seek to capitalize on windows of opportunity in which DSM measures are most cost-effective, such as new residential and commercial construction, and the replacement and renovation markets. PGE continues to provide a weatherization program for eligible low-income families. PGE recognizes the value of and remains committed to encouraging the efficient use of energy. With the prospect of increased competition and customer choice, PGE is focusing its DSM programs more toward customer needs and wants. PGE is also focusing on developing a regional solution to funding and delivering energy efficiency in a competitive environment. 9
BONDABLE CONSERVATION INVESTMENT In late 1996, the OPUC designated $81 million of PGE's energy efficiency investment as Bondable Conservation Investment, pursuant to recent Oregon legislation, and authorized the issuance of conservation bonds collateralized by an OPUC assured future revenue stream. Subsequently, PGE issued a 10 year conservation bond which is expected to provide an estimated $21 million in present value savings to customers while granting PGE immediate recovery of its energy efficiency program expenditures. The OPUC assured future revenues collected from customers will pay the debt service obligations on the bond. COMPETITION AND MARKETING GENERAL Recent progress toward greater customer choice and direct access to customers by all competitors has been dramatic and underscores the theme of competition and prospective deregulation in the electric utility industry. The National Energy Policy Act of 1992 (Energy Act) granted the FERC authority to order wholesale wheeling between utilities. In 1996 the FERC issued Order 888 requiring non-discriminatory open access transmission by all public utilities that own interstate transmission. The Energy Act reserved the right to order true "retail wheeling" to the individual states. Retail wheeling is the movement of electric energy produced and sold by another entity over an electric utility's transmission and distribution system to a retail customer in the utility's service territory. Retail wheeling would permit retail customers to purchase electric capacity and energy from any electric utility or power supplier. In 1996 the OPUC began an investigation into restructuring the state's electric utility industry by meeting with state utility executives, customers, environmental advocates and other interested parties. The Governor of Oregon has issued objectives for restructuring and it is expected that several bills proposing retail competition will be introduced during the 1997 Oregon Legislative session. RETAIL COMPETITION AND MARKETING PGE operates within a state-approved service area and under current regulation is substantially free from direct retail competition with other electric utilities. PGE's competitors within its Oregon service territory include other fuel suppliers, such as the local natural gas company, which compete with PGE for the residential and commercial space and water heating market. In addition there is the potential of a loss of PGE service territory to the creation of public utility districts by voters. In the near term much of the Company's business is likely to remain regulated with progress toward increased retail competition taking place in stages. For example, basic residential electric service is likely to remain regulated with competition introduced slowly, while industrial service may see the rapid development of competition. Deregulation of other industries such as telecommunications has led to a host of new suppliers, products and services. The same is expected for the electric industry as more and more groups of customers will have increasing degrees of choice and alternative suppliers from whom to purchase. Increased competition presents both a threat and an opportunity. Portland General is preparing to meet varying levels of competition from traditional and non-traditional sources in the various retail markets within PGE's service territory as well as throughout the western United States. Much of Portland General's growth potential may no longer be limited by service territory boundaries or activities traditionally subject to regulation. Portland General has begun to look beyond traditional boundaries for opportunities to serve customers with energy related products and services allowable in the current regulated markets and the emerging unregulated markets. For example, Portland General, through a wholly-owned non-regulated subsidiary was recently selected to be the City of Palm Springs new energy services partner in a strategic alliance designed to help the city develop a municipal utility. PGE will continue to deliver quality electric service within the core markets that make up PGE's current service territory by focusing on traditional values like reliability, cost management, resource acquisition, effective energy efficiency services, safe operations and responsive customer- oriented service. In addition, Portland General, through PGE and new non- regulated subsidiaries, will continue to develop and provide an array of products and services to PGE's existing and prospective customers. This includes power quality-related services and lighting maintenance; power services, such as load following and system control; utility services, such as automated billing services and outage management; and retail services, such as power quality and time-of-day rates. 10
PGE has implemented several experimental tariff schedules during the past two years that have allowed certain of its larger customers to acquire electricity at market based prices. Eligible customers have the opportunity to purchase energy at prices that reflect actual market conditions. The tariffs are presently limited to a combined 250 MW of participating customer load or 12% of total PGE retail load. PGE is evaluating a power delivery service tariff which, if approved by the OPUC, will allow large industrial and commercial customers to purchase a portion of their electricity needs from any provider. In November 1996 Portland General and Enron committed to submit to the OPUC within 60 days of the Merger completion, a plan to open PGE's service area to competition. The plan will allow residential, commercial and industrial customers to choose their energy provider and will include a proposal to separate PGE generating facilities from its transmission and distribution system. In addition, this plan will include a proposal for the treatment of transition or stranded costs. This action will position the generating side of the organization to compete more effectively in an open marketplace, and will allow the distribution side to focus on customer service. WHOLESALE COMPETITION AND MARKETING During the last few years, the western United States has become a vibrant marketplace for the trading of electricity in which PGE has been an active participant. Wholesale sales continue to contribute to Company revenues. During 1996 PGE's wholesale revenues increased 104% over 1995 levels with wholesale activities accounting for 18% of total revenues and 37% of total sales. The advent of NYMEX electricity contracts and broker markets has increased price discovery. This, along with the entrance of numerous power marketers, brokers, and independent power producers has reduced margins significantly and increased risks. During 1996, the average price of PGE's wholesale sales decreased 33%. The FERC has taken steps to provide a framework for increased competition in the electric industry. In 1996 the FERC issued Order 888 requiring non- discriminatory open access transmission by all public utilities that own interstate transmission. The final rule requires utilities to file tariffs that offer others the same transmission services they provide themselves under comparable terms and conditions. This rule also allows public utilities to recover stranded costs in accordance with the terms, conditions and procedures set forth in Order 888. The ruling requires reciprocity from municipals, cooperatives and federal power marketers receiving service under the tariff. The new rules became effective July 1996 and are expected to result in increased competition, lower prices and more choices to wholesale energy customers. The Company's transmission system connects winter-peaking utilities in the Northwest and Canada, which have access to low-cost hydroelectric generation, with summer-peaking wholesale customers in California and the Southwest, which have higher-cost fossil fuel generation. PGE has used this system to purchase and sell in both markets depending upon the relative price and availability of power, water conditions, and seasonal demand from each market. Under its open access tariff the Company will lose any competitive advantage it may have had through the use of its transmission assets for wholesale transactions. Open access may provide new opportunities as the Company has equal access to the transmission capabilities of other utilities. PGE, along with a number of other public and private Northwest utilities and the BPA have signed a memorandum of understanding to create an independent transmission grid operator (IndeGo). Under the agreement, IndeGo would assume responsibility for day to day operation of main transmission lines which are directly owned by the various parties. The parties would maintain ownership of the lines, as well as responsibility for repair and upgrades. POWER SUPPLY Growth within PGE's service territory as well as its aggressive wholesale marketing plans have underscored the Company's need for sources of reliable, low-cost energy supplies. The demand for energy within PGE's service territory has experienced an average annual growth rate of approximately 2.5% over the last 10 years. Wholesale demand has experienced significant increases. In 1996 alone PGE's wholesale sales increased by over 200%. PGE has relied increasingly on short-term purchases to supplement its existing base of generating resource and long-term power contracts to meet its energy needs. Short-term purchases include spot market, or secondary, purchases as well as firm purchases for periods less than one year in duration. The availability of short-term firm purchase agreements and PGE's ability to renew these contracts on a month by month basis has enabled PGE to minimize risk and enhance its ability to provide reliable low cost energy to retail 11
customers. The emergence of NYMEX electricity futures contracts and open transmission are expected to place competitive pressures on the price of short-term power as well as enhance its availability. Northwest hydro conditions also have a significant impact on regional power supply. Plentiful water conditions can lead to surplus power and the economic displacement of more expensive thermal generation. GENERATING CAPABILITY PGE's existing hydroelectric, coal-fired and gas-fired plants are important resources for the Company, providing 2,119 MW of generating capability (see Item 2., Properties, for a full listing of PGE's generating facilities). PGE's lowest- cost producers are its eight hydroelectric projects on the Clackamas, Sandy, Deschutes, and Willamette rivers in Oregon. In 1996 generation from PGE's hydroelectric facilities met 9% of the Company's total load. These facilities, operate under federal licenses, which will be up for renewal between the years 2001 and 2006. PURCHASED POWER PGE has long-term power contracts with four hydro projects on the mid-Columbia River which provide PGE with 590 MW of firm capacity. PGE also has firm contracts, ranging in term from one to 30 years, to purchase 675 MW, primarily hydro-generated, from other Pacific Northwest utilities. In addition, PGE has long-term exchange contracts with summer-peaking Southwest utilities to help meet its winter-peaking requirements. These resources, along with short-term contracts, provide PGE with sufficient firm capacity to serve its peak loads. January reserve margin for WSCC region available capability less peak load (megawatts & percent) MEGAWATTS PERCENT 1992 34,689 35.2 1993 22,997 21.7 1994 31,033 31.0 1995 28,693 28.8 1996 31,125 29.3 1997 27,490 27.4 1998 29,671 28.1 1999 29,234 27.6 2000 28,500 26.3 2001 25,340 24.3 SYSTEM RELIABILITY AND THE WSCC PGE relies on wholesale market purchases within the WSCC in conjunction with its base of generating resources to supply its resource needs and maintain system reliability. The WSCC is geographically the largest of the nine regional electric reliability councils. The WSCC performs an essential role in developing and monitoring established reliability criteria guides and procedures to ensure continued reliability of the electric system. During the last few years, the area covered by WSCC has become a dynamic marketplace for the trading of electricity. This area, which includes 11 Western states, is very diverse in climates. Peak loads occur at different times of the year in the different regions within the WSCC area. Energy loads in the Southwest peak in summer due to air conditioning; northern loads peak during winter heating months. Further, according to WSCC forecasts, the nearly 80 electric organizations participating in the WSCC, which include utilities, independent power producers and transmission utilities, have sufficient generating capacity to cover loads 25% to 30% greater than anticipated peak loads for each month of the year beyond the year 2000, even assuming adverse water conditions. Favorable water conditions have the ability to further increase energy supplies. This generating capacity and the resultant wholesale power in the WSCC has made the traditional utility reserve margin less relevant. The need for an individual utility to maintain a reserve margin of 20% or higher in order to assure that it has the capacity to meet, without interruption, customer peak energy needs is no longer necessary. TRADING FLOOR OPERATIONS PGE's trading floor operation integrates the Company's wholesale trading, fuels, energy supply, power operations and price risk management functions. The trading floor activities seek to enhance PGE's low-cost supply of energy to meet retail and wholesale loads. 12
1996 Actual Power Sources pie chart: (megawatt hours) Combustion Turbines: 7% (1,864,000) PGE Hydro: 9% (2,702,000) Coal: 9% (2,657,000) Purchased Power: 75% (21,813,000) 1997 Forecasted Power Sources pie chart: (megawatt hours) PGE Hydro: 9% (3,048,000) Coal: 9% (3,390,000) Combustion Turbines: 7% (2,330,000) Purchased Power: 73% (23,889,000) YEAR IN REVIEW PGE generated 25% of its load requirements in 1996 compared with 36% in 1995. Firm and secondary purchases met the remaining load. Low gas prices, increased competition, and abundant hydro power resulting from above average precipitation in the Columbia River basin contributed to the availability of inexpensive power and the economic displacement of more expensive thermal generation. During 1996, PGE's peak load was 3,888 MW, of which 49% was met through economical short-term purchases. PGE's firm resource capacity, including short-term purchase agreements totaled approximately 4,759 MW as of December 31, 1996. 1997 OUTLOOK The early predictions of water conditions indicate they will be above normal in 1997 but not quite as favorable as those experienced in 1996. Efforts to restore salmon runs on the Columbia and Snake rivers may reduce hydro generation which would adversely affect the supply and price of purchased power. RESTORATION OF SALMON RUNS Several species of salmon found in the Snake River, a major tributary of the Columbia River, have been granted protection under the Federal Endangered Species Act (ESA). In an effort to help restore these fish, the federal government has reduced the amount of water allowed to flow through the turbines at the hydro electric dams on the Snake and Columbia River while the young salmon are migrating to the ocean. This has resulted in reduced amounts of electricity generated at the dams. Favorable hydro conditions helped mitigate the affect of these actions in 1996. Similar conditions are expected in 1997. If this practice is continued in future years it could mean less water available in the fall and winter for generation when demand for electricity in the Pacific Northwest is highest. Although PGE does not own any hydroelectric facilities on the Columbia and Snake rivers, it does buy large amounts of energy from the agencies which do. Several other species of salmon have been proposed for protection under the ESA. Actions taken to protect these species will not be in affect for several years. It is unclear how these potential ESA listings will impact future hydro operations. PGE's hydroelectric projects are located on rivers with depressed but not endangered salmon runs. PGE biologists are working with state and federal natural resource agencies to ensure PGE's hydro operations are compatible with the survival and enhancement of these populations of salmon. PGE does not expect that any actions will be taken that will have an adverse impact on PGE hydro operations in the foreseeable future. 13
FUEL SUPPLY PGE manages its fuel supply contracts as part of its trading floor operations. Fuel supply contracts are negotiated to support annual planned plant operations. Flexibility in contract terms is sought to allow for the most economic dispatch of PGE's thermal resources in conjunction with the current market price of wholesale power. COAL BOARDMAN PGE has an agreement to purchase coal for Boardman through the year 2000. The agreement does not require a minimum amount of coal to be purchased, allowing PGE to obtain coal from other sources. During 1996 PGE did not take deliveries under this contract but purchased coal under favorable short-term agreements. Coal purchases in 1996 contained less than 0.4% of sulfur by weight and emitted less than the EPA allowable limit of 1.2 pounds of sulfur dioxide per MMBtu when burned. The coal, from surface mining operations in Montana and Wyoming, was subject to federal, state and local regulations. Coal is delivered to Boardman by rail under a contract which expires in 2002. COLSTRIP Coal for Colstrip Units 3 and 4, located in southeastern Montana, is provided under contract with Western Energy Company, a wholly owned subsidiary of Montana Power Company. The contract provides that the coal delivered will not exceed a maximum sulfur content of 1.5% by weight. The Colstrip plant has sulfur dioxide removal equipment to allow operation in compliance with EPA's source-performance emission standards. CENTRALIA Coal for Centralia Units 1 and 2, located in Southwestern Washington, is provided under contract with PacifiCorp doing business as PacifiCorp Electric Operations. Most of Centralia's coal requirements are expected to be provided under this contract for the foreseeable future. <TABLE> <CAPTION> SULFUR TYPE OF POLLUTION PLANT CONTENT CONTROL EQUIPMENT <S> <C> <C> Boardman, OR 0.3% Electrostatic precipitators Centralia, WA 0.7% Electrostatic precipitators Colstrip, MT 0.7% Scrubbers and precipitators </TABLE> NATURAL GAS In addition to the agreements discussed below, the Company utilizes short-term and spot market purchases to secure transportation capacity and gas supplies sufficient to fuel plant operations. BEAVER PGE owns 90% of the Kelso-Beaver Pipeline which directly connects its Beaver generating station to Northwest Pipeline, an interstate gas pipeline operating between British Columbia and New Mexico. During 1996, PGE had access to 76,000 MMBtu/day of firm transportation capacity, enough to operate Beaver at a 70% load factor. COYOTE SPRINGS The Coyote Springs generating station utilizes 41,000 MMBtu/day of firm transportation on three interconnected pipeline systems accessing the gas fields in Alberta, Canada. Coyote Spring's two-year gas supply contracts expire in October 1997. Gas supplies and transportation capacity are sufficient to fully fuel Coyote Springs. Minimum purchase requirements represent 75% of the plant's capacity. 14
ENVIRONMENTAL MATTERS PGE operates in a state recognized for environmental leadership. PGE's environmental stewardship policy emphasizes minimizing waste in its operations, minimizing environmental risk and promoting energy efficiency. ENVIRONMENTAL REGULATION PGE's current and historical operations are subject to a wide range of environmental protection laws covering air and water quality, noise, waste disposal, and other environmental issues. PGE is also subject to the Federal Rivers and Harbors Act of 1899 and similar Oregon laws under which it must obtain permits from the U.S. Army Corps of Engineers or the Oregon Division of State Lands to construct facilities or perform activities in navigable waters of the State. The EPA regulates the proper use, transportation, cleanup and disposal of polychlorinated biphenyls (PCBs). State agencies or departments which have direct jurisdiction over environmental matters include the Environmental Quality Commission, the DEQ, the Oregon Department of Energy and EFSC. Environmental matters regulated by these agencies include the siting and operation of generating facilities and the accumulation, cleanup and disposal of toxic and hazardous wastes. ENVIRONMENTAL CLEANUP PGE is involved with others in the environmental clean-up of PCB contaminants at various sites as a potentially responsible party (PRP). The cleanup effort is considered complete at several sites which are awaiting consent orders from the appropriate regulatory agencies. These and future cleanup costs are not expected to be material. AIR/WATER QUALITY The Clean Air Act (Act) requires significant reductions in emissions of sulfur dioxide, nitrogen oxide and other contaminants over the next several years. Coal-fired plant operations will be affected by these emission limitations. State governments are also charged with monitoring and administering certain portions of the Act. Each state is required to set guidelines that at least equal the federal standards. Boardman was assigned sufficient emission allowances by the EPA to operate after the year 2000 at a 60% to 67% capacity factor without having to further reduce emissions. If needed PGE will purchase additional allowances to meet excess capacity needs. Centralia will be required to reduce emissions by the year 2000. The owner-operator utility has recommended the installation of scrubbers. It is not anticipated that Colstrip will be required to reduce emissions because it utilizes scrubbers. However, future legislation, if adopted, could affect plant operations and increase operating costs or reduce coal-fired capacity. Boardman's air contaminant discharge permit, issued by the DEQ, has no limitations on power production. This permit expires in the year 2001. The water pollution control facilities permit for Boardman expired in May 1991. The DEQ is processing the permit application and renewal is expected. In the interim, Boardman is permitted to continue operating under the terms of the original permit. DEQ air contaminant discharge permits for the combustion turbine generators at Bethel expired in 1995 and were replaced by new federal permits. Bethel was one of the first plants in the nation to successfully pass the more rigorous federal permitting process. DEQ still limits night operations of Bethel to one unit due to noise considerations. Maximum plant operations are allowed during the day. The combustion turbines are allowed to operate on either natural gas or oil. PGE is no longer accepting oil shipments by river for its Beaver plant in order to eliminate the risk of an oil spill into the Columbia River. Instead, the rail off-loading facility has been upgraded. This plant is normally fired by natural gas, and only small amounts of oil are used. 15
PORTLAND GENERAL HOLDINGS, INC. - NONUTILITY BUSINESSES GENERAL Holdings is a wholly owned subsidiary of Portland General and is the parent company of Portland General's subsidiaries engaged in leveraged leasing, administrative services for electric futures trading, telecommunications and non-regulated energy services. Holdings has provided organizational separation from PGE and financial flexibility and support for the operation of non-utility businesses. The assets and businesses of Holdings are primarily its investments in its subsidiaries. LEASING COLUMBIA WILLAMETTE LEASING (CWL) CWL acquires and leases capital equipment on a leveraged basis. During 1996, CWL made no new investments in leveraged leases. CWL's investment portfolio consists of six commercial aircraft, two container ships, approximately 5,500 containers, coal, tank, and hopper railroad cars, a truck assembly plant, an acid treatment facility, and a wood chipping facility, totaling $151 million of net investment. No new investments are expected or planned for the foreseeable future. 16
ITEM 2. PROPERTIES PORTLAND GENERAL CORPORATION Discussion regarding nonutility properties is included in the previous section. PORTLAND GENERAL ELECTRIC COMPANY PGE's principal plants and appurtenant generating facilities and storage reservoirs are situated on land owned by PGE in fee or land under the control of PGE pursuant to valid existing leases, federal or state licenses, easements, or other agreements. In some cases meters and transformers are located upon the premises of customers. The Indenture securing PGE's first mortgage bonds constitutes a direct first mortgage lien on substantially all utility property and franchises, other than expressly excepted property. The map below shows PGE's Oregon service territory and location of generating facilities: OREGON 17
Generating facilities owned by PGE are set forth in the following table: <TABLE> <CAPTION> PGE Net MW Capability FACILITY Location Fuel <S> <C> <C> <C> <C> WHOLLY OWNED: Faraday Clackamas River Hydro 44 North Fork Clackamas River Hydro 54 Oak Grove Clackamas River Hydro 44 River Mill Clackamas River Hydro 23 Pelton Deschutes River Hydro 108 Round Butte Deschutes River Hydro 300 Bull Run Sandy River Hydro 22 Sullivan Willamette River Hydro 16 Beaver Clatskanie, OR Gas/Oil 500 Bethel Salem, OR Gas/Oil 116 Coyote Springs Boardman, OR Gas/Oil 241 PGE JOINTLY OWNED: INTEREST Boardman Boardman, OR Coal 330 @ 65.0% Centralia Centralia, WA Coal 33 @ 2.5% Colstrip 3 & 4 Colstrip, MT Coal 288 @ 20.0% Trojan Rainier, OR Nuclear - @ 67.5% 2,119 </TABLE> PGE holds licenses under the Federal Power Act for its hydroelectric generating plants. Five licenses expire during the years 2001 to 2006. FERC requires that a notice of intent to relicense these projects be filed approximately five years prior to expiration of the license. PGE is actively pursuing the renewal of these licenses. The State of Oregon also has licensed all or portions of five hydro plants. For further information see the Hydro Relicensing discussion in Item 7., Management's Discussion and Analysis of Financial Condition and Results of Operations. Following the 1993 Trojan closure, PGE was granted a possession-only license amendment by the NRC. In early 1996 PGE received NRC approval of its Trojan decommissioning plan. See Note 12, Trojan Nuclear Plant, in the Notes to the Financial Statements for further information. LEASED PROPERTIES Combustion turbine generators at Bethel and Beaver are leased by PGE. These leases expire in 1999. PGE leases its headquarters complex in downtown Portland and the coal-handling facilities and certain railroad cars for Boardman. 18
ITEM 3. LEGAL PROCEEDINGS NONUTILITY PORTLAND GENERAL HOLDINGS, INC. V. DELOITTE & TOUCHE, ET AL, THIRD JUDICIAL DISTRICT COURT FOR SALT LAKE COUNTY On January 22, 1992, Holdings filed a complaint alleging Deloitte & Touche and certain individuals associated with Bonneville Pacific misrepresented the financial condition of Bonneville Pacific. The complaint alleges that Holdings relied on fraudulent statements and omissions by Deloitte & Touche and the individual defendants in acquiring a 46% interest in and making loans to Bonneville Pacific starting in September 1990. Holdings alleges, among other things, the existence of transactions in which generation projects developed or purchased by Bonneville Pacific were transferred at exaggerated valuations or artificially inflated prices to Bonneville Pacific's affiliated entities, Bonneville Pacific related parties or third parties. The suit claims that Bonneville Pacific's books, as audited by Deloitte & Touche, led Holdings to conclude wrongly that Bonneville Pacific's management was effective and could achieve the profitable sale of certain assets, as called for in Holdings' purchase agreement with Bonneville Pacific. Holdings is seeking approximately $228 million in damages. UTILITY SOUTHERN CALIFORNIA EDISON COMPANY V. PGE, U.S. DISTRICT COURT FOR THE DISTRICT OF OREGON The settlement by PGE and SCE of this case has been approved by the FERC and the California Public Utility Commission and needs no further approvals. The settlement terminates a long-term contract and releases all previous claims asserted in the legal dispute. SCE's annual payments under the settlement will be $15 million from 1997 through 1999 and $32 million from 2000 through 2002. UTILITY REFORM PROJECT V. OPUC, MULTNOMAH COUNTY CIRCUIT COURT On February 18, 1992 the Utility Reform Project (URP) filed a complaint in Multnomah County Oregon Circuit Court asking the OPUC to set aside and rescind OPUC Order No. 91-1781 which authorized PGE a temporary rate increase to recover a portion of the excess power costs incurred during the 1991 Trojan outage. URP and the OPUC agreed to stay the case pending OPUC hearings on the OPUC order. On February 22, 1992 the OPUC issued an order approving the rate increase. The case is currently under a stay. PGE has not intervened in this case. This case remains inactive. COLUMBIA STEEL CASTING CO., INC. V. PGE, PACIFICORP, AND MYRON KATZ, NANCY RYLES AND RONALD EACHUS, NINTH CIRCUIT COURT OF APPEALS On June 19, 1990 Columbia Steel filed a complaint for declaratory judgment, injunctive relief and damages in U.S. District Court for the District of Oregon contending that a 1972 territory allocation agreement between PGE and PacifiCorp, dba Pacific Power & Light Company (PP&L), which was subsequently approved by the OPUC and the City of Portland, does not give PGE the exclusive right to serve them nor does it allow PP&L to deny service to them. Columbia Steel is seeking an unspecified amount in damages amounting to three times the excess power costs paid over a 10 year period. 19
On July 3, 1991 the Court ruled that the Agreement did not allocate customers for the provision of exclusive services and that the 1972 order of the OPUC approving the Agreement did not order the allocation of territories and customers. Subsequently, on August 19, 1993 the Court ruled that Columbia Steel was entitled to receive from PGE approximately $1.4 million in damages which represented the additional costs incurred by Columbia Steel for electric service from July 1990 to July 1991, trebled, plus costs and attorney's fees. PGE appealed to the U.S. Court of Appeals for the Ninth Circuit which, on July 20, 1995, issued an opinion in favor of PGE, reversing the judgment and ordering judgment to be entered in favor of PGE. Columbia Steel filed a petition for reconsideration and on December 27, 1996 , the Ninth Circuit Court of Appeals reversed its earlier decision, ruling in favor of Columbia Steel. The case has been remanded to the US District Court for a new determination of damages for service rendered from early 1989 to July 1991. PGE has asked for reconsideration by the Ninth Circuit. CITIZEN'S UTILITY BOARD OF OREGON V. PUBLIC UTILITY COMMISSION OF OREGON AND UTILITY REFORM PROJECT AND COLLEEN O'NEIL V. PUBLIC UTILITY COMMISSION OF OREGON, MARION COUNTY OREGON CIRCUIT COURT The Citizen's Utility Board (CUB) appealed a 1994 ruling from the Marion County Circuit Court which upheld the order of the OPUC in its Declaratory Ruling proceeding (DR-10). In the DR-10 proceeding, PGE filed an Application with the OPUC requesting a Declaratory Ruling regarding recovery of the Trojan investment and decommissioning costs. On August 9, 1993 the OPUC issued the declaratory ruling. In its ruling, the OPUC agreed with an opinion issued by the Oregon Department of Justice (Attorney General) stating that under current law, the OPUC has Authority to allow recovery of and a return on Trojan investment and future decommissioning costs. In PGE's 1995 general rate case, the OPUC issued an order granting PGE full recovery of Trojan Decommissioning costs and 87% of its remaining investment in the plant. The URP filed an appeal of the OPUC's order. URP alleges that the OPUC lacks authority to allow PGE to recover Trojan costs through its rates. The complaint seeks to remand the case back to the OPUC and have all costs related to Trojan immediately removed from PGE's rates. The CUB also filed an appeal challenging the portion of the OPUC's order issued in PGE's 1995 general rate case that authorized PGE to recover a return on its remaining investment in Trojan. CUB alleges that the OPUC's decision is not based upon evidence received in the rate case, is not supported by substantial evidence in the record of the case, is based on an erroneous interpretation of law and is outside the scope of the OPUC's discretion, and otherwise violates constitutional or statutory provisions. CUB seeks to have the order modified, vacated, set aside or reversed. On April 4, 1996 a circuit court judge in Marion County, Oregon rendered a decision that contradicted a November 1994 ruling from the same court. The 1996 decision found that the OPUC could not authorize PGE to collect a return on its undepreciated investment in Trojan currently in PGE's rate base. Both the 1994 and 1996 circuit court decisions have been appealed to the Oregon Court of Appeals where they have been consolidated. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS At a special shareholder meeting on November 12, 1996 in Portland, Oregon the shareholders of Portland General's common stock voted to approve the transactions contemplated by the Merger Agreement between Portland General, Enron Corp, and Enron Oregon Corp. The results of voting were as follows: FOR AGAINST ABSTAIN 39,250,549 716,681 505,289 20
EXECUTIVE OFFICERS OF PORTLAND GENERAL CORPORATION AND PORTLAND GENERAL ELECTRIC (*) <TABLE> <CAPTION> NAME AGE BUSINESS EXPERIENCE <S> <C> <C> PGC/PGE Ken L. Harrison 54 Appointed to current position of Chairman of the Board, Chief Chairman of the Board and Chief Executive Officer Executive Officer on December 1, 1988 President and President of Portland General since August 4, 1992. Served as President of Portland General Electric from June 1987 until September 1989. Reappointed President of PGE on January 1, 1996. Alvin Alexanderson 49 Appointed to current position on Senior Vice President December 12, 1995. Served as Vice General Counsel and Secretary President, Rates and Regulatory Affairs from February 1991 until appointed to current position. Previously served as President of Portland General Exchange from May 1988 until February 1991. David K. Carboneau 50 Appointed to current position on Vice President January 28, 1997. Served as Vice Utility Service and President, Information Technology Telecommunications from January 1, 1996 until appointed to current position. Previously served as Vice President, Thermal and Power Operations from September 1995 to January 1996. Served as Vice President, Administration from October 1992 to September 1995. Served as Vice President, Information Resources from October 1989 to October 1992. For four years prior to October 1989, served as an executive officer of PGE. Joseph M. Hirko 40 Appointed to Senior Vice President on Senior Vice President September 12, 1995. Has served as Chief Financial Officer Vice President-Finance, Chief Financial Officer and Chief Accounting Officer since December 1991. Served as Treasurer beginning in June 1989. Served as Vice President, Portland General Financial Services, Inc. from November 1985 until June 1989. Donald F. Kielblock 55 Appointed to current position on October Vice President - PGC/PGE 4, 1989. Previously served as General Human Resources Manager, Information Services of PGE until appointed to current position. PGE Richard E. Dyer 54 Appointed to current position on Senior Vice President September 12, 1995. Previously served Power Supply as Vice President and General Manager of Power Resources and Marketing from August 1994 until appointed to current position. Served as Vice President, PGE Marketing and Supply from July 1991 to August 1994. Served as PGC Vice President and Assistant to the Chairman of the Board from October 1990 until July 1991. Peggy Y. Fowler 45 Appointed to current position on Executive Vice President November 5, 1996. Served as Senior Vice Chief Operating Officer President, Energy Services from September 1995 until appointed to current position. Served as Vice President, Distribution and Power Production from January 1990 to September 1995. Served as General Manager, Hydro Production and Transmission from September 1989 to January 1990. Pamela Lesh 40 Appointed to current position on Vice President November 5, 1996. Served as Director of Rates and Regulatory Affairs Marketing Strategy from May 1996 until appointed to current position. Served as Director of Rates and Regulatory Affairs from January 1992 to May 1996. Frederick D. Miller 55 Appointed to Senior Vice President on Senior Vice President November 5, 1996. Served as Director of Public Affairs and Corporate Executive Department, State of Oregon, Services from 1987 until appointed to Vice President, Public Affairs and Corporate Services on October 15, 1992. <FN> (*) Officers are listed as of January 31, 1997. The officers are elected to serve for a term of one year or until their successors are elected and qualified. </FN> </TABLE> 21
PART II ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS PORTLAND GENERAL CORPORATION Portland General's common stock is publicly held and traded on the New York and Pacific Stock Exchanges. The table below reflects the dividends on Portland General's common stock and the stock price ranges as reported by THE WALL STREET JOURNAL for 1996 and 1995. <TABLE> <CAPTION> 1996 1995 QUARTER 1ST 2ND 3RD 4TH 1ST 2ND 3RD 4TH <S> <C> <C> <C> <C> <C> <C> <C> <C> High 31-1/2 30-7/8 38-5/8 44-3/4 20-7/8 23-1/4 25-3/4 29-1/4 Low 28-1/2 27-3/4 28 37-5/8 18-7/8 20-1/4 21-5/8 25-1/4 Closing price 30-3/4 30-7/8 38-3/8 42 20-7/8 22-3/8 25-5/8 29-1/8 Cash dividends declared (cents) 32 32 32 32 30 30 30 30 </TABLE> The approximate number of shareholders of record as of December 31, l996 was 38,189. PORTLAND GENERAL ELECTRIC COMPANY PGE is a wholly owned subsidiary of Portland General. PGE's common stock is not publicly traded. Aggregate cash dividends declared on common stock were as follows (thousands of dollars): QUARTER 1996 1995 First $14,966 $11,545 Second 17,959 11,545 Third 56,014 13,682 Fourth 16,248 13,684 PGE is restricted, without prior OPUC approval, from making any dividend distributions to Portland General that would reduce PGE's common equity capital below 36% of total capitalization. 22
ITEM 6. SELECTED FINANCIAL DATA PORTLAND GENERAL CORPORATION <TABLE> <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 1993 1992 (thousands of dollars except per share amounts) <S> <C> <C> <C> <C> <C> Operating Revenues $1,111,816 $983,582 $959,409 $946,829 $883,266 Net Operating Income 224,559 195,576 154,296 158,181 163,500 Income from Continuing Operations 129,536{1} 81,036{2} 93,058 89,118 89,623 Gain from Discontinued Operations{3} - - 6,472 - - Net Income $129,536{1} $ 81,036{2} $ 99,530 $ 89,118 $ 89,623 Earnings per Average Common Share Continuing Operations $ 2.53 $ 1.60 $ 1.86 $ 1.88 $ 1.93 Discontinued Operations{3} - - .13 - - $ 2.53 $ 1.60 $ 1.99 $ 1.88 $ 1.93 Dividends Declared per Common Share $ 1.28 $ 1.20 $ 1.20 $ 1.20 $ 1.20 Total Assets $3,583,249 $3,448,017 $3,559,271 $3,449,328 $3,140,625 Long-Term Obligations{4} 963,042 930,556 885,814 912,994 937,938 </TABLE> PORTLAND GENERAL ELECTRIC COMPANY <TABLE> <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 1993 1992 (thousands of dollars) <S> <C> <C> <C> <C> <C> Operating Revenues $1,109,831 $981,628 $958,955 $944,531 $880,098 Net Operating Income 224,746 195,186 153,208 154,200 160,037 Net Income 155,915 92,787{2} 106,118 99,744 105,562 Total Assets $3,398,212 $3,245,597 $3,354,151 $3,226,674 $2,920,980 Long-Term Obligations{4} 963,042 930,556 855,814 872,994 887,938 <FN> NOTES TO THE TABLES ABOVE: 1 Includes $18 million charge for merger costs 2 Includes a loss of $50 million from regulatory disallowances. 3 Reflects the results of discontinued real estate operations. 4 Includes long-term debt, preferred stock subject to mandatory redemption requirements and long-term capital lease obligations. </FN> </TABLE> 23
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS RESULTS OF OPERATIONS GENERAL Portland General reported 1996 earnings of $130 million or $2.53 per share, compared to $81 million or $1.60 per share for 1995. 1996 results include $18 million of after-tax merger related costs. 1995 earnings include a $50 million after-tax charge to income related to the OPUC's rate orders disallowing certain deferred power costs and 13% of PGE's remaining investment in Trojan. Excluding the effect of merger related costs and regulatory disallowances, income from continuing operations would have been $148 million and $131 million, respectively. PGE ACCOUNTS FOR SUBSTANTIALLY ALL OF PORTLAND GENERAL'S ASSETS, REVENUES AND NET INCOME. THE FOLLOWING DISCUSSION FOCUSES ON PGE UTILITY OPERATIONS, UNLESS OTHERWISE NOTED. Operating Revenue and Net Income (Loss) graph: ($ Millions): Operating Net Revenue Income 1992 883 90 1993 947 89 1994 959 100 1995 984 81 1996 1112 130 PGE Electricity Sales graph: (Billions of kWh) 1992 Residential 6.3 Commercial 5.8 Industrial 3.6 Wholesale 2.7 1993 Residential 6.8 Commercial 6.0 Industrial 3.8 Wholesale 1.6 1994 Residential 6.7 Commercial 6.2 Industrial 3.9 Wholesale 2.7 1995 Residential 6.6 Commercial 6.4 Industrial 4.1 Wholesale 3.3 1996 Residential 7.1 Commercial 6.6 Industrial 3.9 Wholesale 10.2 1996 COMPARED TO 1995 Strong operating earnings reflected the benefits of low variable power costs due to optimal hydro conditions and a competitive wholesale market. Sales growth due to a growing retail customer base, along with favorable weather conditions contributed to new record peak loads for both the summer and winter periods. Retail revenues exceeded the prior year by $29 million, largely due to rate increases accompanied by 3% higher energy sales. These increases were partially offset by revenue refund provisions for SAVE adjustments and certain state tax benefits. Favorable weather conditions contributed to higher energy sales in both residential and commercial classes. In January and February mean temperatures were colder than average by 2.6 and 4.5 degrees respectively, and temperatures in August and September were warmer than average by 3.1 and 3.2 degrees respectively. Industrial loads declined 3.8% due to weak demand from paper manufacturers and metals fabricators despite benefiting from growth in the high-tech industries. During 1996, PGE revenues decreased $20 million due to adjustments related to SAVE refund provisions, decoupling revenues and certain state tax benefits. Wholesale revenues exceeded 1995 levels by $99 million due to aggressive marketing efforts. Sales increased by 6.8 million MWh over 1995, however, average sales prices decreased by 33%. The price of variable power dropped 18% in 1996, averaging 13 mills versus 15.9 mills (10 mills = 1 cent) last year. Total costs increased only $23 million or 8%, despite a 36% rise in total Company energy requirements. Optimal hydro conditions brought steep reductions in the cost of secondary power, as well as the cost of firm power purchased from the mid-Columbia projects. Power purchases amounted to 75% of total PGE load in 1996 at an average cost of 13.9 mills compared to 18.3 mills in 1995. 24
PGE hydro projects generated 9% of the Company's energy needs, an 11% increase in production levels. PGE's thermal plants operated efficiently, and with the addition of Coyote Springs, average overall costs dropped to 6.1 mills from 8.0 mills in 1995. Excluding Coyote Springs, thermal plants generation was down 13% due to economic displacement early in the year. <TABLE> <CAPTION> RESOURCE MIX/VARIABLE POWER COSTS Average Variable Resource Mix Power Cost (Mills/KWh) 1996 1995 1996 1995 <S> <C> <C> <C> <C> Generation 25% 36% 6.1 8.0 Firm Purchases 62% 39% 14.6 22.7 Secondary Purchases 13% 25% 10.4 11.3 Total 100% 100% 13.0 15.9 </TABLE> Operating expenses (excluding variable power, depreciation and income taxes) were $32 million or 12% higher than 1995. The increase is primarily due to additional costs associated with fixed natural gas transportation, storm related repair and maintenance projects and increased customer support. Incremental operating costs associated with Coyote Springs, which was placed in operation in late 1995, were offset by decreased costs at other thermal facilities resulting from economic displacement. Throughout the year PGE was able to economically dispatch or displace thermal generation in response to movements in the cost of short-term power and the availability of low-cost hydro power. Depreciation and amortization increased $20 million, or 15%, due primarily to depreciation related to Coyote Springs. Excluding regulatory disallowances of $50 million in 1995, other income declined $9 million due to a reduced return on regulatory assets and the absence of equity AFDC. Interest charges are $7 million above 1995 due to reduced AFDC and higher levels of short-term debt. Preferred dividend requirements were down $7 million due to the retirement of nearly $80 million in preferred stock in 1995. Operating Expenses graph: ($ Millions) 1992 Operating Costs 327 Variable Power 222 Depreciation 99 1993 Operating Costs 283 Variable Power 311 Depreciation 122 1994 Operating Costs 262 Variable Power 347 Depreciation 124 1995 Operating Costs 271 Variable Power 294 Depreciation 134 1996 Operating Costs 306 Variable Power 317 Depreciation 155 1995 COMPARED TO 1994 Strong operating earnings reflected the benefits of low variable power costs due to improved hydro conditions, lower natural gas prices and a competitive wholesale market. The Company also benefited from continued sales growth and a retail price increase. Retail revenues increased $32 million, or nearly 4%, due largely to the Company's general rate increase and continued load growth. An average 5% general rate increase effective in 1995, coupled with a 263,000 MWh increase in energy sales, resulted in $45 million of additional revenue. An increase in retail customers of 14,600 and a continuing strong local economy resulted in weather-adjusted load growth of 2.8%. Industrial customers contributed the major portion of load growth for the year due to the recent expansion of high- technology and supporting industries in the region. Weather-adjusted load for residential customers increased 1.2% over 1994. Over 12,900 residential customers were added during 1995. Retail revenue increases were partially offset by warmer than normal weather during winter heating months which decreased residential demand for energy, and a decrease in accrued revenues, a result of fewer power cost deferrals and SAVE incentive revenues. 25
Wholesale sales contributed $95 million or approximately 10% of total operating revenues. The Company's aggressive marketing efforts resulted in a 25% increase in sales; however, revenues declined $11 million as average prices decreased 28%. Variable power costs fell $54 million, or 15%, despite increased Company load as the average cost of power decreased from 19.1 to 15.9 mills (10 mills = 1 cent). Improved hydro conditions, mild weather, cheaper natural gas, and competition among suppliers all contributed to abundant and low-cost supplies of secondary energy in the region. Company hydro generation increased 20%, or 412,000 MWh, reflecting good water conditions on the Clackamas River system similar to those experienced throughout the West. Energy purchases were up 28% due to increased loads and economic displacement of thermal generation, while abundant supplies of energy drove secondary prices below 1994 levels. Secondary purchases averaged 11.3 mills, ranging from 1.8 to 28 mills, compared to an average 20.1 mills in 1994. Throughout the year PGE was able to economically dispatch or displace thermal generation in response to movements in the cost of short-term power. Low-cost hydro significantly displaced PGE thermal generation, which decreased 32% from 1994. Beaver generated electricity at 38% lower cost due to favorable gas prices. Operating expenses (excluding variable power costs, depreciation and income taxes) were $10 million, or 4%, higher primarily due to storm damages incurred in December 1995. A combination of wind and ice storms caused a record number of customer outages in PGE's service territory. Repair efforts to restore customers' service included around the clock efforts from PGE personnel and contract crews at a total cost exceeding $10 million, of which PGE is self- insured for the first $5 million. A March 1995 general rate order disallowed recovery of 13% of PGE's Trojan investment resulting in a $37 million after-tax charge to income. PGE also recorded a $13 million after-tax third quarter loss as a result of an OPUC order which disallowed recovery of a portion of the Company's deferred power costs. Depreciation increased $10 million, or 8%, largely due to higher depreciation rates effective with the Company's general rate increase. Income taxes increased $18 million primarily due to an increase in before- tax operating income. The Company benefited from a one-time state tax refund of approximately $4 million which contributed to a lower effective tax rate for the year. The construction of Coyote Springs accounted for the increases in capitalized interest during each year, which partially offset a corresponding increase in interest expense. Income also includes a $5 million charge for increased charitable donations. CASH FLOW Utility Capital Expenditures graph: ($ Millions) 1992 159 1993 149 1994 243 1995 232 1996 185 PORTLAND GENERAL CORPORATION Portland General requires cash to pay dividends to its common shareholders, to provide funds to its subsidiaries, to meet debt service obligations and for day-to-day operations. Sources of cash are dividends from PGE, leasing rentals, short- and intermediate-term borrowings, and the sale of Portland General's common stock. In order to meet periodic liquidity and operational needs, Portland General maintains a $20 million one-year credit facility. In February 1996 the Board of Directors approved an increase in PGC's quarterly dividend from $.30 to $.32 per share. This was the first change in Portland General's dividend since 1990. Portland General received $103 million in dividends from PGE. In addition, Portland General received $3 million in proceeds from the issuance of new shares of common stock under its Dividend Reinvestment and Optional Cash Payment Plan (DRIP). 26
PORTLAND GENERAL ELECTRIC COMPANY CASH PROVIDED BY OPERATIONS is used to meet the day-to-day cash requirements of PGE. Supplemental cash is obtained from external borrowings as needed. PGE maintains varying levels of short-term debt, primarily in the form of commercial paper, which serve as the primary form of daily liquidity with 1996 balances ranging from $83 million to $251 million. PGE has committed borrowing facilities totaling $200 million which are used as backup for PGE's commercial paper facility. A significant portion of cash provided by operations comes from depreciation and amortization of utility plant, charges which are recovered in customer revenues but require no current cash outlay. Changes in accounts receivable and accounts payable can also be significant contributors or users of cash. Improved cash flow for 1996 reflects a higher percentage of cash revenues combined with lower variable power costs. INVESTING ACTIVITIES include generation, transmission and distribution facilities improvements, as well as energy efficiency programs. 1996 capital expenditures of $185 million were primarily for the expansion and upgrade of the transmission and distribution system. Annual capital expenditures are expected to be approximately $170 million over the next few years. The majority of anticipated capital expenditures are for improvements to the Company's expanding distribution system to support the addition of new customers. The Company does not anticipate construction of new generating resources in the foreseeable future. The Company will continue to make energy efficiency expenditures similar to 1996 levels. FINANCING ACTIVITIES provide supplemental cash for day-to-day operations and capital requirements as needed. During 1996 both Standard & Poor's Investor Services (S&P) and Moody's Investor Services (Moody's) reviewed and upgraded PGE's debt ratings. S&P upgraded PGE's senior secured debt from A- to A, its unsecured debt from BBB+ to A-, and commercial paper from A2 to A1 with a Stable Outlook. Similarly Moody's upgraded the Company's debt ratings, raising PGE's secured debt from A3 to A2, unsecured debt from Baa1 to A3 and commercial paper from P2 to P1. The improved ratings, especially on short-term debt, should help lower the Company's future borrowing costs. During 1997 internal funding is expected to cover the Company's capital expenditures. During 1996 the Company issued $170.6 million of long-term debt. The proceeds were used to retire $97.6 million in long-term debt and to pay down outstanding short-term debt. Also in 1996 PGE redeemed the final 200,000 outstanding shares of its 8.10% preferred stock, at par. The $20 million redemption leaves only the Company's 7.75% preferred stock outstanding which has sinking fund requirements beginning in 2002. The issuance of additional First Mortage Bonds and preferred stock requires PGE to meet earnings coverage and security provisions set forth in the Articles of Incorporation and the Indenture securing its First Mortgage Bonds. As of December 31, 1996, PGE had the capability to issue additional First Mortgage Bonds and preferred stock in amounts sufficient to meet its capital requirements. 27
FINANCIAL AND OPERATING OUTLOOK PORTLAND GENERAL CORPORATION - HOLDING COMPANY PROPOSED MERGER GENERAL During 1996 Portland General entered into an Amended and Restated Agreement and Plan of Merger (Merger Agreement) with Enron Corp (Enron) and Enron Oregon Corp. (New Enron), a wholly-owned subsidiary of Enron. Under the terms of the Merger Agreement Portland General will merge into New Enron (Merger) and each share of the common stock of Portland General will be converted into one share of the common stock of New Enron. Immediately prior to the consummation of the Merger, Enron will merge into New Enron for the purpose of reincorporating Enron in Oregon (Reincorporation Merger). The Merger Agreement provides that if certain regulatory reforms are enacted, the structure of the transaction contemplated by the Merger Agreement will be revised to eliminate the Reincorporation Merger. The Merger has been approved by both companies' boards of directors, shareholders, and the FERC. However, before the Merger can be completed, approvals and consents must be obtained from the NRC and the OPUC. APPROVALS AND CONSENTS OPUC - PGE is subject to the jurisdiction of the OPUC with respect to its electric utility operations. The approval of the OPUC is required for any transaction in which a person seeks to acquire the power to exercise any substantial influence over the policies and actions of a public utility subject to the OPUC's jurisdiction. Upon completion of the Merger, Enron will be the sole owner of PGE common stock. On August 30, 1996, Enron filed an application with the OPUC seeking approval of the Merger. The OPUC must approve the merger if they find that it will serve the customers of PGE in the public interest. In making that finding the OPUC may consider whether the change in ownership of PGE will impair the ability of the utility to provide adequate service at just and reasonable rates. The Staff of the OPUC issued a preliminary recommendation that the OPUC approve the merger application, subject to certain conditions. Portland General and Enron have entered into discussions with the Staff which are intended to settle differences over the proposed conditions. There is no assurance that the parties will reach agreement. An OPUC decision on the merger application was expected by the end of March 1997. However, there is no assurance that the OPUC will have rendered a decision by that time. FERC - The FERC approved the Merger, without conditions, on February 26, 1997. OTHER - Consent and approval of the Merger is still pending before the NRC. OPERATIONS AFTER THE BUSINESS COMBINATION When the merger is complete, Portland General will cease to exist. PGE, Portland General's utility subsidiary will retain its name, most of its functions and maintain its principal corporate offices in Portland, Oregon. It will be a subsidiary of Enron, an integrated natural gas company headquartered in Houston, Texas. Essentially all of Enron's operations are conducted through its subsidiaries and affiliates which are principally engaged in the gathering, transportation and wholesale marketing of natural gas; the exploration and production of natural gas and crude oil; the production, purchase, transportation and marketing of natural gas liquids and refined petroleum products; the independent development, promotion, construction and operation of power plants, natural gas liquids facilities and pipelines; and the non-price regulated purchasing and marketing of energy related commitments. ACCOUNTING TREATMENT The Merger will be accounted for by Enron as a purchase for financial reporting purposes. PGE will continue to report its assets and liabilities at historical cost. 28
PORTLAND GENERAL ELECTRIC COMPANY - ELECTRIC UTILITY COMPETITION The Energy Policy Act of 1992 (Energy Act) set the stage for change in federal and state regulations aimed at increasing both wholesale and retail competition in the electric industry. The Energy Act eased restrictions on independent power production and granted authority to the FERC to mandate open access for the wholesale transmission of electricity. The FERC has taken steps to provide a framework for increased competition in the electric industry. In 1996 the FERC issued Order 888 requiring non- discriminatory open access transmission by all public utilities that own interstate transmission. The final rule requires utilities to file tariffs that offer others the same transmission services they provide themselves under comparable terms and conditions. This rule also allows public utilities to recover stranded costs in accordance with the terms, conditions and procedures set forth in Order 888. The ruling requires reciprocity from municipals, cooperatives and federal power marketers receiving service under the tariff. The new rules became effective July 1996 and are expected to result in increased competition, lower prices and more choices to wholesale energy customers. In February 1997 PGE signed a long-term transmission agreement with Washington Water Power (WWP) under these new rules. WWP will receive 100 MW of firm transmission capacity through the end of 1997 and a total 200 MW of firm transmission capacity from January 1998 through the end of the year 2001. PGE, along with a number of other public and private Northwest utilities and the BPA have signed a memorandum of understanding to create an independent transmission grid operator (IndeGo). Under the agreement, IndeGo would assume responsibility for day to day operation of main transmission lines which are directly owned by the various parties. The parties would maintain ownership of the lines, as well as responsibility for repair and upgrades. FERC actions apply only to the wholesale transmission of electricity. Terms and conditions of retail transmission service are subject to individual state regulation. Since the passage of the Energy Act, various state utility commissions have addressed proposals which would allow retail customers direct access to generation suppliers, marketers, brokers and other service providers in a competitive marketplace for energy services (retail wheeling). It is expected that several bills proposing retail competition will be introduced during the 1997 Oregon legislative session. PGE has initiated several experimental tariff schedules during the past two years that have allowed certain of its larger customers to acquire electricity at market based prices. Eligible customers have the opportunity to purchase energy at prices that reflect actual market conditions. The tariffs are limited to a total of 250 MW or 12% of total PGE retail load. PGE has filed a tariff which, upon approval by the OPUC, will allow large industrial and commercial customers to purchase as much as one-third of their electricity needs from any provider. This Power Delivery Service Tariff initially will be available for up to 75 megawatts of load per year. If the OPUC approves the merger of Portland General and Enron, affected customers will be allowed to purchase 100 percent of their electricity through the tariff, up to 225 megawatts per year. Absent OPUC approval of the merger, PGE will phase in the tariff over a longer period of time. In November 1996 Portland General and Enron committed to submit to the OPUC within 60 days of the merger completion a plan to open PGE's service area to competition. The plan will allow residential, commercial and industrial customers to choose their energy provider and will include a proposal to separate PGE generating facilities from its transmission and distribution system. In addition, the plan will include a proposal for the treatment of transition or stranded costs. The action will position the generating side of the organization to compete more effectively in an open marketplace, and will allow the distribution side to focus on quality of service, safety and reliability. 29
REGULATORY MATTERS Industry Restructuring - Historically the OPUC has approached the issues of retail competition on an informal, utility-by-utility basis, rather than through generic, broad-based proceedings. However, in June 1996 the OPUC began an investigation into restructuring the state's electric utility industry by meeting with state utility executives, customers, environmental advocates and other interested parties to discuss how competition in the generation of electric power could be introduced and when to allow customers access to competing power suppliers. Four specific issues were the focus of subsequent meetings: how an electricity distribution company would operate and be regulated; how energy efficiency and other public purpose programs will be offered and funded in a restructured environment; what treatment is appropriate for utility investment in a generating plant that is no longer economic; and whether vertical integration of electrical utilities should be discouraged or prohibited. The OPUC has stated its intent to use these discussions to prepare for action on the competitive initiatives that can be implemented under its direct authority and to work with the legislature in assessing proposals for restructuring. It remains to be determined what effect future competitive factors may have on retail rates in Oregon and the Company's ability to fully recover remaining regulation assets. 1996 RATE SETTLEMENT - During 1996 PGE worked with the OPUC staff and other interested parties to develop a plan for dealing with significant savings which resulted from lower natural gas and power purchase prices. This resulted in $55 million in annual rate reductions that began December 1, 1996. The rate reductions will result in an after tax earnings decrease of approximately $32 million for 1997. In addition, the order incorporated $15 million in rate reductions previously approved by the OPUC resulting in total 1997 rate reductions of $70 million. BONDABLE CONSERVATION INVESTMENT - In late 1996, the OPUC designated $81 million of PGE's energy efficiency investment as Bondable Conservation Investment, pursuant to recent Oregon legislation, and authorized issuance of conservation bonds collateralized by an OPUC assured future revenue stream. Subsequently, PGE issued a 10 year conservation bond which is expected to provide an estimated $21 million in present value savings to customers while granting PGE immediate recovery of its energy efficiency program expenditures. The OPUC assured future revenues collected from customers will pay debt service obligations. TROJAN INVESTMENT RECOVERY - In April 1996 a circuit court judge in Marion County, Oregon found that the OPUC could not authorize PGE to collect a return on its undepreciated investment in Trojan contradicting a November 1994 ruling from the same court. The ruling was the result of an appeal of PGE's 1995 general rate order which granted PGE recovery of, and a return on, 87 percent of its remaining investment in Trojan. The November 1994 ruling, by a different judge of the same court, upheld the Commission's 1993 Declaratory Ruling (DR-10). In DR-10 the OPUC ruled that PGE could recover and earn a return on its undepreciated Trojan investment, provided certain conditions were met. The Commission relied on a 1992 Oregon Department of Justice opinion issued by the Attorney General's office stating that the Commission had the authority to set prices including recovery of and on investment in plant that is no longer in service. The 1994 ruling was appealed to the Oregon Court of Appeals and stayed pending the appeal of the Commission's March 1995 order. Both PGE and the OPUC have separately appealed the April 1996 ruling which was combined with the appeal of the November 1994 ruling at the Oregon Court of Appeals. For further information regarding the legal challenges to the OPUC's authority to grant recovery for PGE's Trojan investment see Item 3., Legal proceedings. LEAST COST ENERGY PLANNING - In August 1996 the OPUC acknowledged PGE's 1995- 1997 Integrated Resource Plan (IRP). The OPUC adopted Least Cost Energy Planning for all energy utilities in Oregon with the goal of selecting the mix of options that yields an adequate and reliable supply of energy at the least cost to the utilities and customers. The 1995-1997 IRP reflects: the recognition that the geographic area PGE presently serves no longer defines our customer base; the accelerated pace of technological change; transition of a key fuel, natural gas, to a market commodity; and the development of a vibrant electricity marketplace. 30
The IRP outlines a strategy which emphasizes: (1) the purchase of energy in the marketplace at competitive prices, (2) acquisition of energy efficiency at reduced levels while maintaining market presence and capability for possible future increases when justified, (3) economical use of our existing assets and (4) the use of other supply-side actions, including acquisition of renewable resources. RETAIL CUSTOMER GROWTH AND ENERGY SALES Weather adjusted retail energy sales grew less than 1 percent during 1996, reflecting cutbacks by paper manufacturers and metal fabricators. Nevertheless, the Company benefited from continued growth in residential sales of 1.8% with the addition of nearly 15,500 new customers as well as increased commercial sales which rose 3%. Industrial sales, although negatively affected in 1996 by weak demand from the paper manufacturers and metals fabricators, continues to benefit from growth in the high-tech and transportation sectors. Rising demand from the high-tech industry in Oregon combined with continued gains in residential and commercial customer classes is expected to contribute to 6.7% load growth for 1997. WHOLESALE SALES The surplus of electric generating capability in the Western U.S., the entrance of numerous wholesale marketers and brokers into the market, and open access transmission is contributing to increasing pressure on the price of power. In addition the development of financial markets and NYMEX electricity contract trading has led to increased price discovery available to market participants, further adding to the competitive pressure on wholesale margins. During 1996 PGE's wholesale revenues increased 104% over 1995 levels with wholesale activity accounting for 18% of total revenues and 37% of total sales. In future years PGE will continue its participation in the wholesale marketplace to balance its supply of power to meet the needs of its retail customers, manage risk and to administer PGE's current long-term wholesale contracts. Due to increasing volatility and reduced margins resulting from increased competition, long-term wholesale marketing activites will be performed by PGE's non-regulated affiliates. COMMODITY PRICE RISK MANAGEMENT The Company is exposed to market risk arising from the need to purchase fuel for its generating units (both natural gas and coal) as well as the direct purchase and sale of wholesale electricity in support of its retail and wholesale markets. PGE operates without a power cost adjustment tariff, and therefore adjustments for power costs above or below those used in existing general tariffs are not automatically reflected in retail customers' rates. Through the formation of the trading floor, PGE integrated its wholesale trading, fuels, energy supply, power operations and price risk management functions. The Company must purchase energy to serve its wholesale markets. This along with the development of a broader, more competitive wholesale electricity market, means the Company must actively hedge its market price risk. The Company uses financial instruments, such as commodity futures, options, forwards and swaps, to hedge the price of natural gas and electricity and reduce its exposure to fluctuations in these commodities. In addition to hedging activities, financial instruments are used for trading purposes. PGE trades instruments on the New York Mercantile Exchange as well as in the over the counter market. Consequently the Company is exposed to credit risk in the event of non-performance by the counterparties and has established guidelines to mitigate that risk. POWER & FUEL SUPPLY PGE's base of hydro and thermal generating capacity provides the Company with the flexibility needed to respond to seasonal fluctuations in the demand for electricity both within its service territory and from its wholesale customers. PGE plans to generate 27% of its energy requirements during 1997, approximately the same level achieved during 1996. PGE maintains flexibility in fuel supply contracts to allow for the economic dispatch of PGE's thermal resources in conjunction with hydro operations and the current market price of wholesale power. The Company benefits from a strategic location which places it adjacent to two competing natural gas pipelines with access to three significant producing basins. Firm transportation on both pipelines provides an adequate supply of natural gas to meet plant generating capacities. In addition, the Company maintains a flexible portfolio of physical supply which relies heavily on short-term agreements and spot-market purchases of fuel to meet plant operations. 31
During 1996 the Company relied on wholesale purchases to supply approximately 75% of its energy needs, and expects to purchase approximately 73% of its 1997 load requirements. PGE has long-term power contracts with four hydro projects on the mid-Columbia River which provide PGE with 590 MW. Early forecasts indicate above average water conditions for 1997. However, efforts to restore salmon runs on the Columbia and Snake Rivers may reduce the amount of water available for generation which could affect the supply, availability and price of purchased power. Additional factors that could affect the availability and price of purchased power include weather conditions in the Northwest during winter months and in the Southwest during summer months, as well as the performance of major generating facilities in both regions. PGE has increasingly relied upon short-term purchases to meet its energy needs. The Company anticipates that an active wholesale market and a surplus of generating capacity within the WSCC should provide sufficient wholesale energy available at competitive prices to supplement Company generation and purchases under existing firm power contracts. RESTORATION OF SALMON RUNS - Several species of salmon found in the Snake River, a major tributary of the Columbia River, have been granted protection under the Federal Endangered Species Act (ESA). In an effort to help restore these fish, the federal government has reduced the amount of water allowed to flow through the turbines at the hydro electric dams on the Snake and Columbia River while the young salmon are migrating to the ocean. This has resulted in reduced amounts of electricity generated at the dams. Favorable hydro conditions helped mitigate the affect of these actions in 1996. Similar conditions are expected in 1997. If this practice is continued in future years it could mean less water available in the fall and winter for generation when demand for electricity in the Pacific Northwest is highest. Although PGE does not own any hydroelectric facilities on the Columbia and Snake rivers, it does buy large amounts of energy from the agencies which do. Several other species of salmon have been proposed for protection under the ESA. Actions taken to protect these species will not be in affect for several years. It is unclear how these potential ESA listings will impact future hydro operations. PGE's hydroelectric projects are located on rivers with depressed but not endangered salmon runs. PGE biologists are working with state and federal natural resource agencies to ensure PGE's hydro operations are compatible with the survival and enhancement of these populations of salmon. PGE does not expect that any actions will be taken that will have an adverse impact on PGE hydro operations in the foreseeable future. HYDRO RELICENSING PGE HYDRO - PGE's hydroelectric plants are some of the Company's most valuable resources supplying economical generation and flexible load following capabilities. Company-owned hydro generation produced 2.7 million MWh of renewable energy in 1996, meeting 9% of PGE's load. PGE's hydroelectric plants, operate under federal licenses, which will be up for renewal between the years 2001 and 2006. PGE officially began the relicensing process for its 408-MW Pelton Round Butte Project in July 1996. The Confederated Tribes of Warm Springs, currently the licensee for a powerhouse located at the reregulating dam (one of three dams within the Pelton Round-Butte Project), have also filed a notice stating their intent to seek a license for the entire project. Should relicensing not be completed prior to the expiration of the original license, annual licenses will be issued, usually under the original terms and conditions. The relicensing process includes the involvement of numerous interested parties such as governmental agencies, public interest groups and communities, with much of the focus on environmental concerns. PGE has already performed many pre-filing activities including nearly 50 public meetings with such groups. The cost of relicensing includes legal and filing fees as well as the cost of environmental studies, possible fish passage measures and wildlife habitat enhancements. Relicensing cost may be a significant factor in determining whether a project remains cost-effective after a new license is obtained, especially for smaller projects. Although FERC has never denied an application or issued a license to anyone other than the incumbent licensee, there is no assurance that a new license will be granted to PGE. 32
MID-COLUMBIA HYDRO - PGE's long-term power purchase contracts with certain public utility districts in the state of Washington expire between 2005 and 2018. Certain Idaho Electric Utility Co-operatives have initiated proceedings with FERC seeking to change the allocation of generation from the Priest Rapids and Wanapum dams between electric utilities in the region upon the expiration of the current contracts. An initial decision was issued in December 1996 by the presiding FERC administrative law judge. This decision does not substantially change PGE's share of power from these two dams. This decision is expected to be appealed. PGE will continue to seek renewal of these contracts under terms and conditions similar to the original. For further information regarding the power purchase contracts on the mid-Columbia dams, including Priest Rapids and Wanapum, see Note 8, Commitments, in the Notes to Financial Statements. NUCLEAR DECOMMISSIONING In 1996 the NRC and EFSC approved PGE's Trojan decommissioning plan. The plan, which estimates PGE's cost to decommission Trojan at $358 million in nominal dollars (actual dollars to be spent in each year), represents a site-specific decommissioning estimate performed for Trojan by an engineering firm experienced in decommissioning nuclear plants. This estimate assumes that the majority of decommissioning activities will occur between 1997 and 2001, after the spent fuel has been transferred to a temporary dry spent fuel storage facility. The plan anticipates final site restoration activities will begin in 2018 after PGE completes shipment of spent fuel to a USDOE facility (see Note 12, Trojan Nuclear Plant, for further discussion of the decommissioning plan and other Trojan issues). Current decommissioning activities are focused on the licensing, planning and construction of a temporary dry spent fuel storage facility and the removal of the Trojan reactor vessel. 33
MANAGEMENT'S STATEMENT OF RESPONSIBILITY Portland General Corporation's management is responsible for the preparation and presentation of the consolidated financial statements in this report. Management is also responsible for the integrity and objectivity of the statements. Generally accepted accounting principles have been used to prepare the statements, and in certain cases informed estimates have been used that are based on the best judgment of management. Management has established, and maintains, a system of internal accounting controls. The controls provide reasonable assurance that assets are safeguarded, transactions receive appropriate authorization, and financial records are reliable. Accounting controls are supported by written policies and procedures, an operations planning and budget process designed to achieve corporate objectives, and internal audits of operating activities. Portland General's Board of Directors includes an Audit Committee composed entirely of outside directors. It reviews with management, internal auditors and independent auditors the adequacy of internal controls, financial reporting, and other audit matters. Arthur Andersen LLP is Portland General's independent public accountant. As a part of its annual audit, selected internal accounting controls are reviewed in order to determine the nature, timing and extent of audit tests to be performed. All of the corporation's financial records and related data are made available to Arthur Andersen LLP. Management has also endeavored to ensure that all representations to Arthur Andersen LLP were valid and appropriate. Joseph M. Hirko Senior Vice President, Chief Financial Officer REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS To the Board of Directors and Shareholders of Portland General Corporation: We have audited the accompanying consolidated balance sheets of Portland General Corporation and subsidiaries as of December 31, 1996 and 1995, and the related consolidated statements of income, retained earnings and cash flows for each of the three years in the period ended December 31, 1996. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Portland General Corporation and subsidiaries as of December 31, 1996 and 1995, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1996 in conformity with generally accepted accounting principles. Arthur Andersen LLP Portland, Oregon, January 20, 1997 34
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA PORTLAND GENERAL CORPORATION AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF INCOME <TABLE> <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 (THOUSANDS OF DOLLARS EXCEPT PER SHARE AMOUNTS) <S> <C> <C> <C> OPERATING REVENUES $ 1,111,816 $ 983,582 $ 959,409 OPERATING EXPENSES Purchased power and fuel 316,729 293,589 347,125 Production and distribution 81,968 63,841 61,891 Maintenance and repairs 55,508 47,532 47,391 Administrative and other 115,881 108,067 100,596 Depreciation and amortization 154,670 134,423 124,081 Taxes other than income taxes 52,513 51,490 52,151 777,269 698,942 733,235 OPERATING INCOME BEFORE INCOME TAXES 334,547 284,640 226,174 INCOME TAXES 109,988 89,064 71,878 NET OPERATING INCOME 224,559 195,576 154,296 OTHER INCOME (DEDUCTIONS) Regulatory disallowances - net of income taxes of $25,542 - (49,567) - Interest expense (79,180) (79,128) (71,653) Allowance for funds used during construction 1,642 11,065 4,314 Preferred dividend requirement - PGE (2,793) (9,644) (10,800) Other - net of income taxes (14,692) 12,734 16,901 INCOME FROM CONTINUING OPERATIONS 129,536 81,036 93,058 DISCONTINUED OPERATIONS Gain on disposal of real estate operations - net of income taxes of $4,226 - - 6,472 NET INCOME $ 129,536 $ 81,036 $ 99,530 COMMON STOCK Average shares outstanding 51,144,462 50,766,916 49,896,685 Earnings per average share Continuing operations $2.53 $1.60 $1.86 Discontinued operations - - 0.13 Earnings per average share $2.53 $1.60 $1.99 Dividends declared per share $1.28 $1.20 $1.20 PORTLAND GENERAL CORPORATION AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF RETAINED EARNINGS <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 (THOUSANDS OF DOLLARS) <S> <C> <C> <C> BALANCE AT BEGINNING OF YEAR $ 135,885 $ 118,676 $ 81,159 NET INCOME 129,536 81,036 99,530 ESOP TAX BENEFIT AND OTHER (2,093) (2,872) (1,705) 263,328 196,840 178,984 DIVIDENDS DECLARED ON COMMON STOCK 65,516 60,955 60,308 BALANCE AT END OF YEAR $ 197,812 $ 135,885 $ 118,676 <FN> The accompanying notes are an integral part of these consolidated statements. </FN> </TABLE> 35
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS <TABLE> <CAPTION> AT DECEMBER 31 1996 1995 (THOUSANDS OF DOLLARS) <S> <C> <C> ASSETS ELECTRIC UTILITY PLANT - ORIGINAL COST Utility plant (includes Construction Work in Progress of $36,919 and $33,382) $ 2,899,746 $ 2,754,280 Accumulated depreciation (1,124,337) (1,040,014) 1,775,409 1,714,266 Capital leases - less amortization of $30,569 and $27,966 6,750 9,353 1,782,159 1,723,619 OTHER PROPERTY AND INVESTMENTS Leveraged leases 150,695 152,666 Trojan decommissioning trust, at market value 78,448 68,774 Corporate Owned Life Insurance less loans of $26,411 and $26,432 83,666 74,574 Contract termination receivable 111,447 - Other investments 29,745 28,603 454,001 324,617 CURRENT ASSETS Cash and cash equivalents 29,802 11,919 Accounts and notes receivable 125,314 104,815 Unbilled and accrued revenues 53,317 64,516 Inventories, at average cost 32,903 38,338 Prepayments and other 17,613 16,953 258,949 236,541 DEFERRED CHARGES Unamortized regulatory assets Trojan investment 275,460 301,023 Trojan decommissioning 282,131 311,403 Income taxes recoverable 195,592 217,366 Debt reacquisition costs 28,063 29,576 Conservation investments - secured 80,102 - Energy efficiency programs 11,974 77,945 Other 22,575 24,322 WNP-3 settlement exchange agreement 163,217 168,399 Miscellaneous 29,026 33,206 1,088,140 1,163,240 $ 3,583,249 $ 3,448,017 CAPITALIZATION AND LIABILITIES CAPITALIZATION Common stock equity Common stock, $3.75 par value per share 100,000,000 shares authorized, 51,317,828 and 51,013,549 shares outstanding $ 192,442 $ 191,301 Other paid-in capital - net 584,272 574,468 Unearned compensation (3,072) (8,506) Retained earnings 197,812 135,885 971,454 893,148 Cumulative preferred stock of subsidiary Subject to mandatory redemption 30,000 40,000 Long-term debt 933,042 890,556 1,934,496 1,823,704 CURRENT LIABILITIES Long-term debt and preferred stock due within one year 92,559 105,114 Short-term borrowings 92,027 170,248 Accounts payable and other accruals 149,255 133,405 Accrued interest 14,372 16,247 Dividends payable 17,386 16,668 Accrued taxes 30,985 15,151 396,584 456,833 OTHER Deferred income taxes 614,576 652,846 Deferred investment tax credits 47,314 51,211 Deferred gain on contract termination 112,697 - Trojan decommissioning and transition costs 357,844 379,179 Miscellaneous 119,738 84,244 1,252,169 1,167,480 $ 3,583,249 $ 3,448,017 <FN> The accompanying notes are an integral part of these consolidated balance sheets. </FN> </TABLE> 36
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES CONSOLIDATED STATEMENT OF CASH FLOWS <TABLE> <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 <S> <C> <C> <C> (THOUSANDS OF DOLLARS) CASH PROVIDED (USED) BY - OPERATIONS: Net income $ 129,536 $ 81,036 $ 99,530 Adjustment to reconcile net income to net cash provided by operations: Depreciation and amortization 118,929 102,266 94,217 Amortization of WNP-3 exchange agreement 5,182 4,910 4,695 Amortization of Trojan investment 24,244 24,884 26,738 Amortization of Trojan decommissioning 14,041 13,336 11,220 Amortization of deferred charges - other 5,034 (1,777) 2,712 Deferred income taxes - net (19,979) (9,555) 37,396 Other noncash revenues (1,697) (5,037) (2,570) Regulatory Disallowances - 49,567 - Changes in working capital: (Increase) Decrease in receivables (9,381) (14,687) (22,952) (Increase) Decrease in inventories 5,435 (7,189) 3,264 Increase (Decrease) in payables 40,052 22,122 (5,105) Other working capital items - net (644) 1,957 (18,104) Trojan decommissioning expenditures (8,231) (10,927) (3,360) Deferred charges - other 35,454 (9,472) 13,987 Miscellaneous - net 7,772 15,108 5,897 345,747 256,542 247,565 INVESTING ACTIVITIES: Utility construction - new resources - (49,096) (87,537) Utility construction - other (184,717) (158,198) (131,675) Energy efficiency programs (12,318) (25,013) (23,745) Rentals received from leveraged leases 29,623 21,204 20,886 Nuclear decommissioning trust deposits (15,435) (16,598) (11,220) Nuclear decommissioning trust withdrawals 7,888 13,521 - Discontinued operations - - 26,288 Other (10,659) (1,465) (14,058) (185,618) (215,645) (221,061) FINANCING ACTIVITIES: Short-term borrowings - net (78,221) 21,650 (10,816) Borrowings from Corporate Owned Life Insurance - 4,679 21,731 Long-term debt issued 170,590 147,138 74,631 Long-term debt retired (127,661) (69,445) (49,882) Repayment of nonrecourse borrowings for leveraged leases (25,535) (18,741) (18,046) Preferred stock retired (20,000) (79,704) (20,000) Common stock issued 3,380 10,299 50,074 Dividends paid (64,799) (62,396) (59,856) (142,246) (46,520) (12,164) INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 17,883 (5,623) 14,340 CASH AND CASH EQUIVALENTS AT THE BEGINNING OF YEAR 11,919 17,542 3,202 CASH AND CASH EQUIVALENTS AT THE END OF YEAR $ 29,802 $ 11,919 $ 17,542 Supplemental disclosures of cash flow information Cash paid during the year: Interest, net of amounts capitalized $ 76,105 $ 66,584 $ 60,852 Income taxes 111,630 86,778 31,539 <FN> The accompanying notes are an integral part of these consolidated statements. </FN> </TABLE> 37
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES NOTES TO FINANCIAL STATEMENTS NATURE OF OPERATIONS Portland General Corporation is an electric utility holding company. PGE, an electric utility company and Portland General's principal operating subsidiary, accounts for substantially all of Portland General's assets, revenues and net income. During 1996 Portland General entered into an Amended and Restated Agreement and Plan of Merger (Merger Agreement) with Enron Corp (Enron) and Enron Oregon Corp. (New Enron), a wholly-owned subsidiary of Enron. The Merger will be accounted for by Enron as a purchase for financial reporting purposes. PGE will continue to report its assets and liabilities at historical cost (see Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations). PGE is engaged in the generation, purchase, transmission, distribution, and sale of electricity in the State of Oregon. PGE also sells energy to wholesale customers, predominately utilities throughout the western United States. PGE's Oregon service area is 3,170 square miles, including 54 incorporated cities, of which Portland and Salem are the largest, within a state-approved service area allocation of 4,070 square miles. At the end of 1996, PGE's service area population was approximately 1.4 million, constituting approximately 44% of the state's population. At December 31, 1996, PGE served approximately 668,000 customers. NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES CONSOLIDATION PRINCIPLES The consolidated financial statements include the accounts of Portland General and all of its majority-owned subsidiaries. Significant intercompany balances and transactions have been eliminated. BASIS OF ACCOUNTING Portland General and its subsidiaries' financial statements conform to generally accepted accounting principles. In addition, PGE's accounting policies are in accordance with the requirements and the ratemaking practices of regulatory authorities having jurisdiction. USE OF ESTIMATES The preparation of financial statements require management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. RECLASSIFICATIONS Certain amounts in prior years have been reclassified for comparative purposes. REVENUES PGE accrues estimated unbilled revenues for services provided from the meter read date to month-end. PURCHASED POWER PGE credits purchased power costs for the net amount of benefits received through a power purchase and sale contract with the BPA. Reductions in purchased power costs that result from this exchange are passed directly to PGE's residential and small farm customers in the form of lower prices. DEPRECIATION PGE's depreciation is computed on the straight-line method based on the estimated average service lives of the various classes of plant in service. Depreciation expense as a percent of the related average depreciable plant in service was approximately 4.3% in 1996, 4.0% in 1995 and 3.8% in 1994. The cost of renewal and replacement of property units is charged to plant, while repairs and maintenance costs are charged to expense as incurred. The cost of utility property units retired, other than land, is charged to accumulated depreciation. 38
ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION (AFDC) AFDC represents the pretax cost of borrowed funds used for construction purposes and a reasonable rate for equity funds. AFDC is capitalized as part of the cost of plant and is credited to income but does not represent current cash earnings. The average rates used by PGE were 5.52%, 7.16%, and 4.65% for the years 1996, 1995 and 1994, respectively. INCOME TAXES Portland General files a consolidated federal income tax return. Portland General's policy is to collect for tax liabilities from subsidiaries that generate taxable income and to reimburse subsidiaries for tax benefits utilized in its tax return. Deferred income taxes are provided for temporary differences between financial and income tax reporting. Amounts recorded for Investment Tax Credits (ITC) have been deferred and are being amortized to income over the approximate lives of the related properties, not to exceed 25 years. See Notes 3 and 3A, Income Taxes, for more details. INVESTMENT IN LEASES CWL, a subsidiary of Holdings, acquires and leases capital equipment. Leases that qualify as direct financing leases and are substantially financed with nonrecourse debt at lease inception are accounted for as leveraged leases. Recorded investment in leases is the sum of the net contracts receivable and the estimated residual value, less unearned income and deferred ITC. Unearned income and deferred ITC are amortized to income over the life of the leases to provide a level rate of return on net equity invested. The components of CWL's net investment in leases as of December 31, 1996 and 1995, are as follows (thousands of dollars): <TABLE> <CAPTION> 1996 1995 <S> <C> <C> Lease contracts receivable $460,061 $508,190 Nonrecourse debt service (345,450) (389,619) Net contracts receivable 114,611 118,571 Estimated residual value 84,604 84,610 Less - Unearned income ( 39,435) (41,134) Investment in leveraged leases 159,780 162,047 Less - Deferred ITC (9,085) (9,381) Investment in leases, net $150,695 $152,666 </TABLE> CASH AND CASH EQUIVALENTS Highly liquid investments with original maturities of three months or less are classified as cash equivalents. DERIVATIVE FINANCIAL INSTRUMENTS PGE uses financial instruments such as commodity futures, options, forwards and swaps to hedge against exposures to interest rate, foreign currency and commodity price risks. The objective of PGE's hedging program is to mitigate risks due to market fluctuations associated with external financings or the purchase of natural gas, electricity and related products. Gains and losses from derivatives that reduce commodity price risks are recognized as fuel or purchased power expense. Gains and losses on financial instruments that reduce interest rate risk of future debt issuances are deferred and amortized over the life of the related debt as an adjustment to interest expense. Company policy also allows the use of the financial instruments, noted above, for trading purposes. Gains or losses on financial instruments that are used for trading purposes or otherwise do not qualify for hedge accounting are recognized in income on a current basis (see Note 7, Other Financial Instruments for further information). WNP-3 SETTLEMENT EXCHANGE AGREEMENT The WNP-3 Settlement Exchange Agreement, which has been excluded from PGE's rate base, is an intangible asset with the carrying amount being amortized over the life of the related agreement. 39
REGULATORY ASSETS AND LIABILITIES The Company is subject to the provisions of Statement of Financial Accounting Standards No. 71, "Accounting for the Effects of Certain Types of Regulation" (SFAS No. 71). When the requirements of SFAS No. 71 are met PGE defers, or accrues revenue for, certain costs which would otherwise be charged to expense, if it is probable that future rates will permit recovery of such costs (regulatory assets). In addition PGE defers, or accrues a liability for, certain revenues, gains or cost reductions which would otherwise be reflected in income but through the ratemaking process ultimately will be refunded to customers (regulatory liabilities). These regulatory assets and liabilities are reflected as deferred charges, accrued revenues and other liabilities in the financial statements and are amortized over the period in which they are included in billings to customers. Regulatory assets and liabilities reflected in the Consolidated Balance Sheets as of December 31 relate to the following: <TABLE> <CAPTION> 1996 1995 <S> <C> <C> (thousands of dollars) Regulatory Assets Trojan-related 557,591 612,426 Income taxes recoverable 195,592 217,366 Debt reacquisition and other 50,638 53,898 Conservation investments - secured 80,102 - Energy efficiency programs 11,974 77,945 Total Regulatory Assets $895,897 $961,635 Regulatory Liabilities Deferred gain on SCE Termination $112,697 - Miscellaneous 35,893 11,081 Total Regulatory Liabilities $148,590 $ 11,081 </TABLE> As of December 31, 1996, all of the Company's regulatory assets and liabilities are being reflected in rates charged to customers over periods ranging from approximately 5 to 28 years. Based on rates in place at year end 1996, the Company estimates that it will collect the majority of its regulatory assets within the next 10 years and substantially all of its regulatory assets within the next 20 years. In late 1996, the OPUC designated $81 million of PGE's energy efficiency investment as Bondable Conservation Investment, pursuant to recent Oregon legislation, and approved PGE's request to issue conservation bonds collateralized by an OPUC assured future revenue stream. Subsequently, PGE issued a 10 year conservation bond providing savings to customers while granting PGE immediate recovery of its energy efficiency program expenditures. Future revenues collected from customers will pay debt service obligations. NOTE 2 -EMPLOYEE BENEFITS PENSION PLAN Portland General has a non-contributory defined benefit pension plan (the Plan) covering substantially all of its employees. Benefits under the Plan are based on years of service, final average pay and covered compensation. Portland General's policy is to contribute annually to the Plan at least the minimum required under the Employee Retirement Income Security Act of 1974 but not more than the maximum amount deductible for income tax purposes. The Plan's assets are held in a trust and consist primarily of investments in common stocks, corporate bonds and U.S. government issues. Portland General determines net periodic pension expense according to the principles of SFAS No. 87, "Employers' Accounting for Pensions". Differences between the actual and expected return on Plan assets are included in net amortization and deferral and are considered in the determination of future pension expense. 40
The following table sets forth the Plan's funded status and amounts recognized in Portland General's financial statements (thousands of dollars): <TABLE> <CAPTION> 1996 1995 <S> <C> <C> Actuarial present value of benefit obligations: Accumulated benefit obligation, including vested benefits of $174,540 and $174,694 $187,847 $187,977 Effect of projected future compensation levels 38,841 34,345 Projected benefit obligation (PBO) 226,688 222,322 Plan assets at fair value 323,717 295,516 Plan assets in excess of PBO 97,029 73,194 Unrecognized net experience gain (95,055) (71,691) Unrecognized prior service costs amortized over 13- to 16-year periods 11,846 13,180 Unrecognized net transition asset being recognized over 18 years (15,660) (17,618) Pension liability $ (1,840) $ (2,935) </TABLE> <TABLE> <CAPTION> 1996 1995 1994 <S> <C> <C> <C> ASSUMPTIONS: Discount rate used to calculate PBO 7.50% 7.00% 8.50% Rate of increase in future compensation levels 5.50 5.00 6.50 Long-term rate of return on assets 8.50 8.50 8.50 COMPONENTS OF NET PERIODIC PENSION EXPENSE (THOUSANDS OF DOLLARS): Service cost $ 6,940 $ 5,500 $ 6,199 Interest cost on PBO 15,911 15,722 14,693 Actual return on plan assets (39,542) (61,377) 6,011 Net amortization and deferral 15,596 37,830 (25,971) Net periodic pension expense/(benefit) $ (1,095) $ (2,325) $ 932 </TABLE> OTHER POST-RETIREMENT BENEFIT PLANS Portland General accrues for health, medical and life insurance costs during the employees' service years, in accordance with SFAS No. 106. PGE receives recovery for the annual provision in customer rates. Employees are covered under a Defined Dollar Medical Benefit Plan which limits Portland General's obligation by establishing a maximum contribution per employee. The accumulated benefit obligation for post-retirement health and life insurance benefits at December 31, 1996 was $27 million, for which there were $28 million of assets held in trust. The benefit obligation for post-retirement health and life insurance benefits at December 31, 1995 was $30 million. Portland General also provides senior officers with additional benefits under an unfunded Supplemental Executive Retirement Plan (SERP). Projected benefit obligations for the SERP are $15 million at December 31, 1996 and 1995. DEFERRED COMPENSATION Portland General provides certain employees with benefits under an unfunded Management Deferred Compensation Plan (MDCP). Obligations for the MDCP are $30 million and $25 million at December 31, 1996 and 1995, respectively. EMPLOYEE STOCK OWNERSHIP PLAN Portland General has an Employee Stock Ownership Plan (ESOP) which is a part of its 401(k) retirement savings plan. Employee contributions up to 6% of base pay are matched by employer contributions in the form of ESOP common stock. Shares of common stock to be used to match contributions by PGE employees were purchased from a $36 million loan from PGE to the ESOP trust in late 1990. This loan is presented in the common equity section as unearned compensation. Cash contributions from PGE and dividends on shares held 41
in the trust are used to pay the debt service on PGE's loan. As the loan is retired, an equivalent amount of stock is allocated to employee accounts. Contributions to the ESOP, combined with dividends on unallocated shares were used to pay principal and interest on PGE's loan. These amounts are not material. Shares of common stock used to match contributions by employees of Portland General and its non-regulated subsidiaries are purchased on the open market. NOTE 3 - INCOME TAXES The following table shows the detail of taxes on income and the items used in computing the differences between the statutory federal income tax rate and Portland General's effective tax rate. NOTE: The table does not include income taxes related to 1994 gains on discontinued real estate operations (thousands of dollars): <TABLE> <CAPTION> 1996 1995 1994 <S> <C> <C> <C> Income Tax Expense: Currently payable Federal $102,066 $ 77,845 $41,833 State 21,472 9,230 7,072 123,538 87,075 48,905 Deferred income taxes Federal (13,401) (15,359) 22,269 State (2,539) (6,741) 4,472 (15,940) (22,100) 26,741 Investment tax credit adjustments (4,193) (5,725) (4,145) $103,405 $ 59,250 $ 71,501 Provision Allocated to: Operations $109,988 $ 89,064 $ 71,878 Other income and deductions (6,583) (29,814) (377) $103,405 $ 59,250 $ 71,501 Effective Tax Rate Computation: Computed tax based on statutory federal income tax rates applied to income before income taxes $ 81,529 $ 49,101 $ 57,596 Increases (Decreases) resulting from: Flow through depreciation 9,497 6,715 8,283 Regulatory disallowance - 3,470 - State and local taxes - net 11,719 4,857 8,953 State of Oregon refund - (3,668) - Investment tax credits (4,193) (5,725) (4,145) Excess deferred taxes (750) (700) (767) Merger expenses 3,724 - - Preferred dividend requirement 912 3,155 3,526 Other 967 2,045 (1,945) $103,405 $ 59,250 $ 71,501 Effective tax rate 44.4% 42.2% 43.5% </TABLE> 42
As of December 31, 1996 and 1995, the significant components of the Company's deferred income tax assets and liabilities were as follows (thousands of dollars): <TABLE> <CAPTION> 1996 1995 <S> <C> <C> DEFERRED TAX ASSETS Plant-in-service $ 64,471 $ 86,721 Other 61,012 60,245 125,483 146,966 DEFERRED TAX LIABILITIES Plant-in-service (414,417) (448,049) Energy efficiency programs (32,026) (30,314) Trojan abandonment (69,315) (54,335) WNP-3 exchange contract (59,302) (60,489) Leasing (136,478) (142,606) Other (7,918) (43,470) (719,456) (779,263) Less current deferred taxes (430) (414) Less valuation allowance (20,173) (20,135) Total $(614,576) $(652,846) </TABLE> Portland General has recorded deferred tax assets and liabilities for all temporary differences between the financial statement and tax basis of assets and liabilities. Valuation allowances represent capital loss carryforwards that presently cannot be offset with capital gains. 43
NOTE 4 - COMMON AND PREFERRED STOCK COMMON AND PREFERRED STOCK <TABLE> <CAPTION> CUMULATIVE PREFERRED COMMON STOCK OF SUBSIDIARY Other Number $3.75 Par Number $100 Par No-Par Paid-in Unearned OF SHARES VALUE OF SHARES VALUE VALUE CAPITAL COMPENSATION* <S> <C> <C> <C> <C> <C> <C> <C> (thousands of dollars except share amounts) December 31, 1993 47,634,653 $178,630 1,497,040 $119,704 $30,000 $519,058 $(19,151) Sales of stock 2,864,839 10,743 - - - 40,390 - Redemption of stock (4,000) (15) (200,000) (20,000) - 2,055 - Repayment of ESOP loan and other - - - - - 2,412 5,515 December 31, 1994 50,495,492 $189,358 1,297,040 $ 99,704 $30,000 $563,915 $(13,636) Sales of stock 539,057 2,022 - - - 9,355 - Redemption of stock (21,000) (79) (797,040) (79,704) - 2,778 - Repayment of ESOP loan and other - - - - - (1,580) 5,130 December 31, 1995 51,013,549 $191,301 500,000 $20,000 $30,000 $574,468 $ (8,506) Sales of stock 350,778 1,315 - - - 5,335 - Redemption of stock (46,499) (174) (200,000) (20,000) - 449 - Tax benefits stock options, repayment of ESOP loan and other - - - - - 4,020 5,434 December 31, 1996 51,317,828 $192,442 300,000 $ - $30,000 $584,272 $(3,072) <FN> *See the discussion of stock compensation plans below and Note 2, Employee Benefits, for a description of the ESOP. </FN> </TABLE> COMMON STOCK As of December 31, 1996, Portland General had reserved 2,333,386 and 8,185 authorized but unissued common shares for issuance under its dividend reinvestment plan and employee stock purchase plan, respectively. CUMULATIVE PREFERRED STOCK The 7.75% series preferred stock has an annual sinking fund requirement which requires the redemption of 15,000 shares at $100 per share beginning in 2002. At its option, PGE may redeem, through the sinking fund, an additional 15,000 shares each year. All remaining shares shall be mandatorily redeemed by sinking fund in 2007. This series is only redeemable by operation of the sinking fund. <TABLE> <CAPTION> PGE's cumulative preferred stock consisted of: At December 31, 1996 1995 (thousands of dollars) <S> <C> <C> Subject to mandatory redemption No par value 30,000,000 shares authorized 7.75% Series 300,000 shares outstanding $30,000 $30,000 $100 par value, 2,500,000 shares authorized 8.10% Series 200,000 shares outstanding - 20,000 Current sinking fund - (10,000) $30,000 $40,000 </TABLE> 44
No dividends may be paid on common stock or any class of stock over which the preferred stock has priority unless all amounts required to be paid for dividends and sinking fund payments have been paid or set aside, respectively. COMMON DIVIDEND RESTRICTION OF SUBSIDIARY PGE is restricted from paying dividends or making other distributions to Portland General without prior OPUC approval to the extent such payment or distribution would reduce PGE's common stock equity capital below 36% of its total capitalization. At December 31, 1996, PGE's common stock equity capital was 49% of its total capitalization. STOCK COMPENSATION PLANS Portland General has authorized 2.3 million shares of Portland General common stock under its Long-Term Incentive Plan (LTIP). Stock options represent the majority of activity under this plan. Stock option plan activity is as follows: <TABLE> <CAPTION> Option Price Options Per Share <S> <C> <C> December 31, 1993 856,800 $14-$22.25 Granted 32,000 $13-$18.125 Exercised (10,000) $15.75 Canceled (43,500) $14-$22.25 December 31, 1994 835,300 $13-$22.25 Granted 88,600 $17-$25 Exercised (114,400) $14.75 -$18.125 Canceled (17,000) $14 -$20 December 31, 1995 792,500 $13 -$25 Granted 373,029 $25 - $43.50 Exercised (306,930) $14 - $25 Canceled (31,096) $14 - $37.625 December 31, 1996 827,503 $13 - $43.25 Stock options exercisable at December 31, 1996 473,870 $13 -$25 </TABLE> At December 31, 1996, 831,946 common shares were available for issuance under the LTIP. Portland General accounts for stock-based compensation plans under APB Opinion 25. Due to a limited number of Portland General stock options granted on an annual basis, the amount of compensation expense, which would be required to be disclosed under Statement of Financial Accounting Standards No. 123, "Accounting for Stock Based Compensation", is not material. 45
NOTE 5 - SHORT-TERM BORROWINGS At December 31, 1996, Portland General and PGE had total committed lines of credit of $220 million. Portland General has a $20 million committed facility expiring in July 1997. PGE has a committed facility of $200 million expiring in July 2000. These lines of credit have annual fees of 0.10% and do not require compensating cash balances. The facilities are used primarily as backup for both commercial paper and borrowings from commercial banks under uncommitted lines of credit. At December 31, 1996, there were no outstanding borrowings under the committed facilities. PGE has a $200 million commercial paper facility. Unused committed lines of credit must be at least equal to the amount of PGE's commercial paper outstanding. Commercial paper and lines of credit borrowings are at rates reflecting current market conditions. Short-term borrowings and related interest rates were as follows: <TABLE> <CAPTION> 1996 1995 1994 <S> <C> <C> <C> AS OF YEAR-END: (thousands of dollars) Aggregate short-term debt outstanding Commercial paper $ 83,027 $170,248 $148,598 Bank loans 9,000 - - Weighted average interest rate* Commercial paper 5.6% 6.1% 6.2% Bank loans 7.3 - - Unused committed lines of credit $220,000 $215,000 $215,000 FOR THE YEAR ENDED: Average daily amounts of short-term debt outstanding Commercial paper 158,259 111,366 138,718 Bank loans $ 7,013 $ 206 $ 1,273 Weighted daily average interest rate* Commercial paper 5.6 6.3 4.5 Bank loans 5.8% 6.5% 4.3% Maximum amount outstanding during the year $251,462 $170,248 $174,082 <FN> * Interest rates exclude the effect of commitment fees, facility fees and other financing fees. </FN> </TABLE> 46
NOTE 6 - LONG-TERM DEBT The Indenture securing PGE's First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility property and franchises, other than expressly excepted property. <TABLE> <CAPTION> Schedule of long-term debt at December 31 1996 1995 (thousands of dollars) <S> <C> <C> First Mortgage Bonds Maturing 1996 through 2001 5.875 % Series due June 1, 1996 $ - $ 5,066 6.60% Series due October 1, 1997 15,063 15,363 Medium-term notes 5.65% - 9.00% 295,000 210,000 Maturing 2002 - 2007 6.47% - 9.07% 168,000 260,595 Maturing 2021 - 2023 7.75% - 9.46% 195,000 195,000 673,063 686,024 Pollution Control Bonds Port of Morrow, Oregon, variable rate (Average 3.5% - 4.3% for 1996), due 2013 & 29,400 23,600 2031 City of Forsyth, Montana, variable rate (Average variable rates 3.4%- 3.5% for 1996), due 2013-2016 118,800 118,800 Amount held by trustee (8,236) (8,152) Port of St. Helens, Oregon, variable rate due 2010 and 2014 (Average variable rates 3.4% - 3.5% 51,600 51,600 for 1996) 191,564 185,848 Other 8.25% Junior Subordinated Deferrable Interest Debentures, due December 31, 2035 75,000 75,000 Portland General medium-term notes 8.09% due - 30,000 1996 6.91% Conservation Bonds maturing monthly to 79,790 - 2006 Capital lease obligations 6,750 9,353 Other (566) (555) 160,974 113,798 1,025,601 985,670 Long-term debt due within one year (92,559) (95,114) Total long-term debt $ 933,042 $ 890,556 </TABLE> The following principal amounts of long-term debt become due through regular maturities (thousands of dollars): <TABLE> <CAPTION> 1997 1998 1999 2000 2001 <S> <C> <C> <C> <C> <C> Maturities: PGE $92,559 $71,073 $102,124 $32,222 $57,737 </TABLE> 47
NOTE 7 - OTHER FINANCIAL INSTRUMENTS FINANCIAL INSTRUMENTS The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value. CASH AND CASH EQUIVALENTS -The carrying amount of cash and cash equivalents approximates fair value because of the short maturity of those instruments. OTHER INVESTMENTS - Other investments approximate market value. REDEEMABLE PREFERRED STOCK - The fair value of redeemable preferred stock is based on quoted market prices. LONG-TERM DEBT - The fair value of long-term debt is estimated based on the quoted market prices for the same or similar issues or on the current rates offered to Portland General for debt of similar remaining maturities. The estimated fair values of financial instruments are as follows (thousands of dollars): <TABLE> <CAPTION> 1996 1995 <S> <C> <C> <C> <C> Carrying Fair Carrying Fair Amount Value Amount Value Preferred stock subject to mandatory redemption $ 30,000 $ 31,455 $ 50,000 $ 52,900 Long-term debt PGC (Parent only) $ - $ - $ 30,000 $ 30,531 PGE 939,627 959,668 946,872 994,996 $939,627 $959,668 $976,872 $1,025,527 Interest rate swaps in net receivable position - $582 - - </TABLE> NON-TRADING ACTIVITIES Commodity - Company policy allows the use of financial instruments such as commodity futures, options and swap contracts to hedge the price of natural gas and electricity and reduce the Company's exposure to market fluctuations in these commodities. In 1996 hedge transactions consisted of commodity futures and swap contracts where the Company receives from or makes payments to counterparties based on the differential between a fixed price and an index reference price for natural gas or electricity. The Company is exposed to credit risk in the event of non-performance by the counterparties and has established guidelines to mitigate this risk. At December 31, 1996 and 1995 outstanding futures and swap contracts related to natural gas had an absolute notional contract quantity of 6,085,000 million British thermal units (MMBtu) and 4,500,000 MMBtu's, respectively. In addition, outstanding swap contracts related to electricity had an absolute notional contract quantity of 1,410,000 Mwh and 256,000 Mwh as of December 31, 1996 and 1995, respectively. The commodity futures and swap contracts extend for a period of up to three years. Recognition of gains or losses on hedging instruments is deferred until the underlying physical transaction occurs. Upon recognition, these gains or losses are recognized in income as a reduction to or increase in purchased power and fuel expense. 48
The estimated fair value of outstanding natural gas financial instruments was $5,153,000 at December 31, 1996 and $(261,000) at December 31, 1995. The estimated fair value of outstanding electricity financial instruments was $(375,000) at December 31, 1996 and $(335,000) at December 31, 1995. INTEREST RATE - In August 1996 PGE entered into a 3 year interest rate swap agreement with a notional amount of $50 million. This puts PGE in a floating rate position on the additional $50 million of long term debt issued in August 1996. At December 31, 1996, the fair value PGE would receive if the interest rate swap agreement was terminated is not material. TRADING ACTIVITIES In addition to hedging activities, Company policy allows the use of the financial instruments noted above for trading purposes in support of Company operations. Realized and unrealized gains or losses on commodity-based financial instruments that do not qualify as hedges are recognized in income on a current basis in purchased power and fuel expense. Net losses arising from natural gas trading activities during the period ended December 31, 1996 were $4,481,000. Net gains arising from electricity trading activities during the period ended December 31, 1996 were $260,000. At December 31, 1996 outstanding swap and option contracts related to natural gas had an absolute notional contract quantity of 280,000 MMBtu's. In addition, outstanding futures, swap and option contracts related to electricity had an absolute notional contract quantity of 1,099,000 Mwh as of December 31, 1996. The commodity futures, swaps and option contracts extend for a period of up to two years. The Company is exposed to credit risk in the event of non-performance by the counterparties and has established guidelines to mitigate this risk. The fair value of the financial instruments as of December 31, 1996 and the average fair value of those instruments held during the year are as follows (thousands of dollars): <TABLE> <CAPTION> AVERAGE FAIR VALUE FAIR VALUE AS OF FOR THE YEAR ENDED (A) 12/31/96 12/31/96 PRODUCT ASSETS LIABILITIES ASSETS LIABILITIES <S> <C> <C> <C> <C> Natural Gas $ 48 $ 360 $ 52 $ 528 Electricity $2,296 $2,469 $1,181 $1,476 <FN> (a) Computed using the ending balance at each month end. </FN> </TABLE> NOTE 8 - COMMITMENTS NATURAL GAS AGREEMENTS PGE has long-term agreements for transmission of natural gas from domestic and Canadian sources to natural gas-fired generating facilities. The agreements provide firm pipeline capacity. Under the terms of these agreements, PGE is committed to paying capacity charges of approximately $16 million annually in 1997 through 2001, and $124 million over the remaining years of the contracts which expire at varying dates from 1998 to 2015. PGE has the right to assign unused capacity to other parties. PURCHASE COMMITMENTS Purchase commitments outstanding (principally construction at PGE) which include coal and railroad service agreements totaled approximately $63 million at December 31, 1996. Cancellation of these purchase agreements could result in cancellation charges. PURCHASED POWER PGE has long-term power purchase contracts with certain public utility districts in the state of Washington and with the City of Portland, Oregon. PGE is required to pay its proportionate share of the operating and debt service costs of the hydro projects whether or not they are operable. 49
Selected information is summarized as follows (thousands of dollars): <TABLE> <CAPTION> ROCKY PRIEST PORTLAND REACH RAPIDS WANAPUM WELLS HYDRO <S> <C> <C> <C> <C> <C> Revenue bonds outstanding at December 31, 1996 $200,011 $186,785 $209,130 $183,920 $ 36,825 PGE's current share of: Output 12.0% 13.9% 18.7% 21.8% 100% Net capability (megawatts) 154 128 194 177 36 Annual cost, including debt service: 1996 $5,300 $3,700 $4,700 $5,700 $4,300 1995 4,900 3,900 4,700 5,700 4,300 1994 4,500 3,400 4,800 6,600 4,600 Contract expiration date 2011 2005 2009 2018 2017 </TABLE> PGE's share of debt service costs, excluding interest, will be approximately $8 million for 1997, $5 million for 1998, $6 million for 1999 and 2000, and $7 million for 2001. The minimum payments through the remainder of the contracts are estimated to total $87 million. PGE has entered into long-term contracts to purchase power from other utilities in the West. These contracts will require fixed payments of up to $26 million in 1997 through 1999, $23 million in 2000, and $21 million in 2001. After that date, capacity contract charges will average $19 million annually until 2016. LEASES PGE has operating and capital leasing arrangements for its headquarters complex, combustion turbines and the coal-handling facilities and certain railroad cars for Boardman. PGE's aggregate rental payments charged to expense amounted to $22 million for 1996, 1995 and 1994. PGE has capitalized its combustion turbine leases. However, these leases are considered operating leases for ratemaking purposes. Future minimum lease payments under non-cancelable leases are as follows (thousands of dollars): <TABLE> <CAPTION> YEAR ENDING OPERATING LEASES DECEMBER 31 CAPITAL LEASES (NET OF SUBLEASE RENTALS) TOTAL <S> <C> <C> <C> 1997 $ 3,016 $ 19,988 $ 23,004 1998 3,016 19,446 22,462 1999 1,388 20,007 21,395 2000 - 20,053 20,053 2001 - 20,326 20,326 Remainder - 190,800 190,800 Total 7,420 $290,620 $298,040 Imputed Interest (670) Present Value of Minimum Future Net Lease Payments $ 6,750 </TABLE> Included in the future minimum operating lease payments schedule above is approximately $124 million for Portland General's and PGE's headquarters complex. 50
NOTE 9 - WNP-3 SETTLEMENT EXCHANGE AGREEMENT PGE is selling energy received under a WNP-3 Settlement Exchange Agreement (WSA) to WAPA for 25 years which began in October 1990. Revenues from the WAPA sales contract and market sales are used to support the carrying value of PGE's investment. A portion of the energy under the WSA contract is sold at market prices. The energy received by PGE under WSA is the result of a settlement related to litigation surrounding the abandonment of WNP-3. PGE receives about 65 average annual MW for approximately 30 years from BPA under the WSA which began in 1987. In exchange, PGE will make available to BPA energy from its combustion turbines or from other available sources at an agreed-to price. In light of declining market prices for wholesale power, an evaluation of expected future cash flows was completed in late 1996. The Company's best estimates, given reasonable operating assumptions and revenue projections, show that cash flow is expected to be sufficient to support the carrying value of PGE's investment. PGE will continue to monitor related cash flows in light of the continued competitive pressure on electricity prices, as well as possible changes in contractual terms, conditions, and obligations. NOTE 10 - JOINTLY-OWNED PLANT At December 31, 1996, PGE had the following investments in jointly owned generating plants (thousands of dollars): <TABLE> <CAPTION> MW PGE % PLANT ACCUMULATED FACILITY LOCATION FUEL CAPACITY INTEREST IN SERVICE DEPRECIATION <S> <C> <C> <C> <C> <C> <C> Boardman Boardman, OR Coal 508 65.0 $375,133 $188,352 Colstrip 3&4 Colstrip, MT Coal 1,440 20.0 452,762 205,259 Centralia Centralia, WA Coal 1,310 2.5 9,715 5,880 </TABLE> The dollar amounts in the table above represent PGE's share of each jointly owned plant. Each participant in the above generating plants has provided its own financing. PGE's share of the direct expenses of these plants is included in the corresponding operating expenses on Portland General's and PGE's consolidated income statements. NOTE 11 - LEGAL MATTERS BONNEVILLE PACIFIC LAWSUIT - On October 7, 1996 the bankruptcy court approved the settlement entered into by Portland General and Portland General Holdings (collectively referred to as Portland) with the Bonneville Pacific Corporation's (Bonneville) bankruptcy trustee (Trustee). Pursuant to the settlement, Bonneville and its estate released all claims and causes of action, including those asserted in the Trustee's civil action against Portland and its current and former officers and directors. In exchange, Portland released any and all claims against Bonneville, its estate and related entities and individuals relating to its equity investment in and loans to Bonneville, except that Portland will retain ownership of 2 million shares of Bonneville common stock. The settlement with the trustee will not have a material impact on Portland General's results of operations. In early 1997 Portland received payments for certain litigation and settlement costs in other matters related to the Bonneville Pacific lawsuit. These payments will be recognized into income during the first quarter of 1997. TROJAN INVESTMENT RECOVERY - In April 1996 a circuit court judge in Marion County, Oregon found that the OPUC could not authorize PGE to collect a return on its undepreciated investment in Trojan contradicting a November 1994 ruling from the same court. The ruling was the result of an appeal of PGE's 1995 general rate order which granted PGE recovery of, and a return on, 87 percent of its remaining investment in Trojan. 51
The November 1994 ruling, by a different judge of the same court, upheld the Commission's 1993 Declaratory Ruling (DR-10). In DR-10 the OPUC ruled that PGE could recover and earn a return on its undepreciated Trojan investment, provided certain conditions were met. The Commission relied on a 1992 Oregon Department of Justice opinion issued by the Attorney General's office stating that the Commission had the authority to set prices including recovery of and on investment in plant that is no longer in service. The 1994 ruling was appealed to the Oregon Court of Appeals and stayed pending the appeal of the Commission's March 1995 order. Both PGE and the OPUC have separately appealed the April 1996 ruling which were combined with the appeal of the November 1994 ruling at the Oregon Court of Appeals. Management believes that the authorized recovery of and on the Trojan investment and decommissioning costs will be upheld and that these legal challenges will not have a material adverse impact on the results of operations or financial condition of the Company for any future reporting period. OTHER LEGAL MATTERS - Portland General and certain of its subsidiaries are party to various other claims, legal actions and complaints arising in the ordinary course of business. These claims are not considered material. NOTE 12 - TROJAN NUCLEAR PLANT PLANT SHUTDOWN AND TRANSITION COSTS - PGE is a 67.5% owner of Trojan. In early 1993, PGE ceased commercial operation of the nuclear plant. Since plant closure, PGE has committed itself to a safe and economical transition toward a decommissioned plant. Remaining transition costs associated with operating and maintaining the spent fuel pool and securing the plant until dismantlement begins in 1998 are estimated at $24 million and will be paid from current operating funds. DECOMMISSIONING - In 1996, PGE received approval of the decommissioning plan submitted to the NRC and EFSC during 1995. The plan estimates PGE's cost to decommission Trojan at $358 million, reflected in nominal dollars (actual dollars expected to be spent in each year). The plan represents a site-specific decommissioning estimate performed for Trojan by an engineering firm experienced in estimating the cost of decommissioning nuclear plants. This estimate assumes that the majority of decommissioning activities will occur between 1997 and 2001, while fuel management costs extend through the year 2018. Final site restoration activities are anticipated to begin in 2018 after PGE completes shipment of spent fuel to a USDOE facility (see the Nuclear Fuel Disposal discussion below). The cost estimate is adjusted periodically due to refinement of the timing and scope of certain dismantlement activities. Stated in 1996 dollars, the current decommissioning cost estimate is $256 million. <TABLE> <CAPTION> TROJAN DECOMMISSIONING LIABILITY (thousands of dollars) <S> <C> Estimate - 12/31/94 $351,294 Updates filed with NRC - 11/16/95 7,084 358,378 Expenditures through 12/31/96 (24,144) Liability - 12/31/96 $334,234 Decommissioning $334,234 Transition costs 23,610 Total Trojan obligation $357,844 </TABLE> PGE is collecting $14 million annually through 2011 from customers for decommissioning costs. These amounts are deposited in an external trust fund which is limited to reimbursing PGE for activities covered in Trojan's decommissioning plan. Funds were withdrawn during 1996 to cover the costs of planning and licensing activities in support of the independent spent fuel storage installation and the reactor vessel and internals removal project. Decommissioning funds are invested primarily in investment-grade, tax-exempt and U.S. Treasury bonds. Year-end balances are valued at market. Earnings on the trust fund are used to reduce the amount of decommissioning costs to be collected from customers. PGE expects any future changes in estimated decommissioning costs to be incorporated in future revenues to be collected from customers. 52
INVESTMENT RECOVERY - The OPUC issued an order in March 1995 authorizing PGE to recover all of the estimated costs of decommissioning Trojan and 87% of the remaining investment in the plant. Amounts are to be collected over Trojan's original license period ending in 2011. The OPUC's order and the agency's authority to grant recovery of the Trojan investment under Oregon law are being challenged in state courts. Management believes that the authorized recovery of the Trojan investment and decommissioning costs will be upheld and that these legal challenges will not have a material adverse impact on the results of operations or financial condition of the Company for any future reporting period. <TABLE> <CAPTION> DECOMMISSIONING TRUST ACTIVITY (thousands of dollars) <S> <C> <C> Beginning Balance $68,774 $58,485 ACTIVITY Contributions 15,435 16,598 Gain 2,127 7,212 Disbursements (7,888) (13,521) Ending Balance $78,448 $68,774 </TABLE> NUCLEAR FUEL DISPOSAL AND CLEANUP OF FEDERAL PLANTS - PGE contracted with the USDOE for permanent disposal of its spent nuclear fuel in federal facilities at a cost of .1 cent per net kilowatt-hour sold at Trojan which the Company paid during the period the plant operated. Significant delays are expected in the USDOE acceptance schedule of spent fuel from domestic utilities. The federal repository, which was originally scheduled to begin operations in 1998, is now estimated to commence operations no earlier than 2010. This may create difficulties for PGE in disposing of its high-level radioactive waste by 2018. However, federal legislation has been introduced which, if passed, would require USDOE to provide interim storage for high- level waste until a permanent site is established. PGE intends to build an interim storage facility at Trojan to house the nuclear fuel until a federal site is available. The Energy Policy Act of 1992 provided for the creation of a Decontamination and Decommissioning Fund to finance the cleanup of USDOE gas diffusion plants. Funding comes from domestic nuclear utilities and the federal government. Each utility contributes based on the ratio of the amount of enrichment services the utility purchased to the total amount of enrichment services purchased by all domestic utilities prior to the enactment of the legislation. Based on Trojan's 1.1% usage of total industry enrichment services, PGE's portion of the funding requirement is approximately $17 million. Amounts are funded over 15 years beginning with the USDOE's fiscal year 1993. Since enactment, PGE has made the first five of the 15 annual payments with the first payment made in September 1993. NUCLEAR INSURANCE - The Price-Anderson Amendment of 1988 limits public liability claims that could arise from a nuclear incident and provides for loss sharing among all owners of nuclear reactor licenses. Because Trojan has been permanently defueled, the NRC has exempted PGE from participation in the secondary financial protection pool covering losses in excess of $200 million at other nuclear plants. In addition, the NRC has reduced the required primary nuclear insurance coverage for Trojan from $200 million to $100 million following a 3 year cool-down period of the nuclear fuel that is still on-site. The NRC has allowed PGE to self-insure for on-site decontamination. PGE continues to carry non- contamination property insurance on the Trojan plant at the $155 million level. NOTE 13 -SCE CONTRACT TERMINATION AGREEMENT In March 1996, PGE and SCE entered into a termination agreement for the Power Sales Agreement between the two companies. The FERC and the CPUC have approved terms and conditions of the agreement. The agreement requires that SCE pay PGE $141 million over the next 6 years ($15 million per year in 1997 through 1999 and $32 million per year in 2000 through 2002). PGE recorded a discounted receivable in the amount of $112.7 million of which $1.25 million was received in 1996. Disposition of the gain has been deferred pending OPUC determination of the appropriate regulatory treatment. 53
QUARTERLY COMPARISON FOR 1996 AND 1995 (UNAUDITED) PORTLAND GENERAL CORPORATION <TABLE> <CAPTION> MARCH 31 JUNE 30 SEPTEMBER 30 DECEMBER 31 (THOUSANDS OF DOLLARS EXCEPT PER SHARE AMOUNTS) <S> <C> <C> <C> <C> 1996 Operating revenues $300,581 $233,425 $260,091 $317,719 Net operating income 66,744 51,675 44,742 61,398 Net income 49,362 33,679 20,541 25,954 Common stock Average shares outstanding 51,063,105 51,109,790 51,158,923 51,243,669 Earnings per average share{1} $ .97 $.66 $.40 $.51 1995 Operating revenues $259,177 $219,892 $222,612 $281,901 Net operating income 49,553 47,179 40,266 58,578 Net income/(loss) (1,954) 32,403 14,181 36,406 Common stock Average shares outstanding 50,591,449 50,697,040 50,798,082 50,976,781 Earnings/(loss) per average share{1} $(.04) $.64 $.28 $.71 <FN> {1}As a result of dilutive effects of shares issued during the period, quarterly earnings per share cannot be added to arrive at annual earnings per share. </FN> </TABLE> PORTLAND GENERAL ELECTRIC COMPANY <TABLE> <CAPTION> MARCH 31 JUNE 30 SEPTEMBER 30 DECEMBER 31 (THOUSANDS OF DOLLARS) <S> <C> <C> <C> <C> 1996 Operating revenues $300,195 $232,921 $259,656 $317,059 Net operating income 66,816 51,850 45,514 60,566 Net income 50,104 34,914 27,919 42,978 Income available for common stock 49,118 34,269 27,338 42,397 1995 Operating revenues $258,891 $218,476 $222,240 $282,021 Net operating income 49,388 46,499 39,902 59,397 Net income 640 34,800 16,789 40,558 Income/(loss) available for common stock (1,943) 32,383 14,409 38,294 </TABLE> 54
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE None. PART III ITEMS 10-13. INFORMATION REGARDING DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT PORTLAND GENERAL CORPORATION Information for Items 10-13 is incorporated by reference to Portland General's definitive proxy statement to be filed on or about May 27, 1997. Executive officers of Portland General are listed on page 21 of this report. PORTLAND GENERAL ELECTRIC COMPANY Information for Items 10-13 is incorporated by reference to Portland General's definitive proxy statement to be filed on or about May 27, 1997. Executive officers of Portland General Electric are listed on page 21 of this report. PART IV ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K PORTLAND GENERAL CORPORATION AND PORTLAND GENERAL ELECTRIC COMPANY (a) INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES PAGE NO. PGC PGE FINANCIAL STATEMENTS Report of Independent Public Accountants 34 66 Consolidated Statements of Income for each of the three years in the period ended December 31, 1996 35 67 Consolidated Statements of Retained Earnings for each of the three years in the period ended December 31, 1996 35 67 Consolidated Balance Sheets at December 31, 1996 and 1995 36 68 Consolidated Statement of Cash Flows for each of the three years in the period ended December 31, 1996 37 69 Notes to Financial Statements 38 70 FINANCIAL STATEMENT SCHEDULES Schedules are omitted because of the absence of conditions under which they are required or because the required information is given in the financial statements or notes thereto. EXHIBITS See Exhibit Index on Page 59 of this report. (B) REPORT ON FORM 8-K PGC PGE November 1, 1996 - Item 5. Other Events: X X The OPUC staff revised response to rate plan. 55
(B) REPORT ON FORM 8-K PGC PGE November 12, 1996 - Item 5. Other Events: X X Shareholders approve merger with Enron Corp. November 12, 1996 - Item 5. Other Events: X X The OPUC staff stipulation for settlement on rate proposal. November 26, 1996 - Item 5. Other Events: X X The OPUC approves rate settlement. January 16, 1997 - Item 5. Other Events: X X Preliminary merger recommendation from the OPUC staff. January 24, 1997 - Item 5. Other Events: X X Settlement conferences suspended. February 14, 1997 - Item 5. Other Events: X X Settlement conferences continued. 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. Portland General Corporation March 3, 1997 By /S/ KEN L. HARRISON Ken L. Harrison Chairman of the Board and Chief Executive Officer 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. Chairman of the Board and /S/ KEN L. HARRISON Chief Executive Officer March 3, 1997 Ken L. Harrison Senior Vice President, /S/ JOSEPH M. HIRKO Chief Financial Officer March 3, 1997 Joseph M. Hirko *Gwyneth Gamble Booth Peter J. Brix *Carolyn S. Chambers *John W. Creighton, Jr. *Richard Geary *Ken L. Harrison *Jerry E. Hudson Directors March 3, 1997 *Jerome J. Meyer *Randolph L. Miller *Bruce G. Willison *By /S/ JOSEPH E. FELTZ (Joseph E. Feltz, Attorney-in-Fact) 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. Portland General Electric Company March 3, 1997 By /S/ KEN L. HARRISON Ken L. Harrison Chairman of the Board and Chief Executive Officer 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. Chairman of the Board and /S/ KEN L. HARRISON Chief Executive Officer March 3, 1997 Ken L. Harrison Senior Vice President /S/ JOSEPH M. HIRKO Chief Financial Officer March 3, 1997 Joseph M. Hirko *Gwyneth Gamble Booth Peter J. Brix *Carolyn S. Chambers *John W. Creighton, Jr. *Ken L. Harrison *Jerry E. Hudson Directors March 3, 1997 *Richard Geary *Jerome J. Meyer *Randolph L. Miller *Bruce G. Willison *By /S/ JOSEPH E. FELTZ (Joseph E. Feltz, Attorney-in-Fact) 58
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES EXHIBIT INDEX NUMBER EXHIBIT PGC PGE (2) PLAN OF ACQUISITION, REORGANIZATION, ARRANGEMENT, LIQUIDATION OR SUCCESSION * Amended and Restated Agreement and Plan of Merger, dated as of July 20, 1996 and amended and restated as of September 24, 1996 among Enron Corp, Enron Oregon Corp and Portland General Corporation [Amendment 1 to S4 Registration Nos. 333-13791 and 333-13791-1, dated October 10, 1996, Exhibit No. 2.1]. X X (3) ARTICLES OF INCORPORATION AND BYLAWS * Restated Articles of Incorporation of Portland General Corporation [Pre-effective Amendment No. 1 to Form S-4, Registration No. 33-1987, dated December 31, 1985, Exhibit (B)]. X * Certificate of Amendment, dated July 2, 1987, to the Articles of Incorporation limiting the personal liability of directors of Portland General Corporation [Form 10-K for the fiscal year ended December 31, 1987, Exhibit (3)]. X * Copy of Articles of Incorporation of Portland General Electric Company [Registration No. 2-85001, Exhibit (4)]. X * Certificate of Amendment, dated July 2, 1987, to the Articles of Incorporation limiting the personal liability of directors of Portland General Electric Company [Form 10-K for the fiscal year ended December 31, 1987, Exhibit (3)]. X * Form of Articles of Amendment of the New Preferred Stock of Portland General Electric Company [Registration No. 33-21257, Exhibit (4)]. X * Bylaws of Portland General Corporation as amended on February 5, 1991 [Form 10-K for the fiscal year ended December 31, 1990, Exhibit (10)]. X * Bylaws of Portland General Electric Company as amended on October 1, 1991 [Form 10-K for the fiscal year ended December 31, 1991, Exhibit (3)]. X (4) INSTRUMENTS DEFINING THE RIGHTS OF SECURITY HOLDERS, INCLUDING INDENTURES * Portland General Electric Company Indenture of Mortgage and Deed of Trust dated July 1, 1945; * Fortieth Supplemental Indenture, dated October 1, 1990 [Form 10-K for the fiscal year ended December 31, 1990, Exhibit (4)]. X X 59
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES EXHIBIT INDEX NUMBER EXHIBIT PGC PGE (4) * Forty-First Supplemental Indenture dated December 1, CONT. 1991 [Form 10-K for the fiscal year ended December 31, X X 1991, Exhibit (4)]. * Forty-Second Supplemental Indenture dated April 1, 1993 [Form 10-Q for the quarter ended March 31, 1993, Exhibit (4)]. X X * Forty-Third Supplemental Indenture dated July 1, 1993 [Form 10-Q for the quarter ended September 30, 1993, Exhibit (4)]. X X * Forty-Fourth Supplemental Indenture dated August 1, 1994 [Form 10-Q for the quarter ended September 30, 1994, Exhibit (4)]. X X * Forty-Fifth Supplemental Indenture dated May 1, 1995 [Form 10-Q for the quarter ended June 30, 1995, Exhibit (4)]. X X Forty-Sixth Supplemental Indenture dated August 1, 1996 (Filed herewith). X X Other instruments which define the rights of holders of long-term debt not required to be filed herein will be furnished upon written request. (10) MATERIAL CONTRACTS * Residential Purchase and Sale Agreement with the Bonneville Power Administration [Form 10-K for the fiscal year ended December 31, 1981, Exhibit (10)]. X X * Power Sales Contract and Amendatory Agreement Nos. 1 and 2 with Bonneville Power Administration [Form 10-K for the fiscal year ended December 31, 1982, Exhibit (10)]. X X The following 12 exhibits were filed in conjunction with the 1985 Boardman/Intertie Sale: * Long-term Power Sale Agreement, dated November 5, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Long-term Transmission Service Agreement, dated November 5, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Participation Agreement, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X 60
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES EXHIBIT INDEX NUMBER EXHIBIT PGC PGE (10) * Lease Agreement, dated December 30, 1985 [Form 10-K CONT. for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * PGE-Lessee Agreement, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Asset Sales Agreement, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Bargain and Sale Deed, Bill of Sale and Grant of Easements and Licenses, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Supplemental Bill of Sale, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Trust Agreement, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Tax Indemnification Agreement, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Trust Indenture, Mortgage and Security Agreement, dated December 30, 1985 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X * Restated and Amended Trust Indenture, Mortgage and Security Agreement, dated February 27, 1986 [Form 10-K for the fiscal year ended December 31, 1985, Exhibit (10)]. X X _______________________________________________________________________________ * Portland General Corporation Outside Directors' Deferred Compensation Plan, 1996 Restatement dated January 1, 1996 [Form 10-Q for the quarter ended June 30, 1996, Exhibit (10)]. X X * Portland General Corporation Outside Directors' Deferred Compensation Plan, Amendment No. 1 dated October 18, 1996 [Form 10-Q for the quarter ended June 30, 1996, Exhibit (10)]. X X Portland General Corporation Outside Directors' Deferred Compensation Plan, 1996 Restatement, Amendment No. 2 dated November 4, 1996 (filed herewith). X X 61
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES EXHIBIT INDEX NUMBER EXHIBIT PGC PGE (10) * Portland General Corporation Retirement Plan for CONT. Outside Directors, 1996 Restatement dated January 1, 1996 [Form 10-Q for the quarter ended June 30, 1996, Exhibit (10)]. X X * Portland General Corporation Outside Directors' Life Insurance Benefit Plan, 1996 Restatement dated January 1, 1996 [Form 10-Q for quarter ended June 30, 1996, Exhibit (10)]. X X * Portland General Corporation Outside Directors' Life Insurance Benefit Plan, 1996 Restatement, Amendment No. 1 dated September 10, 1996 [Form 10-Q for the quarter ended September 31, 1996, Exhibit (10)]. X X * Portland General Corporation Outside Directors' Stock Compensation Plan, Amended and Restated December 6, 1996 [Form 10-K for the fiscal year ended December 31, X 1991, Exhibit (10)]. Portland General Corporation Outside Directors' Stock Compensation Plan, Amendment No. 1 dated October 2, 1996 (filed herewith). X EXECUTIVE COMPENSATION PLANS AND ARRANGEMENTS * Portland General Corporation Management Deferred Compensation Plan, 1996 Restatement dated January 1, 1996 [Form 10-Q for the quarter ended June 30, 1996, Exhibit (10)]. X X * Portland General Corporation Management Deferred Compensation Plan, Amendment No. 1 dated October 18, 1996 [Form 10-Q for the quarter ended June 30, 1996, Exhibit (10)]. X X. Portland General Corporation Management Deferred Compensation Plan, 1996 Restatement, Amendment No. 2 dated November 4, 1996 (filed herewith). X * Portland General Corporation Senior Officers Life Insurance Benefit Plan, 1996 Restatement Amendment No. 1 dated October 22, 1996 [Form 10-Q for the quarter ended March 31, 1996, Exhibit (10)]. X X * Portland General Corporation Annual Incentive Master Plan [Form 10-K for the fiscal year ended December 31, 1987, Exhibit (10)]. X X * Portland General Corporation Annual Incentive Master Plan, Amendments No. 1 and No. 2 dated March 5, 1990 [Form 10-K for the fiscal year ended December 31, 1989, Exhibit (10)]. X X 62
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES EXHIBIT INDEX NUMBER EXHIBIT PGC PGE (10) * Portland General Electric Company Annual Incentive Master CONT. Plan [Form 10-K for the fiscal year ended December 31, 1987, Exhibit (10)]. X * Portland General Electric Company Annual Incentive Master Plan, Amendments No. 1 and No. 2 dated March 5, 1990 [Form 10-K for the fiscal year ended December 31, 1989, Exhibit (10)]. X * Portland General Corporation Supplemental Executive Retirement Plan, 1996 Restatement dated January 1, 1996 [Form 10-Q for the quarter ended March 31, 1996, Exhibit (10)]. X X * Portland General Corporation Supplemental Executive Retirement Plan, Amendment No. 1 dated January 1, 1991, [Form 10-K for the fiscal year ended December 31, 1991, X X Exhibit (10)]. * Change in Control Severance Agreement, effective October 1, 1994 [Form 10-K for the fiscal year ended December 31, 1994, Exhibit (10)]. X X Portland General Corporation Amended and Restated 1990 Long-Term Incentive Master Plan, 1996 Restatement dated September 10, 1996 (filed herewith). X * Portland General Corporation 1990 Long-Term Incentive Master Plan, Amendment No. 1 dated February 8, 1994 [Form 10-K for the fiscal year ended December 31, 1993, Exhibit (10)]. X (23) CONSENTS OF EXPERTS AND COUNSEL Portland General Corporation Consent of Independent Public Accountants (filed herewith). X Portland General Electric Company Consent of Independent Public Accountants (filed herewith). X (24) POWER OF ATTORNEY Portland General Corporation Power of Attorney (filed herewith). X Portland General Electric Company Power of Attorney (filed herewith). X 63
PORTLAND GENERAL CORPORATION AND SUBSIDIARIES EXHIBIT INDEX NUMBER EXHIBIT PGC PGE (99) ADDITIONAL EXHIBITS Form 11-K relating to Employee Stock Purchase Plan of Portland General Corporation. X _________________________________ * Incorporated by reference as indicated. Note: Although the Exhibits furnished to the Securities and Exchange Commission with the Form 10-K have been omitted herein, they will be supplied upon written request and payment of a reasonable fee for reproduction costs. Requests should be sent to: Joseph M. Hirko Senior Vice President Chief Financial Officer Portland General Corporation 121 SW Salmon Street Portland, OR 97204 64
APPENDIX PORTLAND GENERAL ELECTRIC COMPANY TABLE OF CONTENTS PART II PAGE ITEM 8. FINANCIAL STATEMENTS AND NOTES ...................... 67 65
MANAGEMENT'S STATEMENT OF RESPONSIBILITY PGE's management is responsible for the preparation and presentation of the consolidated financial statements in this report. Management is also responsible for the integrity and objectivity of the statements. Generally accepted accounting principles have been used to prepare the statements, and in certain cases informed estimates have been used that are based on the best judgment of management. Management has established, and maintains, a system of internal accounting controls. The controls provide reasonable assurance that assets are safeguarded, transactions receive appropriate authorization, and financial records are reliable. Accounting controls are supported by written policies and procedures, an operations planning and budget process designed to achieve corporate objectives, and internal audits of operating activities. PGE's Board of Directors includes an Audit Committee composed entirely of outside directors. It reviews with management, internal auditors and independent auditors the adequacy of internal controls, financial reporting, and other audit matters. Arthur Andersen LLP is PGE's independent public accountant. As a part of its annual audit, selected internal accounting controls are reviewed in order to determine the nature, timing and extent of audit tests to be performed. All of the corporation's financial records and related data are made available to Arthur Andersen LLP. Management has also endeavored to ensure that all representations to Arthur Andersen LLP were valid and appropriate. Joseph M. Hirko Senior Vice President, Chief Financial Officer REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS To the Board of Directors and Shareholder of Portland General Electric Company: We have audited the accompanying consolidated balance sheets of Portland General Electric Company and subsidiaries as of December 31, 1996 and 1995, and the related consolidated statements of income, retained earnings and cash flows for each of the three years in the period ended December 31, 1996. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Portland General Electric Company and subsidiaries as of December 31, 1996 and 1995, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1996 in conformity with generally accepted accounting principles. Arthur Andersen LLP Portland, Oregon, January 20, 1997 66
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF INCOME <TABLE> <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 (THOUSANDS OF DOLLARS) <S> <C> <C> <C> OPERATING REVENUES $ 1,109,831 $ 981,628 $ 958,955 OPERATING EXPENSES Purchased power and fuel 316,729 293,589 347,125 Production and distribution 81,968 63,841 61,891 Maintenance and repairs 55,508 47,532 47,389 Administrative and other 111,308 106,128 97,987 Depreciation and amortization 154,586 134,340 124,003 Taxes other than income taxes 52,325 51,489 52,038 Income taxes 112,661 89,523 75,314 885,085 786,442 805,747 NET OPERATING INCOME 224,746 195,186 153,208 OTHER INCOME (DEDUCTIONS) Regulatory disallowances - net of income taxes of $25,542 - (49,567) - Allowance for equity funds used during construction - 3,257 271 Other 5,234 8,415 15,500 Income taxes 1,451 4,272 377 6,685 (33,623) 16,148 INTEREST CHARGES Interest on long-term debt and other 68,116 69,667 61,493 Interest on short-term borrowings 9,042 6,917 5,788 Allowance for borrowed funds used during construction (1,642) (7,808) (4,043) 75,516 68,776 63,238 NET INCOME 155,915 92,787 106,118 PREFERRED DIVIDEND REQUIREMENT 2,793 9,644 10,800 INCOME AVAILABLE FOR COMMON STOCK $ 153,122 $ 83,143 $ 95,318 PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF RETAINED EARNINGS <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 (THOUSANDS OF DOLLARS) <S> <C> <C> <C> BALANCE AT BEGINNING OF YEAR $ 246,282 $ 216,468 $ 179,297 NET INCOME 155,915 92,787 106,118 ESOP TAX BENEFIT & OTHER (2,093) (3,570) (1,705) 400,104 305,685 283,710 DIVIDENDS DECLARED Common stock 105,187 50,456 56,442 Preferred stock 2,793 8,947 10,800 107,980 59,403 67,242 BALANCE AT END OF YEAR $ 292,124 $ 246,282 $ 216,468 <FN> The accompanying notes are an integral part of these consolidated statements. </FN> </TABLE> 67
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS <TABLE> <CAPTION> AT DECEMBER 31 1996 1995 <S> <C> <C> (THOUSANDS OF DOLLARS) ASSETS ELECTRIC UTILITY PLANT - ORIGINAL COST Utility plant (includes Construction Work in Progress of $36,919 and $33,382) $ 2,899,746 $ 2,754,280 Accumulated depreciation (1,124,337) (1,040,014) 1,775,409 1,714,266 Capital leases - less amortization of 6,750 9,353 $30,569 and $27,966 1,782,159 1,723,619 OTHER PROPERTY AND INVESTMENTS Contract termination receivable 111,447 - Trojan decommissioning trust, at market 78,448 68,774 value Corporate Owned Life Insurance, less loans 51,410 44,635 of $ 26,411 and $26,432 Other investments 20,700 24,943 262,005 138,352 CURRENT ASSETS Cash and cash equivalents 19,477 2,241 Accounts and notes receivable 145,372 102,592 Unbilled and accrued revenues 53,317 64,516 Inventories, at average cost 32,903 38,338 Prepayments and other 16,476 15,619 267,545 223,306 DEFERRED CHARGES Unamortized regulatory assets Trojan investment 275,460 301,023 Trojan decommissioning 282,131 311,403 Income taxes recoverable 195,592 217,366 Debt reacquisition costs 28,063 29,576 Conservation investments - secured 80,102 - Energy efficiency programs 11,974 77,945 Other 22,575 24,322 WNP-3 settlement exchange agreement 163,217 168,399 Miscellaneous 27,389 30,286 1,086,503 1,160,320 $ 3,398,212 $ 3,245,597 CAPITALIZATION AND LIABILITIES CAPITALIZATION Common stock equity Common stock, $3.75 par value per share, 100,000,000 shares authorized, 42,758,877 shares outstanding $ 160,346 $ 160,346 Other paid-in capital - net 475,055 466,325 Retained Earnings 292,124 246,282 Cumulative preferred stock Subject to mandatory redemption 30,000 40,000 Long-term debt 933,042 890,556 1,890,567 1,803,509 CURRENT LIABILITIES Long-term debt and preferred stock due 92,559 75,114 within one year Short-term borrowings 92,027 170,248 Accounts payable and other accruals 144,712 132,064 Accrued interest 14,372 15,442 Dividends payable 17,117 14,956 Accrued taxes 31,485 12,870 392,272 420,694 OTHER Deferred income taxes 497,734 525,391 Deferred investment tax credits 47,314 51,211 Deferred gain on contract termination 112,697 - Trojan decommissioning and transition costs 357,844 379,179 Miscellaneous 99,784 65,613 1,115,373 1,021,394 $ 3,398,212 $ 3,245,597 <FN> The accompanying notes are an integral part of these consolidated balance sheets. </FN> </TABLE> 68
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENT OF CASH FLOWS <TABLE> <CAPTION> FOR THE YEARS ENDED DECEMBER 31 1996 1995 1994 (THOUSANDS OF DOLLARS) <S> <C> <C> <C> CASH PROVIDED (USED IN) OPERATIONS: Net Income $ 155,915 $ 92,787 $ 106,118 Non-cash items included in net income: Depreciation and amortization 118,845 102,183 94,140 Amortization of WNP-3 exchange agreement 5,182 4,910 4,695 Amortization of Trojan investment 24,244 24,884 26,738 Amortization of Trojan decommissioning 14,041 13,336 11,220 Amortization of deferred charges - other 5,397 (1,777) 2,712 Deferred income taxes - net (9,071) 1,714 25,720 Regulatory disallowances - 49,567 - Changes in working capital: (Increase) Decrease in receivables (32,025) (11,539) (29,678) (Increase) Decrease in inventories 5,435 (7,189) 3,264 Increase (Decrease) in payables 38,233 13,196 (3,470) Other working capital items - net (841) 1,946 (20,754) Trojan decommissioning expenditures (8,231) (10,927) (3,360) Deferred items - other 34,772 (9,472) 13,987 Miscellaneous - net 5,464 8,871 7,103 357,360 272,490 238,435 INVESTING ACTIVITIES: Utility construction - new resources - (49,096) (87,537) Utility construction - other (184,717) (158,198) (131,675) Energy efficiency programs (12,318) (25,013) (23,745) Nuclear decommissioning trust deposits (15,435) (16,598) (11,220) Nuclear decommissioning trust withdrawals 7,888 13,521 - Other investments (4,431) (8,624) (9,954) (209,013) (244,008) (264,131) FINANCING ACTIVITIES: Short-term debt - net (78,221) 21,650 18,678 Borrowings from Corporate Owned Life Insurance - 4,679 21,731 Long-term debt issued 170,590 147,138 74,631 Long-term debt retired (97,661) (69,445) (29,882) Preferred stock retired (20,000) (79,704) (20,000) Common stock issued - - 41,055 Dividends paid (105,819) (60,149) (73,026) (131,111) (35,831) 33,187 INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 17,236 (7,349) 7,491 CASH AND CASH EQUIVALENTS AT THE BEGINNING OF YEAR 2,241 9,590 2,099 CASH AND CASH EQUIVALENTS AT THE END OF YEAR $ 19,477 $ 2,241 $ 9,590 ______________________________________________________________________________________________________________ Supplemental disclosures of cash flow information Cash paid during the year: Interest, net of amounts capitalized $ 73,396 $ 64,136 $ 55,995 Income taxes 108,277 94,327 44,918 ______________________________________________________________________________________________________________ <FN> The accompanying notes are an integral part of these consolidated statements. </FN> </TABLE> 69
PORTLAND GENERAL ELECTRIC COMPANY AND SUBSIDIARIES NOTES TO FINANCIAL STATEMENTS Certain information, necessary for a sufficient understanding of PGE's financial condition and results of operations, is substantially the same as that disclosed by Portland General in this report. Therefore, the following PGE information is incorporated by reference to Part II of Portland General's Form 10-K on the following page numbers. PAGE Notes to Financial Statements Note 1A. Summary of Significant Accounting Policies 38 Note 2A. Employee Benefits 40 Note 4B. Preferred Stock 44 Note 6A. Long-Term Debt 47 Note 7A. Other Financial Instruments 48 Note 8A. Commitments 49 Note 9A. WNP-3 Settlement Exchange Agreement 51 Note 10A. Jointly-Owned Plant 51 Note 11A. Legal Matters 51 Note 12A. Trojan Nuclear Plant 52 Note 13A. SCE Contract Termination Agreement 53 Management's Discussion and Analysis of Financial Condition and Results of Operations 24 70
NOTE 3A -INCOME TAXES The following table shows the detail of taxes on income and the items used in computing the differences between the statutory federal income tax rate and PGE's effective tax rate (thousands of dollars): <TABLE> <CAPTION> 1996 1995 1994 <S> <C> <C> <C> Income Tax Expense Currently payable Federal $ 98,320 $ 74,089 $ 40,680 State & local 21,963 9,448 8,536 120,283 83,537 49,216 Deferred income taxes Federal (4,500) (11,631) 24,856 State & local (676) (6,648) 4,811 (5,176) (18,279) 29,667 Investment tax credit adjustments (3,897) (5,549) (3,946) $111,210 $ 59,709 $ 74,937 Provision Allocated to: Operations $112,661 $ 89,523 $ 75,314 Other income and deductions (1,451) (29,814) (377) $111,210 $ 59,709 $ 74,937 Effective Tax Rate Computation: Computed tax based on statutory federal income tax rates applied to income before income taxes $ 93,494 $ 53,374 $ 63,369 Flow through depreciation 9,460 7,389 8,080 Regulatory disallowance - 3,456 - State and local taxes - net 11,975 5,552 9,839 State of Oregon refund - (4,346) - Investment tax credits (3,897) (5,549) (3,946) Excess deferred tax (750) (700) (767) Other 928 533 (1,638) $111,210 $ 59,709 $ 74,937 Effective tax rate 41.6% 39.2% 41.4% </TABLE> 71
As of December 31, 1996 and 1995, the significant components of PGE's deferred income tax assets and liabilities were as follows (thousands of dollars): <TABLE> <CAPTION> 1996 1995 <S> <C> <C> DEFERRED TAX ASSETS Plant-in-service $ 64,471 $ 86,721 Other 20,563 23,339 85,034 110,060 DEFERRED TAX LIABILITIES Plant-in-service (414,417) (448,049) Energy efficiency programs (32,026) (30,314) Trojan abandonment (69,315) (54,335) WNP-3 exchange contract (59,302) (60,489) Other (7,897) (42,470) (582,957) (635,657) Less current deferred taxes 189 206 Total $(497,734) $(525,391) </TABLE> PGE has recorded deferred tax assets and liabilities for all temporary differences between the financial statement bases and tax bases of assets and liabilities. NOTE 4A - COMMON STOCK <TABLE> <CAPTION> COMMON STOCK Number of $3.75 Par Other Paid-in Unearned Shares Value Capital Compensation (thousands of dollars) <S> <C> <C> <C> <C> December 31, 1993 40,458,877 $151,721 $433,978 $(17,799) Sales of stock 2,300,000 8,625 32,430 - Redemption of preferred stock - - 2,119 - Repayment of ESOP loan and other - - 1,481 5,203 December 31, 1994 42,758,877 160,346 470,008 (12,596) Redemption of preferred stock - - 3,093 - Repayment of ESOP loan and other - - 338 5,482 December 31, 1995 42,758,877 160,346 473,439 (7,114) Redemption of preferred stock - - 2,195 - Repayment of ESOP loan and other - - 1,677 4,858 December 31, 1996 42,758,877 $160,346 $477,311 $(2,256) </TABLE> COMMON STOCK Portland General is the sole shareholder of PGE common stock. PGE is restricted, without prior OPUC approval, from paying dividends or making other distributions to Portland General to the extent such payment or distribution would reduce PGE's common stock equity capital below 36% of total capitalization. At December 31, 1996, PGE's common stock equity capital was 49% of its total capitalization. 72
NOTE 5A - SHORT-TERM BORROWINGS At December 31, 1996, PGE had total committed lines of credit of $220 million. PGE has a committed facility of $200 million expiring in July 2000. The line of credit has an annual fee of 0.10% and does not require compensating cash balances. The facilities are used primarily as backup for both commercial paper and borrowings from commercial banks under uncommitted lines of credit. At December 31, 1996, there were no outstanding borrowings under the committed facilities. PGE has a $200 million commercial paper facility. Unused committed lines of credit must be at least equal to the amount of PGE's commercial paper outstanding. Commercial paper and lines of credit borrowings are at rates reflecting current market conditions. Short-term borrowings and related interest rates were as follows: <TABLE> <CAPTION> 1996 1995 1994 <S> <C> <C> <C> AS OF YEAR-END: (thousands of dollars) Aggregate short-term debt outstanding Commercial paper $ 83,027 $170,248 $148,598 Bank loans 9,000 - - Weighted average interest rate* Commercial paper 5.6% 6.1% 6.2% Bank loans 7.3 Unused committed lines of credit $200,000 $200,000 $200,000 FOR THE YEAR ENDED: Average daily amounts of short-term debt outstanding Commercial paper 158,259 111,366 126,564 Bank loans $ 5,265 $ 206 $ 1,273 Weighted daily average interest rate* Commercial paper 5.6 6.3 4.6 Bank loans 5.7% 6.5% 4.3% Maximum amount outstanding during the year $251,462 $170,248 $159,482 <FN> * Interest rates exclude the effect of commitment fees, facility fees and other financing fees. </FN> </TABLE> 73