ITEM 1. BUSINESS
HEI
HEI was incorporated in 1981 under the laws of the State of Hawaii and is a holding company with subsidiaries engaged in the electric utility, financial services, freight transportation, real estate development and other businesses, in each case primarily or exclusively in the State of Hawaii. HEI's predecessor, HECO, was incorporated under the laws of the Kingdom of Hawaii (now the State of Hawaii) on October 13, 1891.
As a result of a 1983 corporate reorganization, HECO became an HEI subsidiary and common shareholders of HECO became common shareholders of HEI. HECO and its subsidiaries, MECO and HELCO, are regulated operating public utilities providing the only public utility electric service on the islands of Oahu, Maui, Lanai, Molokai and Hawaii. HEI also owns directly or indirectly the following nonelectric public utility subsidiaries which comprise its diversified companies: HEIDI and its subsidiary, ASB, and ASB's subsidiaries; HTB and its subsidiary; MPC and its subsidiaries; HEIIC; and LVI. HEIDI is also the holder of record of the common stock of HIG, which was acquired in 1987 and provided property and casualty insurance primarily in Hawaii. HIG is currently in rehabilitation proceedings and it is expected that HEIDI will relinquish all ownership rights in HIG and its subsidiaries during 1994. See "Discontinued operations--The Hawaiian Insurance & Guaranty Co., Limited."
ASB was acquired in 1988, is the second largest savings bank in Hawaii as measured by total assets as of September 30, 1993, and has 45 retail branches as of December 31, 1993. HTB was acquired in 1986 and provides ship assist and charter towing services and owns YB, a regulated intrastate public carrier of waterborne freight among the Hawaiian Islands. MPC was formed in 1985 and develops and invests in real estate. HEIIC was formed in 1984 and is a passive investment company which has sold substantially all of its investments in marketable securities over the last few years and currently plans no new investments. In March of 1993, pursuant to the decision made at the end of the third quarter of 1992, the stock of HERS, formerly an HEI wind energy subsidiary, was sold to The New World Power Corporation and LVI became a direct subsidiary of HEI. See "Discontinued operations -- Hawaiian Electric Renewable Systems, Inc."
The financial information about the Company's industry segments is incorporated herein by reference to page 28 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
For additional information about the Company, reference is made to "Management's Discussion and Analysis of Financial Condition and Results of Operations," incorporated herein by reference to pages 29 to 39 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
RATING AGENCIES' ACTIONS
On February 8, 1993, Standard & Poor's (S&P) lowered HEI's and HECO's long- term credit ratings. S&P lowered HEI's medium-term note credit rating to BBB from BBB+, citing HECO's reduced credit worthiness and the write-off of HEI's investment in HIG. S&P noted that considerable political and financial uncertainty will remain until the ultimate impact of HIG on HEI is determined. S&P maintained a negative rating outlook reflecting downward pressure on HEI's and HECO's earnings which could intensify in the absence of adequate rate relief for HECO. HEI's commercial paper rating of A-2 was reaffirmed.
On February 26, 1993, Duff & Phelps Credit Rating Co. (D&P) lowered HEI's medium-term note rating to BBB+ from A- due to the continuing uncertainty surrounding HEI and its decision to cease operations at HIG. D&P noted that the extent of additional financial responsibility ultimately required, if any, is unknown, which adds risk that was not reflected in D&P's prior rating. HEI's commercial paper rating of Duff 1- (one-minus) was reaffirmed.
On February 11, 1994, in response to HEI's announcement that it signed an agreement to settle the lawsuit filed by the Hawaii Insurance Commissioner and Hawaii Insurance Guaranty Association against HEI relating to losses sustained by HIG from Hurricane Iniki, D&P stated that the settlement and additional charge to income fit within the assumptions pertinent to D&P's current ratings for HEI. The settlement agreement is subject to court approval. (See "Discontinued operations -- The Hawaiian Insurance & Guaranty Co., Ltd. for a further discussion on the settlement agreement.)
On April 28, 1993, Moody's Investor Service (Moody's) confirmed the credit ratings of HEI, citing HEI's plans to issue additional common equity in order to rebalance its capital structure. Moody's stated that its concerns regarding a lawsuit associated with HIG and stemming from Hurricane Iniki are partially mitigated by the possible long period before a fully litigated decision is reached. The confirmation concluded a review for possible downgrade initiated on December 4, 1992.
In October 1993, S&P completed its review of the U.S. investor-owned electric utility industry and concluded that more stringent financial risk standards are appropriate to counter mounting business risk. "S&P believes the industry's credit profile is threatened chiefly by intensifying competitive pressures," the agency said in a statement. It also cited sluggish demand expectations, slow earnings growth prospects, high dividend payouts and environmental cost pressures. Under the new guidelines, S&P rated HECO's business position as average.
As of February 11, 1994, HEI's and HECO's S&P, Moody's and D&P security ratings were as follows:
N/A Not applicable.
(1) S&P. Debt rated BBB or BBB+ is regarded as having an adequate capacity to pay interest and repay principal. Whereas it normally exhibits adequate protection parameters, adverse economic conditions or changing circumstances are more likely to lead to a weakened capacity to pay interest and repay principal for debt in this category than in higher rated categories.
The ratings may be modified by the addition of a plus or minus sign to show relative standing within the major categories.
A commercial paper rating is a current assessment of the likelihood of timely payment of debt having an original maturity of no more than 365 days. Commercial paper rated A-2 indicates that capacity for timely payment on issues is satisfactory.
(2) Moody's. Bonds which are rated Baa2 or Baa1 are considered as medium grade obligations, i.e., they are neither highly protected nor poorly secured. Interest payment and principal security appear adequate for the present but certain protective elements may be lacking or may be characteristically unreliable over any great length of time. Such bonds lack outstanding investment characteristics and in fact have speculative characteristics as well.
Bonds which are rated A3 possess many favorable investment attributes and are to be considered as upper medium grade obligations. Factors giving security to principal and interest are considered adequate but elements may be present which suggest a susceptibility to impairment sometime in the future.
Preferred stock rated baa1 is considered to be a medium grade preferred stock, neither highly protected nor poorly secured. Earnings and asset protection appear adequate at present but may be questionable over a great length of time.
Numeric modifiers are added to debt and preferred stock ratings. Numeric modifier 1 indicates that the security ranks in the higher end of its generic rating category and numeric modifier 2 indicates a mid-range ranking.
Commercial paper rated P-2 is considered to have a strong ability for repayment of senior short-term obligations. This will normally be evidenced by the following characteristics: a) leading market positions in well- established industries, b) high rates of return on funds employed, c) conservative capitalization structure with moderate reliance on debt and ample asset protection, d) broad margins in earnings coverage of fixed financial charges and high internal cash generation and e) well established access to a range of financial markets and assured sources of alternate liquidity. Earnings trends and coverage ratios, while sound, may be more subject to variation. Capitalization characteristics, while still appropriate, may be more affected by external conditions. Ample alternate liquidity is maintained.
(3) Duff & Phelps. Debt rated BBB+ is regarded as having below average protection factors, but still considered sufficient for prudent investment. There may be considerable variability in risk during economic cycles.
Debt rated A or A- is considered to have protection factors that are average but adequate. However, risk factors are more variable and greater in periods of economic stress.
Commercial paper rated Duff 1- indicates a high certainty of timely payment. Liquidity factors are strong and supported by good fundamental protection factors. Risk factors are very small.
Each security rating listed above is not a recommendation to buy, sell or hold securities. Each rating may be subject to revision or withdrawal at any time by the assigning rating organization and should be evaluated independently of any other rating.
Neither HEI nor HECO management can predict with certainty future rating agency actions or their effects on the future cost of capital of HEI or HECO.
ELECTRIC UTILITY
HECO AND SUBSIDIARIES AND SERVICE AREAS
HECO, MECO and HELCO are regulated operating electric public utilities engaged in the production, purchase, transmission, distribution and sale of electricity on the islands of Oahu; Maui, Lanai and Molokai; and Hawaii, respectively. HECO acquired MECO in 1968 and HELCO in 1970.
In 1993, the electric utilities contributed approximately 77% of HEI's consolidated revenues from continuing operations and approximately 76% of HEI's consolidated operating income from continuing operations, excluding unallocated corporate expenses and eliminations. At December 31, 1993, the assets of the electric utilities represented approximately 38% of the total assets of the Company, excluding assets at the corporate level and eliminations. For additional information about the electric utilities, see "Management's Discussion and Analysis of Financial Condition and Results of Operations," incorporated herein by reference to pages 29 to 39 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a) and pages 3 to 9 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
The islands of Oahu, Maui, Lanai, Molokai and Hawaii have a combined population estimated at 1,104,000, or approximately 95% of the population of the State of Hawaii, and cover a service area of 5,766 square miles. The principal communities served include Honolulu (on Oahu), Wailuku and Kahului (on Maui) and Hilo and Kona (on Hawaii). The service areas also include numerous suburban communities, resorts, U.S. Armed Forces installations and agricultural operations.
HECO, MECO and HELCO have nonexclusive franchises from the state covering certain areas and authorizing them to construct, operate and maintain facilities over and under public streets and sidewalks. HECO's franchise covers the City & County of Honolulu, MECO's franchises cover the islands of Maui, Lanai and Molokai in the County of Maui and the small County of Kalawao on the island of Molokai, and HELCO's franchise covers the County of Hawaii. Each of these franchises will continue in effect for an indefinite period of time until forfeited, altered, amended or repealed.
SALES OF ELECTRICITY
HECO, MECO and HELCO provide the only electric public utility service on the islands they serve. The following table sets forth the numberEof their electric customer accounts as of December 31, 1993, 1992 and 1991 and their electric sales revenues for each of the years then ended:
(1) Includes the effect of the change in the method of estimating unbilled kilowatthour sales and revenues.
Revenues from the sale of electricity in 1993 were from the following types of customers in the proportions shown:
Total electricity sales for all three utilities in 1993 were 8,325 million kilowatthours (KWH), a 0.1% decrease from 1992 sales. The relatively low sales in 1993 reflect cooler weather, the slowing in the state economy and conservation efforts.
Approximately 10% of consolidated operating revenues of HECO and its subsidiaries was derived from the sale of electricity to various federal government agencies in 1993, 1992 and 1991. HECO's fifth largest customer, the Naval Base at Barbers Point, Oahu, is expected to be closed within the next four to five years. On March 8, 1994, President Clinton signed an Executive Order which mandates that each federal agency develop and implement a program with the intent of reducing energy consumption by 30% by the year 2005 to the extent that these measures are cost-effective. The 30% reductions will be measured relative to the agency's 1985 energy use. HECO is working with various Department of Defense installations to implement demand-side management programs which will help them achieve their energy reduction objectives. It is expected that several Department of Defense installations will sign a Basic Ordering Agreement under which HECO will implement the energy conservation projects. Neither HEI nor HECO management can predict with certainty the impact of President Clinton's Executive Order on the Company's or consolidated HECO's future results of operations.
SELECTED CONSOLIDATED ELECTRIC UTILITY OPERATING STATISTICS
* Sum of the peak demands on all islands served, noncoincident and nonintegrated. ** Includes the effect of the change in the method of estimating unbilled KWH sales and revenues. *** Excluding the effect of the change in the method of estimating unbilled KWH sales and revenues, losses and system uses would have been 5.6%.
GENERATION STATISTICS
The following table contains certain generation statistics as of December 31, 1993, and for the year ended December 31, 1993. The capability available for operation at any given time may be less than the generating capability shown because of temporary outages for inspection, maintenance, repairs or unforeseen circumstances.
(1) HECO units at normal ratings less 14.0 MW due to capability restrictions, and MECO and HELCO units at reserve ratings. (2) Noncoincident and nonintegrated. (3) Independent power producers - 180.0 MW (Kalaeloa), 180.0 MW (AES-BP) and 46.0 MW (HRRV). (4) Non-utility generation-MECO: 16.0 MW (Hawaiian Commercial & Sugar Company) and HELCO: 25.0 MW (Puna Geothermal Ventures), 18.0 MW (HCPC) and 8.0 MW (Hamakua Sugar Company). Hamakua Sugar Company filed for bankruptcy in 1992 and is expected to discontinue operations in 1994.
REQUIREMENTS AND PLANS FOR ADDITIONAL GENERATING CAPACITY
Each of the three utilities completed its first Integrated Resource Plan (IRP) in 1993. These plans identified and evaluated a mix of resources to meet near- and long-term consumer energy needs in an efficient and reliable manner at the lowest reasonable cost. The IRPs include demand-side management (DSM) programs to reduce load and fuel consumption and consider the impact on the environment, culture, community lifestyles and economy of the state.
On July 1, 1993, HECO filed its first Integrated Resource Plan with the Hawaii Public Utilities Commission (PUC). This plan was subsequently modified in January 1994 due to a change in load forecast. The decrease in the load forecast, the inclusion of the impact of proposed DSM programs, and the deferred retirement of Honolulu Unit Nos. 8 & 9 until 2004, allowed HECO to defer its next generating unit addition to the year 2005. In its plan, HECO recommended that this next generating unit be a coal-fired atmospheric fluidized bed combustion unit to provide a fuel alternative to oil. Because of the uncertainty of the impact of new environmental regulations and the political pressure to remove Honolulu Power Plant from downtown Honolulu earlier than the 2004 time frame, alternate plans are being developed to add generating capacity earlier if necessary.
MECO completed construction of its first 58-MW dual-train combined-cycle facility in 1993 at a cost of $78 million. On December 15, 1993, MECO filed its first IRP with the PUC. MECO plans to add a second dual-train combined-cycle unit with the addition of a 20-MW combustion turbine (CT) in 1996, another 20-MW CT in 1999 and the conversion of these units into a 58-MW combined-cycle unit with the addition of an 18-MW steam turbine in 2000. MECO's Molokai Division plans to purchase three 2.2-MW diesel units; two in 1995 and one in 1996. MECO's Lanai Division plans to add three 2.2-MW diesel units in 1996.
On October 15, 1993, HELCO filed its first IRP with the PUC. HELCO has a power purchase agreement with Puna Geothermal Ventures (PGV) for 25 MW which became a firm source of power on June 27, 1993. Hamakua Sugar Company filed for bankruptcy in 1992 and ceased power production on May 7, 1993, but resumed on July 15, 1993, under a court-approved harvest plan which is expected to continue over a period of 10 to 16 months. It is expected that Hamakua's capacity of 8MW will be unavailable to HELCO by the end of 1994. Hilo Coast Processing Company (HCPC) will discontinue harvesting sugar cane in late 1994 and has indicated that it may increase its power export capability and switch its primary fuel from bagasse (sugarcane waste) to coal. This would require a new modified power purchase agreement, which would be subject to PUC approval. For capacity planning, HELCO assumed that HCPC would continue to provide 18 MW of firm power to HELCO under the existing power purchase agreement. The installation of a phased combined-cycle unit is proceeding. The service date for the first CT, CT-4, is scheduled for July 1, 1995 pending Conservation District Use Application approval at the existing Keahole Power Plant site. Although capacity after CT-4 is not required until April 1996, CT-5 is scheduled to be installed immediately after CT-4 in September 1995 based on economies of the earlier schedule which allows HELCO to use the same construction contract as CT-4. In addition, the earlier schedule permits HELCO to proceed with the planned retirements of its older, less efficient units and to mitigate uncertainties with respect to deliveries from HELCO's power purchase producers. Conversion of CT-4 and CT-5 to combined-cycle operation with the addition of a steam unit, ST-7 is expected to occur by October 1997.
NONUTILITY GENERATION
The Company has supported state and federal energy policies which encourage the development of alternate energy sources that reduce dependence on fuel oil. Alternate energy sources range from wind, geothermal and hydroelectric power, to energy produced by the burning of bagasse. Other nonoil projects include a generating unit burning municipal waste and a fluidized bed unit burning coal.
HECO currently has three major power purchase agreements. In general, HECO's payments under these power purchase agreements are based upon available capacity and energy. Payments for capacity generally are not required if the contracted capacity is not available, and payments are reduced, under certain conditions, if available capacity drops below contracted levels. In general, the payment rates for capacity have been predetermined for the terms of the agreements. The energy charges will vary over the terms of the agreements and HECO may pass on changes in the fuel component of the energy charges to customers through energy cost adjustment clauses in its rate schedules. HECO does not operate nor does it participate in the operation of any of the facilities that provide power under the three agreements. Title to the facilities does not pass to HECO upon expiration of the agreements, and the agreements do not contain bargain purchase options with respect to the facilities.
In March 1988, HECO entered into a power purchase agreement with AES Barbers Point, Inc. (AES-BP), a Hawaii-based cogeneration subsidiary of Applied Energy Services, Inc. (AES) of Arlington, Virginia. The agreement with AES-BP, as amended in August 1989, provides that, for a period of 30 years, HECO will purchase 180 MW of firm capacity, under the control of HECO's system dispatcher. The AES-BP 180-MW coal-fired cogeneration plant utilizes a "clean coal" technology and became operational in September 1992. The facility is designed to sell sufficient steam to qualify under the Public Utility Regulatory Policies Act of 1978 (PURPA) as an unregulated cogenerator.
HECO entered into an agreement in October 1988 with Kalaeloa Partners, L.P. (Kalaeloa) a limited partnership whose sole general partner is an indirect, wholly owned subsidiary of ASEA Brown Boveri, Inc., which has guaranteed certain of Kalaeloa's obligations and, through affiliates, has contracted to design, build, operate and maintain the facility. The agreement with Kalaeloa, as amended, provides that HECO will purchase 180 MW of firm capacity for a period of 25 years. The Kalaeloa facility, which was completed in the second quarter of 1991, is a combined-cycle operation, consisting of two oil-fired combustion turbines and a steam turbine which utilizes waste heat from the combustion turbines. The facility is designed to sell sufficient steam to qualify under PURPA as an unregulated cogenerator.
HECO has also entered into a power purchase contract and a firm capacity amendment with Honolulu Resource Recovery Venture (HRRV), which has built a 60- MW refuse-fired plant. The HRRV unit began to provide firm energy in the second quarter of 1990 and currently supplies HECO with 46 MW of firm capacity.
The PUC has approved and allowed rate recovery for the costs related to HECO's three major power purchase agreements, which provide a total of 406 MW of firm capacity, representing 24% of HECO's total generating and firm purchased capability on the island of Oahu as of December 31, 1993. Assuming that the three independent power producers operate at the minimum availability criteria in the power purchase agreements, aggregate fixed capacity charges under the three major agreements are expected to be between approximately $95 million and $98 million annually from 1994 through 2015, $73 million in 2016, between $59 million and $62 million annually from 2017 through 2021, and $46 million in 2022.
As of December 31, 1993, HELCO and MECO had power purchase agreements for 51 MW and 16 MW of firm capacity, respectively, representing 25% and 7% of their respective total generating and firm purchased capabilities. Assuming that the independent power producers operate at the minimum availability criteria in the power purchase agreements, aggregate fixed capacity charges are expected to be approximately $9 million annually in 1994 and 1995, $8 million from 1996 through 1999, $6 million from 2000 through 2002 and $4 million annually from 2003 through 2028.
HELCO has a power purchase agreement with PGV for 25 MW of firm capacity. PGV, an independent geothermal power producer which experienced substantial delays in commencing commercial operations, passed an acceptance test in June 1993 and is now considered to be a firm capacity source for 25 MW.
HERS owned and operated a windfarm on the island of Oahu and sold the electricity it generated to HECO. The windfarm consisted of 14 600-KW and one 3,200-KW wind turbines. In March 1993, HEI sold the stock of HERS to The New World Power Corporation with the power purchase agreements between HERS and HECO continuing in effect. The stock of LVI was transferred to HEI prior to the sale of HERS. LVI's windfarm on the island of Hawaii consists of 54 20-KW and 34 17.5-KW wind turbines. LVI sells its electricity to HELCO and the Hawaii County Department of Water Supply. See "Discontinued operations--Hawaiian Electric Renewable Systems, Inc."
Hamakua Sugar Company has been operating under Federal Bankruptcy Court protection since August 1992. Hamakua is presently in a Chapter 11 bankruptcy proceeding and is conducting a final sugar cane harvest over a period of 10 to 16 months, which began in July 1993. During the harvest, Hamakua has agreed to supply HELCO with 8 MW of firm capacity under an amendment to HELCO's existing power purchase agreement.
HELCO has a power purchase agreement with Hilo Coast Processing Company (HCPC) for 18 MW of firm capacity. On July 31, 1992, C. Brewer and Company, Limited publicly announced that Mauna Kea Agribusiness, which is the primary supplier of sugar cane processed by HCPC, will begin converting its acreage to macadamia nuts, eucalyptus trees and other diversified crops as of November 1, 1992, and will discontinue harvesting sugar cane in late 1994. The announcement also indicated that, after the last sugar harvest, HCPC's primary fuel would be coal, supplemented by macadamia nut husks and other biomass material. It is HELCO's understanding that HCPC plans to continue supplying power after 1994 (and may
even be in a position to supply more than 18 MW after its sugar processing operations are discontinued), and HELCO has assumed that HCPC's commitment to provide 18 MW of capacity will remain in effect for the current term of the contract, which ends December 31, 2002.
BHP Petroleum Americas (Hawaii) Inc. (BHPH), formerly Pacific Resources, Inc., stopped hauling heavy fuel oil from Oahu to the other Hawaiian Islands at the end of May 1992. This may continue to affect the ability of the sugar companies, which relied on the oil delivered by BHPH, to supply power to HELCO and MECO. In light of this situation, some of the sugar companies have or are considering conversion to alternative fuels.
Although it currently appears that heavy fuel oil will continue to be commercially available, in the event of the unavailability of heavy fuel oil, certain nonutility generators of electricity with contracts with HELCO and MECO may need to use a more expensive alternative fuel such as diesel. The legislation amending the state Environmental Response Law allows these producers, subject to PUC approval, to charge the utilities rates for energy purchases reflecting their higher fuel costs rather than the currently approved rates and, in turn, permits each utility to pass on the increases to its customers through an automatic rate adjustment clause. To minimize the rate increase of any one utility, the legislation permits the PUC, under certain conditions, to utilize a statewide automatic adjustment clause. In 1993, HELCO received PUC approval for recovery of the higher fuel costs incurred by HCPC.
FUEL OIL USAGE AND SUPPLY
All rate schedules of the Company's electric utility subsidiaries contain energy cost adjustment clauses whereby the charges for electric energy (and consequently the revenues of the subsidiaries generally) automatically vary with the weighted average price paid for fuel oil and certain components of purchased energy, and the relative amounts of company-generated and purchased power. Accordingly, changes in fuel oil and purchased energy costs are passed on to customers. See "Electric utility -- Rates."
HECO's steam power plants burn low sulfur residual fuel oil. HECO's combustion turbines (peaking units) on Oahu burn diesel fuel. MECO and HELCO burn medium sulfur industrial fuel oil in their steam generating plants and diesel fuel in their diesel engine and combustion turbine generating units.
In the second half of 1993, HECO concluded agreements with Chevron, U.S.A., Inc. (CUSA) and BHP Petroleum Americas Refining Inc. (BHP), formerly Hawaiian Independent Refinery, Inc., to purchase supplies of low sulfur fuel oil for a two-year term commencing January 1, 1994. The PUC approved these agreements and issued a final order in December 1993 permitting inclusion of costs under the contracts in the energy cost adjustment clause. HECO pays market-related prices for fuel purchases made under these contracts.
HECO, MECO and HELCO have extended a contract with CUSA under which they will purchase No. 2 diesel fuel over a period of two years beginning January 1, 1994. The Company's utility subsidiaries jointly purchase medium sulfur residual fuel oil under this same contract and together purchase diesel fuel and residual fuel oil under a recently extended contract with BHP. The contracts with CUSA and BHP have been approved by the PUC which issued a final order in December 1993 permitting inclusion of costs under the contracts in the respective utility's energy cost adjustment clause. Diesel fuel and residual fuel oil supplies purchased under these agreements are priced on a market-related basis.
The diesel fuel supplied to the Lanai Division of MECO is provided under an agreement with the CUSA jobber (i.e., wholesale merchant) on Lanai. The Molokai Division of MECO receives diesel fuel supplies through the joint purchase contract between HECO, MECO and HELCO and CUSA referred to above.
The low sulfur residual fuel oil burned by HECO on Oahu is derived primarily from Indonesian and domestic crude oils. The medium sulfur residual fuel oil burned by MECO and HELCO is generally derived from domestic crude oil.
The fuel oil commitments information in Note 11 to HECO's Consolidated Financial Statements is incorporated herein by reference to page 24 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
The following table sets forth the average costs of fuel oil used to generate electricity in the years 1993, 1992 and 1991:
The average cost per barrel of fuel oil used to generate electricity for HECO, MECO and HELCO reflects the different fuel mix of each company. HECO uses primarily low sulfur residual fuel oil, MECO uses a significant amount of diesel fuel and HELCO uses primarily medium sulfur residual fuel oil and a lesser amount of diesel fuel. In general, medium sulfur fuel oil is the least costly per barrel and diesel fuel is the most expensive. During 1993, the prices of diesel fuel and low sulfur oil declined, while the price of medium sulfur fuel oil displayed no sustained trend.
HTB was contractually obligated to ship heavy fuel oil for HELCO and MECO through December 1993. Effective December 31, 1993, HTB exited the heavy fuel oil shipping business. See "Regulation and other matters -- Environmental regulation -- Water quality controls." HELCO and MECO carried out a bidding process to determine who would ship heavy fuel oil beyond 1993. Several bids were received and evaluated and two contracts have been signed with Hawaiian Interisland Towing, Inc., subject to PUC approval (which has been obtained on an interim basis). HELCO and MECO have also begun to convert their generating plants from burning heavy fuel oil to burning either heavy fuel oil or diesel fuel in the event heavy fuel oil is no longer available in the future. Diesel fuel does not pose the same environmental liability concerns as heavy fuel oil, but it is more expensive and the use of diesel fuel could significantly increase HELCO's and MECO's electric rates. Conversion would assure HELCO and MECO more flexibility by permitting use of another type of fuel besides heavy fuel oil.
In 1994, it is estimated that 75% of the net energy generated and purchased by HECO and its subsidiaries will come from oil, down from 77% in 1993. Failure by the Company's oil suppliers to provide fuel pursuant to the supply contracts and/or extremely high fuel prices could adversely affect HECO and its subsidiaries' and the Company's financial condition and results of operations.
RATES
HECO, MECO and HELCO are subject to the regulatory jurisdiction of the PUC with respect to rates, standards of service, issuance of securities, accounting and certain other matters. See "Regulation and other matters -- Electric utility regulation."
All rate schedules of HECO and its subsidiaries contain an energy cost adjustment clause to reflect changes in the price paid for fuel oil and certain components of purchased power, and the relative amounts of company-generated and purchased power. Under current law and practices, specific and separate PUC approval is not required for each rate change pursuant to automatic rate adjustment clauses previously approved by the PUC. Rate increases, other than pursuant to such automatic adjustment clauses, require the prior approval of the PUC after public and contested case hearings. PURPA requires the PUC to periodically review the energy cost adjustment clauses of electric and gas utilities in the state, and such clauses, as well as the rates charged by the utilities generally, are subject to change.
The PUC has broad discretion in its regulation of the rates charged by the Company's utility subsidiaries. Any adverse decision by the PUC concerning the level or method of determining electric utility rates, the authorized returns on equity or other matters or any delay in rendering a decision in a rate proceeding could have a material adverse effect on consolidated HECO's and the Company's financial condition and results of operations. Upon a showing of probable entitlement, the PUC is required to issue an interim decision in a rate case within 10 months from the date of filing a complete application if the evidentiary hearing is completed -- subject to extension for 30 days if the evidentiary hearing is not completed. However, there is no time limit for rendering a final decision.
HECO
Rate increase. On July 29, 1991, HECO applied to the PUC for permission to increase electric rates on the island of Oahu in 1992. The rates requested would have provided approximately $138 million in annual revenues, or approximately 26.4% over HECO's then existing rates, based on January 1, 1992 fuel oil and purchased energy prices. The request was based on a 13.5% return on average common equity.
On June 30, 1992, HECO received a final decision and order from the PUC. The decision and order granted an increase of $124 million in annual revenues, based on a 13.0% return on average common equity.
The increase took effect in steps in 1992. $28 million of the $124 million increase was granted in the interim decision effective April 1, 1992. A step increase of $2.3 million in annual revenues became effective July 8, 1992. Approximately $93 million of the $124 million increase represented a pass-through of costs when HECO began purchasing generating capacity from independent power producer AES-BP in September 1992. The increase is subject to possible adjustments for postretirement benefits other than pensions.
The major reason for the difference between revenues requested in HECO's application and the revenues granted by the PUCO's final decision and order relates to postretirement benefits other than pensions expense. HECO requested $11 million in annual revenues to cover the additional expense required under SFAS No. 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions." The PUC has opened a separate generic docket on postretirement benefits other than pensions and indicated that the total increase granted in the final decision and order will be adjusted to reflect its decision in that docket. The PUC has not yet issued a final decision and order in this generic docket. The information on postretirement benefits other than pensions in Note 10 to HECO's Consolidated Financial Statements is incorporated herein by reference to pages 23 to 24 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
Pending rate requests. On July 26, 1993, HECO applied to the PUC for permission to increase electric rates, using a 1994 test year and requesting rates designed to produce an increase of approximately $62 million in annual revenues over the revenues provided by rates currently in effect. HECO subsequently revised its rate request from $62 million to approximately $54 million by the close of the evidentiary hearings held in March 1994. The revision resulted primarily from rescheduling certain capital projects from 1994 to 1995, and agreements among the parties with respect to certain issues. The requested increase, as revised, is based on a 12.75% return on average common equity and is needed to cover rising operating costs and the cost of new capital projects to maintain and improve service reliability. In addition, the requested increase includes approximately $9 million for costs arising out of the change to accrual accounting for postretirement benefits other than pensions, and the amount of the required increase will be reduced to the extent that rate relief for these costs is received in another proceeding. The information on postretirement benefits other than pensions in Note 10 to HECO's Consolidated Financial Statements is incorporated herein by reference to pages 23 to 24 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b). HECO has requested an interim increase of approximately $39 million by April 1994, and the remainder of the requested increase in steps in 1994.
On December 27, 1993, HECO applied to the PUC for permission to increase electric rates, using a 1995 test year and requesting rates designed to produce an increase of approximately $44 million in annual revenues over revenues provided by the initially proposed 1994 rates. As a result of revisions to the rate increase requested in 1994, the requested increase would be approximately $52 million over revenues provided by proposed 1994 rates. The increase requested by HECO is based on a 12.3% return on average common equity. The rate request based on a 1995 test year is in addition to HECO's pending $54 million rate increase requested for 1994. Both requests combined represent a 16.7% increase, or $106 million, over present rates.
Revenue from the proposed increase would be used in part to cover the costs of major transmission and distribution projects on Oahu, including an important transmission corridor to connect power plants on the island's west side with customers throughout Oahu.
The 1995 application includes requests for approximately $15 million for additional expenses associated with proposed changes in depreciation rates and methods and $7 million to establish a self-insured property damage reserve for transmission and distribution property in the event of catastrophic disasters. HECO seeks to establish the requested reserve because HECO is self-insured for damage to its transmission and distribution property, except substations. (HECO's subsidiaries are similarly self-insured.) Also, a
heightened concern for the risk of loss of this property has grown out of the loss of virtually the entire transmission and distribution system of the unaffiliated electric utility serving the island of Kauai as a result of Hurricane Iniki in September 1992. HECO anticipates that evidentiary hearings on the 1995 application will be held in late 1994.
HELCO
Rate increase. On July 31, 1991, HELCO asked the PUC to increase rates by $7.5 million a year, or 7.5%. The request was based on a 13.5% return on average common equity and a 1992 test year. On October 2, 1992, HELCO received a final decision and order from the PUC authorizing a total increase of $3.9 million in annual revenues, based on a 13.0% return on average common equity.
HELCO's original request for rate increase included approximately $1.9 million to cover the increased cost of postretirement benefits other than pensions, and this request will be considered in a separate generic docket. The PUC has not yet issued a final decision and order in this generic docket. The information on postretirement benefits other than pensions in Note 10 to HECO's Consolidated Financial Statements is incorporated herein by reference to pages 23 to 24 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b). Other rate adjustments could be made based on the results of the PUC's study of HELCO's service reliability. See "Item 3. Legal Proceedings--HELCO reliability investigation."
Pending rate request. On November 30, 1993, HELCO applied to the PUC for permission to increase electric rates, using a 1994 test year and requesting rates designed to produce an increase of approximately $15.8 million in annual revenues, or 13.4%, over revenues provided by rates currently in effect. The requested increase is based on a 12.4% return on average common equity and is needed to cover plant, equipment and operating costs to maintain and improve service and provide reliable power for its customers. HELCO anticipates that evidentiary hearings will be held later this year.
MECO
Pending rate request. In November 1991, MECO filed a request to increase rates by approximately $18.3 million annually, or approximately 17% above the rates in effect at the time of the filing, in several steps. Most of the proposed increase reflected the costs of adding a 58-MW combined-cycle generating unit on Maui in three phases and the costs related to the change in the method of accounting for postretirement benefits other than pensions. Evidentiary hearings were held in January 1993. At the conclusion of the hearings, MECO's final requested increase was adjusted to approximately $11.4 million annually, or approximately 10%, in several steps in 1993. The decrease in the requested rate increase resulted primarily from a reduced cost of capital, lower administrative and general expenses and other revisions to MECO's estimated revenue requirements for the 1993 test year used in the rate case. MECO's revised request reflected a return on average common equity of 13.0%.
On January 29, 1993, MECO received an initial interim decision authorizing an annual increase of $2.8 million, or 2.4%, effective February 1, 1993. This interim decision covered, among other things, the costs associated with the first phase of the 58-MW combined-cycle generating unit, which had been placed in service on May 1, 1992. In the interim decision the PUC used a rate of return on average common equity of 12.75% in light of a drop in interest rates and changes in economic conditions since HECO's and HELCO's most recent rate case decisions and orders. The PUC also stated that MECO is less dependent on purchased power than HECO or HELCO, and that MECO's return on average common equity will be more extensively reviewed for purposes of the final decision and order. On May 7, 1993, MECO received a second interim decision authorizing a step increase of an additional $4 million in annual revenues, or 3.6%, effective May 8, 1993. This step increase covered the estimated annual costs of the second phase of the 58-MW combined-cycle generating unit, a combustion turbine which was placed into service on May 1, 1993. On October 21, 1993, MECO received a third interim decision authorizing a step increase of an additional $1 million in annual revenues, or 0.9%, effective October 21, 1993. This step increase covered the estimated annual costs of the third and final phase of the combined-cycle generating unit, which was placed into service on October 1, 1993. On December 9, 1993, MECO received a fourth interim decision authorizing a step increase of an additional $0.4 million in annual revenues, effective December 10, 1993, to cover wage increases that became effective on November 1, 1993. These interim increases are subject to refund with interest, pending the final outcome of the case. MECO's management cannot predict with certainty when a final decision in MECO's rate case will be rendered or the amount of the final rate increase that will be granted.
SAVINGS BANK -- AMERICAN SAVINGS BANK, F.S.B.
GENERAL
ASB was granted a charter as a federal savings bank in January 1987. Prior to that time, ASB operated as the Hawaii division of American Savings & Loan Association of Salt Lake City, Utah since 1925. At September 30, 1993, ASB's total assets were $2.5 billion and it was the second largest savings and loan institution in Hawaii based on total assets.
ASB was acquired by the Company for approximately $115 million on May 26, 1988. The acquisition was accounted for using the purchase method of accounting. Accordingly, tangible assets and liabilities were recorded at their estimated fair values at the acquisition date. The acquisition was approved by the Federal Home Loan Bank Board (FHLBB) which required HEI to enter into a Regulatory Capital Maintenance/Dividend Agreement (the FHLBB Agreement). Under the FHLBB Agreement, HEI agreed that ASB's regulatory capital would be maintained at a level of at least 6% of ASB's total liabilities, or at such greater amount as may be required from time to time by regulation. Under the FHLBB Agreement, HEI's obligation to contribute additional capital was limited to a maximum aggregate amount of approximately $65.1 million. HEI elected to contribute additional capital of $0.8 million and $24.0 million to ASB during 1993 and 1992, respectively. The FHLBB Agreement also included limitations on ASB's ability to pay dividends. Under the Financial Institutions Reform, Recovery and Enforcement Act of 1989 (FIRREA), the regulations of the FHLBB and the FHLBB Agreement were transferred to the Office of Thrift Supervision (OTS). Effective December 23, 1992, ASB was granted a release from the dividend limitations imposed under the FHLBB Agreement. ASB is subject to the OTS regulations for dividends and other distributions applicable to financial institutions regulated by the OTS.
ASB acquired First Nationwide Bank's Hawaii branches and deposits on October 6, 1990. The acquisition increased ASB's statewide retail branch network from 36 to 45 branches and its deposit base by $247 million, and provided approximately $239 million in cash.
ASB's earnings depend primarily on its net interest income -- the difference between the interest income earned on interest-earning assets (loans receivable, mortgage-backed securities and investments) and the interest expense incurred on interest-bearing liabilities (deposit liabilities and borrowings). Deposits traditionally have been the principal source of ASB's funds for use in lending, meeting liquidity requirements and making investments. ASB also derives funds from receipt of interest and principal on outstanding loans receivable, borrowings from the Federal Home Loan Bank (FHLB) of Seattle, securities sold under agreements to repurchase and other sources, including collateralized medium-term notes.
For additional information about ASB, reference is made to Note 5 to HEI's Consolidated Financial Statements, incorporated herein by reference to pages 53 through 57 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
The following table sets forth selected data for ASB for the periods indicated:
(1) Net income includes amortization of goodwill and core deposit intangibles.
(2) Reflects allocation of corporate-level expenses for segment reporting purposes, which were not billed to ASB. In the second quarter of 1992, HEI changed its method of billing corporate-level expenses to ASB. Under the new billing procedure, only certain direct charges, rather than fully-allocated costs, are billed to ASB. However, no change was made by HEI in the manner in which corporate-level expenses were allocated for segment reporting purposes.
CONSOLIDATED AVERAGE BALANCE SHEET
The following table sets forth average balances of major balance sheet categories for the periods indicated. Average balances for each period have been calculated using the average month-end balances during the period.
ASSET/LIABILITY MANAGEMENT
Interest rate sensitivity refers to the relationship between market interest rates and net interest income resulting from the repricing of interest-earning assets and interest-bearing liabilities. Interest rate risk arises when an interest-earning asset matures or when its interest rate changes in a time frame different from that of the supporting interest-bearing liability. Maintaining an equilibrium between rate sensitive interest-earning assets and interest-bearing liabilities will reduce some interest rate risk but it will not guarantee a stable net interest spread because yields and rates may change simultaneously or at different times and such changes may occur in differing increments. Market rate fluctuations could materially affect the overall net interest spread even if interest-earning assets and interest-bearing liabilities were perfectly matched. The difference between the amounts of interest-earning assets and interest-bearing liabilities that reprice during a given period is called "gap." An asset-sensitive position or "positive gap" exists when more assets than liabilities reprice within a given period; a liability-sensitive position or "negative gap" exists when more liabilities than assets reprice within a given period. A positive gap generally produces more net interest income in periods of rising interest rates and a negative gap generally produces more net interest income in periods of falling interest rates.
As rates in 1993 have remained at low levels, the gap in the near term (0-6 months) was a negative 4.1% of total assets as compared to a cumulative one-year positive gap position of 3.2% of total assets as of December 31, 1993. The negative near-term gap position reflects customers moving more interest sensitive funds into liquid passbook deposits. The cumulative one-year 1993 "positive gap" was primarily due to a very low interest rate environment that led to faster prepayments of fixed rate loans with high interest rates coupled with the increase of noninterest rate sensitive passbook deposits with a life expectancy of greater than a year.
The following table shows ASB's interest rate sensitivity at December 31, 1993:
(1) The table does not include $183 million of noninterest-earning assets and $53 million of noninterest-bearing liabilities. (2) The difference between the total interest-earning assets and the total interest-bearing liabilities.
INTEREST INCOME AND INTEREST EXPENSE
The following table sets forth average balances, interest and dividend income, interest expense and weighted average yields earned and rates paid, for certain categories of interest-earning assets and interest-bearing liabilities for the periods indicated. Average balances for each period have been calculated using the average month-end balances during the period.
(1) ASB has no material amount of tax-exempt investments for periods shown. (2) Excludes nonrecurring items.
The following table shows the effect on net interest income of (1) changes in interest rates (change in weighted average interest rate multiplied by prior period average portfolio balance) and (2) changes in volume (change in average portfolio balance multiplied by prior period rate). Any remaining change is allocated to the above two categories on a pro rata basis.
OTHER INCOME
In addition to net interest income, ASB has various sources of other income, including fee income from servicing loans, fees on deposit accounts, rental income from premises and other income. Other income totaled approximately $11.1 million in 1993, compared to $10.4 million in 1992 and $9.7 million in 1991.
LENDING ACTIVITIES
General. ASB's net loan and mortgage-backed securities portfolio totaled approximately $2.4 billion at December 31, 1993, representing 90.3% of its total assets, compared to $2.2 billion, or 88.3%, and $2.0 billion, or 89.7%, at December 31, 1992 and 1991, respectively. ASB's loan portfolio consists primarily of conventional residential mortgage loans which are not insured by the Federal Housing Administration (FHA) nor guaranteed by the Veterans Administration. At December 31, 1993, mortgage-backed securities represented 26.7% of the loan and mortgage-backed securities portfolio, compared to 32.7% at December 31, 1992 and 41.1% at December 31, 1991.
The following tables set forth the composition of ASB's loan and mortgage- backed securities portfolio:
(1) Includes renegotiated loans.
(1) Includes renegotiated loans.
Origination, purchase and sale of loans. Generally, loans originated and purchased by ASB are secured by real estate located in Hawaii. As of December 31, 1993, approximately $11.9 million of loans which were purchased from other lenders were secured by properties located in the continental United States. For additional information, including information concerning the geographic distribution of ASB's mortgage-backed securities portfolio, reference is made to Note 20 to HEI's Consolidated Financial Statements, incorporated herein by reference to page 67 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
The following table shows the amount of loans originated for the years indicated:
Residential mortgage lending. During 1993, the demand for adjustable rate mortgage (ARM) loans over fixed rate loans decreased compared with 1992. ARM loans carry adjustable interest rates which are typically set according to a short-term index. Payment amounts may be adjusted periodically based on changes in interest rates. ARM loans represented approximately 24.7% of the total originations of first mortgage loans in 1993, compared to 34.0% and 27.4% in 1992 and 1991, respectively. ASB intends to continue to emphasize the origination and purchase of ARM loans to further improve its asset/liability management.
ASB is permitted to lend up to 100% of the appraised value of the real property securing a loan. Its general policy is to require private mortgage insurance when the loan-to-value ratio of owner-occupied property exceeds 80% of the lower of the appraised value or purchase price. On nonowner-occupied residential properties, the loan-to-value ratio may not exceed 80% of the lower of the appraised value or purchase price.
Construction and development lending. ASB provides both fixed and adjustable rate loans for the construction of one-to-four residential unit and commercial properties. Construction and development financing generally involves a higher degree of credit risk than long-term financing on improved, occupied real estate. Accordingly, all construction and development loans are priced higher than loans secured by completed structures. ASB's underwriting, monitoring and disbursement practices with respect to construction and development financing are designed to ensure sufficient funds are available to complete construction projects. As of December 31, 1993, 1992 and 1991, construction and development loans represented 1.5%, 2.2% and 2.1%, respectively, of ASB's gross loan portfolio. See "Loan portfolio risk elements."
Multi-family residential and commercial real estate lending. Permanent loans secured by multi-family properties (generally apartment buildings), as well as commercial and industrial properties (including office buildings, shopping centers and warehouses), are originated by ASB for its own portfolio as well as for participation with other lenders. In 1993, 1992 and 1991, loans on these types of properties accounted for approximately 6.0%, 8.2% and 7.5%, respectively, of ASB's total mortgage loan originations. The objective of commercial real estate lending is to diversify ASB's loan portfolio to include sound, income-producing properties.
Consumer lending. ASB offers a variety of secured and unsecured consumer loans. Loans secured by deposits are limited to 90% of the available account balance. ASB also offers VISA cards, automobile loans, general purpose consumer loans, second mortgage loans, home equity lines of credit, checking account overdraft protection and unsecured lines of credit. In 1993, 1992 and 1991, loans of these types accounted for approximately 4.3%, 4.9% and 11.1%, respectively, of ASB's total loan originations.
Corporate banking/commercial lending. ASB is authorized to make both secured and unsecured corporate banking loans to business entities. This lending activity is designed to diversify ASB's asset structure, shorten maturities, provide rate sensitivity to the loan portfolio and attract business checking deposits. As of December 31, 1993, 1992 and 1991, corporate banking loans represented 1.2%, 1.2% and 1.67%, respectively, of ASB's total net loan portfolio.
Loan origination fee and servicing income. In addition to interest earned on loans, ASB receives income from servicing of loans, for late payments and from other related services. Servicing fees are received on loans originated and subsequently sold by ASB and also on loans for which ASB acts as collection agent on behalf of third-party purchasers.
ASB generally charges the borrower at loan settlement a loan origination fee ranging from 2% to 3% of the amount borrowed. Loan origination fees (net of direct loan origination costs) are deferred and recognized as an adjustment of yield over the life of the loan. Nonrefundable commitment fees (net of direct loan origination costs, if applicable) to originate or purchase loans are deferred. The nonrefundable commitment fees are recognized as an adjustment of yield over the life of the loan if the commitment is exercised. If the commitment expires unexercised, nonrefundable commitment fees are recognized in income upon expiration of the commitment.
Loan portfolio risk elements. When a borrower fails to make a required payment on a loan and does not cure the delinquency promptly, the loan is classified as delinquent. If delinquencies are not cured promptly, ASB normally commences a collection action, including foreclosure proceedings in the case of secured loans. In a foreclosure action, the property securing the delinquent debt is sold at a public auction in which ASB may participate as a bidder to protect its interest. If ASB is the successful bidder, the property is classified
in a real estate owned account until it is sold. At December 31, 1993, there was only one real estate property, a residential property, acquired in settlement of a loan totaling $0.2 million, or 0.01% of total assets. At December 31, 1992 there was only one real estate property, a commercial property, acquired in settlement of a loan totaling $2.0 million, or 0.08% of total assets. There was no real estate owned at December 31, 1991, 1990 and 1989.
In addition to delinquent loans, other significant lending risk elements include: (1) accruing loans which are over 90 days past due as to principal or interest, (2) loans accounted for on a nonaccrual basis (nonaccrual loans), and (3) loans on which various concessions are made with respect to interest rate, maturity, or other terms due to the inability of the borrower to service the obligation under the original terms of the agreement (renegotiated loans). ASB has no loans which are over 90 days past due on which interest is being accrued for the years presented in the table below. The level of nonaccrual and renegotiated loans represented 0.5%, 1.0%, 0.1%, 0.1% and 0.2%, of ASB's total net loans outstanding at December 31, 1993, 1992, 1991, 1990 and 1989, respectively. The following table sets forth certain information with respect to nonaccrual and renegotiated loans for the dates indicated:
ASB's policy generally is to place mortgage loans on a nonaccrual status (interest accrual is suspended) when the loan becomes more than 90 days past due or on an earlier basis when there is a reasonable doubt as to its collectability. Loans on nonaccrual status amounted to $5.7 million (0.32% of total loans) at December 31, 1993, $14.2 million (0.94% of total loans) at December 31, 1992, $1.0 million (0.08% of total loans) at December 31, 1991, $1.0 million (0.10% of total loans) at December 31, 1990 and $1.2 million (0.14% of total loans) at December 31, 1989. The significant increase in loans on nonaccrual status from year-end 1991 to 1992 was primarily due to the effects of Hurricane Iniki on the island of Kauai, such as higher unemployment. As of December 31, 1992, real estate loans with remaining principal balances of $8.9 million were restructured to defer monthly contractual principal and interest payments for three months with repayments of the entire deferred amounts due at the end of the three-month period. These loans had been classified as nonaccrual loans as of December 31, 1992. Substantially all of these loans have resumed their normal repayment schedule and are classified as performing loans as of December 31, 1993. For additional information, see "Potential problem loans."
There were no loan loss provisions with respect to renegotiated loans in 1993, 1992, 1991, 1990 and 1989 because the estimated net realizable value of the collateral for such loans was determined to be in excess of the outstanding principal amounts of these loans. For additional information, see "Potential problem loans."
Potential problem loans. A loan is classified as a potential problem loan when the ability of the borrower to comply with present loan covenants is in doubt. In September 1992, the island of Kauai suffered
substantial property damage from Hurricane Iniki. The high unemployment rate on Kauai due to Hurricane Iniki resulted in loan payment defaults or deferrals requiring such loans to be placed on a nonaccrual status. As of December 31, 1992, delinquencies of ASB's Kauai loans were $2.2 million, $2.5 million, $3.1 million and $0.4 million for 1-29 days, 30-59 days, 60-89 days and 90 days and over delinquent, respectively. In anticipation of additional loans falling into the 90 days and over category, ASB added reserves during 1992 of $0.6 million for Kauai loans. As of December 31, 1993, substantially all of these loans have resumed their normal repayment schedule improving delinquencies of ASB's Kauai loans to $2.1 million, $0.5 million, $0.3 million and $0.7 million for 1-29 days, 30-59 days, 60-89 days and 90 days and over delinquent, respectively.
Due to the losses created by Hurricane Iniki, several insurance companies have discontinued the sale and/or renewal of homeowners' insurance on real estate in Hawaii. If a borrower is unable to obtain insurance, ASB has procedures to "force place" insurance coverage. The "force place" policies are underwritten by two U.S. insurance companies and would protect ASB, as lender, for loans secured by real estate covered by such policies. The cost of the policy is charged to the borrower. Based on the current circumstances, management believes that the current shortage of homeowners' insurance in Hawaii and the effect of Hurricane Iniki on ASB's future earnings will not be material to the Company's financial condition or results of operations.
Allowance for loan losses. The provision for loan losses is dependent upon management's evaluation as to the amount needed to maintain the allowance for loan losses at a level considered appropriate in relation to the risk of future losses inherent in the loan portfolio. While management attempts to use the best information available to make evaluations, future adjustments may be necessary as circumstances change and additional information becomes available.
The following table presents the changes in the allowance for loan losses for the periods indicated.
ASB's ratio of provisions for loan losses during the period to average loans outstanding was 0.05%, 0.11%, 0.06%, 0.07% and 0.06% for the years ended December 31, 1993, 1992, 1991, 1990 and 1989, respectively. The increase in provisions for loan losses during 1992 was primarily due to the 27% increase in average loans outstanding and a $0.6 million additional provision for Kauai loans anticipated to be affected by Hurricane Iniki. See "Potential problem loans." Without the additional $0.6 million provision on Kauai loans, the ratio of provision for loan losses to average loans outstanding for the year ended December 31, 1992 would have been 0.07%, which would be consistent with prior years. The allowance for loan losses for the year ended December 31, 1993 includes the additional provision and charge-off of a single commercial loan of $0.3 million, offset by the reversal of $0.6 million in provisions for Kauai loans reclassified as performing. The ratio of provision for loan losses to average loans outstanding for the year ended December 31, 1993 would have been 0.07%, if the reversal of the $0.6 million in provisions for Kauai loans and the additional provision of $0.3 million for the commercial loan were excluded.
INVESTMENT ACTIVITIES
In recent years, ASB's investment portfolio has consisted primarily of mortgage-backed securities, federal agency obligations and stock of the FHLB of Seattle.
The following table sets forth the composition of ASB's investment portfolio, excluding mortgage-backed securities to be held-to-maturity, at the dates indicated:
(1) On investments during the year ended December 31.
DEPOSITS AND OTHER SOURCES OF FUNDS
General. Deposits traditionally have been the principal source of ASB's funds for use in lending and other investments. ASB also derives funds from receipt of interest and principal on outstanding loans, borrowings from the FHLB of Seattle, securities sold under agreements to repurchase and other sources. ASB borrows on a short-term basis to compensate for seasonal or other reductions in deposit flows. ASB also may borrow on a longer-term basis to support expanded lending or investment activities.
Deposits. ASB's deposits are obtained primarily from residents of Hawaii. In 1993, ASB had average deposits aggregating $2.1 billion. Savings outflow for 1993 was approximately $9 million excluding interest credited to deposit accounts. Savings inflows for 1992 and 1991 were approximately $343 million and $31 million, respectively, excluding interest credited to deposit accounts. The substantial decrease in savings flow for 1993 was due primarily to the low interest rate environment and the withdrawal of a trust company deposit account of $92 million. The trust company was recently acquired by another financial institution. The substantial increase in savings inflow for 1992 was due to ASB's strategy to increase its retail market by paying higher rates of interest on savings accounts than most of its competitors in Hawaii during this period. The weighted average rate paid on deposits during 1993 decreased to 3.74%, compared to 5.01% and 6.36% in 1992 and 1991, respectively. In the three years ended December 31, 1993, ASB had no deposits placed by or through a broker.
The following table shows the distribution of ASB's average deposits and average daily rates by type of deposit for the years indicated. Average balances for a period have been calculated using the average of month-end balances during the period.
At December 31, 1993, ASB had $166 million in certificate accounts of $100,000 or more maturing as follows:
Borrowings. ASB obtains advances from the FHLB of Seattle, provided certain standards related to credit-worthiness have been met. Advances are secured under a blanket pledge of the common stock ASB owns in the FHLB of Seattle and each note or other instrument held by ASB and the mortgage securing it. FHLB advances generally are available to meet seasonal and other withdrawals of deposit accounts, to expand lending and to assist in the effort to improve asset and liability management. FHLB advances are made pursuant to several different credit programs offered from time to time by the FHLB of Seattle.
At December 31, 1993, 1992 and 1991, advances from the FHLB amounted to $290 million, $194 million and $259 million, respectively. The weighted average rate on the advances from the FHLB outstanding at December 31, 1993, 1992 and 1991 were 6.24%, 7.39% and 7.60%, respectively. The maximum amount outstanding at any month-end during 1993, 1992 and 1991 was $290 million, $259 million and $259 million, respectively. Advances from the FHLB averaged $210 million, $221 million and $203 million during 1993, 1992 and 1991, respectively, and the approximate weighted average rate thereon was 6.84%, 7.65% and 7.99%, respectively.
At December 31, 1992 and 1991, securities sold under agreements to repurchase consisted of mortgage-backed securities sold to brokers/dealers under fixed- coupon agreements. The agreements are treated as financings and the obligations to repurchase securities sold are reflected as a liability in the consolidated balance sheets. The dollar amount of securities underlying the agreements remains in the asset accounts. There were no outstanding securities sold under agreements to repurchase as of December 31, 1993. At December 31, 1992 and 1991, $27.2 million (including accrued interest of $0.2 million) and $131.0 million (including accrued interest of $1.8 million), respectively, of the agreements were to repurchase identical securities. The weighted average rates on securities sold under agreements to repurchase outstanding at December 31, 1992 and 1991 were 3.34% and 5.78%, respectively. The maximum amount outstanding at any month-end during 1993, 1992 and 1991 was $27 million, $125 million and $136 million, respectively.
Securities sold under agreements to repurchase averaged $20 million, $66 million and $124 million during 1993, 1992 and 1991, respectively, and the approximate weighted average interest rate thereon was 3.39%, 5.15% and 6.67%, respectively.
Subject to obtaining certain approvals from the FHLB of Seattle, ASB may offer collateralized medium-term notes due from nine months to 30 years from the date of issue and bearing interest at a fixed or floating rate established at the time of issue. At December 31, 1993, 1992 and 1991, ASB had no outstanding collateralized medium-term notes.
The following table sets forth information concerning ASB's advances from FHLB and other borrowings at the dates indicated:
(1) On borrowings at December 31.
COMPETITION
The primary factors in competing for deposits are interest rates, the quality and range of services offered, marketing, convenience of office locations, office hours and perceptions of the institution's financial soundness and safety. Competition for deposits comes primarily from other savings institutions, commercial banks, credit unions, money market and mutual funds and other investment alternatives. Additional competition for deposits comes from various types of corporate and government borrowers, including insurance companies. To meet the competition, ASB offers a variety of savings and checking accounts at competitive rates, convenient business hours, convenient branch locations with interbranch deposit and withdrawal privileges at each office and conducts advertising and promotional campaigns.
The primary factors in competing for first mortgage and other loans are interest rates, loan origination fees and the quality and range of lending services offered. Competition for origination of first mortgage loans comes primarily from other savings institutions, mortgage banking firms, commercial banks, insurance companies and real estate investment trusts. ASB believes that it is able to compete for such loans primarily through the interest rates and loan fees it charges, the type of mortgage loan programs it offers and the efficiency and quality of the services it provides its borrowers and the real estate business community.
OTHER
FREIGHT TRANSPORTATION -- HAWAIIAN TUG & BARGE CORP. AND YOUNG BROTHERS, LIMITED
GENERAL
HTB and its wholly owned subsidiary, YB, were acquired from Dillingham Corporation in 1986 for $18.7 million. HTB provides interisland marine transportation services in Hawaii and the Pacific area, including charter tug and barge and harbor tug operations. YB, which is a regulated interisland cargo carrier, transports general freight and containerized cargo by barge on a regular schedule between all major ports in Hawaii. YB moved 3.1 million revenue tons of cargo between the islands in 1993, compared to 3.2 million tons of cargo in 1992.
A substantial portion of the state's commodities are imported, and almost all of Hawaii's overseas inbound and outbound cargo moves through Honolulu. Cargo destined for the neighbor islands is trans-shipped through the Honolulu gateway. Access to the interisland freight transportation market is generally subject to state or federal regulation, and HTB and YB have active competitors, such as interstate common carriers and, in certain instances, unregulated contract carriers.
YB has a nonexclusive Certificate of Public Convenience and Necessity from the PUC to operate as an intrastate common carrier by water. The Certificate will remain in effect for an indefinite period unless suspended or terminated by the PUC. Although YB encounters competition from, among others, interstate carriers and unregulated contract carriers, YB is the only authorized common carrier under the Hawaii Water Carrier Act.
YB RATES
YB generally must accept for transport all cargo offered. YB rates and charges must be approved by the PUC and the PUC has broad discretion in its regulation of the rates charged by YB.
In June 1987, the PUC commenced a proceeding to determine whether YB's rates and charges should be reduced to reflect the effect of the Tax Reform Act of 1986 (TRA). During the period from January 1, 1988 through June 30, 1993, several rate reductions were imposed by the PUC as well as YB voluntarily reducing its rates for selected commodities. On February 13, 1992, YB filed a motion to rescind a 1.1% interim rate reduction which was implemented on January 1, 1989. On June 30, 1993, the PUC approved YB's motion to rescind the 1.1% interim rate reduction, effective July 8, 1993, and in January 1994, the PUC rendered a decision to close the TRA docket.
In September 1992, YB filed an application for a tariff change in its minimum bill of lading from $10.43 to $21.03 (later increased to $21.62). This application was suspended on October 7, 1992. On November 5, 1992, YB filed a general rate increase application with the PUC for a 17.1% across the board increase in rates effective December 20, 1992. On December 18, 1992, the PUC ordered that the two applications be consolidated and that the consolidated application be suspended for a period of six months to and including June 19, 1993. On February 12, 1993, YB reduced its general rate increase request to 15.7% from the 17.1% originally requested. The decrease in the request was primarily due to a decrease in rate base resulting from the change in the test year period and an adjustment to YB's capital structure to reflect more leverage. The revised request was based on a rate of return of 16.7% on an imputed equity of 55%. Hearings for this general rate increase and the tariff change were held in May 1993. On June 30, 1993, the PUC issued a decision granting an $18.00 minimum bill of lading charge and a 4.3% general rate increase on all rates excluding the Minimum Bill of Lading and Marine Cargo Insurance rates. The new rates and charges became effective on July 8, 1993. This decision was based on a rate of return of 15.15% on an imputed equity of 55%. YB is also participating in the PUC's generic docket to determine whether SFAS No. 106 should be adopted for rate-making purposes. The information on postretirement benefits other than pensions in Note 18 to HEI's Consolidated Financial Statements is incorporated herein by reference to pages 64 to 66 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
On March 15, 1994, YB filed a Notice of Intent with the PUC informing them that YB will be filing an application for a general rate increase.
REAL ESTATE-MALAMA PACIFIC CORP.
GENERAL
MPC was incorporated in 1985 and engages in real estate development activities, either directly or through joint ventures.
MPC's real estate development investments in residential projects are targeted for Hawaii's owner-occupant market. MPC's subsidiaries are currently involved in the active development of five residential projects (Kipona Hills, Kua' Aina Ridge, Westpark, Piilani Village Phase 1 and Sunrise Estates Phase 1) on the islands of Oahu, Maui and Hawaii encompassing approximately 500 homes or lots, of which more than 260 have been completed and sold. Either directly or through its joint ventures, MPC's subsidiaries have access to nearly 450 acres of land for future residential development.
Residential development generally requires long lead time to obtain necessary zoning changes, building permits and other required approvals. MPC's projects are subject to the usual risks of real estate development, including fluctuations in interest rates, the receipt of timely and appropriate state and local zoning and other necessary approvals, possible cost overruns and construction delays, adverse changes in general commerce and local market conditions, compliance with applicable environmental and other regulations, and potential competition from other new projects and resales of existing residences.
In 1993, Malama's real estate development activities continued to be impacted by the economic conditions affecting the entire nation. Although interest rates remained low, the real estate market experienced slowdowns due to the weakness in the U.S. and Hawaii economies and lack of consumer
confidence. Sales prices and velocities are expected to remain relatively flat through most of 1994, with improvement anticipated in late 1994 or 1995.
For a discussion of MPC's transactions with related parties, pages 21 to 23 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994 and filed herein as HEI Exhibit 22, are incorporated herein by reference.
JOINT VENTURE DEVELOPMENTS
Makakilo Cliffs. In 1990, MDC and JGL Enterprises Inc. formed Makakilo Cliffs Joint Venture for the development of a 280-unit multi-family residential project on approximately 26 acres in Makakilo, Hawaii (island of Oahu). MDC's partnership interest was assigned to Malama Makakilo Corp., another wholly owned subsidiary of MPC, in August 1990. Sales of the first 81 units closed in 1991 and all remaining units closed in 1992. The joint venture was dissolved in December 1993.
Sunrise Estates. In 1990, MDC and HSC, Inc. formed Sunrise Estates Joint Venture to develop and sell 165 one-acre house lots in Hilo, Hawaii (island of Hawaii). In 1993 and 1992, sales of three lots and 153Elots closed, respectively. Sales of the remaining nine lots are expected in 1994.
In 1991, HSC, Inc. and Malama Elua Corp., a wholly owned subsidiary of MPC, formed Sunrise Estates II Joint Venture to develop and sell approximately 140 one-acre house lots in Hilo, Hawaii, adjacent to the Sunrise Estates Joint Venture project. Rezoning was completed in 1993 and site work is expected to commence in late 1994 or early 1995.
Ainalani Associates. In 1990, MDC and MDT-BF Limited Partnership (MDT) formed a joint venture known as Ainalani Associates for the acquisition and development of five residential projects on the islands of Kauai, Maui and Hawaii. In 1990, the project on the island of Kauai was completed and sold. In 1992, the land for a project on the island of Maui was sold in bulk. Ainalani Associates also acquired a 50% interest in Palailai Associates, a partnership for the development of residential housing on Oahu. The five projects and partnership interest originally (i.e., before sales) encompassed approximately 270 acres of land. During 1990, MDC assigned its interest in Ainalani Associates to MMO, another wholly owned subsidiary of MPC.
On August 17, 1992, MMO acquired MDT's 50% interest in Ainalani Associates. Upon closing of the purchase, Ainalani Associates was dissolved. The amount of consideration for the transfer, which was not material to the Company's financial condition, was determined by arbitration which ended on March 31, 1993 and was based primarily on the net present value of MDT's partnership interest in Ainalani Associates as of June 30, 1992. MMO plans to complete the development and sale of Ainalani Associates three projects on the islands of Maui and Hawaii, described below under "MMO projects," and has assumed Ainalani Associates' 50% partnership interest in Palailai Associates, a partnership with Palailai Holdings, Inc.
Baldwin*Malama. In 1990, MDC acquired a 50% general partnership interest in Baldwin*Malama, a partnership with Baldwin Pacific Properties, Inc. (BPPI) established to acquire about 172 acres of land for potential development of about 780 single and multi-family residential units in Kihei on the island of Maui. The project has completed site work for the first phase of single family units. At December 31, 1993, 23 homes were completed and sold, four homes were under construction and six completed units were available for sale.
In May 1993, Baldwin*Malama was reorganized as a limited partnership in which MDC is the sole general partner and BPPI is the sole limited partner. In conjunction with the dissolution of the Baldwin*Malama general partnership and formation of the limited partnership, MPC agreed to loan $1.6 million to BPPI and up to $15 million to the limited partnership, and beginning in May 1993, MDC consolidated the accounts of Baldwin*Malama. Previously, MDC accounted for its investment in Baldwin*Malama under the equity method. At December 31, 1993, the outstanding balance on MPC's loan to BPPI was $1.6 million.
Palailai Associates. MMO assumed Ainalani Associates' interest in Palailai Associates on August 17, 1992 upon acquiring MDT's 50% interest in Ainalani Associates. In 1993, Palailai Associates completed the development and sale of the first increment of 107 homes and lots and completed the bulk sale of its 38.8 acres of multi-family zoned land in Makakilo, Oahu. The second increment of 69 single family homes is currently in progress, with 35 homes completed and sold as of December 31, 1993. Palailai Associates owns approximately 62 acres of adjacent land zoned for residential development.
MMO PROJECTS
On August 17, 1992, MMO acquired the Kipona Hills, Kua' Aina Ridge and Hanohano projects of Ainalani as a result of MMO's acquisition of MDT's 50% interest in Ainalani Associates and Ainalani Associates' subsequent dissolution.
Kipona Hills is a 66-unit subdivision located in Waikoloa on the island of Hawaii. Through December 31, 1993, 42 homes or lots were completed and sold, and five completed homes and 19 lots were available for sale.
Kua' Aina Ridge is a 92-lot-only subdivision in Pukalani, Maui. Subdivision improvements have been completed and sales closings commenced in 1993. As of December 31, 1993, five lots were sold.
Kehaulani Place (formerly known as Hanohano), consisting of approximately 50 acres of land in Pukalani, Maui, is currently zoned for agriculture. Rezoning and land-use reclassification will be required before development can commence. Land planning and presentations to local community groups commenced in 1993.
PROJECT FINANCING
At December 31, 1993, MPC or its subsidiaries were directly liable for $11.5 million of outstanding construction loans and had additional construction loan facilities of $5.8 million. In addition, at December 31, 1993, MPC or its subsidiaries had issued (i) guaranties under which they were jointly and severally contingently liable with their joint venture partners for $2.1 million of outstanding construction loans and (ii) payment guaranties under which MPC or its subsidiaries were severally contingently liable for $4.6 million of outstanding construction loans and $4.7 million of additional undrawn construction loan facilities. In total, at December 31, 1993, MPC or its subsidiaries were liable or contingently liable for $18.2 million of outstanding construction loans and $10.5 million in undrawn construction loan facilities. At December 31, 1993, HEI had agreed with the lenders of construction loans and loan facilities, of which approximately $10.5 million was undrawn and $16.1 million was outstanding, that it will maintain ownership of 100% of the stock of MPC and that it intends, subject to good and prudent business practices, to keep MPC financially sound and responsible to meet its obligations. MPC or its subsidiaries may enter into additional commitments in connection with the financing of future phases of development of MPC's projects and HEI may enter into similar agreements regarding the ownership and financial condition of MPC.
MALAMA WATERFRONT CORP.
Malama Waterfront Corp., a wholly owned subsidiary of MPC, entered into an agreement to purchase HECO's Honolulu Power Plant in a sale and leaseback transaction. However, HECO is reconsidering the sale of the plant. See a further discussion in "Item 2.


ITEM 2. PROPERTIES
HEI leases 17,612 square feet of office space in downtown Honolulu. The leases expire at various dates from March 31, 1996 to April 30, 1999 (with an option for HEI to extend one of the leases on most of the office space to March 31, 2001). The properties of HEI's subsidiaries are as follows:
ELECTRIC UTILITY
HECO owns and operates three generating plants on the island of Oahu at Honolulu, Waiau and Kahe, with an aggregate generating capability of 1,263 MW at December 31, 1993. The three plants are situated on HECO-owned land having a combined area of 535 acres. In addition, HECO owns a total of 114 acres of land on which are located substations, transformer vault sites, distribution base yards and the Kalaeloa cogeneration facility site.
Electric lines are located over or under public and nonpublic properties. Most of HECO's leases, easements and licenses have been recorded.
At December 31, 1993, HECO owned approximately 828 miles of overhead transmission lines, 1,171 miles of overhead distribution lines, 2,007 miles of underground cables, 70,395 fully-owned or jointly-owned poles and 194 steel or aluminum high voltage transmission towers. The transmission system operates at 46,000 and 138,000 volts. The total capacity of HECO's transmission and distribution substations was 5,414,000 kilovoltamperes at December 31, 1993.
HECO owns a building and approximately 11.5 acres of land located in Honolulu which houses its operating, engineering and information services departments and a warehousing center. It also leases an office building and certain office spaces in Honolulu. The lease for the office building expires in November 2002, with an option to further extend the lease to November 2012. The leases for certain office spaces expire on December 31, 1996 with options to extend to December 31, 2001.
HECO owns 19.2 acres of land at Barbers Point used to situate fuel oil storage facilities with a combined capacity of 970,700 barrels. HECO also owns fuel oil tanks at each plant site with a total maximum usable capacity of 915,400 barrels.
The properties of HECO are subject to a first mortgage securing HECO's outstanding first mortgage bonds.
On December 20, 1989, HECO applied to the PUC for the approval of the sale to Malama Waterfront Corp. and leaseback of the Honolulu power plant and Iwilei tank farm, the approval of the transfer values and the approval of the accounting and rate-making treatments thereof. Prior to the PUC rendering a decision on this application, HECO determined that changing conditions altered the economics of the proposed sale such that a later retirement of the Honolulu power plant may be more favorable. As such, HECO withdrew its application for the sale and leaseback of the plant in July 1993.
A brief description of the properties of HECO's two electric utility subsidiaries follows:
MECO owns and operates two generating plants on the island of Maui, at Kahului and Maalaea, with an aggregate capability of 201.3 MW. The plants are situated on MECO-owned land having a combined area of 28.6 acres. MECO also owns fuel oil storage facilities at these sites with an aggregate maximum usable storage capacity of 145,300 barrels.
MECO's administrative offices and engineering and distribution departments are located on 9.1 acres of MECO-owned land in Kahului.
MECO also owns and operates smaller distribution and generation systems on the islands of Lanai and Molokai.
The properties of MECO are subject to a first mortgage securing MECO's outstanding first mortgage bonds.
HELCO owns and operates five generating plants on the island of Hawaii. These plants at Hilo (2), Waimea, Kona and Puna have an aggregate generating capability of 154.6 MW (excluding two small run-of-river hydro units). The plants are situated on HELCO-owned land having a combined area of approximately 43 acres. HELCO owns 6.0 acres of land in Kona, which are used for a baseyard, and it leases 4.0 acres of land for its baseyard in Hilo. The lease expires in 2030. The deeds to the sites located in Hilo contain certain restrictions which do not materially interfere with the use of the sites for public utility purposes.
The properties of HELCO are subject to a first mortgage securing HELCO's outstanding first mortgage bonds.
SAVINGS BANK
ASB owns its executive office building located in downtown Honolulu.
The following table sets forth certain information with respect to offices owned and leased by ASB and its subsidiaries at December 31, 1993.
The net book value of office facilities is approximately $31 million. Of this amount, $25 million represents the net book value of the land and improvements for the 13 offices owned by ASB. The remaining $6 million represents the net book value of ASB's leasehold improvements.
OTHER
FREIGHT TRANSPORTATION
HTB, currently owns seven tugboats ranging from 1,430 to 2,668 HP, two tenders of 500 HP and three flatdecked barges.
HTB owns no real property, but rents on a month-to-month basis or leases its pier property used in its operations from the State of Hawaii under a revocable permit and two-year lease. It is expected that expiring leases will be renewed as necessary.
YB, HTB's subsidiary, currently owns four charter tugs, two doubledecked and six flatdecked barges and most of its shoreside equipment, including 20-foot containers, chassis, refrigerated containers, container vans, hi-lifts, flatracks, automobile racks and other related equipment.
YB has three- and four-year leases expiring at various dates in 1994 through 1995 for shoreside equipment (containers, flatracks and chassis) at a monthly cost of approximately $8,500.
YB owns no real property, but rents on a month-to-month basis or leases various pier property and warehouse facilities from the State of Hawaii under a revocable permit, or under a two-year or five-year lease. All lease terms began on January 1, 1992. It is expected that expiring leases will be renewed as necessary.
REAL ESTATE DEVELOPMENT
MPC. See Item 1, "Business--Other--Real estate--Malama Pacific Corp."
OTHER
HEIIC. See Item 1, "Business--Other--HEI Investment Corp."
LVI operates a windfarm on the island of Hawaii with a generating capability of 1.7 MW. LVI leases 78 acres of land for its windfarm.
ITEM 3.
ITEM 3. LEGAL PROCEEDINGS
Except as provided for below and in "Item 1. Business," there are no known pending legal proceedings, other than ordinary routine litigation incidental to their respective businesses, to which HEI or any of its subsidiaries is a party or of which any of their property is the subject.
HECO POWER OUTAGE
On April 9, 1991, HECO experienced a power outage that affected all customers on the island of Oahu. One major transmission line was de-energized for routine maintenance when two major transmission lines tripped, causing another major transmission line to become overloaded and automatically trip. An island-wide power outage resulted. Power was restored over the next twelve hours.
The PUC initiated an investigation of the outage by its order dated April 16, 1991. This investigation was consolidated with a pending investigation of an outage that occurred in 1988. The PUC held an initial hearing on the April 9, 1991 outage in May 1991. In July 1991, HECO filed a report of its internal investigative task force with the PUC. The report indicated that the results of the investigation were inconclusive with respect to why one of the major lines tripped and recommended actions to strengthen system reliability. The parties to the investigation (HECO, Consumer Advocate and U.S. Department of Defense) agreed that HECO should retain an independent consultant to investigate the cause of the line trip. By an order dated October 23, 1991, the PUC approved HECO's retention of Power Technologies, Inc. (PTI) and directed that the objectives of the study be to assess the reliability and overall stability of HECO's electric power system, to identify possible weaknesses, deficiencies and conditions within the system that contributed to the island-wide power outage, and to recommend a plan to increase the reliability of HECO's system and minimize the occurrence of future island-wide outages. In its order, the PUC also stated that: "[n]either the [PUC] nor HECO nor any of the other parties to this docket is bound by PTI's report or analysis or is precluded from retaining other consultants."
In August 1993, PTI's report was submitted to the PUC. In its report, PTI made more than 100 recommendations for HECO to improve reliability, including selective use of herbicides to control the growth of trees under power lines. PTI said some recommendations are for implementation, some are for further
study and possible implementation and some are for consideration. Some of the recommendations relate to the 1991 outage and some do not.
PTI identified four recommendations as deserving immediate attention: (1) perform a detailed inspection of 138-kilovolt overhead transmission lines to ensure that present clearance distances to trees, wire crossings and other conductive objects are sufficient for at least one year; (2) determine relationships between tree clearances and "line sag" changes that result from lines carrying different amounts of electricity; (3) build the Waiau-Campbell Industrial Park 138-kilovolt transmission line as soon as possible and consider building the line to operate at higher voltage in the future; and (4) increase the number of "live-line" overhead transmission linemen and engineering and management personnel to support line and right-of-way functions. Regarding the outage, PTI concluded that the fault on the third of four transmission lines was the result of tree contact. This conclusion conflicts with the finding of another consultant who found that certain evidence favored a fault in the line over a pineapple field with no trees. Other PTI recommendations include (1) reviewing reporting systems used by co-generators and independent power producers from whom HECO buys power to be sure they are adequate to reveal problems that could affect system reliability, and (2) keeping in service the downtown Honolulu power plant previously scheduled for retirement in 1996.
HECO filed its comments on the PTI recommendations with the PUC in November 1993. Further proceedings have not been scheduled at this time. Management cannot predict the timing and outcome of any decision and order to be issued by the PUC with respect to the outages or with respect to the recommendations made by PTI.
HECO's PUC-approved tariff rule states that "[t]he Company will not be liable for interruption or insufficiency of supply or any loss, cost, damage or expense of any nature whatsoever, occasioned thereby if caused by accident, storm, fire, strikes, riots, war or any cause not within the Company's control through the exercise of reasonable diligence and care." Under the rule, customers had 30 days from the date of the power outage to file claims. HECO received approximately 2,900 customer claims which totaled approximately $7 million. Of the 2,900 claims, approximately 1,450 are for property damage. As of December 31, 1993, HECO had settled approximately 542 of these property damage claims, had settlement offers outstanding with respect to approximately 119 more of these claims and anticipates making settlement offers with respect to the remaining property claims upon receipt and review of appropriate supporting documentation. The settlement offers are being made for purposes of settlement and compromise only, and without any admission by HECO of liability for the outage. Not covered in the settlement offers and requests for documentation are approximately 1,450 claims involving alleged personal injury or economic losses, such as lost profits.
On April 19, 1991, seven direct or indirect business customers on the island of Oahu filed a lawsuit against HECO on behalf of themselves and an alleged class, claiming $75 million in compensatory damages and additional unspecified amounts for punitive damages because of the April 9, 1991 outage. The lawsuit was dismissed without prejudice in March 1993 and subsequently refiled by the plaintiffs. HECO has filed an answer which denies the principal allegations in the complaint, sets forth affirmative defenses, and asserts that the suit should not be maintained as a class action. Discovery proceedings have been initiated. No trial date has been set. A motion for an order denying class certification of the lawsuit has been filed and is set for hearing in March 1994.
A reserve equal to the deductible limits with respect to HECO's insurance coverage has been recorded with respect to claims arising out of the April 1991 outage. In the opinion of management, losses (if any), net of estimated insurance recoveries, resulting from the ultimate outcome of the lawsuit and claims related to the April 9, 1991 outage will not have a material adverse effect on the Company or consolidated HECO.
HELCO RELIABILITY INVESTIGATION
In July 1991, following service interruptions and rolling blackouts instituted on the island of Hawaii, the PUC issued an order calling for an investigation into the reliability of HELCO's system.
An evidentiary hearing was held in September 1991 and public hearings were held in October 1991. In light of approximately 20 subsequent incidents of rolling blackouts and service interruptions resulting from insufficient generation margin, further evidentiary hearings were held in July 1992. With the input from an independent consultant and the parties to the proceedings, the PUC may formulate minimum reliability standards for HELCO, use the standards to assess HELCO's system reliability, and re-examine the rate increase approved in October 1992 to see whether any adjustments are appropriate.
HELCO's generation margin has improved with the addition of a 20-MW combustion turbine in August 1992, PGV's commencement of commercial operations and Hamakua's temporary return to commercial operation (see "Item 1. Business--Electric utility-Nonutility generation"). HELCO is proceeding with plans to install two 20-MW combustion turbines in 1995, followed by an 18-MW heat steam recovery generator in 1997, at which time these units will be converted to a combined-cycle unit, subject in each case to obtaining necessary permits.
In the opinion of management, the PUC's adjustment, if any, resulting from the reliability investigation will not have a material adverse effect on the Company's or HECO's consolidated financial condition or results of operations.
HECO POWER PURCHASE AGREEMENTS DISPUTES
HECO is disputing certain amounts billed each month under its power purchase agreements with Kalaeloa Partners, L.P. (Kalaeloa) and AES Barbers Point, Inc. (AES-BP) and has withheld payment of some of the disputed amounts pending resolution. With respect to the billings from Kalaeloa, HECO believes that it has counterclaims which would mitigate, if not more than offset, the disputed amounts billed by Kalaeloa. Disputed amounts billed by Kalaeloa and AES-BP through December 31, 1993 totaled approximately $2.1 million and $1.5 million, respectively. Approximately $0.5 million of the total disputed amounts, if paid, are includable in HECO's energy cost adjustment clause, and would be passed through to customers.
HECO has not recognized any portion of the disputed amounts as an expense or liability in its financial statements. Discussions between HECO and Kalaeloa, and HECO and AES-BP to resolve the disputed billing amounts are continuing. In the event the parties are unable to settle the disputes, both the Kalaeloa and AES-BP power purchase agreements contain provisions whereby either party to the agreement may cause the dispute to be submitted to binding arbitration. Kalaeloa has requested that its dispute with HECO be arbitrated and this arbitration process has commenced. Based on information currently available, HECO's management believes that the ultimate outcome of these disputes will not have a material adverse effect on the Company's or HECO's consolidated financial condition or results of operations.
ITEM 4.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
HEI and HECO:
During the fourth quarter of 1993, no matters were submitted to a vote of security holders of the Registrants.
PART II
ITEM 5.
ITEM 5. MARKET FOR REGISTRANTS' COMMON EQUITY AND RELATED STOCKHOLDER MATTERS HEI:
The information required by this item is incorporated herein by reference to pages 67 and 69 (Note 19, "Regulatory restrictions on net assets" and Note 22, "Quarterly information (unaudited)," of the Notes to HEI's Consolidated Financial Statements) and page 27 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a). Certain restrictions on dividends and other distributions of HEI are described in "Item 1. Business--Regulation and other matters--Restrictions on dividends and other distributions." The total number of holders of record of HEI common stock as of March 21, 1994, was 24,672.
HECO:
Market information and holders--not applicable. Since the corporate restructuring on July 1, 1983, all the common stock of HECO has been held solely by its parent, HEI, and is not publicly traded.
The dividends declared and paid on HECO's common stock for the four quarters of 1993 and 1992 are as follows:
The regulatory restrictions on net assets are incorporated herein by reference to page 27 (Note 12 to HECO's Consolidated Financial Statements, "Regulatory restrictions on distributions to parent") of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
ITEM 6.
ITEM 6. SELECTED FINANCIAL DATA
HEI:
The information required by this item is incorporated herein by reference to page 27 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
HECO:
The information required by this item is incorporated herein by reference to page 2 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
ITEM 7.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
HEI:
The information required by this item is incorporated herein by reference to pages 29 to 39 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
HECO:
The information required by this item is incorporated herein by reference to pages 3 to 9 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
ITEM 8.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
HEI:
The information required by this item is incorporated herein by reference to the section entitled "Segment financial information" on page 28 and to pages 41 to 69 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a).
HECO:
The information required by this item is incorporated herein by reference to pages 10 to 29 and to the section entitled "Consolidated quarterly financial information (unaudited)" on page 31 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b).
ITEM 9.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
HEI AND HECO:
None PART III
ITEM 10.


ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANTS
HEI:
The following persons are, or may be deemed, executive officers of HEI. Their ages are given as of March 10, 1994. Officers are appointed to serve until the meeting of the Board of Directors following the next Annual Meeting of Stockholders (which shall occur on April 19, 1994) and/or until their successors have been appointed and qualified (or until their earlier resignation or removal). Company service includes service with an HEI subsidiary.
HEI's executive officers, with the exception of Peter C. Lewis, Charles F. Wall and Andrew I. T. Chang, are officers and/or directors of one or more of HEI's subsidiaries.
There are no family relationships between any executive officer or director of HEI and any other executive officer or director of HEI.
The list of current directors of HEI is incorporated herein by reference to page 70 of HEI's 1993 Annual Report to Stockholders, portions of which are filed herein as HEI Exhibit 13(a). Information on their business experience and directorships is incorporated herein by reference to pages 3 to 5 of the registrant's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22. Thurston Twigg-Smith (who is not standing for reelection as a Director) is President, Chief Executive Officer and Director of Persis Corporation; Chairman, Chief Executive Officer and Director of Northwest Media, Inc., and Maryville Alcoa Daily Times; Chairman of the Board of The Honolulu Advertiser; Director of HECO, ASB and The Museum of Contemporary Art (Los Angles); Trustee of the McInerny Foundation, Punahou School, Honolulu Academy of Arts, The Contemporary Museum (Honolulu), Old Sturbridge Village (Massachusetts), The Skowhegan School (Maine) and The Philatelic Foundation, N.Y.; and member of the Governing Board of The Yale Art Gallery (Connecticut).
HECO:
The following table sets forth certain information concerning the executive officers of HECO. Their ages are given as of March 10, 1994. Officers are appointed to serve until the meeting of the Board of Directors following the next Annual Meeting and/or until their respective successors have been appointed and qualified. Company service includes service with HECO affiliates.
HECO's executive officers, Robert F. Clarke, Harwood D. Williamson, Edward Y. Hirata, Paul A. Oyer and Molly M. Egged, are officers of one or more of the affiliated HEI companies.
There are no family relationships between any executive officer or director of HECO and any other executive officer or director of HECO.
The list of current directors of HECO is incorporated herein by reference to page 33 of HECO's 1993 Annual Report to Stockholder, portions of which are filed herein as HECO Exhibit 13(b). Information on the business experience and directorships of directors of HECO who are also directors of HEI is incorporated herein by reference to pages 3 through 5 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
Mildred D. Kosaki, age 69, and Paul C. Yuen, age 65, as of March 10, 1994, are the only outside directors of HECO who are not directors of HEI. Mrs. Kosaki has been a Director of HECO from 1973 to the present. She resigned from the HEI Board in 1987. She was also a Director of the International Pacific University from 1989 to 1991 and a Director on the Board of The Honolulu Advertiser from 1983 to 1989. She is a specialist in education research. Dr. Yuen, who was elected a Director of HECO in April 1993, is Senior Vice President for the University of Hawaii and Executive Vice Chancellor for the University of Hawaii-Manoa. In the past five years, he has had various administrative positions at the University of Hawaii-Manoa. He also serves on the Boards of Cyanotech Corporation, the Pacific International Center for High Technology Research and Hawaii Cultured Pearls, Inc. Information on Mr. Oyer's business experience and directorship is indicated above.
The information required under this item by Item 405 of Regulation S-K is incorporated by reference to page 9 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
ITEM 11.
ITEM 11. EXECUTIVE COMPENSATION
HEI:
The information required under this item for HEI is incorporated by reference to pages 6 to 7 and 9 to 22 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
HECO:
The following tables set forth the information required for the chief executive officer of HECO and the four other most highly compensated HECO executive officers serving at the end of 1993. All executive compensation amounts presented for Harwood D. Williamson are duplicative of the amounts presented in HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
SUMMARY COMPENSATION TABLE
The following is the summary compensation table which sets forth the annual and long-term compensation of the chief executive officer of HECO and the four other most highly compensated executive officers of HECO serving at the end of 1993.
SUMMARY COMPENSATION TABLE
(1) Includes directors' fees of $28,000 in 1993 and $25,000 in 1992 for Mr. Williamson and directors' fees of $5,600 in 1993 and $4,700 in 1992 for Mr. Oyer. (2) The named executive officers are eligible for an incentive award under the Company's annual Executive Incentive Compensation Plan (EICP). A decision on EICP bonus payouts is made at the beginning of each year for the previous year's performance period. (3) Covers interest earned on deferred compensation and includes above-market earnings in the amount of $63,467 for 1993 and $57,498 for 1992 on deferred annual and Long-Term Incentive Plan (LTIP) payouts for Mr. Williamson. Also includes above-market earnings in the amount of $10,806 for 1993 and $9,790 for 1992 on deferred annual payouts for Mr. Oyer. (4) Includes a special one-time, premium-priced grant of 40,000 shares without dividend equivalents for Mr. Williamson in 1992. Other options granted in each of the three years for Mr. Williamson included dividend equivalents. For each of the other named executive officers, options granted in 1993 and 1991 did not include dividend equivalents. (5) LTIP payouts are determined in April each year for the three-year cycle ending on December 31 of the previous calendar year. In 1993, only Mr. Williamson was eligible to receive a LTIP payout; however, no LTIP payout was received for the 1990-1992 performance cycle because none of the minimum earnings threshold levels were achieved. The determination of whether there will be a payout for Mr. Williamson under the 1991-1993 LTIP will not be made until April 1994. (6) Represents amounts accrued by the Company in 1993 for certain death benefits provided to the named executive officers. In 1992 and 1991, the Company did not accrue for these benefits. Additional information is incorporated by reference to page 19 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22. Covers reimbursement of moving expenses for Mr. May in 1992. (7) Mr. May joined HECO as the Senior Vice President on February 1, 1992.
OPTION GRANTS IN LAST FISCAL YEAR
The following table shows the HEI stock options which were granted in 1993 to the executives named in the HECO Summary Compensation Table, all of which are nonqualified stock options. The practice of granting stock options, which may include dividend equivalent shares, has been followed each year since 1987.
(1) For the 20,000 option shares granted with an exercise price of $38.27 per share, additional dividend equivalent shares are granted to Mr. Williamson at no additional cost throughout the four-year vesting period (vesting in equal installments) which begins on the date of grant. Dividend equivalents are computed, as of each dividend record date, both with respect to the number of shares under the option and with respect to the number of dividend equivalent shares previously credited to the participant and not issued during the period prior to the dividend record date. Accelerated vesting is provided in the event a Change-in-Control occurs. No stock appreciation rights have been granted under the Company's current benefit plans.
(2) Based on a Binomial Option Pricing Model which is a variation of the Black-Scholes Option Pricing Model. For the stock options granted with a 10-year option period, an exercise price of $38.27, and with additional dividend equivalent shares granted for the first four years of the option, the Binomial Value is $9.66 per share. The following assumptions were used in the model: Stock Price: $38.27; Exercise Price: $38.27; Term: 10 years; Volatility: .55; Interest Rate: 6.0%; and Dividend Rate: 6.4%. The following were the valuation results: Binomial Option Value: $5.03; Dividend Credit Value: $4.63; and Total Value: $9.66.
AGGREGATED OPTION EXERCISES AND FISCAL YEAREND OPTION VALUE TABLE
The following table shows the HEI stock options, including dividend equivalents, exercised in 1993 by the named executive officers in the HECO Summary Compensation Table. Also shown is the number and value of unexercised options and dividend equivalents at the end of 1993. Under the Stock Option and Incentive Plan, dividend equivalents were granted to Mr. Williamson as part of the stock option award, except for the one-time, premium-priced grant in May 1992. For each of the other named executive officers, options granted in 1993 and 1991 did not include dividend equivalents.
Dividend equivalents permit a participant who exercises a stock option to obtain at no additional cost, in addition to the option shares, the amount of dividends declared on the number of shares of common stock with respect to which the option is exercised during the period between the grant and the exercise of the option. Dividend equivalents are computed, as of each dividend record date throughout the four-year vesting period (vesting in equal installments), which begins on date of grant, both with respect to the number of shares underlying the option and with respect to the number of dividend equivalent shares previously credited to the executive officer and not issued during the period prior to the dividend record date.
AGGREGATED OPTION EXERCISES IN LAST FISCAL YEAR AND FISCAL YEAREND OPTION VALUES
(1) Includes dividend equivalents of $79,916 exercisable and $26,296 unexercisable for Mr. Williamson and dividend equivalents of $25,830 exercisable for Mr. Oyer. All options were in the money (where the option price is less than the closing price on December 31, 1993) except the 1990 stock option grant at $36.01 per share, the 1992 stock option grant at $35.94 per share, and the 1993 stock option grant at $38.27 per share and the 1992 premium-priced grant at $41.00 per share. Value based on closing price of $35.875 per share on the New York Stock Exchange on December 31, 1993.
LONG-TERM INCENTIVE PLAN AWARDS TABLE
A Long-Term Incentive Plan award was made to one of the named executive officers in the HECO Summary Compensation Table, Mr. Williamson. Additional information required under this item is incorporated by reference to page 13 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
PENSION PLAN
The Retirement Plan for Employees of Hawaiian Electric Industries, Inc. and Participating Subsidiaries (the Retirement Plan) provides a monthly retirement pension for life. Additional information required under this item is incorporated by reference to pages 14 to 15 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22. As of December 31, 1993, the named executive officers in the HECO Summary Compensation Table had the following number of years of credited service under the Retirement Plan: Mr. Williamson, 37 years; Mr. May, 1 year; Mr. Oyer, 27 years; Mr. Rodrigues, 23 years; and Mr. Iwahiro, 34 years.
CHANGE-IN-CONTROL AGREEMENT
Messrs. Williamson and May are the only named executive officers in the HECO Summary Compensation Table in which HEI has entered into a Change-in-Control Agreement. Additional information required under this item is incorporated by reference to page 15 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
Based on W-2 earnings for the five most recent years (1989-1993) or the portion of such period during which the executive performed personal service for HEI and its subsidiaries, the lump sum severance would be as follows: Mr. Williamson - $1,035,551 and Mr. May - $869,890.
COMPENSATION COMMITTEE REPORT ON EXECUTIVE COMPENSATION
INTRODUCTION
Decisions on executive compensation for the named executive officers are made by the Compensation Committee of the HEI Board of Directors which is composed of six independent nonemployee directors. All decisions by the Compensation Committee are reviewed by the full HEI Board except for decisions about HEI's stock based plans, which must be made solely by the Committee in order to satisfy Securities Exchange Act Rule 16b-3.
The Committee has retained the services of an independent compensation consulting firm to assist in executive compensation matters.
Except for specific compensation decisions regarding Mr. Williamson which are discussed below, additional information required under this item is incorporated by reference to pages 16 through 19 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
BASE SALARY
Mr. Williamson's base salary is determined based on the recommendation of Robert F. Clarke, President and Chief Executive Officer of HEI and Chairman of the Board of HECO, within the recommended salary range and the Committee's approval. Mr. Clarke's recommendation is based on an overall evaluation of Mr. Williamson's performance during the preceding year. This evaluation is subjective in nature and takes into account all aspects of Mr. Williamson's responsibilities at the discretion of Mr. Clarke. Mr. Williamson's base salary was raised from an annual rate of $300,000 to an annual rate of $320,000, effective May 1, 1993. This action by the Committee was subsequently ratified by the HECO Board of Directors.
STOCK OPTIONS
The 1993 stock option award to Mr. Williamson of 8,000 shares of HEI Common Stock plus dividend equivalents was based on the consultant's recommendation and the independent evaluation of an appropriate award level by Mr. Clarke and the HEI Compensation Committee. In this evaluation, the Committee took into account prior awards to Mr. Williamson and an overall subjective evaluation of Mr. Williamson's job performance.
HECO BOARD OF DIRECTORS COMMITTEES OF THE HECO BOARD
The Board of Directors of HECO has only one standing committee, the Audit Committee, which is comprised of three nonemployee directors: Ben F. Kaito, Chairman, and Mildred D. Kosaki and Diane J. Plotts. In 1993, the Audit Committee held four meetings to review with management, the internal auditor and HECO's independent auditors the activities of the internal auditor, the results of the annual audit by the independent auditor and the financial statements which are included in HECO's 1992 Annual Report to Stockholder. The Audit Committee holds such meetings as it deems advisable to review the financial operations of HECO.
REMUNERATION OF THE HECO DIRECTORS AND ATTENDANCE AT MEETINGS
In 1993, William G. Foster (who passed away in October 1993), Mildred D. Kosaki and Paul C. Yuen were the only nonemployee directors of HECO who were not also directors of HEI. They were paid a retainer of $12,000, one-half of which was distributed in the common stock of HEI pursuant to the HEI Nonemployee Director Stock Plan and one-half of which was distributed in cash. The number of shares of stock distributed was based on a price of $38.27 per share, which is equal to the average of the daily high and low sales prices of HEI common stock for all trading days in March 1993, divided into $6,000, with a cash payment made in lieu of any fractional share. In addition, a fee of $700 was paid in cash to each director for each Board and Committee meeting attended by the director. The Chairman of the Audit Committee was paid an additional $100 for each Committee meeting attended.
In 1993, there were six regular bi-monthly meetings and one special meeting of the Board of Directors. All incumbent directors, except William G. Foster, attended at least 75% of the total number of meetings of the Board and Committee on which they served.
HECO participates in the Nonemployee Director Retirement Plan described on page 7 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
ITEM 12.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
HEI:
The information required under this item is incorporated by reference to pages 8 and 9 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
HECO:
HEI owns all of the common stock of HECO, which is HECO's only class of voting securities. HECO has also issued and has outstanding various series of preferred stock, the holders of which, upon certain defaults in dividend payments, have the right to elect a majority of the directors of HECO.
The following table shows the shares of HEI common stock beneficially owned by each HECO director, named HECO executive officers as listed in the Summary Compensation Table on page 57 and by HECO directors and officers as a group, as of February 10, 1994, based on information furnished by the respective individuals.
* Also a named executive officer listed in the Summary Compensation Table on page 57.
** Excludes HECO directors Messrs. Clarke, Henderson, Kaito, and Williamson and Ms. Plotts, who also serve on the HEI Board of Directors. The information required is incorporated by reference to pages 8 and 9 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22. Messrs. Clarke and Williamson are also named executive officers listed in the Summary Compensation Table on page 10 of the above-referenced Definitive Proxy Statement of HEI.
***The number of shares of common stock beneficially owned by any HECO director or by all HECO directors and officers as a group does not exceed 1% of the outstanding common stock of HEI.
(1) Sole voting and investment power.
(2) Shared voting and investment power (shares registered in name of respective individual and spouse).
(3) Shares owned by spouse, children or other relatives sharing the home of the director or an officer in the group and in which personal interest of the director or officer is disclaimed.
(4) Stock options exercisable within 60 days after February 10, 1994, under the 1987 Stock Option and Incentive Plan, as amended. Shares for Mr. Oyer include accompanying dividend equivalents (720 shares) for stock options awarded in 1988 only.
ITEM 13.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
HEI:
The information required under this item is incorporated by reference to pages 21 to 23 of HEI's Definitive Proxy Statement, prepared for the Annual Meeting of Stockholders to be held on April 19, 1994, and filed herein as HEI Exhibit 22.
HECO:
As of December 31, 1992, T. Michael May, Senior Vice President of HECO, was indebted to HECO in the amount of $290,000 by reason of loans made to him by HECO in 1992 for relocation purposes. The noninterest-bearing notes were due in 1993. In 1993, $110,000 of Mr. May's indebtedness was paid and the remaining $180,000 was converted to a 15-year note bearing interest at 6.28%. The note is due in 2008 or upon demand, if Mr. May ceases to be employed by HECO, and is secured by a second mortgage on real estate. As of December 31, 1993, Mr. May was indebted to HECO in the amount of $180,000.
PART IV
ITEM 14.
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a)(1) FINANCIAL STATEMENTS
The following financial statements contained in HEI's 1993 Annual Report to Stockholders and HECO's 1993 Annual Report to Stockholder, portions of which are filed by HEI as Exhibit 13(a) and, portions of which are filed by HECO as Exhibit 13(b), respectively, are incorporated by reference in Part II, Item 8, of this Form 10-K:
(a)(2) FINANCIAL STATEMENT SCHEDULES
The following financial statement schedules for HEI and HECO are included in this Report on the pages indicated below:
Certain Schedules, other than those listed, are omitted because they are not required, or are not applicable, or the required information is shown in the consolidated financial statements or notes included in HEI's 1993 Annual Report to Stockholders and HECO's 1993 Annual Report to Stockholder, which financial statements are incorporated herein by reference.
(a)(3) EXHIBITS
Exhibits for HEI and HECO and their subsidiaries are listed in the "Index to Exhibits" found on pages 87 through 94 of this Form 10-K. The exhibits listed for HEI and HECO are listed in the index under the headings "HEI" and "HECO," respectively, except that the exhibits listed under "HECO" are also considered exhibits for HEI.
(b) REPORTS ON FORM 8-K
HEI AND HECO:
During the fourth quarter of 1993, HEI and HECO filed three Current Reports, Forms 8-K, with the SEC. In the Form 8-K dated October 5, 1993, HEI and HECO filed information under Item 5 regarding HECO and its subsidiaries kilowatthour sales forecast, PTI's report on HECO's power outage, and income taxes. In the Form 8-K dated November 17, 1993, HEI and HECO filed information under Item 5 regarding the HELCO rate case filed in November 1993, MECO rate case filed in November 1991, HECO's comments on PTI's report on HECO's power outage, HELCO and MECO transportation of heavy fuel oil, liquidity and capital resources- electric utility, Kalaeloa Partners, L.P. and AES Barbers Point, Inc. and discontinued operations-insurance companies. In the Form 8-K dated December 27, 1993, HEI and HECO filed information under Item 5 regarding HECO filing its 1995 rate case.
(KPMG Peat Marwick Letterhead)
INDEPENDENT AUDITORS' REPORT
The Board of Directors and Shareholders Hawaiian Electric Industries, Inc.:
Under date of February 11, 1994, we reported on the consolidated balance sheets of Hawaiian Electric Industries, Inc. and subsidiaries as of December 31, 1993 and 1992, and the related consolidated statements of income, retained earnings and cash flows for each of the years in the three-year period ended December 31, 1993, as contained in the 1993 annual report to shareholders. These consolidated financial statements and our report thereon are incorporated by reference in the annual report on Form 10-K for the year 1993. In connection with our audits of the aforementioned consolidated financial statements, we also have audited the related financial statement schedules as listed in the accompanying index. These financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statement schedules based on our audits.
In our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.
As discussed in note 15 to the consolidated financial statements, effective January 1, 1993, the Company changed its method of accounting for income taxes. Additionally, as discussed in note 18 to the consolidated financial statements, effective January 1, 1993, the Company changed its method of accounting for postretirement benefits other than pensions.
/s/ KPMG Peat Marwick
Honolulu, Hawaii February 11, 1994
[KPMG Peat Marwick letterhead]
The Board of Directors and Shareholder Hawaiian Electric Company, Inc.:
Under date of February 11, 1994, we reported on the consolidated balance sheets and consolidated statements of capitalization of Hawaiian Electric Company, Inc. (a wholly-owned subsidiary of Hawaiian Electric Industries, Inc.) and subsidiaries as of December 31, 1993 and 1992, and the related consolidated statements of income, retained earnings and cash flows for each of the years in the three-year period ended December 31, 1993, as contained in the 1993 annual report to shareholder. These consolidated financial statements and our report thereon are incorporated by reference in the annual report on Form 10-K for the year 1993. In connection with our audits of the aforementioned consolidated financial statements, we also have audited the related financial statement schedules as listed in the accompanying index. These financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statement schedules based on our audits.
In our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.
As discussed in note 7 to the consolidated financial statements, effective January 1, 1993, the Company changed its method of accounting for income taxes. Additionally, as discussed in note 10 to the consolidated financial statements, effective January 1, 1993, the Company changed its method of accounting for postretirement benefits other than pensions.
/s/ KPMG Peat Marwick
Honolulu, Hawaii February 11, 1994
Hawaiian Electric Industries, Inc. SCHEDULE I -- MARKETABLE SECURITIES - OTHER INVESTMENTS December 31, 1993
* Represents cost of each issue, except for: ASB's other securities held for trading, which are stated at market, and mortgage-backed securities, which are stated at amortized cost; and MPC's investment in real estate partnerships, which are stated in accordance with the equity method of accounting. ** Secured by residential property. *** Not actively traded. Fair value considered to equal cost basis or amount at which security is carried in the balance sheet.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE II--AMOUNTS RECEIVABLE FROM RELATED PARTIES AND UNDERWRITERS, PROMOTERS AND EMPLOYEES OTHER THAN RELATED PARTIES December 31, 1993
(a) Two unsecured promissory notes payable. Interest rate is based on Bank of Hawaii's prime rate plus 2% for the first note and Bank of Hawaii's prime rate plus 0.75% for the second note.
(b) In May 1993, Baldwin*Malama (B*M) was reorganized as a limited partnership in which Malama Development Corp. (MDC) is the sole general partner and Baldwin Pacific Properties, Inc. (BPPI) is the sole limited partner. In conjunction with the dissolution of the B*M general partnership and formation of the limited partnership, MPC agreed to loan $1.6 million to BPPI and up to $15 million to the limited partnership, and beginning in May 1993, MDC consolidated the accounts of B*M. Previously, MDC accounted for its investment in B*M under the equity method. At December 31, 1993, the outstanding balances on MPC's loan to B*M was $10.6 million, which was eliminated in consolidation as an intercompany account. The interest rate is based on one-half of Bank of Hawaii's prime plus 8.5%. The loan matures in May 1995 and is secured by security interest in real property, option to purchase land, and assignments of BPPI and MDC's partnership interests.
(c) Two unsecured noninterest-bearing notes payable from T. Michael May, Senior Vice President of Hawaiian Electric Company, Inc. (HECO), due and collected in 1993.
(d) Unsecured noninterest-bearing note payable from Warren H. W. Lee, President of Hawaii Electric Light Co., Inc. (HELCO), which note was extended and is currently due in 1995 or upon demand, if he ceases to be employed by HELCO.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE II - AMOUNTS RECEIVABLE FROM RELATED PARTIES AND UNDERWRITERS, PROMOTERS AND EMPLOYEES OTHER THAN RELATED PARTIES December 31, 1992
(a) On August 17, 1992, Malama Mohala Corp. (MMO), a wholly owned subsidiary of Malama Pacific Corp. (MPC), acquired MDT BF Limited Partnership's (MDT) 50% interest in Ainalani Associates (Ainalani), a joint venture between MMO and MDT. Prior to the acquisition of MDT's interest in Ainalani, MMO accounted for its investment in Ainalani under the equity method. Subsequent to the acquisition, MMO consolidated all of Ainalani's assets and liabilities. Consequently, $19,497,000 of accounts receivable from Ainalani was eliminated as a result of the acquisition. Thus, only $1,001,000 of cash was actually collected.
(b) Two unsecured promissory notes payable, due December 31, 1992, extension of maturity dates are being arranged. Interest rate is based on Bank of Hawaii's prime rate plus 2% for the first note and Bank of Hawaii's prime rate plus 0.75% for the second note.
(c) Two unsecured noninterest-bearing notes payable from T. Michael May, Senior Vice President of Hawaiian Electric Company, Inc. (HECO), due in 1993 or upon demand, if he ceases to be employed by HECO.
(d) Unsecured noninterest-bearing note payable from Warren H. W. Lee, President of Hawaii Electric Light Co., Inc. (HELCO), due in 1993 or upon demand, if he ceases to be employed by HELCO.
Hawaiian Electric Industries, Inc. SCHEDULE II--AMOUNTS RECEIVABLE FROM RELATED PARTIES AND UNDERWRITERS, PROMOTERS AND EMPLOYEES OTHER THAN RELATED PARTIES December 31, 1991
(a) Promissory note payable, due July 1992 with an option to extend to July 1993. Interest rate is based on Bank of Hawaii's prime rate plus 3.5%. Promissory note is secured by real estate, the joint venture's interest in a partnership and contract rights.
(b) Promissory note payable, due in 1995, except certain events may trigger earlier partial repayment. Interest rate is based on Bank of Hawaii's prime rate plus 2%. Promissory note is secured by real estate, the joint venture's interest in a partnership and contract rights.
(c) Unsecured promissory note payable, due December 1992. Interest rate is based on Bank of Hawaii's prime rate plus 2%.
Hawaiian Electric Industries, Inc. SCHEDULE III -- CONDENSED FINANCIAL INFORMATION OF REGISTRANT HAWAIIAN ELECTRIC INDUSTRIES, INC. (PARENT COMPANY) BALANCE SHEETS
As of December 31, 1993, HEI guaranteed debt of its subsidiaries and affiliates amounting to $13 million. In addition, in connection with the acquisition of HIG, HEI has agreed to indemnify HIG with respect to 1985 and 1986 claims that exceed an aggregate of $10.8 million up to $12.8 million and 50% of the claims that exceed an aggregate of $12.8 million up to $13.8 million. HEIDI has made a provision for the estimated liability related to these claims. Pursuant to the settlement agreement with the Rehabilitator of HIG entered into in early 1994, which agreement is subject to court approval, HEI will be relieved of all obligations with respect to the indemnification of HIG.
The aggregate payments of principal required on long-term debt subsequent to December 31, 1993 are $26 million in 1994, $1 million in 1995, $37 million in 1996, $51 million in 1997, $21 million in 1998 and $65 million thereafter.
Hawaiian Electric Industries, Inc. SCHEDULE III--CONDENSED FINANCIAL INFORMATION OF REGISTRANT (continued) HAWAIIAN ELECTRIC INDUSTRIES, INC. (PARENT COMPANY) STATEMENTS OF INCOME
Hawaiian Electric Industries, Inc. SCHEDULE III -- CONDENSED FINANCIAL INFORMATION OF REGISTRANT (continued) HAWAIIAN ELECTRIC INDUSTRIES, INC. (PARENT COMPANY) STATEMENTS OF CASH FLOWS
Supplemental disclosures of noncash activities:
In December 1992, the Board of Directors of HEI adopted a resolution which converted $9.5 million of long-term debt of HERS to equity. HEI assumed the $9.5 million of HERS' long-term debt in a noncash transaction.
Common stock dividends reinvested by stockholders in HEI common stock in noncash transactions amounted to $17 million in 1993, $15 million in 1992 and $14 million in 1991.
Hawaiian Electric Industries, Inc. SCHEDULE V--PROPERTY, PLANT AND EQUIPMENT Year ended December 31, 1993
(a) Additions at cost include a $7.0 million allowance for equity funds used during construction and noncash contributions in aid of construction received in 1993 with an estimated fair value of $2.8 million.
(b) Includes transfers, adjustments and other charges and credits.
(c) Includes the estimated fair value of noncash contributions in aid of construction of $23 million received in prior years, but recognized in 1993.
Hawaiian Electric Industries, Inc. SCHEDULE V--PROPERTY, PLANT AND EQUIPMENT December 31, 1992 and 1991
(a) Neither additions nor retirements in 1992 and 1991 amounted to more than 10% of the ending balance as of the end of each of those respective years.
(b) Additions at cost and retirements amounted to $197.4 million and $13.4 million, respectively, in 1992. The additions include a $6.8 million allowance for equity funds used during construction.
(c) Additions at cost and retirements amounted to $161.5 million and $6.9 million respectively, in 1991. The additions include a $4.0 million allowance for equity funds used during construction.
Hawaiian Electric Company, Inc. SCHEDULE V--PROPERTY, PLANT AND EQUIPMENT Year ended December 31, 1993
(a) Additions at cost include a $7.0 million allowance for equity funds used during construction and noncash contributions in aid of construction received in 1993 with an estimated fair value of $2.8 million.
(b) Includes transfers, adjustments and other charges and credits.
(c) Includes the estimated fair value of noncash contributions in aid of construction of $23 million received in prior years, but recognized in 1993.
Hawaiian Electric Company, Inc. SCHEDULE V--PROPERTY, PLANT AND EQUIPMENT Year ended December 31, 1992
(a) Additions at cost include a $6.8 million allowance for equity funds used during construction.
(b) Includes transfers, adjustments and other charges and credits.
Hawaiian Electric Company, Inc. SCHEDULE V--PROPERTY, PLANT AND EQUIPMENT December 31, 1991
(a) Neither additions nor retirements in 1991 amounted to more than 10% of the ending balance as of December 31, 1991.
(b) Additions at cost and retirements amounted to $145.9 million and $4.9 million, respectively, in 1991. The additions include a $4.0 million allowance for equity funds used during construction.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE VI--ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION OF PROPERTY, PLANT AND EQUIPMENT Year ended December 31, 1993
(a) Gross salvage on plant retired, cost of removal, transfers and adjustments.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE VI--ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION OF PROPERTY, PLANT AND EQUIPMENT Year ended December 31, 1992
(a) Gross salvage on plant retired, cost of removal, transfers and adjustments.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE VI--ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION OF PROPERTY, PLANT AND EQUIPMENT Year ended December 31, 1991
(a) Gross salvage on plant retired, cost of removal, transfers and adjustments.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE VIII--VALUATION AND QUALIFYING ACCOUNTS Years ended December 31, 1993, 1992 and 1991
(a) Primarily bad debts recovered. (b) Bad debts charged off. (c) Net charge-offs.
Hawaiian Electric Industries, Inc. SCHEDULE IX--SHORT-TERM BORROWINGS Years ended December 31, 1993, 1992 and 1991
(a) Unsecured promissory notes sold through dealers with a term of three months or less.
(b) Borrowed under a formal credit arrangement with a bank with a term of six months.
(c) Borrowed under formal credit agreements which, as of yearend, had maturities of less than twelve months.
(d) Computed by multiplying the principal amounts of short-term borrowings by the number of days during which those borrowings were outstanding and dividing the sum of the products by the number of days in the year.
(e) Computed by dividing interest expense on short-term borrowings for the period by the average amount of short-term borrowings outstanding during the period.
Hawaiian Electric Company, Inc. SCHEDULE IX--SHORT-TERM BORROWINGS Years ended December 31, 1993, 1992 and 1991
(a) Unsecured promissory notes sold through dealers with a term of three months or less.
(b) Computed by multiplying the principal amounts of short-term borrowings by the number of days during which those borrowings were outstanding and dividing the sum of the products by the number of days in the year.
(c) Computed by dividing interest expense on short-term borrowings for the period by the average amount of short-term borrowings outstanding during the period.
Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. SCHEDULE X--SUPPLEMENTARY INCOME STATEMENT INFORMATION Years ended December 31, 1993, 1992 and 1991
INDEX TO EXHIBITS
The exhibits designated by an asterisk (*) are filed herein. The exhibits not so designated are incorporated by reference to the indicated filing. A copy of any exhibit may be obtained upon written request for a $0.20 per page charge from the HEI Stock Transfer Division, P.O. Box 730, Honolulu, Hawaii 96808-0730.
Hawaiian Electric Industries, Inc. EXHIBIT 11 -- COMPUTATION OF EARNINGS PER SHARE OF COMMON STOCK Years ended December 31, 1993 1992,1991, 1990 AND 1989
Note: The dilutive effect of stock options is not material.
Hawaiian Electric Industries, Inc. EXHIBIT 12(a) -- COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES Years ended December 31, 1993, 1992, 1990 AND 1989
(1) Excluding interest on ASB deposits.
(2) Including interest on ASB deposits.
(3) Total interest charges exclude interest on nonrecourse debt from leveraged leases which is not included in interest expense in HEI's consolidated statements of income.
Hawaiian Electric Industries, Inc. EXHIBIT 12(a) -- COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES Years ended December 31, 1993, 1992, 1991, 1990 and 1989--Continued
(1) Excluding interest on ASB deposits.
(2) Including interest on ASB deposits.
(3) Total interest charges exclude interest on nonrecourse debt from leveraged leases which is not included in interest expense in HEI's consolidated statements of income.
Hawaiian Electric Company, Inc. EXHIBIT 12(b) -- COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES Years ended December 31, 1993, 1992, 1991, 1990 and 1989
* Does not reflect corporate-level segment cost and tax allocation policy adjustments in 1990.
Hawaiian Electric Industries, Inc. EXHIBIT 21(a) -- LIST OF SUBSIDIARIES
The following is a list of all subsidiary corporations of the registrant as of March 21, 1994:
Hawaiian Electric Company, Inc. EXHIBIT 21(b) -- LIST OF SUBSIDIARIES
The following is a list of all subsidiary corporations of the registrant as of March 21, 1994:
[KPMG Peat Marwick letterhead]
HEI EXHIBIT 23
The Board of Directors Hawaiian Electric Industries, Inc.:
We consent to incorporation by reference in Registration Statement Nos. 33-52520 and 33-58820 on Form S-3 and in Registration Statement Nos. 33-65234 and 33-43892 on Form S-8 of Hawaiian Electric Industries, Inc. of our report dated February 11, 1994, relating to the consolidated balance sheets of Hawaiian Electric Industries, Inc. and subsidiaries as of December 31, 1993 and 1992, and the related consolidated statements of income, retained earnings and cash flows for each of the years in the three-year period ended December 31, 1993, which report is incorporated by reference in the 1993 annual report on Form 10-K of Hawaiian Electric Industries, Inc. Our report refers to changes in the method of accounting for income taxes and postretirement benefits other than pensions effective January 1, 1993. We also consent to incorporation by reference of our report dated February 11, 1994 relating to the financial statement schedules of Hawaiian Electric Industries, Inc. in the aforementioned 1993 annual report on Form 10-K, which report is included in said Form 10-K.
/s/ KPMG Peat Marwick
Honolulu, Hawaii March 22, 1994
Hawaiian Electric Company, Inc. EXHIBIT 99(b) -- RECONCILIATION OF ELECTRIC UTILITY OPERATING INCOME PER HEI AND HECO CONSOLIDATED STATEMENTS OF INCOME
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized. The signatures of the undersigned companies shall be deemed to relate only to matters having reference to such companies and any subsidiaries thereof.
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 registrants and in their capacities at March 22, 1994. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named companies and any subsidiaries thereof.
SIGNATURES (continued)
SIGNATURES (continued)