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FORM 10-K--ANNUAL REPORT PURSUANT TO SECTION 13
OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
(As last amended in Rel. No. 34-31327, eff. 10-21-92)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(x)Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange
Act of 1934
For the fiscal year ended December 31, 1999
( )Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange
Act of 1934
For the transition period from_____________________to__________________________
Commission file Number 33-42125
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Chugach Electric Association, Inc.
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(Exact name of registrant as specified in its charter)
Alaska 92-0014224
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(State or other jurisdiction of
incorporation or organization) (I.R.S. Employer Identification No.)
5601 Minnesota Drive, Anchorage, Alaska 99518
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(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code (907) 563-7494
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
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Securities registered pursuant to Section 12(g) of the Act:
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(Title of class)
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(Title of class)
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securites Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was
required to file such reports), and (2) has been subject to such filing
requirements for the past 90 days. /x/ Yes / / No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. N/A
State the aggregate market value of the voting stock held by non-affiliates
of the registrant. The aggregate market value shall be computed by reference
to the price at which the stock was sold, or the average bid and asked prices
of such stock, as of a specified date within 60 days prior to the date of
filing. (See definition of affiliate in Rule 405, 17 CFR 230.405). N/A
CHUGACH ELECTRIC ASSOCIATION, INC.
1999 Form 10-K Annual Report
Table of Contents
PART I Page
Item 1 - Business 1
Item 2 - Properties 12
Item 3 - Legal Proceedings 18
Item 4 - Submission of Matters to a Vote of Security Holders 20
PART II
Item 5 - Market for Registrant's Common Equity and Related
Stockholder Matters 20
Item 6 - Selected Financial Data 21
Item 7 - Management's Discussion and Analysis of Financial Condition
and Results of Operations 22
Item 7A - Quantitative and Qualitative Disclosures About Market Risk 34
Item 8 - Financial Statements and Supplementary Data 36
Item 9 - Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure 59
PART III
Item 10 - Directors and Executive Officers of the Registrant 59
Item 11 - Executive Compensation 61
Item 12 - Security Ownership of Certain Beneficial Owners and Management 65
Item 13 - Certain Relationships and Related Transactions 65
Item 14 - Exhibits, Financial Statement Schedules and Reports on Form 8-K 65
SIGNATURES 80
3
CAUTION REGARDING FORWARD-LOOKING STATEMENTS
Statements in this report that do not relate to historical facts, including
statements relating to future plans, events or performance, are forward-looking
statements that involve risks and uncertainties. Actual results, events or
performance may differ materially. Readers are cautioned not to place undue
reliance on these forward-looking statements, that speak only as of the date of
this report and the accuracy of which is subject to inherent uncertainty.
Chugach Electric Association, Inc. (Chugach or the Association) undertakes no
obligation to publicly release any revisions to these forward-looking statements
to reflect events or circumstances that may occur after the date of this report
or the affect of those events or circumstances on any of the forward-looking
statements contained in this report.
PART I
Item 1 - Business
GENERAL
Chugach is the largest electric utility in Alaska. Chugach was organized as an
Alaska not-for-profit electric cooperative in 1948 and is engaged in the
generation, transmission and distribution of electricity to approximately 71,000
metered locations in the Anchorage and upper Kenai Peninsula areas. Through an
interconnected regional electrical system, Chugach's power flows throughout
Alaska's Railbelt, a 600-mile-long area stretching from the coastline of the
southern Kenai Peninsula to the interior of the state, including Alaska's
largest cities, Anchorage and Fairbanks. On a regular basis, through its direct
service to retail customers and indirectly through its wholesale and economy
energy sales, Chugach provides some or all of the electricity used by
approximately two-thirds of Alaska's electric customers. In addition, on a
periodic basis, Chugach provides electricity to the city-core customers of
Anchorage Municipal Light & Power (AML&P).
Chugach also supplies much of the power requirements of three wholesale
customers, Matanuska Electric Association (MEA), Homer Electric Association
(Homer) and the City of Seward (Seward). Substantially all of Chugach's
currently-owned generating capacity is fueled by natural gas, which Chugach
purchases under long-term, relatively low-cost gas contracts. The remainder of
Chugach's generating resources are hydroelectric facilities. The Chugach system
includes 501.4 megawatts (MW) of installed generating capacity that is provided
by 15 solely-owned generating units, and another 11.7 MW of generating capacity
from two hydroelectric units that are owned jointly with MEA and AML&P. Chugach
operates 1,590 miles of distribution line and 402 miles of transmission line.
During 1999, Chugach sold 2.19 billion kilowatt hours (kWh) of power.
Cooperatives are business organizations that are owned by their members.
Cooperatives are designed to give groups of individuals or entities the
opportunity to serve their own needs in a particular area of business activity
and to solve their own problems in that area more effectively than when acting
individually. In addition, as not-for-profit organizations, cooperatives are
intended to provide services to their members at the lowest possible cost, in
part by eliminating the need to produce profits or a return on equity. Today,
cooperatives operate throughout the United States in such diverse areas as
utilities, agriculture, irrigation, insurance and credit. All cooperatives are
based upon similar principles and legal foundations. Since members' equity is
not considered an investment, a cooperative's objectives and policies are
oriented to serving member interests, rather than maximizing return on
investment.
Chugach's members are the consumers of the electricity sold by Chugach. As of
December 31, 1999, Chugach had approximately 56,858 retail members receiving
service at approximately 71,000 metered locations. The business and affairs of
Chugach are managed by the General Manager and are overseen by its seven-member
Board of Directors (the Board). Directors are elected at large by the membership
and serve three-year staggered terms. Each member is entitled to one vote. In
addition to voting for directors, members have voting rights with respect to the
sale, lease, or other disposition, except by mortgage or deed of trust, of all
or a substantial portion of Chugach's property.
Chugach customers are billed per a tariff rate on a monthly basis for
electrical energy consumed during the preceding month. Billing rates are
approved by the Regulatory Commission of Alaska (RCA), formerly the Alaska
Public Utilities Commission (APUC) (see Rate Regulation and Rates).
Rates (derived from the historic cost of service basis) may generate revenues in
excess of current period costs (net operating margins and nonoperating margins)
in any year and are designated on Chugach's Statements of Revenues, Expenses and
Patronage Capital as "assignable margins." Retained assignable margins are
designated on Chugach's balance sheet as "patronage capital" that is assigned to
each member on the basis of patronage.
In furtherance of Chugach's operations as a cooperative, Chugach credits to its
members, or patrons, all amounts received from the patrons for the furnishing of
electricity in excess of Chugach's operating costs, expenses and provision for
reasonable reserves. Such excess amounts (i.e., assignable margins) are
considered capital furnished by the patrons, and are credited to their accounts
and held by Chugach until such future time as they are retired and returned
without interest. Chugach's Bylaws provide that such capital credits are to be
retired (i) upon Chugach's dissolution or liquidation after payment of all of
Chugach's outstanding indebtedness or (ii) at any earlier time if the Board of
Directors determines that Chugach's financial condition will not be thereby
impaired. At December 31, 1999, Chugach has a practice of retiring patronage
capital on a first in-first out (FIFO) basis for retail customers. At the end of
1999, Chugach had authorized for retirement all retail capital credits through
1983 and approximately two-thirds of 1984 retail credits. Prior to 1999,
wholesale capital credits had been retired on a 10-year cycle pursuant to the
Equity Management Plan Settlement Agreement despite its expiration in 1995.
However, in 1999, there was no wholesale retirement as Chugach implemented a
plan to put wholesale and retail retirements on the same schedule. Approval of
actual capital credit retirements is at the discretion of the Association's
Board of Directors.
As an electric cooperative, Chugach is exempt from federal income taxation under
Section 501(c)(12) of the Internal Revenue Code (Code). Alaska electric
cooperatives must pay to the State of Alaska, in lieu of state and local ad
valorem, income and excise taxes, a tax at the rate of $0.0005 per kWh of
electricity sold in the retail market during the preceding year. In addition,
Chugach collects a regulatory cost charge of $.000309 per kWh of retail
electricity sold. This charge is assessed to fund the operations of the RCA. It
is a pass-through and thus does not impact Chugach margins.
Chugach's workforce consists of approximately 351 full-time employees.
Approximately two-thirds of Chugach's employees are members of the International
Brotherhood of Electrical Workers (IBEW). Chugach has three collective
bargaining agreements with the IBEW that are currently in negotiation. Although
each of the contracts expired January 31, 1998, the parties have agreed that the
contracts shall continue in effect until new contracts are put in place. All
outstanding issues will be decided through binding interest arbitration. The
IBEW cannot strike and Chugach cannot lockout under the continuing agreement.
Fact-finding before a third party fact finder/arbitrator took place in October
and November, 1999, who issued her fact-finding recommendations in mid-February,
2000. An arbitration hearing occurred in March 2000 on the remaining issues, and
a final decision from the arbitrator is anticipated by mid-May 2000.
Characteristics of the Service Areas of Chugach and its Largest Customers
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As indicated in the foregoing, the service areas of Chugach and its wholesale
and economy energy customers are often described collectively as the Railbelt
region of Alaska because the three geographic areas (the Interior, Southcentral
and the Kenai Peninsula) are linked by the Alaska Railroad.
Anchorage is the trade, service and financial center for most of Alaska and
serves as a major center for many state governmental functions. Other
significant contributing factors to the Anchorage economy include a large
federal government and military presence, tourism, air and rail transportation
facilities and headquarters support for the petroleum, mining and other basic
industries located elsewhere in the state.
The Matanuska-Susitna (Mat-Su) Borough is immediately north of the Municipality
of Anchorage, centered around the communities of Palmer and Wasilla. Although
agriculture, tourism, mining and forestry are factors in the economy of the
Matanuska-Susitna Borough, the economic well-being of the area is closely tied
to that of Anchorage and many Mat-Su residents commute to jobs in Anchorage.
The Kenai Peninsula is south of Anchorage with an economy substantially
independent of the Anchorage area. The most significant basic industry on the
Kenai Peninsula is the production and processing of petroleum products from the
Cook Inlet region. Other important basic industries include tourism and fish
harvesting and processing. Principal communities on the Kenai Peninsula are
Homer, Seward, Kenai and Soldotna.
Fairbanks is the center of economic activity for the central part of the state
(known as the Interior). Fairbanks (250 air miles north of Anchorage and about
400 air miles south of Alaska's northern border) is Alaska's second largest
city. Basic economic activities in the Fairbanks region include federal and
state government and military operations, the University of Alaska, tourism and
support of natural resource development in the Interior and northern parts of
the state. Recently a major gold mine commenced operation near Fairbanks. The
Trans-Alaska Pipeline System (crude oil) passes near Fairbanks on its route from
the North Slope oilfield.
Competition
Chugach has been active in the effort to promote customer choice in the retail
market in Anchorage. Chugach requested access over a neighboring utility's
distribution and transmission system and asked the APUC, now the RCA, to enforce
the request. The APUC ruled that open retail competition is permitted in Alaska
only after prior review and approval by the RCA.
Chugach has also been actively supporting the customer's right to choose their
electric power supplier at the State Legislature. Virtually all Alaskan
utilities have opposed Chugach's efforts to develop competition and are striving
to maintain exclusive service territories. At this time no bill relating to
customer choice has moved out of legislative committee.
To meet competitive challenges, Chugach has formed a Marketing Department,
continues to operate its key account program for larger customers and is
developing new services to enhance existing customers' satisfaction.
Rate Regulation and Rates
Chugach is subject to rate regulation by the Regulatory Commission of Alaska
(RCA).
Future demand and energy rate changes are sought through the general rate case
and other normal RCA procedures. While the formal ratemaking process typically
takes nine months to one year, it is within the RCA's authority to authorize,
after a notice period, rate changes on an interim-refundable basis. In addition,
the RCA has been willing to open limited dockets to resolve specific issues from
which expeditious decisions can often be generated.
In Order No. 18 of Docket U-96-37, a general rate case, at the urging of one of
Chugach's wholesale customers, the RCA ordered retroactive refunds in the
approximate amount of $1.2 million for fuel surcharge rates charged in 1995 -
1997. The Order is in connection with Chugach's fuel and purchased power cost
adjustment factors that are adjusted on a quarterly basis. It is Chugach's
position that retroactive refunds of quarterly surcharge revenues violate the
rules against retroactive ratemaking and constitutional due process protections.
Chugach has appealed this decision to the Superior Court for the State of
Alaska. Oral arguments were heard on January 28, 2000 but no decision has been
rendered. Chugach's request for stay of the Commission refund order has been
granted. It is not possible at this time to determine the outcome of this
appeal.
Order No. 18 in Docket U-96-37 also resolved methodological issues in the
calculation of base rates and allowed the provisions of the Settlement Agreement
to be implemented. As part of the Settlement Agreement with AEG&T/MEA/Homer,
Chugach committed that the demand and energy rate levels established on the 1995
test year in Docket U-96-37 will remain at no higher than those levels through
1999 and could be reduced if existing rates provide returns higher than
specified in the agreement. Chugach is required to grant a refund to Homer and
MEA retroactive to January 1, 1997 (based on the 1996 test year filing). A
provision for wholesale rate refunds of approximately $980,000, $993,000 and
$570,000 were recorded at December 31, 1997, December 31, 1998 and December 31,
1999, respectively, to accommodate certain rate adjustment clauses contained in
the Settlement Agreement. After wholesale customer review following the
procedures in the Settlement Agreement, Chugach filed the 1996 test year revenue
requirement in March 1999. The demand and energy rates based on the 1996 test
year were approved on an interim and refundable basis in June 1999. Chugach
expects a final RCA order in the year 2000.
In February 1998, Chugach and the City of Seward entered into a new power sales
agreement which contains provisions allowing Chugach to interrupt service to
Seward up to 12 times per year and provides for a 1/3 reduction in the demand
charge (approximately $350,000 annually). The RCA approved the contract as
proposed except that it shortened the term of the agreement so that it expires
September 1, 2001. Chugach will attempt to renegotiate the agreement but the
outcome of this effort cannot be predicted at this time.
The Association will continue to recover changes in its fuel and purchased power
expense levels through routine fuel surcharge filings with the RCA. See the Fuel
Surcharge section of Management's Discussion and Analysis of Financial Condition
and Results of Operations.
The Indenture of Trust, Series A, First Mortgage bonds (Indenture) dated
September 15, 1991,requires Chugach to set rates designed to yield margins-for-
interest (a TIER-like statistic) equal to at least 1.20 times total interest
expense. The authorized rate-setting TIER level of 1.35 has allowed Chugach to
achieve greater than the 1.20 margins for interest. In 1999, Chugach's achieved
TIER was 1.40.
Sales to Customers
The following table shows the energy sales to and electric revenues from
Chugach's retail, wholesale, and economy energy customers for the year ended
December 31, 1999:
Energy Loads and Revenues by Class of Customer
Percent of Total
MWh 1999 Revenues 1999 Revenues
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Direct retail sales:
Residential 513,493 $ 50,758,860 36.1%
Commercial 572,475 43,298,853 30.8%
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Total 1,085,968 94,057,713 66.9%
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Wholesale sales:
MEA 530,341 25,063,734 17.9%
Homer 435,655 17,357,727 12.4%
Seward 61,444 2,168,982 1.5%
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Total 1,027,440 44,590,443 31.8%
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Economy Energy Sales:
GVEA 76,684 1,860,960 1.3%
Other 161 3,913 0.0%
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Total 76,845 1,864,873 1.3%
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Total sales to
customers 2,190,253 $140,513,029 100.0%
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Note: 1999 Wholesale Revenues include a $569,202 provision for rate refund to
accommodate certain rate adjustment clauses contained in the Settlement
Agreement reached in Docket U-96-37.
Retail Customers
Service Territory. Chugach's retail service area covers the populated areas of
Anchorage as well as remote mountain areas and villages. The service area ranges
from the northern Kenai Peninsula on the South, to Tyonek on the West, to
Whittier on the East and to Fort Richardson on the North.
Customers. Chugach directly serves approximately 71,000 meters. There are
approximately 56,858 members of Chugach (some members are served by more than
one meter). Chugach's customers are primarily urban and suburban. The urban
nature of Chugach's customer base means that Chugach has a relatively high
customer density per line mile. Higher customer density means that fixed costs
can be spread over a greater number of customers. As a result of lower average
costs attributable to each customer, Chugach benefits from a greater stability
in revenue, as compared to a less dense distribution system in which each
individual customer would have a more significant impact on operating results.
For the past five years no retail customer accounted for more than 5% of
Chugach's revenues.
Wholesale Customers
Chugach is the principal supplier of power under wholesale power contracts with
MEA, Seward and Homer. Chugach's wholesale power contracts represented $44.6
million in revenues and 46.9% of Chugach's total MWh sales to customers in 1999.
MEA and Homer. Chugach's contract with AEG&T, a generation and transmission
cooperative of which MEA and Homer are the only full members and AML&P is an
associate member, for the benefit of MEA obligates MEA to purchase all of its
electric power requirements from Chugach. Contractually, MEA has the right,
subject to APUC approval, to convert to a net requirements purchaser of power
from Chugach, under which MEA would be obligated to buy its needed power from
Chugach, net of its power needs satisfied from any of its own or AEG&T's
resources (including from the 39 MW Soldotna 1 gas-fired generating station
owned by AEG&T).
After conversion to net requirements under the contract, MEA cannot reduce the
amount of power it purchases from Chugach below a certain minimum amount. MEA
also has the right, on seven years advance notice and subject to RCA approval,
to convert to a take-or-pay purchaser of a fixed amount of power. If MEA
converts to net-requirements service, MEA will be required to pay demand charges
based upon the highest post-1985 historical coincident peak on the MEA system.
Therefore, Chugach will continue to recover fixed costs if MEA converts to
net-requirements service. Also, Chugach's revenues from energy sales to MEA
would decline in proportion to the reduction in the energy sold, but this
decline would be largely offset by savings in the variable costs associated with
energy production. The MEA contract is in effect through December 31, 2014. This
contract does not protect against loss of load resulting from retail competition
in MEA's distribution service territory. It is not possible at this time to
estimate the potential impact on Chugach's revenues resulting from such
competition.
Chugach's contract with AEG&T for the benefit of Homer obligates Homer to take
or pay for 73 MW of capacity (demand), and not less than 350,000 MWh (energy)
per year. The Homer contract includes certain limitations on the costs that may
be included in the rates charged to Homer by Chugach. The Homer contract expires
on January 1, 2014. Homer's remaining resource requirements are provided by
AEG&T's Soldotna 1 unit and AEG&T shares attributable to Homer from the Bradley
Lake hydroelectric project. Chugach and AEG&T have signed a dispatch agreement
whereby Chugach has access to all of the Soldotna 1 unit output except that
which is required to supply Homer's load in excess of 73 MW. The term is for
40,000 operating hours or 10 years, whichever is first, although the term will
be extended by three years if Chugach makes significant use of the unit during
the last three years of the original contract term. AEG&T receives payment for
variable operating and maintenance costs plus a margin for energy produced by
the unit. Chugach obtained use of the unit output while AEG&T retained ownership
costs and responsibility. In 1999, Chugach used 62,208 MWh from the Soldotna
unit.
In October 1998, the Chugach Board of Directors authorized the General Manager
to enter into a revised dispatch agreement with Homer and AEG&T. Under the
agreement, Homer and AEG&T will relocate the Soldotna 1 unit to a UNOCAL
fertilizer production facility near Nikiski, Alaska in the Homer service area
and install equipment to produce process steam using heat recovery from the
turbine. The dispatch agreement allows Chugach to economically incorporate the
unit into Chugach's generation and transmission system and will ensure that
Homer purchases all energy available under the existing power supply contract.
Gas will be provided by UNOCAL to meet Homer loads in excess of 73 MW and may
provide a portion of the fuel for Homer loads in excess of the minimum energy
takes. The new dispatch agreement will replace the existing agreement when the
unit is relocated and will terminate coincident with the Homer power supply
contract in 2014.
Seward. Chugach currently provides all the firm power needs of Seward. A new
contract with Seward, with an interruptible provision, was approved by the APUC,
now the RCA, and sales to Seward amounted to 2.8% of Chugach's MWh sales to
customers in 1999.
Economy Customers
Golden Valley Electric Association. Under the terms of Chugach's agreement with
Golden Valley Electric Association (GVEA), GVEA is obligated, under certain
circumstances, to purchase, if available from Chugach, its non-firm energy needs
until 2008. Sales under this agreement accounted for 3.5% of Chugach's 1999 MWh
sales. Chugach and GVEA have entered into a tentative pooling agreement whereby
the resources of both utilities would be dispatched on a common basis to reduce
constraints on when non-firm energy would be available to GVEA. Construction of
a coal-fired generation facility at Healy (Healy Clean Coal Project)(HCCP)),
funded from a United States Department of Energy grant under the Clean
Coal Technology III Demonstration Program, is complete. This facility
completed testing in 1999 and has produced up to 50 MW of coal-fired power but
is shut down pending a contract dispute between GVEA and its owner. It is not
known when or if the plant will go into commercial operation. GVEA reduced
its purchases of non-firm energy from Chugach by taking firm power from HCCP.
Chugach's management does not believe that such a reduction will have a
material adverse effect on Chugach. The Ft. Knox gold mine, near Fairbanks,
with a load of 30-35 MW began operation during the last quarter of 1996.
FUEL SUPPLY
In 1999, 86% of Chugach's power was generated from gas, and 90% of that
gas-fired generation took place at Beluga.
Chugach's three sources of natural gas are (1) the Beluga River Field producers
[ARCO Alaska, Inc. (ARCO), AML&P (old Shell) and Chevron USA Inc. (Chevron)],
(2) Marathon Oil Company (Marathon) and (3) ENSTAR Natural Gas Company (ENSTAR).
ARCO, AML&P and Chevron each own one-third of the gas produced from the Beluga
River Field and in 1999 provided approximately equal shares of the Beluga gas.
Chugach has approximately 406 billion cubic feet (BCF) of gas committed to it
from the Beluga River Field producers and Marathon. Chugach currently uses about
20 BCF of natural gas per year for firm service. Chugach believes that this
usage will remain fairly constant and estimates that its current contract gas
will last 15 to 19 years. In 1996, Shell sold its interests in the Beluga River
Field to AML&P and AML&P assumed Shell's contractual obligations to sell natural
gas to Chugach. Chugach believes that this transfer will have no material effect
on the delivery of Beluga gas to Chugach.
The delivered price for Chugach's fuel supply is lower than that available to
other generators in the interconnected Railbelt. AML&P burns natural gas
purchased from the Beluga River Field producers and transported by ENSTAR.
Chugach has a transportation contract with ENSTAR to transport Chugach gas
purchased from Marathon or the Beluga River Producers to the Soldotna (AEG&T)
and/or International Power plants (International). The rate for firm
transportation is $0.63 per MCF and the rate for interruptible transportation is
$0.30 per MCF. There is a minimum monthly bill of $2,600. The primary reasons
that Chugach's fuel supply has a lower delivered price than that available to
other generators are (i) Chugach purchases its gas directly from producers
rather than from gas utilities and (ii) Chugach's power plants are located in
close proximity to gas fields so that there are insignificant transportation
costs included in the price of the fuel. AML&P currently depends on ENSTAR to
transport all of the gas it uses. The ENSTAR tariff rate for this service is
$105,000 per month plus $0.28 per MCF.
GVEA uses both coal-fired and oil-fired generators. Because of the high cost of
fuel oil, GVEA is normally an importer of lower cost power from the south.
Beluga River Field Producers
Chugach has similar requirements contracts with each of ARCO, AML&P (old Shell)
and Chevron that were executed in April 1989, superseding contracts that had
been in place since 1973. Each of the contracts with the Beluga River Field
producers provides for delivery of gas on different terms in three different
periods. Period 1 related to the delivery of gas previously committed by the
respective producer under the 1973 contracts terminated in June 1996. The
maximum deliverability under the Beluga and Marathon contracts is in excess of
the peak winter demand requirements of the Beluga plant and allows for increased
deliverability should Chugach's combined-cycle plant be out of service.
During Period 2, which began in June 1996 and continues until the earlier of the
delivery of 180 BCF of natural gas or December 31, 2013, Chugach is entitled to
take delivery of up to 180 BCF of natural gas (60 BCF per Beluga River Field
producer). During this period, Chugach is required to take 60% of its total fuel
requirements at Beluga from the three Beluga River Field producers, exclusive of
gas purchased at Beluga under the Marathon contract for use in making sales to
GVEA or certain other wholesale purchasers. The price for gas during this period
under the ARCO and AML&P (old Shell) contracts is approximately 88% (or $1.12
per MCF on December 31, 1999) of the price of gas under the Marathon contract
(described below), plus taxes. The price during this period under the Chevron
contract is approximately 110% (or $1.40 per MCF on December 31, 1999) of the
price of gas under the Marathon contract (described below), plus taxes.
During Period 3 under the Beluga River Field producers' contracts, which begins
at the earlier of December 31, 2013 or the end of Period 2, Chugach may become
entitled to take delivery of up to 120 BCF of natural gas (40 BCF per producer).
Whether any gas will be taken in Period 3, and the price and take requirements
with respect thereto, are to be determined in the future based upon then-current
market conditions.
Chugach also has supplemental, annually renewable contracts with the Beluga
River Field producers to supply supplemental gas (for peak periods of energy
usage) if they have it available in excess of the amounts guaranteed in the
basic contracts. The supplemental gas contracts raise the daily deliverability
of gas to an aggregate of 85,200 MCF per day from the Beluga River Field
producers. The base price of the gas under these contracts is the same as the
base price under the Marathon contract described below, plus taxes.
Marathon
Chugach entered into a requirements contract with Marathon in September 1988 for
an initial commitment of 215 BCF. The contract expires December 31, 2015, or, if
earlier, the date on which Marathon has delivered to Chugach a volume of gas in
total which equals or exceeds the total volume of gas that Marathon is required
to sell and deliver to Chugach under the agreement. The base price for gas under
the Marathon contract is $1.35 per MCF, adjusted quarterly to reflect the
percentage change between the preceding twelve-month period and a base period in
the average prices of West Texas Intermediate Crude Oil (a benchmark of the
Light Sweet Crude Oil Futures Index), the Producer Price Index for natural gas,
and the Consumer Price Index for heating fuel oil. The price on December 31,
1999, exclusive of taxes was $1.27 per MCF.
Under the terms of the Marathon contract, Marathon generally provides the
primary supply of gas required for sales to GVEA, all of Chugach's requirements
at Bernice Lake and 40% of the requirements at Beluga. Marathon also has a right
of first refusal to provide additional gas under any sales agreements that
Chugach may enter into with electric utilities that Chugach does not currently
serve.
ENSTAR Natural Gas Company
Chugach and ENSTAR signed a transportation agreement in December 1992 that was
approved by the APUC in January 1993, whereby ENSTAR would transport Chugach's
gas purchased from the Beluga producers or Marathon on a firm basis to both
Chugach's International Power Plant and AEG&T's Soldotna 1 Power Plant at a
transportation rate of $0.63 per MCF. In addition, ENSTAR agreed to transport
gas on an interruptible basis for off-system sales at a rate of $0.30 per MCF.
The agreement contains a minimum monthly bill of $2,600 for firm service.
Chugach holds a reservation to receive its gas requirements at International
Power Plant from ENSTAR under a tariff approved by the APUC in the event that
the transportation agreement is subsequently canceled. Under the currently
suspended tariff, ENSTAR is obligated to supply all of the gas Chugach desires
at a price approved by the APUC. There would be a monthly minimum bill of
$10,465, but no requirement to actually use any gas at the International Power
Plant. The current delivered price under the tariff is $2.53 per MCF.
COMPLIANCE WITH ENVIRONMENTAL STANDARDS
Chugach's operations are subject to certain Federal, State and local
environmental laws which Chugach monitors to ensure compliance. The costs
associated with environmental compliance are included as a component of both the
operating and capital budget processes. Chugach accrues for costs associated
with environmental remediation obligations when such costs are probable and
reasonably estimable.
REFINANCINGS
On September 19, 1991, Chugach issued $314,000,000 of First Mortgage Bonds, 1991
Series A, for purposes of repaying existing debt to the Federal Financing Bank
(FFB) and the Rural Electrification Administration (REA), (now Rural Utilities
Services (RUS)). Pursuant to Section 311 of the Rural Electrification Act,
Chugach was permitted to prepay the REA debt at a discounted rate of
approximately 9%, resulting in a discount of approximately $45,000,000. The gain
on prepayment of the REA debt has been deferred and Chugach obtained permission
from the APUC to flow through the benefit to consumers through lower rates in
the future.
The original issuance consisted of bonds in the amount of $52,000,000 due in
2002 bearing interest at 8.08% (Series A 2002 Bonds) and bonds in the amount of
$262,000,000 due in 2022 and bearing interest at 9.14% (Series A 2022 Bonds).
Interest is payable semiannually on March 15 and September 15. The Series A 2002
Bonds are subject to annual sinking fund redemption at 100% of the principal
amount thereof that commenced March 15, 1993. The Series A 2022 Bonds are
subject to annual sinking fund redemption at 100% of the principal amount
thereof commencing March 15, 2003. The Series A 2002 Bonds are not subject to
optional redemption. The Series A 2022 Bonds are redeemable at the option of
Chugach on any interest payment date at an initial redemption price of 109.14%
of the principal amount thereof declining ratably to par on March 15, 2012. The
Indenture prohibits outstanding short-term indebtedness (other than trade
payables) in excess of 15% of Chugach's net utility plant and limits certain
cash investments to specific securities. Chugach has reacquired $79,190,000 of
the Series A 2022 bonds since December 1995 leaving a remaining outstanding
balance of $182,810,000 at December 31, 1999. In March, 2000 Chugach reacquired
an additional $8,500,000 of the Series A 2022 bonds leaving a remaining
outstanding balance of $174,310,000.
Chugach has negotiated a supplemental indenture (Third Supplemental Indenture of
Trust) with CoBank which previously allowed up to $80 million in future bond
financing. In 1998 Chugach finalized an amendment to the Third Supplemental
Indenture of Trust (Seventh Supplemental Indenture of Trust) that eliminates the
maximum aggregate amount of bonds the company may issue under the agreement. At
December 31, 1999, Chugach had bonds in the amount of $143.3 million outstanding
under this financing arrangement. The balance is comprised of an $817 thousand
bond (CoBank 1) that carries an interest rate of 8.95% maturing in 2002, a $10
million bond (CoBank 2) priced at 7.76% due in 2005, a $21.5 million bond
(CoBank 3), priced at 5.60%, a $23.5 million bond (CoBank 4) priced at 5.60%, a
$15 million bond (CoBank 5) priced at 5.60% due in 2002, 2007 and 2012, a $42.5
million bond (CoBank 6) carrying a variable interest rate (6.88% at December 31,
1999) and a $30 million bond (CoBank 7) also carrying a variable interest rate
(6.85% at December 31, 1999). Principal payments on the CoBank 3 and 4 bonds
commence in 2003 and continue through 2022. Additionally, Chugach has negotiated
a similar supplemental indenture (Fifth Supplemental Indenture of Trust) with
National Rural Utilities Cooperative Finance Corporation (NRUCFC) for $80
million. At December 31, 1998, there were no amounts outstanding under this
financing arrangement.
On March 17, 1999, Chugach entered into a Treasury rate-lock transaction with
Lehman Brothers Financial Products Inc. (Lehman Brothers) for the purpose of
taking advantage of favorable market interest rates in anticipation of
refinancing Chugach's Series A Bonds Due 2022 on their first call date (March
15, 2002). As of September 30, 1999, the aggregate principal amount of Series A
Bonds due 2022 was $182,810,000. Under the Treasury rate-lock contract, Chugach
will receive a lump-sum payment from Lehman Brothers on March 15, 2002, if the
yield on 10 or 30-year Treasury bonds as of mid-February 2002, exceeds a
specified target level (5.653% and 5.838%, respectively). Conversely, Chugach
will on the same date be required to make a payment to Lehman Brothers if the
yield on the 10 or 30-year Treasury bonds falls below its stated target yield.
The amount of the payment will increase as the difference between the actual
yield and the target yield increases. For each basis point (0.01% per annum) by
which the yield on 10-year or 30-year Treasury bonds deviates from the stated
target level, Chugach will receive (if the Treasury yield exceeds the target
yield) or make (if the Treasury yield falls short of the target yield) a payment
equal to the product obtained by multiplying (i) the amount of deviation
(expressed in basis points) by (ii) the changes in the prices of $196 million
(in the case of 10-year Treasury bonds) and $18.7 million (in the case of the
30-year Treasury bonds) of Treasury bonds, given a one-basis-point change in
their respective yields (determined with reference to the Bloomberg Financial
Market's Government Yield Analysis Page). In this way, Chugach intends that
higher interest costs resulting from increases in market interest rates prior to
refinancing of Chugach's long-term debt would be mitigated by a lump-sum,
up-front payment to Chugach at the time of the refinancing.
Item 2 - Properties
SYSTEM ASSETS
General
Chugach has 513.1 MW of installed capacity consisting of 17 generating units at
five power plants. These include 365.6 MW of operating capacity at Beluga on the
west side of Cook Inlet; 70.0 MW of power at Bernice Lake on the Kenai
Peninsula; 48.6 MW of power at International Power Plant in Anchorage; and 17.2
MW at Cooper Lake, which is also on the Kenai Peninsula. Chugach also has 11.7
MW of capacity from the two Eklutna hydroelectric plant generating units owned
jointly with MEA and AML&P. In addition to its own generation, Chugach purchases
power from the 90 MW Bradley Lake hydroelectric project owned by the Alaska
Energy Authority (AEA) through Alaska Industrial Development and Export
Authority (AIDEA). Bradley Lake is operated by Homer and dispatched by Chugach.
The Beluga, Bernice Lake and International facilities are all fueled by natural
gas. Chugach owns its offices and headquarters, located adjacent to its
International Power Plant in Anchorage, in fee simple. Warehouse space for some
generation, transmission and distribution inventory (including a small amount of
office space) is leased from an independent party not directly affiliated with
Chugach.
Generation Assets
Chugach owns the land and improvements comprising its generating facilities at
Beluga and International. It also owns all improvements comprising its
generating plant at Bernice Lake, that is located on land originally leased from
Chevron Oil Company now owned by Homer, and its generating plant at Cooper Lake,
that is located on federal land pursuant to a major project license (Federal
License) granted to Chugach by the Federal Power Commission in 1957. The Bernice
Lake ground lease expires in 2011 and the federal license for the Cooper Lake
facility expires in 2007. The management of Chugach has no reason to believe
that it will not be able to renew the Federal License or the Bernice Lake ground
lease if desirable.
In 1997, Chugach acquired a partial interest in the Eklutna Hydroelectric
Project. The plant is located on federal land pursuant to a United States Bureau
of Land Management (BLM) right-of-way grant issued in October 1997.
The following table lists specifics of the generating facilities of Chugach:
Facility Type of Fuel Rated Capacity (1) Commercial Operation Date
- -------- ------------ ------------------ -------------------------
Beluga Power Plant:
Unit 1 Natural Gas 15.7 1968
Unit 2 Natural Gas 15.7 1968
Unit 3 Natural Gas 64.7 1972
Unit 5 Natural Gas 66.5 1975
Unit 6 Natural Gas 74.0 1975
Unit 7 Natural Gas 74.0 1978
Unit 8 Steam (2) 55.0 1981
-----
365.6
Bernice Lake PowerPlant:
Unit 2 Natural Gas 19.0 1971
Unit 3 Natural Gas 25.5 1978
Unit 4 Natural Gas 25.5 1981
-----
70.0
International Power Plant:
Unit 1 Natural Gas 15.0 1964
Unit 2 Natural Gas 15.1 1965
Unit 3 Natural Gas 18.5 1969
-----
48.6
Cooper Lake Hydroelectric
Plant:
Unit 1 Hydroelectric 8.6 1960
Unit 2 Hydroelectric 8.6 1960
-----
Eklutna Hydroelectric Plant 17.2
(4):
Unit 1 Hydroelectric 5.8 1955
Unit 2 Hydroelectric 5.9 1955
----
11.7
Total units 17 513.1
-- -----
(1) Capacity rating in MW at 30 degrees Fahrenheit.
(2) Steam-turbine powered generator with heat provided by exhaust from
natural-gas fueled Units 6 and 7 (combined-cycle). (3) Beluga Unit 4 and Bernice
Lake Unit 1 were retired during 1994. (4) The Eklutna Hydroelectric Plant is
jointly owned by Chugach, MEA and AML&P. The capacity shown is Chugach's 30%
share of the plant's maximum output.
Transmission and Distribution Assets
As of December 31, 1999, Chugach's transmission and distribution assets included
39 substations and 402 miles of transmission lines, 931 miles of overhead
distribution lines and 659 miles of underground distribution line. Chugach owns
the land on which 21 of its substations are located and a portion of the
right-of-way connecting its Beluga plant to Anchorage. In the 1997 Eklutna
acquisition, Chugach also acquired a partial interest in two substations and
additional transmission facilities.
Many substations and a substantial number of Chugach's transmission and
distribution rights-of-way are the subject of federal or state permits and
licenses. Under the federal license and a permit from the United States Forest
Service, Chugach operates its Quartz Creek transmission substation, substations
at Hope, Summit Lake and Daves Creek, and transmission lines over all federal
lands between Cooper Lake on the Kenai Peninsula and Anchorage. Long-term
permits from the Alaska Division of Lands and the Alaska Railroad Corporation
govern much of the rest of Chugach's transmission system outside the Anchorage
area. Within the Anchorage area, Chugach operates its University Substation and
several major transmission lines pursuant to long-term rights-of-way grants from
the BLM, and transmission and distribution lines have been constructed across
privately-owned lands pursuant to easements across public rights-of-way and
waterways pursuant to authority granted by the appropriate governmental entity.
Title
Substantially all of the properties and assets of Chugach, including generation,
transmission and distribution properties, but excluding all excepted property,
are pledged to secure repayment of the Series A Bonds and all other bonds that
may be issued under the Indenture. The Indenture defines excepted property to
include, among other things, cash on hand, instruments and certain securities
(other than those required to be deposited with the Trustee under the terms of
the Indenture), patents and transportation equipment (including vehicles,
vessels and barges), leases for an original term of less than five years,
certain non-assignable permits, licenses and contractual rights, property
located outside the State of Alaska and not used in connection with Chugach's
generation, transmission and distribution system and other property in which a
security interest cannot legally be perfected. The lien of the Indenture is
subject to certain permitted encumbrances that the Indenture defines to include
certain identified restrictions, exceptions, reservations, conditions and
limitations existing on the date of the Indenture, reservations in U.S. patents,
nondelinquent or contested tax liens, local easements, leases and reservations
and liens for nondelinquent rent or wages. The lien of the Indenture is also
subject to the lien in favor of the Trustee to recover amounts owing to the
Trustee under the Indenture.
In addition to the Indenture, many of Chugach's properties are burdened by
easements, plat restrictions, mineral reservation, water rights and similar
title exceptions common to the area or customarily reserved in conveyances from
federal or state governmental entities, and to additional minor title
encumbrances and defects. In the opinion of Chugach's General Counsel, none of
these title defects will materially impair the use of its properties in the
operation of its business.
In addition, a lawsuit was filed against the State of Alaska in which the
plaintiffs allege that the manner in which the State administered and disposed
of certain lands violates the Alaska Mental Health Enabling Act. One of
Chugach's substations and its right-of-way across State lands were potentially
subject to the plaintiffs' claims. The suit has been settled and Chugach is in
the process of determining whether any of Chugach's interests must be perfected
through the Mental Health Trust Land Office Unit. Chugach's management believes
that perfection of Chugach's interest, should that be necessary, will not
materially affect Chugach's financial position, results of operations or cash
flows.
Chugach operates its Bernice Lake facility on lands originally leased from
Chevron Oil Company (fee interest now owned by Homer) pursuant to a lease that
is scheduled to expire in 2011. Chugach also operates several terminal
connection sites and a substation under long-term or renewable leases from the
State of Alaska and private parties. In addition, as discussed above, a
substantial number of Chugach's transmission and distribution rights-of-way, and
several distribution substations, are the subject of federal or state permits
and easements.
Under the Alaska Electric and Telephone Cooperative Act, Chugach is given the
power of eminent domain for the purpose and in the manner provided by Alaska
condemnation laws for acquiring private property for public use.
Other Assets
Bradley Lake. Chugach is a participant in the Bradley Lake Hydroelectric Project
(Bradley Lake), which is a 90 MW hydroelectric facility near Homer on the
southern end of the Kenai Peninsula that was placed into service in September
1991. The project was financed and built by AEA through grants from the State of
Alaska and the issuance of $166 million principal amount of revenue bonds
supported by power sales agreements with six electric utilities that will share
the output from the facility (Chugach, AML&P, Homer and MEA (through AEG&T),
GVEA and Seward). Effective August 12, 1993, AEA became part of the Alaska
Industrial Development and Export Authority (AIDEA). Chugach and the other
participating utilities have entered into take-or-pay power sales agreements
under which AEA has sold percentage shares of the project capacity and the
utilities have agreed to pay a like percentage of annual costs of the project
(including ownership, operation and maintenance costs, debt-service costs and
amounts required to maintain established reserves). Under these take-or-pay
power sales agreements, the purchasing utilities have agreed to pay all project
costs from the date of commercial operation even if no energy is produced.
Chugach has a 27.4 MW or 30.4% share in Bradley Lake, and takes Seward's and
MEA's shares which it net bills to them, for a total of 45% of the project's
capacity.
The length of the agreement is fifty years from the date of commercialization or
when the revenue bond principal is repaid, whichever is the longer. Chugach
believes that, under a worst-case scenario, it could be faced with annual
expenditures of approximately $4.1 million as a result of its Bradley Lake
take-or-pay obligations. Chugach believes that this expense would be recoverable
through the fuel surcharge ratemaking process. The share of debt service for
which the Association is responsible is approximately $46,000,000 plus interest.
In December 1997, $59,485,000 of the Power Revenue Bonds, Third Series and
$47,710,000 of the Power Revenue Bonds, Fourth Series were refinanced under a
forward refunding arrangement. The true interest cost of the new bonds decreased
to 5.611% for the Third Series bonds and 6.06% for the Fourth Series bonds from
7.295% and 7.235%, respectively. This refunding produced a net present value
saving to the participating utilities of approximately $8,500,000. The
Association's share of these savings will be approximately $1,600,000.
In January 1999, $28,910,000 of the Power Revenue Bonds, Fifth Series, were
refinanced under a forward refunding arrangement. The true interest cost of the
new bonds decreased to 5.25%. This produced a Net Present Value savings to the
participating utilities of approximately $2,875,000. The Association's share of
these savings will be approximately $546,000.
In April 1999, AEA issued $59,485,000 of Power Revenue Refunding Bonds, Third
Series, for the purpose of refunding $59,110,000 of the First Series Bonds. The
refunded First Series Bonds were called on July 1, 1999. The refunding resulted
in aggregate debt service payments over the next nineteen years in a total
amount approximately $9,500,000 less than the debt service payments which would
be due on the refunded bonds. There was an economic gain of approximately
$5,900,000. Economic gain is calculated as the net difference between the
present value of the old debt service requirements and the present value of the
new debt service requirements, discounted at the effective interest rate and
adjusted for additional cash paid.
In April 1999, AEA issued $30,640,000 of Power Revenue Refunding Bonds, Fifth
Series, for the purpose of refunding $28,910,000 of the First Series Bonds. The
refunded First Series Bonds were called on July 1, 1999. The refunding resulted
in aggregate debt service payments over the next twenty-three years in a total
amount approximately $4,400,000 less than the debt service payments which would
be due on the refunded bonds. There was an economic gain of approximately
$2,900,000. The Association's share of these savings will be approximately
$546,000.
Chugach also provides transmission and related services as a wheeling agent (one
who dispatches and transmits power of third parties over its own system) for all
of the participants in the project. Upon the default of a participant, and
subject to certain other conditions, AEA is entitled to increase each
participant's share of costs pro rata, to the extent necessary to compensate for
the failure of another participant to pay its share, provided that no
participant's percentage share is increased by more than 25%.
Chugach and AEG&T have also negotiated a Bradley Lake Scheduling Agreement
whereby Chugach schedules AEG&T/Homer's share of the Bradley Lake project for
the benefit of the Chugach system. AEG&T continues to pay its Bradley Lake costs
and receives credit for the Bradley Lake energy generated for Homer. Chugach
pays a fixed annual fee of $112,000 to AEG&T for these scheduling rights. This
agreement allows Chugach to improve the efficiency of its generating resources
through better hydrothermal coordination.
Eklutna. Chugach purchased a 30% undivided interest in the Eklutna Hydroelectric
Project from the federal government. MEA purchased a 17% undivided interest in
the Eklutna Project. The power MEA purchases from Eklutna is pooled with
Chugach's purchases and sold back to MEA to be used in meeting MEA's overall
power requirements. AML&P purchased the remaining 53% undivided interest in the
Eklutna Project.Transfer of ownership occurred on October 2, 1997, in accordance
with a transition plan. Chugach believes that the cost of power from the Eklutna
Project will be less than it would have been under continued federal ownership.
Item 3 - Legal Proceedings
LITIGATION
Matanuska Electric Association, Inc. v. Chugach Electric Association U-98-180
- -----------------------------------------------------------------------------
On December 2, 1998, MEA filed a complaint with what is now the Regulatory
Commission of Alaska (RCA): In the Matter of the Formal Complaint filed by
MATANUSKA ELECTRIC ASSOCIATION, INC. Against CHUGACH ELECTRIC ASSOCIATION, INC.,
U-98-180. MEA alleged in its complaint that Chugach has engaged in "unreasonable
management practices" in the management of its Series A Bonds. The complaint
asks the RCA to issue an order instituting an investigation into the
reasonableness and propriety of the continuing decision of Chugach not to
defease such Bonds, which investigation would include convening a public hearing
to take evidence as to whether Chugach's decision not to defease the Bonds
constitutes an unreasonable management decision, and awarding MEA such
additional relief as the RCA may find just and equitable. Chugach filed an
answer denying the material allegations of MEA's complaint, asserting that its
management of the Series A Bonds has been reasonable and sound, and contending
that defeasance of the Bonds would not be prudent. The answer also asserts that
the RCA should not open an investigation on the grounds that MEA's allegations
do not implicate the kinds of mangement decisions into which it is appropriate
for the RCA to inquire. MEA filed a reply to Chugach's answer in which it relied
on new factual allegations not contained in the complaint. Each party has filed
additional motions regarding the pleadings of the other party. The RCA has not
yet ruled on any of those motions.
Chugach filed a motion for summary disposition of MEA's complaint on January 14,
2000. Chugach argued that its management of its long-term debt has been
recognized by the financial marketplace as being sound, that its handling of its
Bonds (i.e., entering into a rate-lock) is demonstrably superior to defeasance,
that the investigation MEA seeks would be costly and prejudicial to Chugach, and
that MEA has failed to make the showing necessary to justify investigating
Chugach's financial management. MEA filed its opposition on February 15, 2000,
in which it argued that defeasance is a superior tactic for managing Chugach's
long-term debt and that the rate-lock was a suspect financial management tactic
that the RCA should examine closely. On March 6, 2000, Chugach filed its reply
to MEA's opposition. It argued that MEA has not disputed Chugach's showing that
the rate-lock is superior to defeasance, and that MEA's confusion about the
terms and effect of the rate-lock does not constitute the `good cause' necessary
to justify an investigation.
The RCA has taken no action in this matter, although its predecessor, the Alaska
Public Utilities Commission, did convene an informal status conference on April
30, 1999. If the RCA authorizes an investigation, Chugach will vigorously defend
its financial management. Because of the preliminary nature of the case, Chugach
has not been able to estimate the costs of its participation should the case
proceed.
Matanuska Electric Association, Inc. v. Chugach Electric Association, Inc.
3AN-99-8152 CI
- --------------------------------------------------------------------------------
On July 7, 1999, MEA filed a complaint against Chugach in the above referenced
matter in Alaska Superior Court in Anchorage. In its complaint, MEA asserted
that Chugach has violated the Power Supply Agreement between the parties, state
statutes and its own bylaws in failing to provide MEA with information about
several different matters that MEA asserts could affect the cost of power MEA
purchases from Chugach. MEA also asserted that Chugach violated the Power Supply
Agreement in its management of its long-term bonded indebtedness.
On September 9, 1999, Chugach filed a motion requesting the dismissal of the
portion of MEA's claim seeking to recover damages for Chugach's alleged
financial mismanagement. In its motion to dismiss, Chugach asserted that MEA's
claim regarding Chugach's alleged financial mismanagement is essentially the
same as MEA's financial mismanagement claim in U-98-180, referenced above. MEA
opposed Chugach's motion to dismiss asserting that its financial mismanagement
claim in this action is different from its claim before the RCA, because in this
case it seeks monetary damages for past losses, while in its action before the
RCA it seeks to force Chugach to change its future financial management
practices. Thereafter, Chugach answered MEA's complaint, on November 3, 1999,
and replied to MEA's opposition to Chugach's motion to dismiss. After oral
argument on Chugach's motion to dismiss on November 17, 1999, the court entered
an order on December 21, 1999, in which it denied Chugach's motion.
MEA filed a corrected Second Amended Complaint on February 8, 2000, in which it
added a new claim. MEA asked for an order directing that Chugach be required to
present its general rate case filing to the Joint Rate Committee prior to
presenting it to the RCA. Chugach did not oppose MEA's request to amend its
Complaint a second time, and on February 29, 2000, the court granted MEA's
motion to amend. Chugach filed its answer to MEA's Second Amended Complaint on
or about March 10, 2000, and specifically denied MEA's assertion that it never
responded to MEA's correspondence regarding bringing its general rate case
before the Joint Rate Committee and opposed the relief MEA requested.
Also, the parties conducted a scheduling conference on February 29, 2000, and
set a trial date of April 2, 2001. Discovery has now commenced. Because of the
preliminary nature of the case, Chugach has not been able to estimate the costs
of its participation.
Matanuska Electric Association, Inc. v. Chugach Electric Association, Inc.
3AN-99-10830 CI
- --------------------------------------------------------------------------------
On October 13, 1999, Chugach filed a complaint against MEA in Alaska Superior
Court in Anchorage. In it, Chugach asked the court to enforce the APUC and RCA
orders obligating MEA to pay Chugach for MEA's pro rata share (approximately
20%) of Chugach's Fuel and Purchased Power Cost Adjustment (FPPCA) attributable
to an $839,000 tax liability Chugach incurred in connection with its supply
contract with Marathon Oil Company.
On October 22, 1999, Chugach filed a motion for a preliminary injunction in the
same case asking the court to enjoin MEA's attempt to have the question of its
liability for Chugach's FPPCA attributable to the Marathon tax liability
submitted to an arbitrator. On November 16, 1999, Chugach filed a motion for
summary judgment on the question of whether the RCA's orders should be enforced
against MEA, which by agreement of the parties subsumed the motion for
preliminary injunction. On December 8, 1999, MEA opposed that motion and filed a
cross motion contesting the enforceability of the RCA's orders and asserting
that it should not have to pay its share of the Marathon tax liability because
Chugach failed to comply with provisions of the parties' Power Supply Agreement.
The parties have exchanged responsive briefs and the issue is now set for oral
argument on April 18, 2000. The parties anticipate that the court's ruling on
the pending motion and cross-motion for summary judgment will dispose of this
claim.
Item 4 - Submission of Matters to a Vote of Security Holders
Not Applicable
PART II
Item 5 - Market for Registrant's
Common Equity and Related Stockholder Matters
Not Applicable
Item 6 - Selected Financial Data
The following tables present selected historical information relating to
financial condition and results of operations over the past five years:
Balance Sheet Data 1999 1998 1997 1996 1995
---- ---- ---- ---- ----
Plant net:
In service $ 398,544,496 $ 386,235,421 $ 393,228,853 $ 400,052,837 $ 391,200,269
Construction work in
progress 47,257,296 30,405,736 24,664,395 19,826,957 27,068,964
----------- ----------- ------------ ------------ ------------
Electric plant, net 445,801,792 416,641,157 417,893,248 419,879,794 418,269,233
Other assets 72,553,745 64,450,293 67,674,051 62,608,636 66,521,090
------------ ------------ ------------ ------------ ------------
Total assets $518,355,537 $481,091,450 $485,567,299 $482,488,430 $484,790,323
============= ============= ============== ============= ============
Capitalization:
Long-term debt 337,150,295 305,917,699 312,006,501 307,905,847 305,641,703
Capital leases - - - - -
Equities and margins 122,524,645 114,023,296 109,119,697 104,477,942 99,230,550
----------- ----------- ----------- ----------- -----------
Total capitalization $459,674,940 $419,940,995 $421,126,198 $412,383,789 $404,872,253
============= ============= ============= ============= =============
Summary Operations Data
Operating revenues 142,644,327 141,825,373 143,947,730 134,876,668 129,379,308
Operating expenses 110,456,886 110,737,441 113,070,990 100,913,804 95,920,361
Interest expense 25,228,001 26,011,392 26,661,510 27,052,186 27,207,648
Amortization of gain on
refinancing 1,092,620 1,542,723 1,577,149 1,703,136 2,150,476
----------- ----------- ----------- ----------- -----------
Net operating margins 8,052,060 6,619,263 5,792,379 8,613,814 8,401,775
Nonoperating margins 1,615,374 2,111,141 1,762,018 1,217,557 604,418
----------- ----------- ----------- ----------- ------------
Assignable margins $9,667,434 $8,730,404 $7,554,397 $9,831,371 $9,006,193
=============== ============== =============== =============== ===============
Item 7 - Management's Discussion and Analysis
of Financial Condition and Results of Operations
Reference is made to the information contained under the caption "CAUTION
REGARDING FORWARD-LOOKING STATEMENTS" at the beginning of this Report. Reference
is also made to the information contained in Item 1 with respect to the MEA
proposal.
RESULTS OF OPERATIONS
Chugach operates on a not-for-profit basis and, accordingly, seeks only to
generate revenues sufficient to pay operating and maintenance costs, the cost of
purchased power, capital expenditures, depreciation and principal and interest
on all indebtedness of Chugach and to provide for the establishment of
reasonable margins and reserves. Revenues in excess of current period costs (net
operating margins and nonoperating margins) in any year are designated on
Chugach's Statements of Revenues, Expenses and Patronage Capital as assignable
margins. Retained assignable margins are designated on Chugach's balance sheet
as patronage capital, which is assigned to each member on the basis of
patronage. This patronage capital constitutes the principal equity of Chugach.
Revenues
Operating revenues include sales of electric energy to retail, wholesale and
economy energy customers and other miscellaneous revenues. In 1999, operating
revenues were approximately .58% higher than 1998. This was attributable to
increased sales to GVEA due to operating problems with the Healy Clean Coal
Plant, as well as increased kWh sales across the board due to colder weather. A
total of $2,553,047 has been recorded in the provision for rate refund account
since 1997. This provision was recorded in response to Docket U-96-37 which was
opened by the APUC to resolve certain rate disputes with the wholesale
customers. At December 31, 1999, Docket U-96-37 had not been closed. Retail
demand and energy rates did not change in 1999 while demand and energy rates
charged to MEA and Homer decreased due to the approval of the 1996 test year
filing on an interim and refundable basis. Seward's demand and energy rates
remained unchanged. In 1998 operating revenues were approximately 1.5% lower
than 1997. This decrease was largely attributable to lower sales to Homer due to
economy energy purchases from AML&P. Also, economy energy sales to GVEA
decreased due to the Healy Clean Coal Plant testing activity in 1998. Retail
demand and energy rates did not change in 1998 while demand and energy rates
charged to MEA decreased slightly. Demand and energy rates to Homer remained
unchanged while Seward's demand and energy rates dropped by 15%. Revenues and
power sold were as follows for the years ended December 31:
Year MWh sold Operating revenues
- ---- -------- ------------------
1999 2,190,253 $ 142,644,327
1998 2,055,963 141,825,373
1997 2,269,453 143,947,730
Chugach makes economy sales primarily to GVEA. These sales commenced in 1988 and
have contributed to a portion of Chugach's growth in operating revenues. Chugach
does not take such economy sales into consideration in its long-range resource
planning process because these sales are non-firm sales that depend on GVEA's
need for additional power and Chugach's available generating capacity at the
time. In 1999, economy sales to GVEA constituted approximately 1.32% of
Chugach's sales revenues. This increase from previous year's Economy Energy
sales is due primarily to operating problems with the HCCP, increasing the
need for GVEA to make economy power purchases.
The impact of inflation on Chugach's revenues falls into two rate categories as
follows:
Fuel Surcharge
Fuel and purchased power costs are passed directly to Chugach's wholesale
and retail customers through a fuel and purchased power adjustment factor
(fuel surcharge). Changes in these costs due to inflation or other market
conditions are passed directly to Chugach's retail and wholesale customers
which results in either a direct increase or decrease to Chugach's system
revenues. The fuel adjustment factor is currently approved on a quarterly
basis by the RCA. There are no limitations on surcharge rate changes.
Increases in Chugach's fuel and purchased power costs result in increased
revenues while decreases in costs result in lower revenues. Revenue from
the fuel adjustment charge normally does not impact margins.
At the urging of one of Chugach's wholesale customers, in Order No. 18 of
Docket U-96-37, the APUC ordered retroactive refunds in the approximate
amount of $1.2 million for fuel surcharge rates charged in 1995 - 1997. The
order is in connection with Chugach's fuel and purchased power cost
adjustment factors that are adjusted on a quarterly basis. It is Chugach's
position that retroactive refunds of quarterly surcharge revenues violate
the rules against retroactive ratemaking and constitutional due process
protections. Chugach has appealed this decision to the Superior Court for
the State of Alaska. Chugach's request for stay of the Commission refund
order has been granted. It is not possible at this time to determine the
outcome of this appeal.
In 1999, Chugach's wholesale customers challenged the calculation of the
annual update to the G&T loss factor. As a result, the RCA has made
Chugach's surcharges interim and refundable since July 1, 1999. The RCA
issued Order No. 2 on March 16, 2000, accepting Chugach's proposed revised
calculation of line losses and ordered the new figure to be applied July 1,
1999. MEA has also challenged the recovery of a State of Alaska back-tax
assessment against Marathon Oil Company, which, following the contract
between Chugach and Marathon, is to be paid by Chugach. Despite repeated RCA
approval of the recovery of this cost, MEA continues to dispute this finding
on procedural grounds and has withheld partial payments of its monthly
invoices. Chugach has undertaken court intervention to recover these
payments.
General Rate Filing
Operating and maintenance and other non-fuel and purchased power costs are
recovered through a general rate case process or through other normal RCA
procedures. While the formal ratemaking process typically takes nine months
to one year, it is within the RCA's authority to authorize, after a notice
period, rate changes on an interim and refundable basis. In addition, the
RCA has been willing to open limited dockets to resolve specific issues
from which expeditious decisions can often be generated.
Chugach's annual base rate changes, excluding fuel and purchased power cost
adjustments, for retail and wholesale classes for the years 1997 through
1999 were as follows:
1999 1998 1997
---- ---- ----
Retail 0.00% 0.00% 0.00%
Wholesale:
Homer (0.30%)1 0.00% 0.00%
MEA (3.80%)1 (0.20%) (0.80%)
Seward (0.00%) (15.00%)2 0.00%
1 Interim refundable rates pursuant to Settlement Agreement.
2 Reflects interruptible power sales contract
Expenses
Chugach's operating expenses for the years ended December 31, 1999, 1998 and
1997 were as follows:
Year Operating expenses
---- ------------------
1999 $110,456,886
1998 $110,737,441
1997 $113,070,990
Operating expenses for 1999 were 0.25% lower than 1998. Operating expenses for
1998 were 2.1% lower than 1997. The reasons for the significant operating
expense variances follow:
Year ended December 31, 1999, compared to the year ended December 31, 1998
--------------------------------------------------------------------------
Production expense decreased in 1999 from 1998. There were no substantial
variances in total actual operating and maintenance expenses between 1999
and 1998, however, the decrease in fuel expense from $34.5 million in 1998
to $29.6 million in 1999 is a result of an average 16.0% decrease in fuel
prices from 1998 to 1999.
Transmission expense increased in 1999 from 1998 due to unanticipated
transmission line repairs, Y2K preparation and testing and overhead line
maintenance activity as a result of outages early in 1999.
Distribution expense increased in 1999 from 1998 due primarily to the
increased outage activity that occurred early in 1999.
Sales expense increased in 1999 compared to 1998. The slight variance is
due to positions in the Marketing Department that were vacant in 1998, but
filled in 1999.
Administrative and General expense increased from 1998 to 1999. The $5.2
million increase from 1998 is the result of an increase in software
amortization expense, increased maintenance costs of the Y2K compliant
software implementation completed in 1998, additional expenses associated
with Chugach's ancilliary businesses, and multiple insurance settlements
paid in 1999. In addition, general plant maintenance expenses were higher
due to multiple projects completed in 1999.
Depreciation expense decreased from 1998 to 1999. This variance was due to
adjustments made in 1999 for the over-amortization of general plant and the
unitization of the 1997 Beluga Unit #5 overhaul.
Year ended December 31, 1998, compared to the year ended December 31, 1997
--------------------------------------------------------------------------
Production expense decreased in 1998 over 1997. Due to significantly
reduced economy energy sales, there was a substantial decrease in the
consumption of fuel at Beluga. This, however, was offset by increased fuel
costs for Bernice Lake due to decreased power purchases from Soldotna 1.
Purchased power expense decreased in 1998 over 1997. This was due primarily
to the decreased purchases from Soldotna 1. In addition, to promote system
stability and avoid possible outages, there were unusual purchases made
from AML&P in 1997 while maintenance was being performed on the
transmission lines between Beluga and Anchorage.
Consumer accounts expense decreased in 1998 from 1997. This was due to the
reclassification of expenses to the added financial category Sales Expense.
Administrative and General expense increased in 1998 from 1997. This was
caused by an update in the amount of common information services costs
allocated to this category.
Depreciation expense increased in 1998 from 1997 due to the
over-amortization of general plant.
Other interest expense decreased in 1998 from 1997. This was caused by
converting a portion of short-term borrowings to long term debt which
caused lower average outstanding balance on the short-term lines of credit
throughout the year.
Margins
Chugach's assignable margins for the years ended December 31, 1999, 1998 and
1997, were as follows:
Period Net operating margins Nonoperating margins Assignable margins
------ --------------------- -------------------- ------------------
1999 $ 8,052,060 $ 1,615,374 $ 9,667,434
1998 $ 6,619,263 $ 2,111,141 $ 8,730,404
1997 $ 5,792,379 $ 1,762,018 $ 7,554,397
Nonoperating margins decreased in 1999 over 1998. The primary contributor to the
decrease from 1998 is the gain on the sale of a surplus compressor rotor to
Golden Valley Electric Association, Inc. in 1998. The variance is also due to
higher than anticipated patronage capital from CoBank but is offset by a
decrease in interest earnings as a result of decreased borrowing activity.
Nonoperating margins increased in 1998 over 1997. This increase was caused
mostly by an increase in patronage capital allocation from CoBank in 1998 versus
1997.
Patronage Capital (Equity)
Chugach's patronage capital and total equity have shown steady growth, both in
dollars and as a percentage of capitalization. The following table summarizes
Chugach's patronage capital and total equity position since 1997:
1999 1998 1997
---- ---- ----
Patronage capital at beginning of year $109,622,996 $104,800,092 $100,685,517
Retirement of capital credits and estate
Payments (1,954,949) (3,907,500) (3,439,822)
Assignable margins 9,667,434 8,730,404 7,554,397
------------ ------------ ------------
Patronage capital at end of year 117,335,481 109,622,996 104,800,092
Other equity 5,189,164 4,400,300 4,319,605
------------ ------------ ------------
Total equity $122,524,645 $114,023,296 $109,119,697
============ ============ ============
The Indenture includes a covenant restricting the distribution of patronage
capital to members. Chugach cannot distribute patronage capital to members if 1)
an event of default exists or 2) the aggregate amount of patronage capital
distribution exceeds the sum of $7,000,000 plus 35 percent of the aggregate
assignable margins earned after December 31, 1990.
Times Interest Earned Ratio (TIER)
Alaska electric cooperatives generally set rates on the basis of TIER. TIER is
determined by dividing the sum of assignable margins plus long-term interest
expense (excluding capitalized interest) by long-term interest expense.
Beginning in 1989, Chugach's Board of Directors approved an Equity Management
Plan that established a schedule for building Chugach's equity. Since then
Chugach has managed its business with a view toward achieving a TIER of 1.25 or
greater. Chugach's achieved TIERs for the past five years were as follows:
Period TIER
1999 1.40
1998 1.35
1997 1.30
1996 1.39
1995 1.34
The Indenture requires Chugach to establish rates reasonably expected to yield
margins for interest (MFI) equal to at least 1.20 times total interest expense.
Margins for interest are defined as net margins plus interest charges and
accruals for federal income and other taxes imposed on income after deduction of
interest charges for such period, however, the amount of nonoperating margins
included in assignable margins shall not exceed 50% of assignable margins.
Chugach's achieved MFI/I for the past five years are not materially different
from the TIER calculations shown above.
The Indenture requires that Chugach achieve such a 1.20 ratio for any 12
consecutive month period of the last 18 months before issuing additional Bonds
(other than additional Bonds issued based on deposited cash and, under certain
circumstances, retirement of Bonds).
MATERIAL CHANGES IN FINANCIAL CONDITION
Chugach maintained a stable asset base from 1998 to 1999. Notable changes among
the components include an increase in cash (and cash equivalents) due to a
retail prepayment promotion, which began in November 1999, as well as an
increase in accounts payable.
Notable changes to other liabilities include: a higher balance in other
liabilities due to increased fuel and purchased power payables caused by
increased economy energy sales to GVEA; and the decrease in deferred credits
resulting from the annual amortization of the original refinancing gain.
LIQUIDITY AND CAPITAL RESOURCES
Chugach satisfies its operational and capital cash requirements through
internally generated funds, a $50 million line of credit with the NRUCFC and a
$35 million line of credit with CoBank.
At December 31, 1999, no balance was outstanding on the NRUCFC line. The NRUCFC
line of credit expires October 14, 2002. At December 31, 1999, no amount was
outstanding on the CoBank line. The CoBank line of credit expires August 1,
2000, but carries an annual automatic renewal clause.
Chugach's capital improvement requirements are based on long-range plans and
other supporting studies and are executed through a five-year construction work
plan.
Five-year work plans are fully developed and updated every year. Shown below is
an estimate of capital expenditures for the years 2000 through 2004:
2000 $32.2 million
2001 33.6 million
2002 27.6 million
2003 33.4 million
2004 34.5 million
Following is a five-year summary of anticipated capital credit retirements:
Year ending Wholesale Retail Total
- ----------- --------- ------ -----
2000 0 3,750,000 3,750,000
2001 0 4,004,000 4,004,000
2002 0 9,499,000 9,499,000
2003 0 5,399,000 5,399,000
2004 1,359,000 5,383,000 6,742,000
Chugach's outstanding long-term obligations at December 31, 1999 are as
follows:
First mortgage bonds of 8.08% maturing in
2002 and 9.14% maturing in 2022 with
interest payable semiannually March 15
and September 15:
8.08% $ 17,396,000
9.14% 182,810,000
CoBank 8.95% bond maturing in 2002,
with interest payable monthly and
principal due semi-annually 816,700
CoBank 7.76% bond maturing in 2005,
with interest payable monthly 10,000,000
CoBank 5.60% bonds maturing 2022, with
interest payable monthly 45,000,000
CoBank 5.60% bonds maturing in 2002,
2007 and 2012 with interest payable
monthly 15,000,000
CoBank 6.88% bonds maturing in 2002,
with interest payable monthly 42,500,000
CoBank 6.85% bonds maturing in 2002,
with interest payable monthly 30,000,000
-------------
Total long-term obligations 343,522,700
Less current installments 6,372,405
-------------
Long-term obligations, excluding
Current installments $337,150,295
============
Maturities of Long-term Obligations
Long-term obligations at December 31, 1999, mature as follows:
Year ending Sinking Fund Requirements Principal maturities Total
December 31
First mortgage CoBank
bonds Mortgage bonds
2000 6,067,000 305,405 3,372,405
2001 6,097,000 333,350 6,430,350
2002 5,232,000 77,677,944 82,909,944
2003 5,041,000 865,821 5,906,821
2004 5,502,000 945,000 6,447,000
Thereafter 172,267,000 63,189,180 235,456,180
------------ ---------- -----------
$200,206,000 $143,316,700 $343,522,700
============ ============ ============
On September 19, 1991, Chugach issued $314 million of First Mortgage Bonds, 1991
Series A, for purposes of repaying existing debt to the FFB and the REA.
Pursuant to Section 311 of the Rural Electrification Act, Chugach was permitted
to prepay the REA debt at a discounted rate of approximately 9%, resulting in a
discount of approximately $45 million. The gain on prepayment was deferred at
December 31, 1991, because Chugach expected to pass the benefit of the gain
through to ratepayers prospectively in the form of lower rates. In April 1992,
Chugach received formal approval from the APUC to defer the gain and amortize it
into income over the life of the bonds. Annual amortization for 1999 was $1.2
million and for 1998 and 1997 was $1.7 million.
Chugach has negotiated a supplemental indenture (Third Supplemental Indenture of
Trust) with CoBank that previously allowed up to $80 million in future bond
financing. In 1997 Chugach finalized an amendment to the Third Supplemental
Indenture of Trust (Seventh Supplemental Indenture of Trust) that eliminates the
maximum aggregate amount of bonds the company may issue under the agreement. At
December 31, 1999, Chugach had bonds in the amount of $143.6 million outstanding
under this financing arrangement. The balance is comprised of a $1.1 million
bond (CoBank 1) that carries an interest rate of 8.95% maturing in 2002, a $10
million bond (CoBank 2) priced at 7.76% due in 2005, a $21.5 million bond
(CoBank 3), priced at 5.60%, a $23.5 million bond (CoBank 4) priced at 5.60%, a
$15 million bond (CoBank 5) priced at 5.60% due in 2002, 2007 and 2012 and a
$42.5 million bond (CoBank 6) carrying a variable interest rate currently priced
at 7.10% (as of March 2000) and a $30 million bond (CoBank 7) carrying a
variable interest rate currently priced at 7.18% (as of March 2000) both due in
March, 2002. Principal payments on the CoBank 3 and 4 bonds commence in 2003 and
continue through 2022. Additionally, Chugach has negotiated a similar
supplemental indenture (Fifth Supplemental Indenture of Trust) with NRUCFC for
$80 million. At December 31, 1999, there were no amounts outstanding under this
financing arrangement.
Chugach management expects that cash flows from operations and external funding
sources will be sufficient to cover operational and capital funding requirements
in 2000 and thereafter.
YEAR 2000
Chugach has recognized the need to investigate, test and remediate if necessary
the critical systems and equipment under its control which could cause power and
business disruptions in conjunction with what are collectively called "Year
2000" dates. Chugach completed Year 2000 conversion and remediation efforts. No
adverse impacts to service were experienced at year end.
ENVIRONMENTAL MATTERS
Compliance with Environmental Standards
Chugach's operations are subject to certain federal, state and local
environmental laws which Chugach monitors to ensure compliance. The costs
associated with environmental compliance are included as a component of both the
operating and capital budget processes. Chugach accrues for costs associated
with environmental remediation obligations when such costs are probable and
reasonably estimable.
Standard Steel Salvage Yard Site
The remedial action at the Standard Steel Metals Salvage Yard Superfund Site has
been completed. However, EPA will not approve a certificate of completion for
the Site until its final oversight cost bill for the remedial action has been
paid. The Standard Steel PRP Group (of which Chugach is a member) anticipates
receiving and paying EPA's final oversight cost bill in the Spring of 2000.
Presently, it is anticipated that the PRP Group will have sufficient funds on
account to pay the oversight cost bill in full without an additional assessment
of its members. Additional costs will also be incurred in the future for
groundwater monitoring and operation and maintenance of the cleanup remedy. The
PRP Group is in the process of estimating these costs and providing for their
payment out of the funds already on account. Therefore, it is not anticipated
that the Company will have to make any further payments related to the remedial
action at the Site. In fact, Chugach will likely receive a refund from the PRP
Group once the final costs are known. If any additional costs are incurred in
addition to those already paid to the PRP Group and not covered by Chugach's
settlement with its insurers, Chugach management believes that they would be
fully recoverable in rates and therefore would have no impact on Chugach's
financial condition or results of operations.
OUTLOOK
Nationwide, the electric utility industry is entering a period of unprecedented
competition. Electric utilities in Alaska will not be immune from these
competitive forces. Chugach has taken several steps to be more effectively
positioned to meet the challenge of a competitive market for electricity.
Chugach participates in national benchmarking projects to improve system
operations. Studies have focused on mailroom operations, remittance processing,
new service connections, system reliability and power production. As a result of
these studies, Chugach has been able to make these processes more efficient
which has led to lower costs. The Association is committed to continue reviewing
all areas of its operations and to serve its customers in a way that maintains
high reliability while containing the cost of electricity.
In addition to participation in benchmarking studies, Chugach has also
implemented strategic alliances in the purchasing and warehousing areas. These
alliances are designed to improve efficiency and thus contribute to lower
operating costs. In 1997, Chugach was able to lower inventory unit costs,
increase inventory turns and decrease project cost by furnishing materials to
contractors as a direct result of these strategic alliances. Chugach will
continue to explore other areas for strategic alliance opportunities.
During 1998 Chugach updated its new strategic plan. In this plan, priority
issues are identified that are critical to the company's success. Updated key
result area targets were developed that track the most important measures of
Chugach's performance.
Chugach has been active at the State Legislature in support of the customer's
right to choose their electric power supplier. Virtually all Alaskan utilities
have opposed Chugach's efforts to develop competition and are attempting to
create exclusive service territories. At this time no bill relating to customer
choice has moved out of legislative committee, thus, it is not possible to
predict the outcome of this legislative process.
In 1997 Chugach made organizational changes in preparation for competition.
Recognizing that the new marketplace will probably be "unbundled" along the
functional lines of generation, transmission and distribution and retail
services, Chugach's organizational structure reflects these functions. Operating
with three divisions: Finance and Energy Supply, Transmission and Distribution
Network Services and Retail Services, Chugach has positioned itself to meet
competition in the electric industry. Chugach's Marketing Department continues
to operate a key account program for larger customers and is developing new
services to enhance existing customers' satisfaction.
Chugach commenced operation as an internet service provider (ISP) in February
1999. Also in 1999 Chugach began selling spare microwave bandwidth to industrial
customers.
Chugach has three collective bargaining agreements with the IBEW that have
reached impasse and have gone to an arbitrator for resolution. Although each of
the contracts had an expiration date of January 31, 1998, the parties have
agreed that the contracts shall continue in effect until new contracts are put
in place. The Union cannot strike and Chugach cannot lockout under the
continuing agreement.
Item 7A - Quantitative and Qualitative Disclosures
About Market Risk
Chugach is exposed to a variety of risks, including changes in interest rates
and changes in commodity prices due to re-pricing mechanisms inherent in gas
supply contracts as described on page 10 under the heading "Marathon". In the
normal course of its business, Chugach manages its exposure to these risks as
described below. Chugach does not engage in trading market risk sensitive
instruments for speculative purposes.
Interest rate risk - As of December 31, 1999, except for CoBank 6 and 7, which
carry variable interest rates that are periodically re-priced, Chugach's
outstanding borrowings were at fixed interest rates with varying maturity dates.
The following table provides information regarding cash flows and related
weighted average interest rates by expected maturity dates for Chugach's debt
obligations (dollars in thousands):
Fair
2000 2001 2002 2003 2004 Thereafter Total Value
---- ---- ---- ---- ---- ---------- ----- -----
Long-term debt, including
current portion $6,372 $6,430 $82,910 $5,907 $6,447 $235,456 $343,522 $354,534
Chugach is exposed to market risk from changes in interest rates. To manage this
exposure, Chugach entered into a Treasury rate-lock transaction in anticipation
of refinancing the Series A Bonds due 2022 on the call date, March 15, 2002. The
agreement specifies that Chugach will receive a payment from the counter-party
in February 2002 if the yield on 10 year ($196,000,000 notional amount) or 30
year ($18,700,000 notional amount) Treasury bonds exceeds specified target
levels of 5.653% and 5.838%, respectively, as of that date. At December 31,
1999, the fair value of this agreement approximated $13,000,000. A 10 basis
point change in the yield would change the fair value of the agreement as
follows:
- --------------------------------------------------------------------------------
Notional Amount Change in Fair Value
- ----------------------------------- --------------------------------------------
- ----------------------------------- --------------------------------------------
$ 18,700,000 $ 213,000
- ----------------------------------- --------------------------------------------
- ----------------------------------- --------------------------------------------
$ 196,000,000 $ 1,308,000
- ----------------------------------- --------------------------------------------
Commodity price risk - As described on page 10 under the heading "Marathon",
Chugach's gas contracts provide for adjustments to gas prices based on
fluctuations of certain commodity prices and indices. As described on page 23
under the heading "Fuel Surcharge", purchased power costs are passed directly to
Chugach's wholesale and retail customers through a fuel surcharge, therefore,
fluctuations in the price paid for gas pursuant to long-term gas supply
contracts does not normally impact margins. The fuel surcharge mechanism
mitigates the commodity price risk related to market fluctuations in the price
of purchased power.
Item 8 - Financial Statements and Supplementary Data
December 31, 1999 and 1998
Independent Auditors' Report
The Board of Directors
Chugach Electric Association, Inc.:
We have audited the accompanying balance sheets of Chugach Electric Association,
Inc. as of December 31, 1999 and 1998, and the related statements of revenues,
expenses and patronage capital and cash flows for each of the years in the
three-year period ended December 31, 1999. These financial statements are the
responsibility of the Association's management. Our responsibility is to express
an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of Chugach Electric Association,
Inc. as of December 31, 1999 and 1998, and the results of its operations and its
cash flows for each of the years in the three-year period ended December 31,
1999, in conformity with generally accepted accounting principles.
Anchorage, Alaska
February 25, 2000
CHUGACH ELECTRIC ASSOCIATION, INC.
Balance Sheets
December 31, 1999 and 1998
Assets 1999 1998
------ ---- ----
Utility plant (notes 2, 6, 13 and 14):
Electric plant in service $ 641,627,328 $ 620,216,818
Construction work in progress 47,257,296 30,405,736
---------- ------------
688,884,624 650,622,554
Less accumulated depreciation 243,082,832 233,981,397
----------- ------------
Net utility plant 445,801,792 416,641,157
----------- ------------
Other property and investments, at cost:
Nonutility property 413,515 3,550
Investments in associated organizations
(note 3) 8,946,861 8,356,364
--------- ------------
9,360,376 8,359,914
--------- ------------
Current assets:
Cash and cash equivalents, including
Repurchase agreements of $6,574,457 in
1999 and $4,153,475 in 1998 4,110,030 2,312,574
Cash-restricted construction funds 538,404 177,366
Special deposits 182,164 121,164
Accounts receivable, less provision for
doubtful accounts of $389,223 in 1999
and $447,908 in 1998 17,911,749 17,243,266
Materials and supplies 17,180,136 15,963,434
Prepayments 861,947 917,381
Other current assets 341,702 349,030
---------- ----------
Total current assets 41,126,132 37,084,215
---------- -----------
Deferred charges (notes 9 and 15) 22,067,237 19,006,164
---------- -----------
$ 518,355,537 $ 481,091,450
============= =============
See accompanying notes to financial statements.
CHUGACH ELECTRIC ASSOCIATION, INC.
Balance Sheets, Continued
December 31, 1999 and 1998
Liabilities 1999 1998
----------- ---- ----
Equities and margins (note 11):
Memberships $ 960,808 $ 911,253
Patronage capital (note 4) 117,335,481 109,622,996
Other (note 5) 4,228,356 3,489,047
------------ ------------
122,524,645 114,023,296
------------ ------------
Long-term obligations, excluding current installments (notes 6, 7 and 11):
First mortgage bonds payable 194,139,000 235,101,000
National Bank for Cooperatives bonds
Payable 143,011,295 70,816,699
------------- ------------
337,150,295 305,917,699
------------ ------------
Current liabilities:
Current installments of long-term debt and
capital leases (notes 6, 7 and 11) 6,372,405 6,088,802
Accounts payable 9,508,851 8,838,757
Consumer deposits 1,059,677 993,616
Accrued interest 6,066,114 6,722,325
Salaries, wages and benefits 4,053,228 3,755,837
Fuel 4,381,304 5,362,713
Other 2,527,798 1,318,947
------------ ------------
Total current liabilities 33,969,377 33,080,997
------------ ------------
Deferred credits (note 12) 24,711,220 28,069,458
------------ ------------
$518,355,537 $ 481,091,450
============ =============
See accompanying notes to financial statements.
CHUGACH ELECTRIC ASSOCIATION, INC.
Statements of Revenues, Expenses and Patronage
Capital Years ended December 31, 1999, 1998
and 1997
1999 1998 1997
---- ---- ----
Operating revenues $ 142,644,327 $ 141,825,373 $ 143,947,730
------------ ------------ ------------
Operating expenses:
Production 40,301,607 45,261,450 45,879,337
Purchased power 8,581,979 8,462,835 14,033,282
Transmission 3,813,438 2,771,652 3,378,540
Distribution 9,400,618 8,876,890 8,640,443
Consumer accounts 4,387,421 4,177,980 4,955,838
Sales expense 1,227,908 1,125,410 -
Administrative, general and other 22,892,479 17,592,829 15,071,966
Depreciation 19,851,436 22,468,395 21,111,584
------------ ------------ ------------
Total operating expenses 110,456,886 110,737,441 113,070,990
------------ ------------ ------------
Interest:
On long-term debt 24,137,593 25,159,660 24,942,281
Charged to construction - credit (1,000,246) (821,137) (629,764)
On short-term debt 998,034 130,146 771,844
------------- ------------- ------------
Net interest 24,135,381 24,468,669 25,084,361
------------ ------------ ------------
Net operating margins 8,052,060 6,619,263 5,792,379
Nonoperating margins:
Interest income 592,208 711,155 632,191
Other 1,003,029 1,050,899 520,414
Property gain (loss) 20,137 349,087 609,413
----------- ------------ ------------
Assignable margins 9,667,434 8,730,404 7,554,397
Patronage capital at beginning of year 109,622,996 104,800,092 100,685,517
Retirement of capital credits and
estate payments (note 4) (1,954,949) (3,907,500) (3,439,822)
----------- ------------ ------------
Patronage capital at end of year $117,335,481 $109,622,996 $104,800,092
============ ============ ============
See accompanying notes to financial statements.
CHUGACH ELECTRIC ASSOCIATION, INC.
Statements of Cash Flows
Years ended December 31, 1999, 1998 and 1997
1999 1998 1997
---- ---- ----
Cash flows from operating activities:
Assignable margins $9,667,434 $8,730,404 $7,554,397
Adjustments to reconcile assignable margins to net cash
provided by operating activities:
Depreciation and amortization 23,563,805 24,605,760 23,532,263
Capitalized interest (1,151,720) (1,081,394) (799,999)
Property (gains) losses and obsolete inventory write-off 242 (349,087) (609,413)
Other (221) 60,734 (241,317)
Changes in assets and liabilities:
(Increase) decrease in assets:
Special deposits (61,000) 30,540 (62,471)
Accounts receivable (668,483) 6,755,872 (8,629,254)
Prepayments 55,434 (359,010) 135,886
Materials and supplies, net (1,216,702) (344,349) 568,507
Deferred charges (14,179,418) (7,898,240) (2,299,547)
Other assets 7,328 (43,615) (11,035)
Increase (decrease) in liabilities:
Accounts payable 670,093 1,800,524 1,860,074
Accrued interest (656,211) (182,010) (172,052)
Deferred credits (2,973,944) (1,829,112) (755,366)
Consumer deposits, net 66,061 (44,625) (28,665)
Other liabilities 524,833 (3,129,329) (1,076,365)
------------ ----------- -----------
Total adjustments 3,980,097 17,992,659 11,411,246
----------- ---------- ----------
Net cash provided by operating activities 13,647,531 26,723,063 18,965,643
---------- ---------- ----------
Cash flows from investing activities:
Extension and replacement of plant (40,864,582) (19,447,902) (17,487,859)
(Increase) decrease in investments in associated (590,276) (552,827) 24,235
-------------- -------------- ---------------
organizations
Net cash (used) in investing activities (41,454,858) (20,000,729) (17,463,624)
------------ ------------ ------------
Cash flows from financing activities:
Transfer of restricted construction funds (361,038) 187,412 1,006,608
Net decrease in notes payable 0 0 (2,750,000)
Proceeds from long-term debt 72,500,000 0 15,000,000
Repayments of long-term debt (40,983,801) (5,913,512) (10,957,586)
Memberships and donations received 788,865 80,695 527,179
Retirement of patronage capital (1,954,949) (3,907,500) (3,439,822)
Net refunds of consumer advances for construction (384,294) (81,384) (1,083,688)
----------- ------------- -----------
Net cash used by financing activities 29,604,783 (9,634,289) (1,697,309)
---------- ----------- -----------
Net increase in cash and cash equivalents 1,797,456 (2,911,955) (195,290)
Cash and cash equivalents at beginning of year $ 2,312,574 $ 5,224,529 $ 5,419,819
- ---------------------------------------------- ----------- ----------- -----------
Cash and cash equivalents at end of year $ 4,110,030 $ 2,312,574 $5,224,529
- ---------------------------------------- =========== =========== ==========
Supplemental disclosure of cash flow information - interest
expense paid, net of amounts capitalized 24,791,592 24,650,680 25,256,413
========== ========== ==========
See accompanying notes to financial statements.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
December 31, 1999 and 1998
(1) Description of Business and Summary of Significant Accounting Policies
Description of Business
Chugach Electric Association, Inc. (Association or Chugach) is the
largest electric utility in Alaska. The Association is engaged in the
generation, transmission and distribution of electricity to directly
served retail customers in the Anchorage and upper Kenai Peninsula areas.
Through an interconnected regional electrical system, Chugach's power
flows throughout Alaska's Railbelt, a 400-mile-long area stretching from
the coastline of the southern Kenai Peninsula to the interior of the
state, including Alaska's largest cities, Anchorage and Fairbanks.
Chugach also supplies much of the power requirements of three wholesale
customers, Matanuska Electric Association (MEA), Homer Electric
Association (Homer) and the City of Seward (Seward).
The Association operates on a not-for-profit basis and, accordingly,
seeks only to generate revenues sufficient to pay operating and
maintenance costs, the cost of purchased power, capital expenditures,
depreciation, and principal and interest on all indebtedness and to
provide for reasonable margins and reserves. The Association is subject
to the regulatory authority of the Regulatory Commission of Alaska (RCA),
(formerly the Alaska Public Utilities Commission (APUC)).
Management Estimates
In preparing the financial statements, management of the Association is
required to make estimates and assumptions relating to the reporting of
assets and liabilities and the disclosure of contingent assets and
liabilities as of the date of the balance sheet and revenues and expenses
for the reporting period. Actual results could differ from those
estimates.
Regulation
The accounting records of the Association conform to the Uniform System
of Accounts as prescribed by the Federal Energy Regulatory Commission.
The Association meets the criteria, and accordingly, follows the
accounting and reporting requirements of Statement of Financial
Accounting Standards No. 71, Accounting for the Effects of Certain Types
of Regulation (SFAS 71). Revenues in excess of current period costs (net
operating margins and nonoperating margins) in any year are designated on
the Association's statement of revenues and expenses as assignable
margins. Retained assignable margins are designated on the Association's
balance sheet as patronage capital, which is assigned to each member on
the basis of patronage. This patronage capital constitutes the principal
equity of the Association.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
In July 1997, the Financial Accounting Standards Board (FASB) Emerging
Issues Task Force (EITF) reached a consensus on EITF 97-4 "Deregulation
of the Pricing of Electricity - Issues Related to the Application of FASB
Statements No. 71 and No. 101." This issue discusses when an enterprise
should stop applying SFAS 71 to the separable portion of its business
whose product or service pricing is being deregulated and how a company
should account for its stranded costs after it has discontinued the
application of SFAS 71. It also provides guidance with respect to the
evaluation of regulatory assets and liabilities and concluded that these
items should be determined on the basis of where in the business the
regulated cash flows to realize and settle them will be derived. The
Association's current method of accounting is consistent with the EITF.
The Association performs an annual evaluation of the requirements of SFAS
71 and related exposures.
Reclassifications
Certain reclassifications have been made to the 1997 and 1998 financial
statements to conform to the 1999 presentation.
Plant Additions and Retirements
Additions to electric plant in service are recorded at original cost of
contracted services, direct labor and materials, and indirect overhead
charges. For property replaced or retired, the average unit cost of the
property unit, plus removal cost, less salvage, is charged to accumulated
provision for depreciation. The cost of replacement is added to electric
plant.
Operating Revenues
Operating revenues are based on billing rates authorized by the RCA which
are applied to customers' usage of electricity. Included in operating
revenue are billings rendered to customers adjusted for differences in
meter read dates from year to year. The Association's tariffs include
provisions for the flow through of gas cost increases pursuant to
existing gas supply contracts.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
In August 1996, the Board of Directors approved a petition to the APUC
to withdraw from the Simplified Rate Filing (SRF) process. This petition
was submitted to the APUC as part of Docket U-96-37, which was opened to
resolve rate disputes with two of Chugach's wholesale customers
(AEG&T/MEA/Homer). Interim-refundable rates for AEG&T/MEA/Homer were
ordered pending resolution of the docket. In February 1997, the APUC
approved a Settlement Agreement between Chugach and AEG&T/MEA/Homer
resolving issues in the docket and establishing permanent rates. As part
of the APUC order, the Association was required to file Cost of Service
and Revenue Requirement Studies. These studies were filed in March 1997.
The APUC approved Chugach's withdrawal from SRF in July 1998. Rate changes
will be applied for through general rate case and other normal APUC
procedures. At December 31, 1999, Docket U-96-37 had not been closed. A
provision for a wholesale rate refund of $2,553,047 to AEG&T/MEA/Homer was
recorded at December 31, 1999 to accommodate certain rate adjustment
clauses contained in the Settlement Agreement.
In 1998 a new power sales agreement was negotiated between Chugach and
Seward. The new contract was filed with the APUC and approved on an
interim-refundable basis effective September 11, 1998 by an order dated
October 12, 1998. The APUC specifically postponed a decision on whether
to allow the reduced rates under the contract to be effective as of March
1, 1998 as the parties had agreed in the contract. In a subsequent order
issued June 14, 1999 the RCA made the interim refundable rates permanent
effective September 11, 1998 and did not allow the request to make the
rates effective March 1, 1998.
In October 1998 Marathon Oil Company, one of Chugach's natural gas
suppliers, notified Chugach that it had reached a settlement with the
State of Alaska regarding additional excise and royalty taxes for the
period 1989 through 1998. In accordance with the purchase contract,
Chugach would be responsible for these additional taxes. The RCA approved
Chugach's plan to recover this over 12 months through the Fuel Surcharge
mechanism except for the retail portion in the amount of $436,778 that
was written-off at December 31, 1998. Recovery of this expense began in
rates on April 1, 1999. Despite RCA approval and subsequent
re-confirmation by the RCA, MEA has refused to pay the portion of its
monthly bill it considers to be recovery of the Marathon tax.
Investments in Associated Organizations
Investments in associated organizations represent capital requirements as
part of financing arrangements.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
The Association has the intent and ability to hold these investments to
maturity, and accordingly has elected to account for them at cost under
SFAS 115.
Deferred Charges and Credits
Deferred charges, representing regulatory assets, are amortized to
operating expense over the period allowed for rate-making purposes,
generally five years.
Nonrefundable contributions in aid of construction are credited to the
associated cost of construction of property units. Refundable
contributions in aid of construction are held in deferred credits pending
their return or other disposition.
Depreciation and Amortization
Depreciation and amortization rates have been applied on a straight-line
basis and at December 31, 1999 are as follows:
Rate (%)
Steam production plant 2.70 - 2.96
Hydraulic production plant 1.33 - 2.88
Other production plant 3.34 - 6.50
Transmission plant 1.85 - 5.37
Distribution plant 2.10 - 4.55
General plant 2.22 - 20.00
Other 1.88 - 2.75
In 1997 an update of the Depreciation Study was completed utilizing
Electric Plant in Service balances as of December 31, 1995. Depreciation
rates developed in that Study were implemented in January, 1998.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
Capitalized Interest
Allowance for funds used during construction and interest charged to
construction - credit are the estimated costs during the period of
construction of equity and borrowed funds used for construction purposes.
The Association capitalized such funds at the average rate (adjusted
monthly) of 7.4% during 1999 and 8.3% during 1998 and 1997.
Cash and Cash Equivalents
For purposes of the statement of cash flows, the Association considers
all highly liquid debt instruments with a maturity of three months or
less upon acquisition by the Association (excluding restricted cash and
investments) to be cash equivalents.
Materials and Supplies
Materials and supplies are stated at the lower of cost or market and
valued at average cost.
Fair Value of Financial Instruments
Statement of Financial Accounting Standards 107, Disclosures About the
Fair Value of Financial Instruments, requires disclosure of the fair
value of certain on and off balance sheet financial instruments for which
it is practicable to estimate that value. The following methods are used
to estimate the fair value of financial instruments:
Cash and cash equivalents and restricted cash - the carrying amount
approximates fair value because of the short maturity of those
instruments.
Investments in associated organizations - the carrying amount
approximates fair value because of limited marketability and current
market interest rates which approximate interest rates on the
investments.
Consumer deposits - the carrying amount approximates fair value
because of the short refunding term.
Long-term obligations - the fair value is estimated based on the
quoted market price for same or similar issues (note 7).
Financial Instruments and Hedging
The Association uses interest rate swap and forward rate lock agreements
to manage interest costs and the risk associated with changing interest
rates. As interest rates change, the differential paid or received is
recognized in interest expense of the period.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
Environmental Remediation Costs
The Association accrues for losses associated with environmental
remediation obligations when such losses are probable and can be
reasonably estimated. Such accruals are adjusted as further information
develops or circumstances change. Estimates of future costs for
environmental remediation obligations are not discounted to their present
value.
2) Utility Plant Summary
Major classes of electric plant as of December 31 are as follows:
1999 1998
---- ----
Electric plant in service:
Steam production plant $60,392,869 $60,392,869
Hydraulic production plant 8,798,695 8,798,695
Other production plant 104,925,446 109,153,064
Transmission plant 211,881,174 191,960,788
Distribution plant 162,365,836 156,976,983
General plant 47,704,821 44,782,572
Unclassified electric plant in service 38,834,298 41,598,712
Equipment under capital lease 56,323 56,323
Other 6,667,866 6,496,812
------------- -------------
Total electric plant in service 641,627,328 620,216,818
Construction work in progress 47,257,296 30,405,736
------------ ------------
Total electric plant in service
and construction work in progress $688,884,624 $650,622,554
============ ============
Depreciation of unclassified electric plant in service has been included
in functional plant depreciation accounts in accordance with the
anticipated eventual classification of the plant investment.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(3) Investments in Associated Organizations
Investments in associated organizations include the following at December
31:
1999 1998
---- ----
National Rural Utilities Cooperative Finance
Corporation (NRUCFC) $ 6,095,980 $ 6,095,980
National Bank for Cooperatives (CoBank) 2,708,200 2,117,924
NRUCFC capital term certificates 32,300 32,300
Other 110,381 110,160
--------- ---------
$8,946,861 $8,356,364
========== ==========
The Farm Credit Administration, CoBank's federal regulators, requires
minimum capital adequacy standards for all Farm Credit System
institutions. CoBank's loan agreements require, as a condition of the
extension of credit, that an equity ownership position be established by
all borrowers. The Association's investment in NRUCFC similarly was
required by its financing arrangements with NRUCFC. The investments in
NRUCFC and CoBank mature at various dates through 2020 and bear interest
at rates ranging from 3% to 5%.
(4) Patronage Capital
The Association has approved an Equity Management Plan which established
in general, a ten-year (for wholesale customers) and twenty-year (for
retail customers) capital credit retirement of patronage capital, based
on the members' proportionate contribution to Association assignable
margins. At December 31, 1999, out of the total of $117,335,481
patronage capital, the Association had assigned $108,605,077 of such
patronage capital (net of capital credit retirements). Approval of
actual capital credit retirements is at the discretion of the
Association's Board of Directors. In December 1997, the Board of
Directors authorized the retirement of $1,859,730 of retail capital
credits representing the remaining 1983 patronage capital. The Board of
Directors also authorized the retirement of 1987 wholesale capital
credits in the amount of $1,205,510 in December 1997. A special
wholesale capital credit retirement of $88,818, representing wholesale
margins from 1985, was authorized in December 1997.
In December 1998 the Board of Directors authorized the retirement of
$2,208,997 of retail capital credits representing the balance of 1984
retail distribution patronage. The Board also authorized the retirement
of $1,533,287 of wholesale patronage for 1988.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
In November 1999 the Board of Directors authorized the retirement of
$1,766,000 of retail patronage for 1984.
Following is a five-year summary of anticipated capital credit
retirements:
Year ending Wholesale Retail Total
----------- --------- ------ -----
2000 - 3,750,000 3,750,000
2001 - 4,004,000 4,004,000
2002 - 9,499,000 9,449,000
2003 - 5,399,000 5,399,000
2004 1,359,000 5,383,000 6,742,000
(5) Other Equities
A summary of other equities at December 31 follows:
1999 1998
---- ----
Nonoperating margins, prior to 1967 $ 23,625 $ 23,625
Donated capital 183,907 184,581
Unredeemed capital credit retirement 4,020,824 3,280,841
---------- ----------
$4,228,356 $3,489,047
========== ==========
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(6) Long-term Obligations
Long-term obligations at December 31 are as follows:
1999 1998
---- ----
First mortgage bonds of 8.08% maturing in
2002 and 9.14% maturing in 2022 with interest
payable semiannually March 15 and September 15:
8.08% $ 17,396,000 $ 23,205,000
9.14% 182,810,000 217,705,000
CoBank 8.95% bond maturing in 2002,
with interest payable monthly and
principal due semi-annually 816,700 1,096,501
CoBank 7.76% bond maturing in 2005,
with interest payable monthly 10,000,000 10,000,000
CoBank 5.60% bonds maturing 2022, with
interest payable monthly 45,000,000 45,000,000
CoBank 5.60% bonds maturing in 2002,
2007 and 2012 with interest payable
monthly 15,000,000 15,000,000
CoBank 6.88% bonds maturing in 2002,
with interest payable monthly 42,500,000 0
CoBank 6.85% bonds maturing in 2002,
with interest payable monthly 30,000,000 0
------------- -------------
Total long-term obligations 343,522,700 312,006,501
Less current installments 6,372,405 6,088,802
------------- -------------
Long-term obligations, excluding
Current installments $337,150,295 $305,917,699
============ ============
Substantially all assets are pledged as collateral for the long-term
obligations.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
Maturities of Long-term Obligations
Long-term obligations at December 31, 1999 mature as follows:
Year ending Sinking Fund Requirements Principal maturities Total
December 31
First mortgage CoBank
bonds mortgage bonds
2000 6,067,000 305,405 6,372,405
2001 6,097,000 333,350 6,430,350
2002 5,232,000 77,677,944 82,909,944
2003 5,041,000 865,821 5,906,821
2004 5,502,000 945,000 6,447,000
Thereafter 172,267,000 63,189,180 235,456,180
------------ ---------- -----------
$200,206,000 $143,316,700 $343,522,700
============ ============ ============
Lines of Credit
The Association had an annual line of credit of $35,000,000 in 1999 and
1998 available with CoBank. The CoBank line of credit expires August 1,
2000 but carries an annual automatic renewal clause. At December 31, 1999
and 1998, there was no outstanding balance on this line of credit. In
addition, the Association had an annual line of credit of $50,000,000
available at December 31, 1999 and 1998 with NRUCFC. At December 31, 1999
and 1998 there was no outstanding balance on this line of credit. The
NRUCFC line of credit expires October 14, 2002.
Refinancing
On September 19, 1991, Chugach issued $314,000,000 of First Mortgage
Bonds, 1991 Series A (Bonds), for purposes of repaying existing debt to
the Federal Financing Bank and the Rural Electrification Administration
(now Rural Utilities Services). Pursuant to Section 311 of the Rural
Electrification Act, Chugach was permitted to prepay the REA debt at a
discounted rate of approximately 9%, resulting in a discount of
approximately $45,000,000 (note 12).
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
The bonds maturing in 2002 (Series A 2002 Bonds) are subject to annual
sinking fund redemption at 100% of the principal amount thereof which
commenced March 15, 1993. The bonds maturing in 2022 (Series A 2022
Bonds) are subject to annual sinking fund redemption at 100% of the
principal amount thereof commencing March 15, 2003. The Series A 2002
Bonds are not subject to optional redemption. The Series A 2022 Bonds are
redeemable at the option of Chugach on any interest payment date at an
initial redemption price commencing in 2002 of 109.140% of the principal
amount thereof declining ratably to par on March 15, 2012. The Bonds are
secured by a first lien on substantially all of Chugach's assets. The
Indenture prohibits outstanding short-term indebtedness (other than trade
payables) in excess of 15% of Chugach's net utility plant and limits
certain cash investments to specific securities.
In April 1997, Chugach reacquired $5,000,000 of the Series A 2022 Bonds
at a premium of 109.7500. Total transaction cost, including accrued
interest and premium, was $5,510,350.
In February 1999, Chugach reacquired $11,000,000 of the Series A 2022
Bonds at a premium of 117.05. Total transaction cost, including accrued
interest and premium, was $13,322,344.
In February 1999, Chugach reacquired $14,000,000 of the Series A 2022
Bonds at a premium of 116.25. Total transaction cost, including accrued
interest and premium, was $16,868,592.
In February 1999, Chugach reaquired $9,895,000 of the Series A 2022 Bonds
at a premium of 116.75. Total transaction cost, including accrued
interest and premium, was $11,974,467.
In March 2000, Chugach reaquired $8,500,000 of the Series A 2022 Bonds at
a premium of 104.00. Total transaction cost, including accrued interest
and premium, was $9,215,502.
On March 17, 1999, Chugach entered into a Treasury rate-lock transaction
with Lehman Brothers Financial Products Inc. (Lehman Brothers) for the
purpose of taking advantage of favorable market interest rates in
anticipation of refinancing Chugach's Series A Bonds due 2022 on their
call date (March 15, 2002). As of December 31, 1999, the aggregate
principal amount of Series A Bonds due 2022 was $182,810,000. Under the
treasury rate-lock contract, Chugach will receive a lump-sum payment
from Lehman Brothers on March 15, 2002, if the yield on 10- or 30-year
Treasury bonds as of mid-February 2002, exceeds a specified target level
(5.653% and 5.838%, respectively). Conversely, Chugach will on the same
date be required to make a payment to Lehman Brothers if the yield on
the 10- or 30-year Treasury bonds falls below its stated target yield.
The fair value of the treasury rate lock agreement at December 31, 1999
approximated $13,000,000.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(7) Fair Value of Financial Instruments
The estimated fair values (in thousands) of the long-term obligations
included in the financial statements at December 31 are as follows:
1999 1998
---- ----
Carrying Fair Carrying Fair
Value Value Value Value
Long-term obligations
(including current installments) $343,523 $354,534 $312,007 $349,353
Fair value estimates are dependent upon subjective assumptions and
involve significant uncertainties resulting in variability in estimates
with changes in assumptions.
(8) Employee Benefits
Pension benefits for substantially all employees are provided through the
Alaska Electrical Trust and Alaska Hotel, Restaurant and Camp Employees
Health and Welfare Trust Funds (union employees) and the National Rural
Electric Cooperative Association (NRECA) Retirement and Security Program
(nonunion employees). The Association makes annual contributions to the
plans equal to the amounts accrued for pension expense. For the union
plans, the Association pays a contractual hourly amount per union
employee which is based on total plan costs for all employees of all
employers participating in the plan. In these master, multiple-employer
plans, the accumulated benefits and plan assets are not determined or
allocated separately to the individual employer. Pension costs for union
plans were approximately $1,832,000 in 1999, $1,805,000 in 1998 and
$1,810,000 in 1997. For several years, NRECA did not require
contributions to the plan; consequently, no pension cost was incurred. In
1996 a moratorium was in effect from January through September. In 1997
approximately $601,000 was contributed to the NRECA plan. In 1998
approximately $813,000 was contributed to the NRECA plan for the full
year. In 1999 approximately $868,000 was contributed to the NRECA plan
for the full year.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(9) Deferred Charges
Deferred charges consisted of the following at December 31:
1999 1998
---- ----
Debt issuance and reacquisition costs $ 6,196,555 $ 3,838,237
Refurbishment of transmission equipment 262,346 271,605
Computer software and conversion 12,186,272 11,104,406
Studies 1,880,734 2,253,165
Business venture studies 273,660 72,961
Fuel supply negotiations 369,609 392,325
Major overhaul of steam generating unit 427,305 632,411
Environmental matters and other (note 1 470,756 441,054
---------- ----------
$22,067,237 $19,006,164
(10) Income Taxes
The Association is exempt from federal income taxes under the provisions
of Section 501(c)(12) of the Internal Revenue Code, except for unrelated
business income. For the years ending December 31, 1999, 1998 and 1997
the Association received no unrelated business income.
(11) Return of Capital
Under provisions of its long-term debt agreements, the Association is not
directly or indirectly permitted to declare or pay any dividend or make
any payments, distributions or retirements of patronage capital to
members if an event of default exists with respect to its bonds (event of
default), if payment of such distribution would result in an event of
default, or if the aggregate amount expended for all distributions on and
after September 26, 1991 exceeds the sum of $7,000,000 plus 35% of the
aggregate assignable margins (whether or not such assignable margins have
since been allocated to members) of the Association earned after December
31, 1990 (or, in the case such aggregate shall be a deficit, minus 100%
of such deficit). The Association may declare and make distributions at
any time if, after giving effect thereto, the Association's aggregate
margins and equities as of the end of the most recent fiscal quarter
would be not less than 45% of the Association's total liabilities and
equities as of the date of the distribution. The Association does not
anticipate that this provision will limit the anticipated capital credit
retirements described in note 4.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(12) Deferred Credits
Deferred credits at December 31 consisted of the following:
1999 1998
---- ----
Regulatory liability - unamortized gain on
reacquired debt $ 21,271,412 $ 25,796,171
Refundable consumer advances for
Construction 2,123,913 1,739,618
Estimated initial installation costs for
Transformers and meters 272,554 277,969
Post retirement benefit obligation 286,200 255,700
New business venture 46,185 0
Other 710,956 0
------------- ------------------
$24,711,220 $28,069,458
=========== ===========
In conjunction with the refinancing described in note 6, the Association
recognized a gain of approximately $45,000,000. The APUC permitted the
Association to flow through the gain to consumers in the form of reduced
rates over a period equal to the life of the bonds using the effective
interest method; consequently, the gain has been deferred for financial
reporting purposes as required by SFAS 71. Approximately $1,215,000 of
the deferred gain was amortized in 1999. Approximately $1,700,000 of the
deferred gain was amortized annually in 1998 and 1997.
(13) Bradley Lake Hydroelectric Project
The Association is a participant in the Bradley Lake Hydroelectric
Project (Bradley Lake). Bradley Lake was built and financed by the
Alaska Energy Authority (AEA) through State of Alaska grants and
$166,000,000 of revenue bonds. The Association and other participating
utilities have entered into take-or-pay power sales agreements under
which shares of the project capacity have been purchased and the
participants have agreed to pay a like percentage of annual costs of the
project (including ownership, operation and maintenance costs, debt
service costs and amounts required to maintain established reserves).
Under these take-or-pay power sales agreements, the participants have
agreed to pay all project costs from the date of commercial operation
even if no energy is produced. The Association has a 30.4% share of the
project's capacity. The share of debt service exclusive of interest, for
which the Association is responsible is approximately $46,000,000. Under
a worst case scenario, the Association could be faced with annual
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
expenditures of approximately $4.1 million as a result of its Bradley
Lake take-or-pay obligations. Management believes that such
expenditures, if any, would be recoverable through the fuel surcharge
ratemaking process. Upon the default of a Bradley Lake participant, and
subject to certain other conditions, AEA, through Alaska Industrial
Development and Export Authority, is entitled to increase each
participant's share of costs pro rata, to the extent necessary to
compensate for the failure of another participant to pay its share,
provided that no participant's percentage share is increased by more
than 25%.
On April 6, 1999, AEA issued $59,485,000 of Power Revenue Refunding
Bonds, Third Series, for the purpose of refunding $59,110,000 of the
First Series Bonds. The refunded First Series Bonds were called on July
1, 1999. The refunding resulted in aggregate debt service payments over
the next nineteen years in a total amount approximately $9,500,000 less
than the debt service payments which would be due on the refunded bonds.
There was an economic gain of approximately $5,900,000. Economic gain is
calculated as the net difference between the present value of the old
debt service requirements and the present value of the new debt service
requirements, discounted at the effective interest rate and adjusted for
additional cash paid.
On April 13, 1999, AEA issued $30,640,000 of Power Revenue Refunding
Bonds, Fifth Series, for the purpose of refunding $28,910,000 of the
First Series Bonds. The refunded First Series Bonds were called on July
1, 1999. The refunding resulted in aggregate debt service payments over
the next twenty-three years in a total amount approximately $4,400,000
less than the debt service payments which would be due on the refunded
bonds. There was an economic gain of approximately $2,900,000. The
Association's share of these savings will be approximately $546,000.
The following represents information with respect to Bradley Lake at June
30, 1999 (the most recent date for which information is available). The
Association's share of expenses were $3,902,737 in 1999, $4,112,292 in
1998 and $3,981,624 in 1997 and are included in purchased power in the
accompanying financial statements.
Other electric plant in service of $6,667,866 represents the
Association's share of a Bradley Lake transmission line financed
internally and the Association's share of the Eklutna Hydroelectric
Project, purchased in 1997.
Total Proportionate Share
Plant in service $ 306,872,387 $ 93,289,206
Accumulated depreciation (53,593,915) (16,292,550)
Interest expense 10,538,354 3,203,660
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(14) Eklutna Hydroelectric Project
During October 1997, the ownership of the Eklutna Hydroelectric Project
formally transferred from the Alaska Power Administration to the
participating utilities. This group consists of the Association along
with Matanuska Electric Association (MEA) and Municipal Light and Power
(AML&P).
Other electric plant in service includes $1,956,954 representing the
Association's share of the Eklutna Hydroelectric Plant. This balance will
be amortized over the estimated life of the facility. During the
transition phase and after the transfer of ownership, Chugach, MEA and
AML&P have jointly operated the facility. Each participant contributes
their proportionate share for operations and maintenance costs. Under net
billing arrangements, Chugach then reimburses MEA for their share of the
costs. Prior to the transfer of ownership, these costs were recorded as
purchased power expenses; after the transfer these costs were recorded as
power production expenses. In 1999, the Association charged $246,080 to
various expense categories representing Chugach's share of Eklutna
operations.
(15) Commitments and Contingencies
Construction
The Association is engaged in a continuous construction program.
Management estimates that approximately $32,000,000 will be spent on the
construction program in 2000.
Contingencies
The Association is a participant in various legal actions, claims and
unasserted claims, both for and against its interests. Management
believes that the outcome of any such matters will not materially impact
the Association's financial condition, results of operations or
liquidity.
Standard Steel Salvage Yard Site
A cost recovery action was filed in Federal District Court on December
27, 1991 by the United States against the Association and six other
Potentially Responsible Parties seeking reimbursement of removal and
response action costs incurred by the United States Environmental
Protection Agency ("EPA") at the Standard Steel and Metals Salvage Yard
Superfund Site in Anchorage, Alaska. The site work and reporting required
to complete the remedial action have been done. Although the total
oversight costs of EPA and other federal agencies is not yet known,
Chugach has prefunded these costs and believes that sufficient funds
remain in the account to pay these costs and the on-going future site
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
monitoring costs. Chugach's total costs for the site not reimbursed by
its insurers will not exceed $500,000. Management believes that this
amount is fully recoverable in rates and therefore would have no impact
on Chugach's financial condition or results of operations.
Unsolicited Acquisition Proposal by Matanuska Electric Association, Inc.
In October 1998, Matanuska Electric Association (MEA), Chugach's largest
wholesale customer, presented to the Board of Directors of Chugach (the
Board) an unsolicited proposal (the MEA Proposal) to acquire
substantially all of Chugach's assets in exchange for the assumption of
Chugach's liabilities. After evaluating information provided by MEA and
analyses of the MEA Proposal presented by Chugach's staff and independent
financial advisors, on November 12, 1998 the Board rejected the MEA
Proposal. Subsequently, MEA gathered a sufficient number of signatures
from Chugach's members to force a special meeting of Chugach's members
for the purpose of considering the MEA Proposal. Under the Alaska
Electric & Telephone Cooperative Act (AETCA), a special meeting may be
called by 10% of Chugach's members. Chugach held the special meeting to
consider the MEA Proposal on November 18, 1999. Of the 14,492 ballots
received and validated, 13,156 were cast against the MEA proposal and
1,336 (9.2%) were cast in favor. The proposal therefore fell far short of
the approximately 27,500 members (including at least 2/3 of the members
actually voting) that would have had to vote in favor of the MEA Proposal
in order for the members to register their approval under Chugach's
bylaws and the AETCA.
Year 2000 Conversion
Chugach has recognized the need to investigate, test and remediate if
necessary the critical systems and equipment under its control which
could cause power and business disruptions in conjunction with what are
collectively called "Year 2000" dates. Chugach completed Year 2000
conversion and remediation efforts. No adverse impacts to service were
experienced at year end.
Regulatory Cost Charge
In 1992 the State of Alaska Legislature passed legislation authorizing
the Department of Revenue to collect a regulatory cost charge from
utilities in order to fund the APUC. The tax is assessed on all retail
consumers and is based on kilowatt hour (kWh) consumption. The
Regulatory Cost Charge has decreased since its inception (November 1992)
from an initial rate of $.000626 per kWh to the current rate of
$.000309, effective October 1, 1999.
CHUGACH ELECTRIC ASSOCIATION, INC.
Notes to Financial Statements
(16) Segment Reporting
During 1998, Chugach adopted the Financial Accounting Standards Board
Statement No. 131, Disclosures About Segments of an Enterprise and
Related Information, which establishes standards for reporting
information about a company's operating segments. The Association had
divided its operations into two reportable segments: Energy and Internet
service. The energy segment derives its revenues from sales of
electricity to residential, commercial and wholesale customers, while
the Internet segment derives its revenues from provision of residential
and commercial internet services and products. The reporting segments
follow the same accounting policies used for the Association's financial
statements and described in the summary of significant accounting
policies. Management evaluates a segment's performance based upon profit
or loss from operations. Jointly used assets are allocated by percentage
of reportable segment usage and centrally incurred costs are allocated
using factors developed by the Association, which are patterned upon
usage. The Internet segment began operations during 1998, the results of
which are immaterial to the financial statements. The following is a
tabulation of business segment information for the year ended December
31, 1999:
Operating Revenues
Internet 374,296
Energy 142,270,031
-----------
Total operating revenues 142,644,327
===========
Assignable Margins
Internet -1,293,388
Energy 10,960,822
------------
Total assignable margins 9,667,434
=============
Assets
Internet 564,477
Energy 517,791,060
-----------
Total assets 518,355,537
===========
Capital Expenditures
Internet 508,082
Energy 36,756,005
------------
Total capital expenditures 39,264,087
============
Item 9 - Changes in and Disagreements with
Accountants on Accounting and Financial Disclosure
None
PART III
Item 10 - Directors and Executive Officers of the Registrant
MANAGEMENT
Executives
Chugach operates under the direction of a Board of Directors that is elected at
large by its membership. Day-to-day business and affairs are administered by the
General Manager. Chugach's seven-member Board of Directors sets policy and
provides direction to the General Manager. The following table sets forth
certain information with respect to the executive management of Chugach:
Name Age Position held
- ---- --- -------------
Eugene N. Bjornstad 62 General Manager
Lee D. Thibert 44 Executive Manager, Transmission & Distribution Network Services
Evan J. Griffith, Jr. 58 Executive Manager, Finance & Energy Supply
William R. Stewart 53 Executive Manager, Retail Services
Eugene N. Bjornstad was appointed General Manager of Chugach June 22, 1994.
Prior to that he served as Acting General Manager from March 28, 1994, until his
permanent appointment. He joined Chugach in 1983 and served as Executive
Manager, Operating Divisions from 1988 to 1994.
Lee D. Thibert, in a reorganization on June 1, 1997, was appointed Executive
Manager, Transmission & Distribution Network Services. Prior to that he was
Executive Manager, Operating Divisions from June of 1994. Before moving up to
the Executive Manager position, he served as Director of Operations from June
1987.
Evan J. Griffith, Jr. was Executive Manager, Finance & Planning of Chugach
from August 1989 to June 1997. In the June 1, 1997 reorganization he assumed
the position of Executive Manager, Finance and Energy Supply. Prior to
coming to Chugach, he was Budget/Program Analyst for the Anchorage Municipal
Assembly from August 1984 to August 1989.
William R. Stewart was Executive Manager, Administration of Chugach from July
1987 to June 1, 1997 when he assumed the duty as Executive Manager, Retail
Services in a reorganization of functions. He was Division Director of
Administration of Chugach from January 1984 to July 1987 and Staff Assistant to
the General Manager of Chugach from November 1982 to January 1984. He has been
employed at Chugach since 1969.
Board of Directors
Christopher Birch - President. Chris Birch, 49, is a professional engineer
employed by the Alaska Department of Transportation and Public Facilities. He
was appointed to the Board to fill a vacated seat in October 1996 and was
elected to that seat in April 1997. He served as Secretary from April 1997 to
April 1998. He became President in April 1999.
Pat Jasper - Vice President. Pat Jasper, 70, is a small business owner and has
been a computer programmer and systems analyst. She was originally elected to
the Board in April 1995 to fill a one-year term, and served as Secretary to
April 1996. She was re-elected in April 1996 and served as Vice President until
April 1997 when she became President. In April 1999, she relinquished the
President position to be Vice President again.
Bruce Davison - Secretary. Bruce Davison, 51, was appointed to the Association's
Board of Directors in June of 1997. Prior to his appointment, Mr. Davison
served two years on the Chugach Electric Association Bylaws Committee.
Mr. Davison is a 25-year Alaska resident and a partner in the law firm of
Davison & Davison, Inc. He became Secretary in April 1998.
Mary Minder - Treasurer. Mary Minder, 60, was elected to the Board in April
1995 and served as Treasurer until April 1996 when she became Secretary. In
April 1997, she was again elected Treasurer and serves in that same capacity
today. Ms. Minder is a realtor and associate real estate broker.
Elizabeth Page "Pat" Kennedy - Director. Pat Kennedy, 61, was President of
Chugach from April 1994 to April 1995. Ms. Kennedy has served on the board since
1993 and was Secretary from April 1993 to April 1994. She is an attorney who has
been licensed to practice law since 1976 and has been in private practice since
1990.
Raymond A. "Ray" Kreig - Director. Ray Kreig, 53, is president of R.A. Kreig &
Associates, a consulting firm specializing in land and site assessment. He
is a professional civil engineer and geologist. Mr. Kreig was elected to
the board in April 1994 and was President from April 1995 to April 1997.
H.A. "Red" Boucher - Director. Red Boucher, 70, owns a consulting firm, is
president of another telecommunication firm and hosts a weekly statewide TV
show. He has held many elected offices including Lieutenant Governor of
Alaska. He was elected to the board in April 1999.
Item 11 - Executive Compensation
CASH COMPENSATION
The following table sets forth all remuneration paid by Chugach for the calendar
years ended December 31, 1999, 1998 and 1997 with respect to each of the four
executive officers of Chugach, all of whose total cash and cash equivalent
compensation exceeded $100,000, and for all such executive officers as a group:
Name Principal Position Year Salary
---- ------------------ ---- ------
Eugene N. Bjornstad General Manager 1999 $204,948
1998 200,423
1997 164,482
Lee D. Thibert Executive Manager, Transmission
& Distribution Network Services 1999 136,147
1998 125,880
1997 125,626
Evan J. Griffith, Jr. Executive Manager, Finance &
Energy Supply 1999 147,897
1998 134,934
1997 126,866
William R. Stewart Executive Manager, Retail Services 1999 150,133
1998 143,943
1997 142,213
Directors of Chugach are compensated for their services in the amount of $100
per board meeting attended (including committee meetings) up to a maximum of
seventy meetings per year for a director and eighty-five meetings per year for
the President. Upon termination, Mr. Bjornstad's employment agreement provides
that he may receive an amount equal to his salary for the remaining term of his
employment agreement (which number shall not be less than six months) plus any
accrued annual leave or other compensation then due as of the effective date of
the notice of termination.
COMPENSATION PURSUANT TO PLANS
Chugach has elected to participate in the National Rural Electric Cooperative
Association (NRECA) Retirement and Security Program (Plan), a multiple employer
defined benefit master pension plan maintained and administered by the NRECA for
the benefit of its members and their employees. The Plan is intended to be a
qualified pension plan under Section 401(a) of the Code. All employees of
Chugach not covered by a union agreement become participants in the Plan on the
first day of the month following completion of one year of eligibility service.
An employee is credited with one year of eligibility service if he completes
1,000 hours of service either in his first twelve consecutive months of
employment or in any calendar year for Chugach or certain other employers in
rural electrification (related employers). Pension benefits vest at the rate of
10% for each of the first four years of vesting service and become fully vested
and nonforfeitable on the earlier of the date a participant has five years of
vesting service or the date the participant attains age fifty-five while
employed by Chugach or a related employer. A participant is credited with one
year of vesting service for each calendar year in which he performs at least one
hour of service for Chugach or a related employer. Pension benefits are
generally paid upon the participant's retirement or death. A participant may
also elect to receive pension benefits while still employed by Chugach if he has
reached his normal retirement date by completing thirty years of benefit service
(as hereinafter defined) or, if earlier, by attaining age sixty-two. A
participant may elect to receive actuarially reduced early retirement pension
benefits before his normal retirement date provided he has attained age
fifty-five.
Pension benefits paid in normal form are paid monthly for the remaining lifetime
of the participant. Unless an actuarially equivalent optional form of benefit
payment to the participant is elected, upon the death of a participant the
participant's surviving spouse will receive pension benefits for life equal to
50% of the participant's benefit. The annual amount of a participant's pension
benefit and the resulting monthly payments the participant receives under the
normal form of payment are based on the number of his years of participation in
the Plan (benefit service) and the highest five-year average of the annual rate
of his base salary during the last ten years of his participation in the Plan
(final average salary). Annual compensation in excess of $200,000, as adjusted
by the Internal Revenue Service for cost of living increases, is disregarded
after January 1, 1989. The participant's annual pension benefit at his normal
retirement date is equal to the product of his years of benefit service (up to
thirty) times final average salary times 2%.
In 1998, NRECA notified the Association that there were employees whose pension
benefits from NRECA's Retirement & Security Program would be reduced because of
limitations on retirement benefits payable under Section 401(a)(17) or 415 of
the Internal Revenue Code of 1986, as amended. NRECA made available a Pension
Restoration Severance Pay Plan and a Pension Restoration Deferred Compensation
Plan for cooperatives to adopt in order to make employees whole for their lost
benefits. Adopting these plans would allow Chugach to protect the benefits of
current and future employees whose pension benefits would be reduced because of
these limitations. On May 6, 1998, the Association adopted the NRECA Pension
Restoration Severance Pay Plan and the Pension Restoration Deferred Compensation
Plan and amended its NRECA Retirement & Security Program accordingly.
The following table sets forth the estimated annual pension benefit payable at
normal retirement date for participants in the specified final average salary
and years of benefit service categories:
Final Years of benefit service
Average
Salary
15 20 25 30 35
-- -- -- -- --
$ 125,000 $ 37,500 $ 50,000 $ 62,500 $ 75,000 $ 75,000
150,000 45,000 60,000 75,000 90,000 90,000
The annual pension benefits indicated above are the joint and surviving spouse
life annuity amounts payable by the Plan, and they are not subject to any
deduction for Social Security or other offset amounts.
Benefit service as of December 31, 1999 taken into account under the Plan for
the executive officers is shown below. Base salary for 1999 taken into account
under the Plan for purposes of determining final average salary is also
included.
Name Principal Position Benefit Service Covered
Compensation
Eugene N. Bjornstad General Manager 15.7 $ 156,021
Lee D. Thibert Executive Manager, T&D Network 11.7 122,242
Services
Evan J. Griffith, Jr. Executive Manager, Finance & 9.4 123,968
Energy Supply
William R. Stewart Executive Manager, Retail Services 29.9 123,968
BOARD COMPENSATION COMMITTEE REPORT ON EXECUTIVE COMPENSATION
The NRECA's COMPensate Wage and Salary Plan was developed in 1986 by NRECA to
provide its members with a systematic and standardized method of evaluating jobs
in each cooperative by grading them and comparing wages and salaries within
similar rural electric systems, as well as the external market-place, and then
creating and applying statistically determined equitable pay scales. In 1988 the
Chugach Board approved implementation of NRECA's COMPensate Wage and Salary Plan
for all non-bargaining unit employees of the Association. The Plan was adopted
by the Board in 1989 and is administered in accordance with the COMPensate
guidelines. This Plan was last updated and approved by the Board in 1996 and
further updated by the General Manager in 1997 to adjust the Alaskan
differential for all management salaries from 20% to 15%. The Chugach Board has
directed that this Plan will be updated annually although the update does not
guarantee an adjustment to the salary ranges. The General Manager annually
conducts a performance appraisal for each of the Executive Managers.
Since 1994, the General Manager has had an Employment Agreement with the Chugach
Board of Directors. The Operations committee of the Board of Directors appraises
annually the performance of the General Manager and makes a written report to
the Board prior to April 24 of each year. The General Manager's performance for
1999 will be determined based on the criteria outlined in the Employment
Agreement between Chugach and Eugene N. Bjornstad dated July 6, 1994 and amended
February 25, 1998 (filed as Exhibit 10.60.1 in the March 31, 1998 Form 10-Q).
Item 12 - Security Ownership of
Certain Beneficial Owners and Management
Not Applicable
Item 13 - Certain Relationships and Related Transactions
Not Applicable
PART IV
Item 14 - Exhibits, Financial Statement Schedules and Reports on Form 8-K
Page
Financial Statements
Included in Part IV of this Report:
Independent Auditors' Report 36
Balance Sheets, December 31, 1999 and 1998 37-38
Statements of Revenues, Expenses and Patronage Capital,
Years ended December 31, 1999, 1998 and 1997 39
Statements of Cash Flows,
Years ended December 31, 1999, 1998 and 1997 40
Notes to Financial Statements 41-58
Financial Statement Schedules
Included in Part IV of this Report:
Independent Auditors' Report 66
Schedule II - Valuation and Qualifying Accounts,
Years ended December 31, 1999, 1998 and 1997 67
Other schedules are omitted as they are not required or are not applicable, or
the required information is shown in the applicable financial statements or
notes thereto.
Independent Auditors' Report
The Board of Directors
Chugach Electric Association, Inc.:
Under the date of February 25, 2000, we reported on the balance sheets of
Chugach Electric Association, Inc. as of December 31, 1999 and 1998 and the
related statements of revenues, expenses and patronage capital and cash flows
for each of the years in the three-year period ended December 31, 1999 which are
included in Part II of the Company's Annual Report on Form 10-K. In connection
with our audits of the aforementioned financial statements, we also audited the
related financial statement schedule listed in the index to Item 14 of the
Company's 1999 Annual Report on Form 10-K. This financial statement schedule is
the responsibility of the Company's management. Our responsibility is to express
an opinion on this financial statement schedule based on our audits.
In our opinion such schedule, when considered in relation to the basic financial
statements taken as a whole, presents fairly, in all material respects, the
information set forth therein.
Anchorage, Alaska
February 25, 2000
Schedule II
CHUGACH ELECTRIC ASSOCIATION, INC.
Valuation and Qualifying Accounts
Balance at Charged Balance
beginning To costs at end
of year And expenses Deductions of year
------- ------------- ---------- -------
Allowance for doubtful accounts:
Activity for year ended:
December 31, 1999 $(447,908) $(733,494) $792,179 $(389,223)
December 31, 1998 (368,029) $(697,181) $617,302 $(447,908)
December 31, 1997 (367,085) (618,379) 617,435 (368,029)
EXHIBITS
Listed below are the exhibits which are filed as part of this Report:
Exhibit Description Page
----------- ----
Number
*********3.1 Articles of Incorporation of the Registrant (as amended
April 29, 1999)
******3.2 Bylaws of the Registrant (as amended April 30, 1998)
*4.1 Trust Indenture, dated as of September 15, 1991,
Between the Registrant and Security Pacific
Bank Washington, N.A., Trustee (Including forms
of bonds)
*4.2 First Supplemental Indenture of Trust by and among
Chugach Electric Association, Inc. and Seattle-
First National Bank dated March 17, 1993
*4.3 Second Supplemental Indenture of Trust by and among
Chugach Electric Association, Inc. and Seattle-
First National Bank dated May 19, 1994
*4.4 Third Supplemental Indenture of Trust by and among
Chugach Electric Association, Inc. and Seattle-
First National Bank dated June 29, 1994
*4.4.1 Closing Documents dated November 30, 1994,
First Mortgage Bond, CoBank Series (CoBank-1),
Due March 15, 2002 pursuant to the Third
Supple- mental
Indenture of Trust dated June 29, 1994
*4.4.2 Closing documents dated August 31, 1995 First
Mortgage Bond, CoBank Series (CoBank-2), due
August 31, 2005 pursuant to the Third
Supplemental Indenture of Trust
*4.4.3 Closing documents dated April 30, 1996 First
Mortgage Bond, CoBank Series (CoBank-3), due
March 15, 2022 pursuant to the Third
Supplemental Indenture of Trust
*4.4.4 Closing documents dated September 30, 1996 First
Mortgage Bond, CoBank Series (CoBank-4), Due
June 15, 2022 pursuant to the Third Supplemental
Indenture of Trust
Exhibit
number Description Page
****4.4.5 Closing documents dated November 26, 1997 First
Mortgage Bond, CoBank Series (CoBank-5), Due
June 15, 2012 pursuant to the Third Supplemental
Indenture of Trust
*********4.4.6 Closing documents dated March 30, 1999 First
Mortgage Bond, CoBank Series (CoBank-6), Due
March 15, 2002 pursuant to the Third
Supplemental Indenture of Trust
4.4.7 Closing documents dated December 20, 1999 First Mortgage Bond, CoBank
Series (CoBank-7), Due March 15, 2002 pursuant to the Third 82
Supplemental Indenture of Trust
*4.5 Fourth Supplemental Indenture of Trust by and among
Chugach Electric Association, Inc. and Seattle-First
National Bank dated March 1, 1995
*4.6 Fifth Supplemental Indenture of Trust by and among
Chugach Electric Association, Inc. and Seattle-First
National Bank dated September 6, 1995
*4.7 Sixth Supplemental Indenture of Trust by and among
Chugach Electric Association, Inc. and Seattle-First
National Bank dated April 3, 1996
***4.8 Seventh Supplemental Indenture of Trust by and
among Chugach Electric Association, Inc. and
Seattle-First National Bank dated June 1, 1997
*****4.9 Eighth Supplemental Indenture of Trust dated as of
February 4, 1998, by and between Chugach
Electric Association, Inc. and Security Pacific Bank
Washington, N.A.
*10.1 Joint Use Agreement between the City of Seward and
the Registrant
*10.2 Wholesale Power Agreement between the City of
Seward and the Registrant
*10.3 Agreement for Sale of Electric Power and Energy
between Homer Electric Association, Inc., Alaska
Electric Generation and Transmission Association,
Inc. and the Registrant
*10.4 Modified Agreement for the Sale and Purchase of
Electric Power and Energy between Matanuska
Electric Association, Inc., Alaska Electric
Generation and Transmission Association, Inc.
and the Registrant
Exhibit Description Page
----------- ----
number
*10.4.1 First Amendment to Modified Agreement for the Sale
and Purchase of Electric Power and Energy dated
April 5, 1989 by and among Chugach Electric
Association, Inc., Matanuska Electric Association,
Inc. and Alaska Electric Generation & Trans-
mission Cooperative, Inc.
*10.5 Agreement for the Sale and Purchase of Natural Gas
between the Registrant and ARCO Alaska, Inc.
*10.6 Amendment No. 1 to Agreement for the Sale and
Purchase of Natural Gas between the Registrant
and ARCO Alaska, Inc.
*10.7 Agreement for the Sale and Purchase of Natural Gas
between the Registrant and Marathon Oil Company
*10.8 Amendatory Agreement No. 1 to Agreement for the
Sale and Purchase of Natural Gas between the
Registrant and Marathon Oil Company
*10.9 Amendatory Agreement No. 2 to Agreement for the
Sale and Purchase of Natural Gas between the
Registrant and Marathon Oil Company
*10.10 Amendatory Agreement No. 3 to Agreement for the
Sale and Purchase of Natural Gas between the
Registrant and Marathon Oil Company
*10.11 Letter of Understanding between the Registrant and
Marathon Oil Company
*10.12 Agreement for the Sale and Purchase of Natural Gas between the
Registrant and Shell Western E&P Inc.
*10.13 Amendatory Agreement No. 1 to the Agreement for the
Sale of Natural Gas between the Registrant and
Shell Western E&P Inc.
*10.14 Amendment No. 2 to the Agreement for the Sale of
Natural Gas between the Registrant and Shell
Western E&P Inc.
*10.14.1 Amendment No. 3 to the Agreement for the Sale of
Natural Gas between the Registrant and Shell
Western E&P Inc.
*10.15 Agreement for the Sale and Purchase of Natural Gas
between the Registrant and Chevron USA Inc.
Exhibit Description Page
----------- ----
number
*10.17 Amendment No. 2 to Agreement for the Sale and
Purchase of Natural Gas between the Registrant
and Chevron USA Inc.
*10.18 Nonfirm Energy Agreement between the Registrant and
Golden Valley Electric Association, Inc.
*10.19 Alaska Intertie Agreement between Alaska Power
Authority, Municipality of Anchorage, the
Registrant, City of Fairbanks, Alaska Municipal
Utilities System, Golden Valley Electric
Association, Inc. and Alaska Electric Generation
and Transmission Cooperative, Inc.
*10.20 Memorandum of Understanding Regarding Intertie
Upgrades among Alaska Energy Authority, the
Registrant, Golden Valley Electric Association,
Inc., Homer Electric Association, Inc., Matanuska
Electric Association, Inc., Municipality of
Anchorage dba Municipal Light and Power, and
the City of Seward d/b/a Seward Electric System
*10.21 Addendum No. 1 to the Alaska Intertie Agreement--
Reserve Capacity and Operating Reserve
Responsibility
*10.22 Bradley Lake Agreement for the Sale and Purchase of
Electric Power between the Alaska Power
Authority, Golden Valley Electric Association, Inc.,
the Municipality of Anchorage, the City of Seward,
the Alaska Electric Generation & Transmission
Cooperative, Inc., Homer Electric Association, Inc.,
Matanuska Electric Association Inc. and the
Registrant
*10.23 Agreement for the Wheeling of Electric Power and for
Related Services by and among the Registrant,
Homer Electric Association, Inc., Golden Valley
Electric Association, Inc., Matanuska Electric
Association, Inc., the Municipality of Anchorage,
Inc. dba Municipal Light & Power, the City of
Seward dba Seward Electric System and Alaska
Electric Generation and Transmission Cooperative, Inc.
*10.24 Transmission Sharing Agreement by and among Homer
Electric Association, Inc., the Registrant, Golden
Valley Electric Association, Inc., and the Municipality of
Anchorage d/b/a Municipal Light and Power
Exhibit
number Description Page
*10.25 Amendment to Agreement for Sale of Transmission
Capability among Homer Electric Association, Inc.,
Alaska Electric Generation and Transmission
Cooperative, Inc., the Registrant, Golden Valley
Electric Association, Inc. and the Municipality of
Anchorage d/b/a Municipal Light and Power
*10.26 Net Billing Agreement among the Registrant,
Matanuska Electric Association, Inc. and Alaska
Electric Generation and Transmission Cooperative,
Inc.
*10.27 Interconnection Agreement between the Registrant and
Municipality of Anchorage Municipal Light and
Power
*10.28 Interconnection Agreement between the Registrant and
Municipality of Anchorage Municipal Light and
Power Addendum No. 1
*10.29 Amendment No. 1 to Interconnection Agreement
between the Registrant and Municipality of
Anchorage Municipal Light and Power
*10.30 Agreement between the Registrant and Chevron USA,
Inc. for the Sale and Purchase of Supplemental
Natural Gas
*10.31 Agreement between the Registrant and Shell Western
E&P Inc. for the Sale and Purchase of
Supplemental Natural Gas
*10.32 Agreement between the Registrant and ARCO Alaska,
Inc. for the Sale and Purchase of Supplemental
Natural Gas
*10.33 Eklutna Purchase Agreement among the Registrant,
Matanuska Electric Association, Inc., Municipality
of Anchorage d/b/a Municipal Light and Power and
Alaska Power Administration
*10.33.1 Amendment No. 1 to Eklutna Purchase Agreement
among the Registrant, Matanuska Electric
Association, Inc., Municipality of Anchorage d/b/a
Municipal Light and Power and Alaska Power
Administration
*10.33.2 Eklutna Purchase Agreement Amendment No. 2
effective June 14, 1993 between Chugach, MEA,
AML&P and the Alaska Power Administration
Exhibit Description Page
----------- ----
number
*10.33.3 Eklutna Hydroelectric Project Transition Plan,
by and among the Registrant; The United States
of America d/b/a Alaska Power Administration,
a unit of the Department of Energy; the
Municipality of Anchorage d/b/a Municipal
Light & Power; and Matanuska Electric
Association, Inc.
*10.34 University Substation 1991 Improvements Contract
between the Registrant and Alcan Electrical and
Engineering, Inc.
*10.35 Camp Facilities Replacement Contract between the
Registrant and Baugh Construction and
Engineering Company
*10.36 Lease Amendment between Standard Oil Company of
California and the Registrant
*10.37 Lease Amendment between Chevron USA, Inc. and the
Registrant
*10.38 Settlement Agreement among the Registrant, Homer
Electric Association, Inc., Matanuska Electric
Association, Inc., the City of Seward and Alaska
Electric Generation and Transmission Cooperative,
Inc. resolving G&T TIER Level, Equity Level,
Capital Credits, Equity Management Plan, and
Loan Covenant Disputes
*10.38.1 First Amendment to "Settlement Agreement
Resolving G&T TIER Level, Equity Level,
Capital Credits, Equity Management Plan and
Loan Covenant Disputes" in APUC Docket U-92-10
between Chugach and MEA, Homer and AEG&T dated
March 1993
*10.39 Loan Agreement between the National Bank for
Cooperatives (formerly Spokane Bank for
Cooperatives) and the Registrant, as amended
*10.40 Amendment dated September 13, 1991 to Loan
Agreement between the National Bank for
Cooperatives and the Registrant
*10.41 Form of Commitment Letter to be entered into between
the National Bank for Cooperatives and Registrant
Exhibit
number Description Page
*10.42 Agreement between the Municipality of Anchorage
d/b/a Anchorage Municipal Light and Power,
Chugach Electric Association, Inc., Matanuska
Electric Association, Inc., U.S. Fish and Wildlife
Service, National Marine Fisheries Service, Alaska
Energy Authority, and the State of Alaska Relative
to the Eklutna and Snettisham Hydroelectric
Projects
*10.43 Bradley Lake Hydroelectric Agreement for the
Dispatch of Electric Power and for Related
Services by and among Chugach Electric
Association, Inc. and the Alaska Energy Authority
*10.44 Net Billing Agreement among Chugach Electric
Association, Inc. and the City of Seward
*10.45 Soldotna One System Use and Dispatch Agreement by
and among Alaska Electric Generation and
Transmission Cooperative, Inc. and Chugach
Electric Association, Inc.
*10.46 Agreement for Bradley Lake Resource Scheduling
between Chugach, Homer Electric Association, Inc.
and the Alaska Electric Generation and
Transmission Cooperative, Inc. dated September
29, 1992
*10.47 Gas Transportation Agreement between Chugach,
Alaska Pipeline Company and ENSTAR Natural
Gas Company dated December 7, 1992
*10.48 Daves Creek Substation Agreement between Chugach
and the Alaska Energy Authority dated March 13,
1992
*10.49 Memorandum of Agreement between Chugach and
AEG&T dated April 27, 1993 regarding Interest
Expense Allocator
*10.50 Settlement Agreement between Chugach and
Intervenor Wholesale Customers in APUC Docket
U-93-15 dated September 1993 regarding
depreciation of submarine cables
*10.52 Twenty Five Million Dollar Line of Credit Agreement
and Promissory Note between Chugach and
National Bank for Cooperatives
Exhibit
number Description Page
*10.52.1 Amendment to Line of Credit Agreement between
Chugach and National Bank for Cooperatives dated
March 11, 1994
*10.52.2 Amendment to Line of Credit Agreement between
Chugach and National Bank for Cooperatives and
amended and restated Promissory Note
(thirty-five million dollars) dated April 18,
1994
*10.52.3 Amendment to Line of Credit Agreement between
Chugach and National Bank for Cooperatives
(thirty-five million dollars) dated May 1, 1995
*10.52.4 Amendment to Line of Credit Agreement between
Chugach and National Bank for Cooperatives
(thirty-five million dollars) dated May 15, 1995
*10.53 Bill of Sale between Chugach and Cook Inlet Tug &
Barge Co. for the barge SUSITNA dated March 1,
1993
*10.54 Intertie Grant Agreement between Chugach and
GVEA, FMUS, AML&P, AEG&T, MEA, Homer, Seward,
the State of Alaska, Department of
Administration, and AIDEA dated October 26,
1993
*10.55 Grant Transfer and Delegation Agreement
between Chugach and GVEA, FMUS, AML&P, AEG&T,
MEA, Homer, Seward, the State of Alaska,
Department of Administration, and AIDEA dated
November 5, 1993
*10.56 Letter of Understanding between Chugach and IBEW
dated January 6, 1993 regarding the Outside Plant
Personnel Agreement
*10.57 Letter of Understanding between Chugach and IBEW
dated January 6, 1993 regarding the Office and
Engineering Agreement
*10.58 Letter of Understanding between Chugach and IBEW
dated January 6, 1993 regarding the Generation
Plant Personnel Agreement
*10.59 Eklutna Power Sales Contract No. 85-79AP10004
between Chugach and Alaska Power
Administration dated October 13, 1979
Exhibit
number Description Page
------ ----------- ----
*10.59.1 Contract Modification No. 1 to Contract No.
85-79AP10004 between Chugach and the Alaska
Power Administration dated October 19, 1988
extending the Eklutna Power Sales Agreement
*10.59.2 Amendment to Exhibit E of Modification No. 1 to
Contract No. 85-79AP10004 between Chugach
and Alaska Power Administration dated October
29, 1993 regarding the Eklutna Power Sales
Agreement
*10.59.3 Contract Modification No. 2 to Contract No.
85-79AP10004 between Chugach and the Alaska
Power Administration dated November 9, 1993
extending the Eklutna Power Sales Agreement
*10.60 Employment Agreement by and among Chugach
Electric Association, Inc. and Eugene N.
Bjornstad dated July 6, 1994
*****10.60.1 Amendment to Employment Agreement by and
among Chugach Electric Association, Inc. and
Eugene N. Bjornstad dated February 25, 1998
*10.61 United States Department of Energy, Alaska Power
Administration, Eklutna Project, Contract No.
DE-SC85-95AP10042 for Electric Service to
Chugach Electric Association, Inc., Matanuska
Electric Association, Inc. and Municipality of
Anchorage dba Municipal Light & Power dated
December 29, 1994
*10.62 Hotel Employees & Restaurant Employees Union
agreement covering terms and conditions of
employment - Beluga Power Plant Culinary
Employees dated the 2nd day of March, 1995
***10.63 National Bank for Cooperatives (CoBank) Credit
Agreement dated June 22, 1994
***10.63.1 Amendment No. 1 to National Bank for
Cooperatives (CoBank) Credit Agreement dated
June 1, 1997
****10.64 Eklutna Hydroelectric Project Closing Documents
dated October 2, 1997
****10.65 Fifty Million Dollar Line of Credit Agreement
between Chugach and the National Rural Utilities
Cooperative Finance Corporation executed
October 22, 1997
Exhibit
Number Description Page
********10.66 Contract of Sale PC25TM Model C Fuel Cell Power
Plants between ONSI Corporation ("Seller") and
Chugach Electric Association, Inc. ("Buyer")
dated April 24, 1998
********10.67 International Swap Dealers Association, Inc. (ISDA)
Master Agreement dated as of March 17, 1999
between Lehman Brothers Financial Products
Inc. and Chugach Electric Association, Inc.
*********10.68 Confirmation for U.S. dollar Treasury rate-lock transaction to be
subject to 1992 Master Agreement, dated March 17, 1999, between
Lehman Brothers Financial Products Inc. and Chugach Electric
Association, Inc.
**********10.70 Nikiski Corporation Plant System Use and Dispatch Agreement between
Chugach Electric Association, Inc. and Alaska Electric Generation
and Transmission Cooperative, Inc.
**********10.71 Agreement for the Sale and Purchase of Electric Power and Energy
between Chugach Electric Association, Inc. and the City of Seward
**********10.72 Amendment No. 2 to Agreement for the Sale and Purchase of Natural Gas
between Chugach Electric Association, Inc. and ARCO Beluga, Inc.
**********10.73 Amendatory Agreement No. 5 to Agreement for the Sale and Purchase of
Natural Gas between Chugach Electric Association, Inc. and Marathon
Oil Company
**********10.74 Amendment No. 3 to Agreement for the Sale and Purchase of Natural Gas
between Chugach Electric Association, Inc. and Chevron U.S.A. Inc.
12.1 N/A
19.0 Administrative Order on Consent for Remedial
Investigation/Feasibility Study between Chugach
and the United States Environmental Protection
Agency dated September 23, 1992
*19.1 Proposed Partial Consent Decree in Standard Steel
Superfund Site matter
*19.2 Partial Consent Decree in Standard Steel Superfund
Site matter
Exhibit Description Page
----------- ----
Number
*****19.3 Memorandum of Agreement by and among Chugach
Electric Association, Inc. and Admiral Insurance
Company Alaska, Alaska National Insurance
Company, Nationwide Mutual Insurance
Company and Providence Washington Insurance
Company relating to Chugach's PRP obligations
at the Standard Steel Superfund Site dated
February 3, 1998
*****19.4 CERCLA Remedial Design and Remedial Action
Consent Decree in the Standard Steel Superfund
Site matter dated January 24, 1998
******19.5 Settlement Agreement dated the 15th day of May
1998 by and between Nationwide Mutual Insurance
Company, Alaska National Insurance Company,
Providence Washington Insurance Company and
Admiral Insurance Company and Chugach Electric
Association, Inc.
27 Financial Data Schedule (filed electronically)
* Previously referred to in the Registrant's Annual Report on Form 10-K
dated December 31, 1996. ** Previously filed as an exhibit to the
Registrant's Quarterly Report on Form 10-Q dated June 30, 1997.
*** Previously filed as an exhibit to the Registrant's Quarterly Report on
Form 10-Q dated September 30, 1997. **** Previously filed as an exhibit to
the Registrant's Annual Report on Form 10-K dated December 31, 1997
***** Previously filed as an exhibit to the Registrant's Quarterly Report on
Form 10-Q dated March 31, 1998 ****** Previously filed as an exhibit to the
Registrants Quarterly Report on Form 10-Q dated June 30, 1998
******* Previously filed as an exhibit to the Registrants Quarterly Report on
Form 10-Q dated September 30, 1998 ******** Previously filed as an exhibit to
the Registrants Annual Report on Form 10-K dated December 31, 1998 *********
Previously filed as an exhibit to the Registrants Quarterly Report on Form 10-Q
dated March 31, 1999 ********** Previously filed as an exhibit to the
Registrants Quarterly Report on Form 10-Q dated June 30, 1999
REPORTS ON FORM 8-K
Reference is made to the November 1999 8-K, which discussed the outcome of the
special meeting of members that was held by Chugach on November 18, 1999, to
consider and vote on the MEA proposal and the November 17, 1999 response to the
petitions to remove five of its seven directors from office.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized on March 30, 2000.
CHUGACH ELECTRIC ASSOCIATION, INC.
By: /s/ Eugene N. Bjornstad
Eugene N. Bjornstad, General Manager
Date: March 30, 2000
Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following persons on behalf of the registrant and
in the capacities and on the date indicated March 30, 2000:
/s/ Eugene N. Bjornstad
Eugene N. Bjornstad General Manager
/s/ Lee D. Thibert
Lee D. Thibert Executive Manager, T&D Network Services
/s/ Evan J. Griffith, Jr.
Evan J. Griffith, Jr. Executive Manager, Finance & Energy Supply
(Principal financial officer)
/s/ William R. Stewart
William R. Stewart Executive Manager, Retail Services
/s/ Michael R. Cunningham
Michael R. Cunningham Controller
(Principal accounting officer)
/s/ Chris Birch
Chris Birch President and Director
(Principal executive officer)
/s/ Patricia Jasper
Patricia Jasper Vice President and Director
/s/ Bruce E. Davison
Bruce E. Davison Secretary and Director
/s/ Mary Minder
Mary Minder Treasurer and Director
/s/ H.A. "Red" Boucher
H.A. "Red" Boucher Director
/s/ Pat Kennedy
Pat Kennedy Director
/s/ Ray Kreig
Ray Kreig Director
Supplemental information to be furnished with reports filed pursuant to Section
15(d) of the Act by registrants which have not registered securities pursuant to
Section 12, of the Act:
Chugach has not made an Annual Report to securities holders for 1999 and will
not make such a report after the filing of this Form 10-K. As a consequence, no
copies of any such report will be furnished to the Securities and Exchange
Commission.