HomeMy WebLinkAboutProject Managment Committee State Energy Commision 1997PROJECT MANAGEMENT COMMITTEE Tar Fle
THE STATE ENERGY PROGRAM
Following the dramatic increase in oil prices in 1979-1980, the State was in a
financial position to pump massive amounts of money into the development of energy
projects.
During the early 1980s, the Alaska Energy Authority constructed or acquired four
projects -- Tyee Lake, Terror Lake, Swan Lake, and Solomon Gulch. The costs for
constructing or acquiring the projects was initially paid by bond financing. Eventually, the
bonds were replaced with money lent to the Authority by the Department of Commerce and
Economic Development, from the Power Development Revolving Loan Fund.
In an effort to equalize power costs for the communities served by the four projects,
the Alaska legislature provided that these four projects would be considered as one project --
the Initial Project. Together they would be operated and managed jointly and the wholesale
power rate for power sales would be the same for all four projects.
Between May and October of 1985, the parties engaged in intense negotiations. The
Memorandum of Understanding between the Authority and the Representatives of the Four
Dam Pool communities (signed on May 8, 1985), forged the basic tenets of what was to
become the Long-term Power Sales Agreement for the Four Dam Pool.
THE POWER SALES AGREEMENT
On October 28, 1985, the Alaska Power Authority (now the Alaska Energy
Authority), the Cities of Ketchikan, Wrangell and Petersburg, the Copper Valley Electric
Association and the Kodiak Electric Association entered into a Long-term Power Sales
Agreement.
WHO The long term power sales contract is between the City of Petersburg,
the City of Ketchikan, the City of Wrangell, Kodiak Electric
Association, Copper Valley Electric Association and the Alaska Energy
Authority.
WHAT There are four operating hydroelectric projects owned by the State of
Alaska: Lake Tyee, serving Petersburg and Wrangell; Swan Lake,
serving Ketchikan; Terror Lake, serving Kodiak; and Solomon Gulch,
serving Copper Valley.
WHY Energy from the projects displaces energy formerly generated by diesel
plants in each community. Electricity costs no longer depend upon
diesel fuel prices and were projected to be lower than diesel-generated
HOW
power. The contract provides a long term resource with a relatively
stable cost and predictable economic future.
Term: The contract is for 45 years (1985 to 2030), renewable for a
period up to the useful life of the projects.
Power: Each purchasing utility is entitled to receive, as needed, all the
power available from its project and can benefit directly and indirectly
from the sale of any surplus power from its project. The utility pays the
agreed upon rate for the power it requires. No minimum amount or
minimum payment is required.
Wholesale Power Cost: Each community pays the AEA a "postage
stamp" rate for energy from the projects. The rate is established at the
start of each fiscal year to cover estimated operating costs and agreed
contributions toward debt retirement.
Operating Costs: Payments cover actual on-site costs, project-specific
costs incurred by the AEA and utility management personnel,
maintenance, and a fixed annual contribution of $500,000 to an
equipment renewals and replacement fund.
Debt Service: A schedule of debt service rates is agreed in advance for
successive 15-year periods during the contract. The 1986 rate started at
2.6 cents per Kwh, rising in steps to four cents per Kwh for the years
1990-2000. Prior to 2000, a "rate opener" mechanism will establish the
basis for rates between the years 2000-2015.
Risks: As owner of the four projects the AEA bears certain risks
throughout the term of the contract and any renewals. These risks are:
Uninsured project failures;
Substandard project performance;
Inadequacies in the funds for renewal and replacement of
components;
Failure of any of the participating utilities to pay their share.
Operation and Maintenance: The five utilities operate and maintain the four
projects through a combination of local control and oversight by a Project
Management Committee. The Committee consists of representatives from each
of the five utilities and the AEA, and operating decisions are subject to
management procedures adopted by the Committee (see Four Dam Pool
Policies and Rules of Procedure Handbook).
"UNUSUAL" PROVISIONS
OF THE
POWER SALES AGREEMENT
Construction financing - substantial State grant
-no bonds (loan from general fund)
- rate not tied to actual debt service
Requirements obligation, no "take or pay" obligation
Pooling of costs - concept of "Initial Project"
Division of risks between Authority and Purchasing Utilities
Use of the PMC for contract implementation
OBLIGATIONS OF THE AEA, PURCHASING UTILITIES AND PMC
The Long-Term Power Sales Agreement creates a number of duties and
responsibilities. Some, such as the financial obligations, rest on the individual parties (the
AEA and purchasing utilities). Other responsibilities are vested in the group jointly through
the PMC.
A. Financial Obligations of AEA and Purchasing Utilities
The Long-Term Power Sales Agreement imposes certain financial
responsibilities on both the Alaska Energy Authority, as seller, and the five utility
signatories, as buyers.
Generally speaking, the obligations of the utilities are for regular, recurring
expenses that are funded through the rates paid by the utilities to buy power from the AEA.
The obligations of the AEA, on the other hand, are for the coverage of various
contingencies.
1. AEA Financial Obligations
The agreement requires the AEA to pay for any of the following items:
a. Any costs associated with damage to or premature failure of any
Four Dam Pool equipment that is not covered by insurance
(Sections 4(d) and 6(b)(ii));
b. Any costs associated with substandard performance of any of the
Four Dam Pool facilities (Sections 4(d) and 6(b)(ii));
c. Any costs of necessary renewals or replacements of equipment
at any of the Four Dam Pool facilities to the extent there are
any unexpended proceeds from the loan used to finance the
Initial Project (Section 6(b)(iii)(D));
d. Any costs of necessary renewals or replacements of equipment
at any of the Four Dam Pool facilities that exceed the amounts
then available in the Renewals and Replacements Fund (Section
4(d)); and
e. Any costs associated with the failure of any purchasing utility to
make its required payments (Section 4(d)).
2. Purchasing Utility Financial Obligations
The agreement requires the purchasing utilities to pay for the following items:
a. The total costs of operating the Four Dam Pool facilities,
including the costs of insurance (Sections 5(b)(i)(A) and (B)(I));
The specific administrative and general costs of the AEA
required for administration of the Four Dam Pool facilities
(Section 5(b)(i)(B)(11));
The costs associated with the Project Management Committee
(Section 5(b)(i)(B)(IID);
The annual contributions to the Renewals and Replacement Fund
(Section 5(b)(i)(C)); and
An agreed-upon contribution to the debt service on the loan
from the Alaska Department of Commerce that financed
construction of the Four Dam Pool facilities (Section 5(b)(ii)).
B. Other Duties and Responsibilities
In addition to financial obligations, the Long-Term Power Sales Agreement
imposes duties and responsibilities for the operation and protection of the Initial Project:
1. AEA Duties
a. To sell power to each Purchasing Utility up to the full capability
of each dedicated facility (Section 3(a));
To make power continuously available to each Purchasing
Utility and subject to certain rights of interruption (Section
4(a));
To construct, maintain and repair any AEA owned facilities in
accordance with Prudent Utility Practice (Section 4(b)); and
To maintain records necessary for purposes of the agreement
and of FERC licensing requirements (Section 10).
Participating Utility Duties
a. To purchase and pay for power needed for utility loads in excess
of loads served by pre-existing hydro facilities (Sections 3(a),
3(b) and 3(c));
b. To construct, maintain and repair any utility owned facilities in
accordance with Prudent Utility Practice (Section 4(b));
c. To maintain records necessary for purposes of the agreement
and of FERC licensing requirements (Section 10); and
d. To take actions necessary to maintain the integrity of the
agreement (Section 12).
PMC Duties
a. To establish and deposit funds in the Initial Project Revenue
Fund (Section 5(e));
b. To establish, administer and approve expenditures from the
R&R Fund (Sections 6(b)(i), 6(b)(iii)(C) and 7(e)(ii));
ce To disburse funds to pay operating costs and debt service and to
make the R&R contribution (Section 5(f));
d. To meet at least quarterly (Section 7(c));
ey To adopt rules to govern the Committee’s affairs (Sections 7(d)
and 7(e)(iv));
f. To develop annual budgets (Section 7(e)(i));
g. To arrange for insurance for Initial Project facilities, including
determination of coverage limits, choice of insurers and
disposition of insurance claim proceeds (Section 7(e)(iii));
h. To adopt standards and arrange for the annual audit of all power
production costs (Sections 7(e)(iv) 7(e)(v) and 7(g));
Develop and adopt technical, operating and maintenance
standards for the Initial Project equipment and facilities (Section
T(e)(vi));
Establish an annual rate that is sufficient to pay for all costs
under the contract (Sections 7(e)(vii) and 5(f));
Develop load estimates as necessary for the Agreement (Section
7(e)(viii));
Develop standards for capital asset acquisition and accounting
(Section 7(e)(ix));
Develop standards for expenditures which acquire unanimous
agreement (Sections 7(e)(x) and 1(f));
To adjudicate disputes, or adopt procedures for the adjudication
of disputes between parties, prior to litigation (Section 8(a)); and
Various duties relative to rate reopener, the first such duty being
to provide a load forecast by 1998 (Section 9(c)).
CREATION OF THE COMMITTEE
In order to implement the provisions of the Power Sales Agreement, the Project
Management Committee was formed. The membership of the PMC consists of a
representative of the AEA and one representative of each utility party to the agreement. The
PMC has the general authority to implement the agreement and is charged with the overall
management of the Project and operation of its facilities.
COMMITTEE PROCEDURES
1 Representatives: each party gets one, plus an alternative.
2. Meetings:
e annual, quarterly, special;
e need public notice and are open to the public;
e teleconferences okay;
e quorum is any four members (but note special voting rules).
3. Manner of Acting:
e roll call votes;
e presumed to vote yes unless register dissent;
e special majority necessary
for adoption of procedural rules,
annual budgets,
minimum levels of insurance for O&M standards.
4. Committees: can create any committees, but all decisions are subject to PMC
adoption.
ey Officers:
e Chairman
e Vice Chairman
e Secretary
e Treasurer
6. Budget and Audit:
e PMC to develop
e Annual audit to verify expenses, true-up wholesale power rate
e Initial Project Revenue Fund
e R&R Fund
e Construction Loan Fund
e Working Capital Fund
e Initial Project Revolving Loan Fund
Insurance:
e Amended Insurance Agreement
AMENDED AGREEMENT FOR SATISFACTION OF INSURANCE
COST PAYMENT
OBLIGATION AND CONCERNING RISK ALLOCATION
PURPOSE: Fulfills the PMC’s obligations from the Power Sales Agreement to arrange and
pay the costs of satisfactory insurance for the Initial Project. Clarifies AEA’s
responsibility for Losses.
TERM: Original Agreement signed April 24, 1989. Amended Agreement effective
June 23, 1994 and continues until terminated. Cannot be terminated prior to
June 30, 1999.
AEA OBLIGATIONS:
e Responsible for all losses of the Initial Project.
e Responsible for substandard facility performance. No such thing as an
“uninsured facility failures".
e Arrangements for insurance/self-insurance.
e Repair damaged facilities as quickly as possible.
PMC OBLIGATIONS:
PROCEDURES:
Annual Payment Amount - $1,100,000, adjusted annually. To be
renegotiated July 1, 1999.
Payments for Operating Losses:
the first $25,000 per occurrence;
total payments for losses (in excess of $25,000 per occurrence),
shall not exceed $300,000 in any fiscal year.
Premium on PMC treasurer fidelity bond.
AEA shall evaluate and process claims. AEA shall arrange for the
initial payment of loss and shall bill the PMC for amounts only when
(a) the final amount of loss has been determined or (b) when the
amount of expense exceeds $25,000.
10
THE PMC’s TOP TEN LIST OF ISSUES
The Project Management Committee and Alaska Energy Authority are guided
primarily by the provisions of the Power Sales Agreement. As the Agreement couldn’t
possibly contemplate all issues that could arise over time, it instead provided the parties with
the basic tools to deal with issues encountered along the way. To memorialize certain
Committee decisions, the PMC and AEA have entered into Memorandums of Understanding
(MOU), or prepared resolutions to outline their reasoning and detail future practices.
Since 1985, the PMC has acted on many issues, The following list represents some of
the major issues, MOU’s and resolutions affecting the operation of the Initial Project.
1: AEA ADMINISTRATIVE COSTS
As the owner of the Initial Project, the AEA has specific duties, To formalize
the duties and corresponding compensation, the parties adopted a MOU in June 1986.
AEA’s Duties:
e Maintain all federal and state licenses, permits or certificates necessary
for the operation of the Initial Project;
e Ensure that the construction and operation of the Initial Project
complies with all applicable state and federal requirements; and
e Provide other services related to the Initial Project as time and
resources permit.
In order to carry out these duties, the AEA is committed to provide the
services of approximately 3'4 full-time-equivalent personnel.
In return, the PMC compensates the AEA from the Revenue Fund. The
amount was established in 1986 and escalates annually by either the GNP deflator or 6%
(whichever is less). Payments are made monthly,
Should the duties of the AEA change, or if the duties can be accomplished by
less that 3% FTEs, the payment may be reduced.
2. CAPITAL ASSET ACQUISITION
The PMC and AEA adopted a MOU (April 1988) on capital asset acquisition
and control. Upon execution of the MOU, the PMC transferred ownership of all capital
assets held in trust for the Initial Project to the AEA. In return, the AEA transferred custody,
control and future management of the assets to the PMC.
11
Capital assets include an asset that has a value of $500 or more and a useful
life of at least one year.
3's COMPLETION OF CONSTRUCTION
The five Purchasing Utilities filed a "friendly" lawsuit in November 1989
against the AEA on a variety of matters. These matters included (1) a demand that AEA
deposit $4 million in unspent construction funds into a fund for renewal and replacement
purposes; (2) a request that the court determine that AEA be deemed "responsible" for
several "uninsured losses" totalling about $150,000; and (3) a request that the court
determine that the Purchasing Utilities are entitled to the benefit of revenues from
"incidental" uses of the facilities.
The settlement was executed by all parties to the lawsuit by May 1991,
approved by the Attorney General in June 1991, and approved by the court in July 1991.
As part of the settlement, the AEA agreed to deposit $1,000,000 into a loan
fund (the Initial Project Revolving Loan Fund) and future interest is retained, The fund will
be available to the PMC for loans relating to the Initial Project. Decisions about the use of
the loan fund are made by the PMC. All monies borrowed must be repaid to the fund within
five years. The AEA will serve as trustee to the fund.
The AEA also agreed to deposit $3,000,000 into the R&R Fund which will be
used for repairs and rehabilitation of the Tyee Transmission system and the installation of an
automated maintenance management system at the Initial Project. Any remaining portion of
the $3,000,000 will be available for general R&R purposes.
The Purchasing Utilities agreed to pay the AEA $120,000, related to the
disputed issues.
4. WORKING CAPITAL FUND/LINE OF CREDIT
In an MOU approved September, 1990, (amended November 1990) the PMC
and AEA agreed to a mechanism similar to a line of credit to finance the costs of recurring
or special operation or maintenance activities that extend for more than one year. Such
expenses might include R&R items (including items eligible for funding from the Initial
Project Revolving Loan Fund), consultants for FERC inspections, special engineering work,
stockpiling consumable items, and acquisition of spare parts or specialty tools or equipment.
The maximum term of any financing is five years and no more than
$1,000,000 in outstanding principal obligations can be financed at any one time.
The PMC approves all requests for financing in the annual budget or by
passing a special supplemental budget resolution. The AEA is then responsible for attempting
12
to establish credit arrangements to finance the fund and develop a repayment schedule for the
PMC to reimburse the fund. The PMC will set the wholesale power rate to produce revenues
to make monthly principal, interest, and expense payments for any costs financed.
Ds FERC FEES
Beginning in 1983, AEA thought itself exempt from the payment of Federal
Energy Regulatory Commission (FERC) annual licensing fees for the Four Dam Pool
projects. In August 1988, FERC staff denied AEA’s exemptions.
The PMC, acting on behalf of AEA, appealed the staff decisions to the
Commission. In October 1989 the Commission Issued an order denying the two appeals of
staff action because: (1) the AEA was entitled to a fee exemption only if project power is
sold to the public without profit; and (2) under Commission regulations, profit is realized
when a purchasing utility’s annual revenues exceed its annual expenses.
AEA petitioned for rehearing. In June 1990 the Commission denied AEA’s
petitions for rehearing, reiterating their earlier reasoning that the power was sold at a profit.
The PMC’s alternatives were to accept the ruling or go to court. The PMC
voted to file an appeal in the D.C. Court of Appeals. The case was filed under AEA’s name
In July 1990. PMC filed an opening brief in November 1990 and reply brief in January
1991. Oral arguments were held February 1991.
The federal court decided (March 1991) that the AEA wasn’t exempt from
FERC licensing fees because the PMC utility purchasers accumulated annual revenues in
excess of their annual expenses, thereby apparently making a profit on the resale of the
power to consumers.
The PMC decided not to pursue further appeals or possible legislative
solutions.
6. INSURANCE
The Power Sales Agreement requires the PMC to arrange for insurance of the
Initial Project. The Committee approved the Agreement for Satisfaction of Insurance Cost
Payment Obligation and Concerning Risk Allocation in April 1989.
In the agreement, the PMC is obligated to pay the joint insurance costs of the
Initial Project which includes an annual payment amount (initially $1,000,000), any operating
losses (the first $300,000 a year of costs not covered by insurance plus $25,000 for each
"event") and the premium on the PMC Treasurer fidelity bond.
13
The AEA retains responsibility for all losses associated with its ownership and
operation of the Initial Project--losses to or from all real and/or personal property (such as
boilers and machinery, transmission and generation facilities, and any improvements and
betterments). This includes substandard facility performance. At the first meeting of each
fiscal year, the AEA will report to the PMC on the arrangements for purchased insurance or
retention of risks, previous amounts paid and identify outstanding claims.
The AEA will be responsible for evaluating, processing and defending any
losses or claims.
Ts INTERRUPTIBLE SALES
At projects where the firm loads utilize less than full project capability, -sales
in excess of firm utility loads at a rate less than the whoiesale rate are beneficial to PMC
members, It utilizes an otherwise unused resource and brings in funds which offset utility,
PMC and AEA costs.
Each utility must negotiate a contract and present the contract to the PMC
prior to any sale of "discounted" energy. The PMC must unanimously approve each
interruptible sale proposal. Each utility making sales under PMC interruptible rates must
report to the PMC on a quarterly basis on sales made under the schedule and sales expected,
along with other relevant information.
The PMC has approved several contracts for sales of interruptible power from
the Initial Project:
e Sales to Alaska Pulp Corporation;
e Sales from Ketchikan Public Utilities and Ketchikan Pulp Company;
e Sales to the City of Wrangell for municipal building use; and
e Kodiak Schools interruptible sales;
8. OPERATION AND MAINTENANCE
At the August 1992 PMC meeting, the Committee approved a generic
Operation and Maintenance contract. The contract is designed to make all project operation
and maintenance consistent with each other and ensure that the appropriate level of O&M is
implemented by project operators. In addition, O&M technical standards for all four projects
have been standardized in several volumes of an O&M manual and distributed to the PMC
utilities.
14
9. R&R FUND
Resolution 89-29 adopted in April, 1989, and an MOU adopted In April 991
outlines R&R standards, defines permitted uses of R&R fund, sets forth a non-exclusive list
of prohibited uses of R&R, and outlines a process approving proposed expenditures from
R&R and withdrawal procedures,
R&R was designed as one source of monies for the routine renewal and
replacement of existing Initial Project facilities and equipment for the purpose of continuing
the function of those items. R&R is not to be used for uninsured facility failures, substandard
facility performance or other risks borne by the AEA, loans for non-R&R expenditures,
facility operating costs, or joint costs of he project.
All requests for an R&R Fund expenditure or reimbursement are made in
writing, explaining the situation and need for funds. The AEA will evaluate the proposal and
provide the PMC with a written recommendation. Upon PMC approval, the AEA will be
responsible for arranging for the performance of the approved work.
10. TAXES
For several years the PMC pursued an effort to obtain a Letter Ruling from
the Internal Revenue Service that the Four Dam Pool is not subject to taxation. The effort
culminated in a successful response from the IRS (September 5, 1991) indicating that the
Four Dam Pool is exempt under Section 501 (c)(4) of the Internal Revenue Code.
The only remaining question is the effective date of the IRS opinion.
Although we were not successful in getting the IRS to formally opine that the opinion is
effective back to 1985 (the creation of the Four Dam Pool PMC), the IRS gave an informal
assurance that it would not pursue any back taxes. As indicated by the IRS, it was necessary
for the PMC to file a tax form on an annual basis, starting in 1991.
To formalize the fiduciary relationship which governs the PMC’s holding and
administration of the R&R Fund, the PMC entered into a trust agreement in April 1991.
The trust agreement was intended to rework a portion of the Power Sales
Agreement into traditional trust language to meet IRS expectations:
e The R&R fund is irrevocable and reverts to the State in the event of the
end of the trust or the Initial Project;
e The individual PMC members are individually trustees of this money
(which is why each PMC member individually signed the agreement);
15
e The trustees accept no personal responsibility for the liabilities of the
trust; and
e Trustees are not to receive any special compensation for this trust
responsibility and resignation as a trustee will be automatic with
resignation from the PMC.
11. PURPA
The Power Sales Agreement provides that the Purchasing Utilities must
purchase their power requirements from the Four Dam Pool projects. The only exceptions to
this priority obligation are for any utility-owned hydroelectric projects that existed prior to
the 1985 signing of the PSA, and purchases of power from any other resource as "required
by law" (§ 3(c) PSA). An issue now exists as to whether private power developers can use
the Public Utilities Regulatory Policy Act to require Four Dam Pool utilities to purchase
from them and displace purchases from the Four Dam Pool projects.
There are now interests which plan to develop projects in areas currently
served by the utilities of the Four Dam Pool. Mahoney Lake is a recently FERC licensed
QF project from which Alaska Power and Telephone propose to provide power to Ketchikan.
Other PURPA projects include Allison Lake on Kodiak and Twin Basin near Valdez (Copper
Valley service area). There have been numerous discussion of this issue, but no binding
legal resolution.
12. DIVESTITURE
For the past couple of years, the AEA has been exploring with the Four Dam
Pool Utilities the possibility of transferring ownership of the projects to the Four Dam Pool
Utilities. This would effectively remove the State from the "partnership," leaving the
utilities with complete control.
Another party which has expressed interest in purchasing the projects is a for-
profit entity called Citizens Power of Alaska (CPOA), headed by former US Senator form
Alaska, Mike Gravel. After modifying his original proposal to terminate the Power Sales
Agreement, Mr. Gravel later agreed to operate under the terms of the existing Power Sales
Agreement, although his proposal continues to have features inconsistent with the agreement.
The Four Dam Pool Utilities made an offer to buy the projects. The
underlying principle of the Four Dam Pool offer is that ownership of the projects by the
participating utilities should not be detrimental to the communities, when compared to
continued State ownership.
The Four Dam Pool Utilities submitted an offer of over $104 million,
including $7 million per year for eleven years. The balance of the payment included the
16
State receiving use of $16 million currently in an unused insurance pool created by past
payments from the Utilities. The offer also creates opportunities to share benefits with the
State if Four Dam Pool loads increase.
Under the Four Dam Pool offer, it is estimated that the cost of power could
initially be reduced by five to ten percent, with possible future reductions as a result of
increased operating efficiency or lower than forecast costs.
The status of divestiture remains unclear. While AEA has put negotiations
"on hold" and proposes to continue State ownership, both CPOA and the Four Dam Pool
Utilities remain interested in further talks.
13. SELF-HELP
Under the terms of the Long Term Power Sales Agreement, the State bears
certain risks related to uninsured facility failures, substandard facility performance,
inadequacy of the R&R fund, etc. If the State lacks the funds to meet this obligation, and
certain repairs must be made to the Initial Project, the PMC is granted the authority to
withdraw funds to pay for the repairs from the Initial Project Revenue Fund. The PMC can
then reduce its debt service payments to the Initial Project Revenue Fund accordingly.
In 1995, the PMC sued AEA for preventing the PMC from exercising its
rights under the PSA to pay for repairs to the Tyee transmission line. The Settlement
Agreement entered into by the PMC and AEA affirmed that PMC’s right to use self-help
under the contractually defined circumstances and provided for immediate use of self-help for
Tyee transmission repairs and certain Terror Lake work.
Every year since the settlement, the AEA and PMC have entered into an
Agreement Regarding the Funding of Certain Repairs which outlines which repairs need to
be made, clarifies that funds from other sources are not available to AEA to make such
repairs and specifies the amount of self-help funds that is to be made available to AEA.
17
PMC REPRESENTATIVES AND ALTERNATES
Copper Valley
Meeting Where
Change Reported
Designated
Representative
Designated
Alternate ae
I
8/85 | Dave Highers Andy Hoge
| 12/85 Dave Highers Dan Tegeler
1/87 Dave Highers Fred Williams
5/87 Fred Williams Frank Bettine
6/88
| 9/87 Doug Bursey Fred Williams
Doug Bursey Jim Gifford
7/189 Doug Bursey Chuck Laughlin
Jack Goddard
| 1/90 Doug Bursey
6/90 Doug Bursey Steve Guest
12/91 Clayton Hurless Steve Guest or
6/92 Clayton Hurless Fred Williams
6/93 Clayton Hurless Wil Steve Guest
9/93 Clayton Hurless Robert Wilkinson
11/93 Robert Wilkinson Mike Easley
Meeting Where ni Designated Designated
Change Reported Representative Alternate
8/85 Rick Newland John Zidalis
12/85 Rick Newland Dick Southworth
| 1/86 Dick Southworth John Zidalis
Ketchikan 7/89 Roger Logan | Tom Waggoner
Public Utilities 4/90 Tom Stevenson Tom Waggoner
| 1/94 Tom Stevenson Tom Friesen
6/95 | Tom Friesen Rich Tremble
10/97 Tom Friesen John Magyar
18
Kodiak Electric
Meeting Where Designated
Change Reported Representative | Alternate
Designated
8/85 David Nease Bill Eberhardt
11/85 | Bill Eberhardt Joe Floyd
1/86 Joe Floyd Dave Nease
3/86 Joe Floyd Bill Eberhardt
5/89 Bill Beaty Bill Eberhardt
8/90 | Walter Sapp Bill Eberhardt
8/92 Walter Sapp Bill Beaty
11/92 Walter Sapp Dave Nease
Walter Sapp Bill Beaty
2/4/98 Walter Sapp Tom Hendel
2/26/98 Walter Sapp Ed Kozak
6/98 Walter Sapp Fred Zharoff
City of Petersburg Meeting Where
Change Reported
8/85
12/85
| 9/88
Designated
Representative
Dennis Lewis
Dennis Lewis
Dennis Lewis
Designated
Alternate
Ed Pefferman
Ralph Buzard
| 4/89 Dennis Lewis David Palmer
| 6/91 Dennis Lewis Dave Carlson
| 10/92 | Dave Carlson Dennis Lewis
19
City of Wrangell
Meeting Where
Change Reported
8/85
12/85
4/90
12/91
Designated
Representative
Joyce Rasler
Designated
Alternate
Eric Redman
Joyce Rasler
Darrell Maple
6/91 | Jeff Jabusch
Jeff Jabusch
6/92 | Larry Barnes
Jeff Jabusch [-nSRSSeEEEES F500) UONEEE OFT
9/89 Robert Grant Jeff Jabusch
Jeff Jabusch
Butch Cooley
George Eades
George Eades
11/92 Larry Barnes Jeff Jabusch
7/93 Larry Barnes Paul Fisher
11/94 Warren Edgley | Paul Fisher
8/95 | --- Terry Nikodym
10/95 Terry Nikodym Zo Herriges-Sherman
10/97 Terry Nikodym | Scott Seabury
| 2/98 Bill Privett Scott Seabury
Meeting Where Designated Designated
Change Reported Representative Alternate
Rudy Etheridge bee
12/85 Rudy Etheridge Ed Morris
6/86 | Ed Morris Gloria Manni
7/87 | Don Shira Gloria Manni
3/88 Brent Petrie Don Shira
Brent Petrie
Stan Sieczkowski
Stan Sieczkowski rent Petrie
Brent Petrie
B
| Stan Sieczkowski
Charlie Bussell Stan Sieczkowski
Brent Petrie Stan Sieczkowski
9/93
Dennis McCrohan
Stan Sieczkowski
20
Chairman
Rick Newland
Dave Highers
Dick Southworth
(re-elected)
(re-elected)
Bill Eberhardt
(re-elected)
(re-elected)
Dennis Lewis
(re-elected)
(re-elected)
(re-elected)
(re-elected)
(re-elected)
Secretary
Rudy Etheridge
Dave Highers
Joyce Rasler
Ed Morris
Don Shira
(re-elected)
(re-elected)
(re-elected)
(re-elected)
Stan Sieczkowski
(re-elected)
(re-elected)
(re-elected)
(re-elected)
(re-elected)
PMC OFFICERS
Meeting Elected
8/85
12/85
10/86
7/87
8/88
7/89
9/90
9/91
8/92
7/93
8/94
8/95
7/96
8/97
Meeting Elected
8/85
12/85
10/86
7/87
8/88
7189
9/90
9/91
8/92
7/93
8/94
8/95
7196
8/97
21
Vice-Chairman
Ed Pefferman
(re-elected)
Bill Eberhardt
Dave Palmer
(re-elected)
Dave Carlson
Tom Stevenson
(re-elected)
(re-elected)
Tom Friesen
(re-elected)
(re-elected)
Treasurer
Bill Eberhardt
Jeff Jabusch
(re-elected)
(re-elected)
(re-elected)
(re-elected)
(re-elected)
Walter Sapp
(re-elected)
(re-elected)
(re-elected)
(re-elected)
(re-elected)
Meeting Elected
10/86
7/87
8/88
7189
9/90
9/92
8/92
7193
8/94
8/95
7196
8/97
Meeting Elected
10/86
7/87
8/88
7189
9/90
9/91
8/92
7193
8/94
8/95
7/96
8/97