AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON DECEMBER 19, 1997
REGISTRATION NO. 333-
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
------------------------
FORM S-4
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
------------------------
OGLETHORPE POWER CORPORATION
(AN ELECTRIC MEMBERSHIP CORPORATION)
(Exact Name of Registrant as Specified in Its Charter)
------------------------------
GEORGIA 4911 58-1211925
(State or Other Jurisdiction of (Primary Standard Industrial (I.R.S. Employer
Incorporation or Organization) Classification Code Number) Identification Number)
POST OFFICE BOX 1349
2100 EAST EXCHANGE PLACE
TUCKER, GEORGIA 30085-1349
(770) 270-7600
(Address, Including Zip Code, and Telephone Number, Including
Area Code, of Registrant's Principal Executive Offices)
--------------------------
ROBERT D. STEELE
OGLETHORPE POWER CORPORATION
POST OFFICE BOX 1349
2100 EAST EXCHANGE PLACE
TUCKER, GEORGIA 30085-1349
(770) 270-7617
(Name, Address Including Zip Code, and Telephone Number,
Including Area Code, of Agent for Service)
--------------------------
COPIES TO:
HERBERT J. SHORT, JR.
SUTHERLAND, ASBILL & BRENNAN LLP
999 PEACHTREE STREET, N.E., 23RD FLOOR
ATLANTA, GEORGIA 30309-3996
(404) 853-8491
--------------------------
Approximate date of commencement of proposed sale to the public: AS SOON AS
PRACTICABLE AFTER THE EFFECTIVE DATE OF THIS REGISTRATION STATEMENT.
--------------------------
If any of the securities being registered on this Form are being offered in
connection with the formation of a holding company and there is compliance with
General Instruction G, check the following box: / /
If this Form is filed to register additional securities for an offering
pursuant to Rule 462(b) under the Securities Act, please check the following box
and list the Securities Act registration statement number of the earlier
effective registration statement for the same offering: / /
If this Form is a post-effective amendment filed pursuant to Rule 462(d)
under the Securities Act, check the following box and list the Securities Act
registration statement number of the earlier effective registration statement
for the same offering: / /
--------------------------
CALCULATION OF REGISTRATION FEE
PROPOSED MAXIMUM PROPOSED MAXIMUM
TITLE OF EACH CLASS AMOUNT TO BE OFFERING PRICE PER AGGREGATE OFFERING AMOUNT OF
OF SECURITIES TO BE REGISTERED REGISTERED UNIT PRICE(1) REGISTRATION FEE
Serial Facility Bonds Due June 30, 2011 $224,702,000 100% $224,702,000 $66,288
(1) Estimated pursuant to Rule 457(f)(2) of the Securities Act of 1933 solely
for the purpose of calculating the registration fee.
--------------------------
THE REGISTRANT HEREBY AMENDS THIS REGISTRATION STATEMENT ON SUCH DATE OR
DATES AS MAY BE NECESSARY TO DELAY ITS EFFECTIVE DATE UNTIL THE REGISTRANT SHALL
FILE A FURTHER AMENDMENT WHICH SPECIFICALLY STATES THAT THIS REGISTRATION
STATEMENT SHALL THEREAFTER BECOME EFFECTIVE IN ACCORDANCE WITH SECTION 8(a) OF
THE SECURITIES ACT OF 1933 OR UNTIL THE REGISTRATION STATEMENT SHALL BECOME
EFFECTIVE ON SUCH DATE AS THE COMMISSION, ACTING PURSUANT TO SAID SECTION 8(a),
MAY DETERMINE.
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
SUBJECT TO COMPLETION, DATED DECEMBER 19, 1997
INFORMATION CONTAINED HEREIN IS SUBJECT TO COMPLETION OR AMENDMENT. A
REGISTRATION STATEMENT RELATING TO THESE SECURITIES HAS BEEN FILED WITH THE
SECURITIES AND EXCHANGE COMMISSION. THESE SECURITIES MAY NOT BE SOLD NOR MAY
OFFERS TO BUY BE ACCEPTED PRIOR TO THE TIME THE REGISTRATION STATEMENT BECOMES
EFFECTIVE. THIS PROSPECTUS SHALL NOT CONSTITUTE AN OFFER TO SELL OR THE
SOLICITATION OF AN OFFER TO BUY NOR SHALL THERE BE ANY SALE OF THESE SECURITIES
IN ANY STATE IN WHICH SUCH OFFER, SOLICITATION OR SALE WOULD BE UNLAWFUL PRIOR
TO REGISTRATION OR QUALIFICATION UNDER THE SECURITIES LAWS OF ANY SUCH STATE.
P R O S P E C T U S
OFFER TO EXCHANGE
6.974% SERIAL FACILITY BONDS DUE JUNE 30, 2011
INTEREST PAYABLE JUNE 30 AND DECEMBER 31
FOR ALL OUTSTANDING 6.974% SERIAL FACILITY BONDS DUE JUNE 30, 2011
------------------------
THE FACILITY BONDS WILL BE PAYABLE FROM AND SECURED, AS DESCRIBED HEREIN, BY
RENTALS TO BE PAID UNDER SEVERAL LEASES RELATING TO PLANT ROBERT W. SCHERER UNIT
NO. 2 BY
OGLETHORPE POWER CORPORATION
THE EXCHANGE OFFER WILL EXPIRE AT 5:00 P.M., NEW YORK CITY TIME,
ON , 1998, UNLESS EXTENDED.
OPC Scherer 1997 Funding Corporation A, a Delaware corporation created for
the purpose of the refinancings described herein ("OPC Scherer 1997 Funding
Corporation"), hereby offers (the "Exchange Offer"), upon the terms and subject
to the conditions set forth in this Prospectus and the accompanying Letter of
Transmittal (the "Letter of Transmittal") relating to the Exchange Offer, to
exchange $1,000 principal amount of its Serial Facility Bonds Due June 30, 2011
(the "Exchange Facility Bonds"), which will be registered under the Securities
Act of 1933, as amended (the "Securities Act"), pursuant to a Registration
Statement of which this Prospectus is a part, for $1,000 principal amount of its
outstanding Serial Facility Bonds Due June 30, 2011 (the "Private Facility
Bonds"), of which an aggregate of $224,702,000 in principal amount is
outstanding as of the date of this Prospectus.
The form and terms of the Exchange Facility Bonds will be identical in all
material respects to the form and terms of the Private Facility Bonds, except
that (i) the Exchange Facility Bonds will not contain certain restrictions on
transfer or registration rights contained in the Private Facility Bonds and (ii)
the Exchange Facility Bonds will not contain any provision for additional
interest in the event of certain defaults in obligations relating to the
Exchange Offer. The Exchange Facility Bonds will evidence the same indebtedness
as the Private Facility Bonds and will be entitled to the benefits of the
Collateral Trust Indenture described herein. The Exchange Facility Bonds and any
Private Facility Bonds not exchanged in the Exchange Offer are sometimes
referred to herein collectively as the "Facility Bonds."
The Private Facility Bonds were issued to finance the refunding of certain
nonrecourse notes of four owner trusts (the "Lessors"), which are the owners and
lessors of undivided ownership interests aggregating 60% of Plant Robert W.
Scherer Unit No. 2, an 818 megawatt ("MW") coal-fired, steam electric generating
unit located near Forsyth, Georgia ("Scherer Unit No. 2"). The Facility Bonds
will be secured by a pledge and assignment of nonrecourse Refunding Lessor Notes
(the "Refunding Lessor Notes") issued by the Lessors under four Lease Indentures
described herein. The Refunding Lessor Notes are secured by, among other things,
liens on and security interests in the basic rentals and certain other amounts
payable by Oglethorpe Power Corporation (An Electric Membership Corporation)
("Oglethorpe") to the Lessors under the several Leases described herein and the
respective undivided ownership interest of each Lessor in Scherer Unit No. 2.
Although the Facility Bonds will not be, and the Refunding Lessor Notes are not,
direct obligations of or guaranteed by Oglethorpe, Oglethorpe is unconditionally
obligated to make basic rental and certain other payments under the Leases in
amounts that will be at least sufficient to pay in full, when due, all payments
of principal of and premium, if any, and interest on the Facility Bonds. For a
more detailed description of the Facility Bonds and the relationships among
Oglethorpe, the Lessors and OPC Scherer 1997 Funding Corporation, see
"INTRODUCTION," "SECURITY AND SOURCE OF PAYMENT FOR THE FACILITY BONDS," "OPC
SCHERER 1997 FUNDING CORPORATION," "FLOW OF FUNDS FOR DEBT SERVICE PAYMENTS ON
THE FACILITY BONDS," "DESCRIPTION OF THE FACILITY BONDS," "DESCRIPTION OF THE
LEASE INDENTURES" AND "DESCRIPTION OF THE LEASES."
Interest on the Facility Bonds will be payable on June 30 and December 31 of
each year, commencing June 30, 1998. The Facility Bonds will mature on June 30,
2011. The Facility Bonds will not be subject to optional redemption prior to
maturity. The Facility Bonds will be redeemable through operation of a sinking
fund on certain specified dates at the principal amount thereof, together with
interest accrued to the redemption date. In certain instances, the Facility
Bonds will be subject to special mandatory redemption at 100% of their principal
amount, together with interest accrued to the redemption date. In certain other
instances, the Facility Bonds will be subject to special mandatory redemption at
redemption prices declining from an initial price of 106.974% of par to 100% of
par at maturity, together with interest accrued to the redemption date. See
"DESCRIPTION OF THE FACILITY BONDS."
OPC Scherer 1997 Funding Corporation will accept for exchange any and all
validly tendered Private Facility Bonds on or prior to 5:00 p.m., New York City
time, on , 1998, unless extended by Oglethorpe (if and as extended,
the "Expiration Date"). Tenders of Private Facility Bonds may be withdrawn at
any time prior to 5:00 p.m., New York City time, on the Expiration Date. See
"THE EXCHANGE OFFER."
--------------------------
THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES AND
EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION NOR HAS THE SECURITIES
AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION PASSED UPON THE
ACCURACY OR ADEQUACY OF THIS PROSPECTUS. ANY REPRESENTATION TO THE
CONTRARY IS A CRIMINAL OFFENSE.
--------------------------
The Date of this Prospectus is .
AVAILABLE INFORMATION
Oglethorpe has filed with the Securities and Exchange Commission (the
"Commission") a Registration Statement (which term includes any amendment
thereto) on Form S-4 under the Securities Act with respect to the Exchange
Facility Bonds offered hereby. This Prospectus does not contain all of the
information set forth in the Registration Statement.
Any statements contained herein concerning the provisions of any document
are not complete. With respect to each such document filed as an exhibit to the
Registration Statement, reference is made to the exhibit to the Registration
Statement, and each such statement is qualified in its entirety by such
reference.
Oglethorpe has been filing periodic reports with the Commission since 1987
and intends to continue filing such reports, to the extent permitted by the
Commission, for as long as any of the Facility Bonds are outstanding, regardless
of whether it is required to do so. Oglethorpe is required to file with the
Collateral Trust Trustee described herein copies of all periodic reports filed
with the Commission and will provide the Collateral Trust Trustee with copies of
its annual report containing audited financial statements.
Reports and other information filed with the Commission can be inspected and
copied at the offices of the Commission at Judiciary Plaza, 450 Fifth Street,
N.W., Room 1024, Washington, D.C. 20549 and at the regional offices of the
Commission at Citicorp Center, 500 West Madison Street, Suite 1400, Chicago,
Illinois 60661, and Seven World Trade Center, 13th Floor, New York, New York
10048. Copies of such material can be obtained from the Public Reference Section
of the Commission at Judiciary Plaza, 450 Fifth Street, N.W., Room 1024,
Washington, D.C. 20549 at prescribed rates. The Commission maintains a World
Wide Web site (http://www.sec.gov) that contains reports, proxy and information
statements and other information regarding registrants, such as Oglethorpe, that
file electronically with the Commission.
UNTIL , ALL DEALERS EFFECTING TRANSACTIONS IN THE REGISTERED
SECURITIES, WHETHER OR NOT PARTICIPATING IN THIS DISTRIBUTION, MAY BE REQUIRED
TO DELIVER A PROSPECTUS. THIS IS IN ADDITION TO THE OBLIGATION OF DEALERS TO
DELIVER A PROSPECTUS WHEN ACTING AS UNDERWRITERS AND WITH RESPECT TO THEIR
UNSOLD ALLOTMENTS OR SUBSCRIPTIONS.
i
NOTICE TO INVESTORS
The Exchange Facility Bonds are being offered hereunder in order to satisfy
certain obligations of Oglethorpe contained in the Exchange and Registration
Rights Agreement described herein. Based on interpretations by the staff of the
Commission set forth in no-action letters issued to third parties in other
transactions, Oglethorpe believes that the Exchange Facility Bonds issued
pursuant to the Exchange Offer in exchange for Private Facility Bonds may be
offered for resale, resold and otherwise transferred by any holder thereof
(other than broker-dealers, as set forth below, and any such holder that is an
"affiliate" of Oglethorpe within the meaning of Rule 405 under the Securities
Act) without compliance with the registration and prospectus delivery
requirements of the Securities Act, provided that such Exchange Facility Bonds
are acquired in the ordinary course of such holder's business and that such
holder does not intend to participate, and has no arrangement or understanding
with any person to participate, in the distribution of such Exchange Facility
Bonds. Any holder who tenders in the Exchange Offer with the intention to
participate, or for the purpose of participating, in a distribution of the
Exchange Facility Bonds or who is an affiliate of Oglethorpe may not rely upon
such interpretations by the staff of the Commission and, in the absence of any
exemption therefrom, must comply with the registration and prospectus delivery
requirements of the Securities Act in connection with any secondary resale
transaction. Holders of the Private Facility Bonds wishing to accept the
Exchange Offer must represent to Oglethorpe in the Letter of Transmittal that
such conditions have been met.
Each broker-dealer who holds Private Facility Bonds acquired for its own
account as a result of market making or other trading activities and who
receives Exchange Facility Bonds for its own account pursuant to the Exchange
Offer must acknowledge that it will deliver a prospectus in connection with any
resale of such Exchange Facility Bonds. The Letter of Transmittal states that by
so acknowledging and by delivering a prospectus, a broker-dealer will not be
deemed to admit that it is an "underwriter" within the meaning of the Securities
Act. This Prospectus, as it may be amended or supplemented from time to time,
may be used by a broker-dealer in connection with resales of Exchange Facility
Bonds received in exchange for Private Facility Bonds where such Private
Facility Bonds were acquired by such broker-dealer as a result of market making
activities or other trading activities. Oglethorpe has agreed that, for a period
of up to 90 days after the Expiration Date, it will make this Prospectus
available to any such broker-dealer for use in connection with any such resale.
(See "PLAN OF DISTRIBUTION.") Any broker-dealer who is an affiliate of
Oglethorpe may not rely on such no-action letters and must comply with the
registration and prospectus delivery requirements of the Securities Act in
connection with a secondary resale transaction. Oglethorpe believes that none of
the registered holders of the Private Facility Bonds is an "affiliate" as such
term is defined in Rule 405 under the Securities Act of Oglethorpe.
Neither Oglethorpe nor OPC Scherer 1997 Funding Corporation will receive any
cash proceeds from this Exchange Offer. No dealer-manager is being used in
connection with this Exchange Offer.
The Exchange Facility Bonds will be a new issue of securities for which
there is currently no market. Accordingly, there can be no assurance as to the
liquidity of any markets that may develop for the Exchange Facility Bonds, the
ability of holders to sell the Exchange Facility Bonds, or the price at which
holders would be able to sell the Exchange Facility Bonds. The Exchange Facility
Bonds will not be listed on any securities exchange and will not be quoted on
the National Association of Securities Dealers Automated Quotation System.
Oglethorpe has been advised that Goldman, Sachs & Co. and Morgan Stanley & Co.
Incorporated have heretofore acted as market makers for the Private Facility
Bonds. Each of these market makers has informed Oglethorpe that it currently
intends to make a market in the Exchange Facility Bonds but they are not
obligated to do so, and any such market making may be discontinued at any time
without notice. Future trading prices of the Exchange Facility Bonds will depend
on many factors, including among other things, prevailing interest rates,
Oglethorpe's operating results and the market for similar securities.
ii
Any Private Facility Bonds not tendered or accepted in the Exchange Offer
will remain outstanding and will be entitled to all the same rights and will be
subject to the same limitations applicable thereto under the Collateral Trust
Indenture (except for those rights which terminate upon consummation of the
Exchange Offer). Following the consummation of the Exchange Offer, the holders
of Private Facility Bonds will continue to be subject to all of the existing
restrictions upon transfer thereof and neither Oglethorpe or OPC Scherer 1997
Funding Corporation will have any further obligation to such holders to provide
for registration under the Securities Act of the Private Facility Bonds held by
them.
THIS PROSPECTUS AND THE RELATED LETTER OF TRANSMITTAL CONTAIN IMPORTANT
INFORMATION. HOLDERS OF PRIVATE FACILITY BONDS ARE URGED TO READ THIS PROSPECTUS
AND THE RELATED LETTER OF TRANSMITTAL CAREFULLY BEFORE DECIDING WHETHER TO
TENDER THEIR PRIVATE FACILITY BONDS PURSUANT TO THE EXCHANGE OFFER.
iii
THE MATERIAL SET FORTH IN THE FOLLOWING SUMMARY IS QUALIFIED IN ITS ENTIRETY
BY THE MORE COMPLETE INFORMATION AND FINANCIAL STATEMENTS, INCLUDING THE NOTES
THERETO, APPEARING ELSEWHERE IN THIS PROSPECTUS. CAPITALIZED TERMS USED HEREIN
AND ON THE COVER PAGE AND NOT OTHERWISE DEFINED SHALL HAVE THE SAME MEANINGS
GIVEN SUCH TERMS ELSEWHERE IN THIS PROSPECTUS.
SUMMARY INFORMATION RELATING TO THE EXCHANGE OFFER
Oglethorpe.............. Oglethorpe is an electric membership corporation incorporated in
1974 in the State of Georgia. Oglethorpe is headquartered in
metropolitan Atlanta. Historically, Oglethorpe operated as a
generation and transmission cooperative. On March 11, 1997, in
connection with the Corporate Restructuring described herein,
Oglethorpe sold its transmission and system operations businesses
to recently formed companies. Oglethorpe continues to own and
operate its power supply business. (See "SUMMARY INFORMATION
RELATING TO OGLETHORPE AND THE MEMBERS" and "BUSINESS OF
OGLETHORPE--Corporate Restructuring.")
Registration Rights
Agreement............. The Private Facility Bonds were sold by OPC Scherer 1997 Funding
Corporation on December 17, 1997, and were subsequently resold to
qualified institutional buyers pursuant to Rule 144A under the
Securities Act. In connection with the offering of Private
Facility Bonds, Oglethorpe and OPC Scherer 1997 Funding
Corporation entered into an Exchange and Registration Rights
Agreement (the "Registration Rights Agreement"), which grants
holders of the Private Facility Bonds certain exchange and
registration rights. The Exchange Offer is intended to satisfy
such exchange and registration rights, which will terminate upon
the consummation of the Exchange Offer. (See "THE EXCHANGE
OFFER--Purpose and Effect of the Exchange Offer.")
The Exchange Offer...... Oglethorpe is hereby offering to exchange $1,000 principal amount
of the Exchange Facility Bonds for each $1,000 principal amount
of Private Facility Bonds. As of the date hereof, $224,702,000
aggregate principal amount of Private Facility Bonds are
outstanding.
Based on interpretations by the staff of the Commission set forth
in no-action letters issued to third parties in other
transactions, Oglethorpe believes that the Exchange Facility
Bonds issued pursuant to the Exchange Offer in exchange for
Private Facility Bonds may be offered for resale, resold and
otherwise transferred by any holder thereof (other than
broker-dealers, as set forth below, and any such holder who is an
"affiliate" of Oglethorpe within the meaning of Rule 405 under
the Securities Act) without compliance with the registration and
prospectus delivery provisions of the Securities Act, provided
that such Exchange Facility Bonds are acquired in the ordinary
course of such holder's business and that such holder does not
intend to participate and has no arrangement or understanding
with any person to participate in the distribution of such
Exchange Facility Bonds. Any holder who tenders in the Exchange
Offer with the intention to participate, or for the purpose of
participating, in a distribution of the Exchange Facility Bonds
may not rely on such interpretations by the staff of the
Commission and, in the absence of an exemption therefrom, must
comply with the registration and
1
prospectus delivery requirements of the Securities Act in
connection with any secondary resale transaction. Failure to
comply with such requirements in such instances may result in
such holder incurring liability under the Securities Act. (See
"THE EXCHANGE OFFER--Resale of the Exchange Facility Bonds.")
Each broker-dealer who holds Private Facility Bonds acquired for
its own account as a result of market making or other trading
activities and who receives Exchange Facility Bonds for its own
account pursuant to the Exchange Offer must acknowledge that it
will deliver a prospectus in connection with any resale of such
Exchange Facility Bonds. The Letter of Transmittal states that by
so acknowledging and by delivering a prospectus, a broker-dealer
will not be deemed to admit that it is an "underwriter" within
the meaning of the Securities Act. This Prospectus, as it may be
amended or supplemented from time to time, may be used by a
broker-dealer in connection with resales of Exchange Facility
Bonds received in exchange for Private Facility Bonds where such
Private Facility Bonds were acquired by such broker-dealer as a
result of market making activities or other trading activities.
Oglethorpe has agreed that for a period of up to 90 days after
the Expiration Date, it will make this Prospectus available to
any such broker-dealer for use in connection with any such
resale. (See "PLAN OF DISTRIBUTION.")
Expiration Date......... 5:00 p.m., New York City time, on , 1998, unless the
Exchange Offer is extended by Oglethorpe, in which case the term
"Expiration Date" means the latest date and time to which the
Exchange Offer is extended. (See "THE EXCHANGE OFFER--Expiration
Date; Extensions; Amendments.")
Interest on the Exchange
Facility Bonds........ The Exchange Facility Bonds will bear interest from the later of
the date of issuance of the Private Facility Bonds that are
tendered in exchange for the Exchange Facility Bonds and the most
recent interest payment date to which interest on such Private
Facility Bonds has been paid. (See "THE EXCHANGE OFFER--Interest
on the Exchange Facility Bonds and the Private Facility Bonds.")
Conditions to the
Exchange Offer........ The Exchange Offer is subject to certain customary conditions,
which may be waived by Oglethorpe. (See "THE EXCHANGE
OFFER--Conditions.")
Procedures for Tendering
Private Facility
Bonds................. Each holder of the Private Facility Bonds wishing to accept the
Exchange Offer must (i) complete, sign and date the Letter of
Transmittal, or a facsimile thereof, in accordance with the
instructions contained herein and therein, and mail or otherwise
deliver such Letter of Transmittal, or such facsimile, together
with any other required documentation to the Exchange Agent
described herein and (ii) deliver their Private Facility Bonds to
OPC Scherer 1997 Funding Corporation by book-entry transfer. (See
"THE EXCHANGE OFFER--Procedures for Tendering.")
By executing the Letter of Transmittal, each holder will
represent to Oglethorpe that, among other things, the person
receiving such Exchange Facility Bonds, whether or not such
person is the holder, is
2
acquiring the Exchange Facility Bonds in the ordinary course of
business and that neither the holder nor any such other person
has any arrangement or understanding with any person to
participate in the distribution of such Exchange Facility Bonds.
(See "THE EXCHANGE OFFER--Resale of Exchange Facility Bonds.")
Special Procedures for
Beneficial Owners..... Any beneficial owner whose Private Facility Bonds are registered
in the name of a broker, dealer, commercial bank, trust company
or other nominee and who wishes to tender should contact the
registered holder promptly and instruct such registered holder to
tender on such beneficial owner's behalf. (See "THE EXCHANGE
OFFER--Procedures for Tendering.")
Guaranteed Delivery
Procedures............ Holders of Private Facility Bonds who wish to tender their
Private Facility Bonds and who cannot deliver the Letter of
Transmittal or any other documents required by the Letter of
Transmittal to the Exchange Agent or comply with the procedures
for book-entry transfer prior to the Expiration Date must tender
their Private Facility Bonds according to the guaranteed delivery
procedures set forth in "THE EXCHANGE OFFER--Guaranteed Delivery
Procedures."
Withdrawal Rights....... Tenders of Private Facility Bonds may be withdrawn at any time
prior to 5:00 p.m., New York City time, on the Expiration Date
pursuant to the procedures described under "THE EXCHANGE
OFFER--Withdrawals of Tenders."
Acceptance of Private
Facility Bonds and
Delivery of Exchange
Facility Bonds........ OPC Scherer 1997 Funding Corporation will accept for exchange any
and all Private Facility Bonds that are properly tendered in the
Exchange Offer prior to 5:00 p.m., New York City time, on the
Expiration Date. The Exchange Facility Bonds issued pursuant to
the Exchange Offer will be delivered promptly following the
Expiration Date.
Absence of Cash
Proceeds.............. Neither Oglethorpe nor OPC Scherer 1997 Funding Corporation will
receive any cash proceeds from the issuance of the Exchange
Facility Bonds. (See "ABSENCE OF CASH PROCEEDS.")
Federal Income Tax
Consequences of the
Exchange Offer........ The issuance of the Exchange Facility Bonds to holders of the
Private Facility Bonds who are U.S. Holders described herein
pursuant to the terms set forth in this Prospectus should not
constitute a taxable event to U.S. Holders for federal income tax
purposes. Consequently, no gain or loss should be recognized by
U.S. Holders of the Private Facility Bonds upon receipt of the
Exchange Facility Bonds. (See "CERTAIN UNITED STATES FEDERAL
INCOME TAX CONSEQUENCES.")
Effect on Holders of the
Private Facility
Bonds................. As a result of completing the Exchange Offer, Oglethorpe will
have fulfilled
3
certain of its obligations under the Registration Rights
Agreement. Any Private Facility Bonds not tendered or accepted in
the Exchange Offer will remain outstanding and will be entitled
to all the same rights and will be subject to the same
limitations applicable thereto under the Collateral Trust
Indenture (except for those rights which terminate upon
consummation of the Exchange Offer). Following the consummation
of the Exchange Offer, the holders of Private Facility Bonds will
continue to be subject to all of the existing restrictions upon
transfer thereof and neither Oglethorpe or OPC Scherer 1997
Funding Corporation will have any further obligation to such
holders to provide for registration under the Securities Act of
the Private Facility Bonds held by them. Because Oglethorpe
anticipates that most holders of Private Facility Bonds will
elect to exchange such Private Facility Bonds for Exchange
Facility Bonds due to the absence of restrictions on the resale
of Exchange Facility Bonds under the Securities Act, Oglethorpe
anticipates that the liquidity of the market for any Private
Facility Bonds remaining after the consummation of the Exchange
Offer may be substantially limited. (See "THE EXCHANGE
OFFER--Consequences of Failure to Exchange.")
Exchange Agent.......... (the "Exchange Agent").
SUMMARY INFORMATION RELATING TO THE FACILITY BONDS
Securities Offered...... $224,702,000 aggregate principal amount of 6.974% Serial Facility
Bonds Due June 30, 2011. The form and terms of the Exchange
Facility Bonds are identical in all material respects to the form
and terms of the Private Facility Bonds except that the Exchange
Facility Bonds will not contain certain restrictions on transfer
or registration rights contained in the Private Facility Bonds,
and the Exchange Facility Bonds will not contain any provision
for additional interest in the event of certain defaults in
obligations of Oglethorpe related to the Exchange Offer. The
Exchange Facility Bonds will evidence the same indebtedness as
the Private Facility Bonds and will be entitled to the benefits
of the Collateral Trust Indenture. (See "THE EXCHANGE
OFFER--Terms of the Exchange Offer.")
Maturity Date........... June 30, 2011
Interest Payment
Dates................. June 30 and December 31 (commencing June 30, 1998).
Sinking Fund............ The Facility Bonds will be subject to pro-rata sinking fund
redemption commencing December 31,1998. (See "DESCRIPTION OF THE
FACILITY BONDS--Sinking Fund Redemption.")
Optional Redemption..... The Facility Bonds will not be subject to optional redemption
prior to maturity. (See "DESCRIPTION OF THE FACILITY
BONDS--Optional Redemption.")
Special Mandatory
Redemption............ In certain instances, the Facility Bonds will be subject to
special mandatory redemption at 100% of their principal amount,
together with interest accrued to the redemption date. In certain
other instances, the Facility Bonds will be subject to special
mandatory redemption at redemption prices declining from an
initial price of 106.974% of par to
4
100% of par at maturity, together with interest accrued to the
redemption date. (See "DESCRIPTION OF THE FACILITY BONDS--Special
Mandatory Redemption at Par" and "--Special Mandatory Redemption
with Premium.")
Settlement, Book-Entry-
Only, Form and
Denomination.......... Delivery of the Facility Bonds will be made in book-entry-only
form as described below. The Facility Bonds will be issued only
in registered form in denominations of $1,000 principal amount
and integral multiples thereof. Exchange Facility Bonds issued in
exchange for Private Facility Bonds currently evidenced by one or
more fully registered global certificates will be evidenced by
one or more certificates in global form, which will be deposited
with a custodian for, and registered in the name of, a nominee of
The Depository Trust Company ("DTC"). Except as described herein,
beneficial interests in such global certificates will be shown
on, and transfers thereof will be effected only through, records
maintained by DTC and its direct and indirect participants. Such
interests will trade in DTC's Same-Day Funds Settlement System,
and secondary market trading activity in such interests will
therefore settle in immediately available funds, subject in all
cases to the rules and procedures of DTC and its participants.
(See "DESCRIPTION OF THE FACILITY BONDS-- Book-Entry-Only
System."
Security and Source of
Payments.............. The Facility Bonds will be secured by a nonrecourse Refunding
Lessor Note of each of the Lessors, issued to OPC Scherer 1997
Funding Corporation and pledged and assigned to the Collateral
Trust Trustee. The payments due on the Refunding Lessor Notes
pledged to the Collateral Trust Trustee will equal all payments
due on the Facility Bonds. To the extent that additional Lessor
Notes described herein are issued, such Lessor Notes will be
secured on a parity basis with the applicable Refunding Lessor
Note under the applicable Lease Indenture. All Lessor Notes,
including the Refunding Lessor Notes, will be secured by, among
other things, a lien on and security interest in the respective
undivided ownership interest of each such Lessor in Scherer Unit
No. 2 and the rights of each such Lessor under its Lease with
Oglethorpe, including the right to receive the basic rentals and
certain other amounts payable by Oglethorpe to the Lessor
thereunder. The holders of the Facility Bonds will have no
recourse against the general credit of the Lessors or the Equity
Investors described herein. Accordingly, the Facility Bonds will
constitute, in effect, a nonrecourse borrowing by and on behalf
of the Lessors, secured by the interest in Scherer Unit No. 2 of
each Lessor and Oglethorpe's obligations to each such Lessor
under its Lease with Oglethorpe.
The Refunding Lessor Notes are senior to the interests of the
Equity Investors in respect of payments made under the Leases
(other than Excepted Payments as defined therein).
Oglethorpe is unconditionally obligated to make payments under
the Leases in amounts that will be at least sufficient to provide
for the payment of principal of and premium, if any, and interest
on the Refunding Lessor
5
Notes, which amounts, in turn, will be sufficient to pay the
principal of and premium, if any, and interest on the Facility
Bonds when due, whether at maturity, upon redemption or
otherwise. (See "DESCRIPTION OF THE FACILITY BONDS--Sinking Fund
Redemption," "--Special Mandatory Redemption at Par" and
"--Special Mandatory Redemption with Premium" and "DESCRIPTION OF
THE LEASES--Term and Rentals.") However, the Facility Bonds will
not be, and the Refunding Lessor Notes are not, direct
obligations of or guaranteed by Oglethorpe, and they will not be
secured by the lien on Oglethorpe's assets created under the
Mortgage Indenture described herein. (See "SECURITY AND SOURCE OF
PAYMENT FOR THE FACILITY BONDS.") For information with respect to
certain factors which may affect the obligations of Oglethorpe
described above, see "DESCRIPTION OF THE FACILITY BONDS--
Considerations Relating to Security."
Scherer Unit No. 2...... Scherer Unit No. 2 is an 818 MW coal-fired, steam electric
generating unit located in Monroe County near Forsyth, Georgia.
It was placed in commercial operation in February 1984. Scherer
Unit No. 2 is one of four units in operation located at the
Robert W. Scherer Plant which are of similar size and design. On
December 30, 1985, Oglethorpe sold undivided ownership interests
to the Lessors aggregating its entire 60% undivided ownership
interest in Scherer Unit No. 2 as part of the Sale and Leaseback
Transactions. Scherer Unit No. 2 is owned by Georgia Power
Company (8.4%), Municipal Electric Authority of Georgia (30.2%),
the City of Dalton, Georgia (1.4%) and the Lessors (60%). The
Lessors are leasing their respective interests back to Oglethorpe
pursuant to the Leases. (See "INTRODUCTION--Sale and Leaseback
Transactions" and "MEMBER REQUIREMENTS AND POWER SUPPLY
RESOURCES--Generating Facilities" and "CO-OWNERS OF THE PLANTS
AND THE PLANT AGREEMENTS--The Plant Agreements.")
OPC Scherer 1997 Funding
Corporation........... OPC Scherer 1997 Funding Corporation is a special purpose
corporation incorporated in Delaware for the purpose of
facilitating the refinancing of the respective undivided
ownership interests of the Lessors in Scherer Unit No. 2. The
only business of OPC Scherer 1997 Funding Corporation is the
issuance and sale of the Private Facility Bonds, application of
the proceeds thereof, the issuance of the Exchange Facility Bonds
and the completion of the Exchange Offer, and, possibly, the
issuance of other indebtedness, the proceeds of which would be
used to make loans to the Lessors to finance, among other things,
additions or improvements to Scherer Unit No. 2. The assets of
OPC Scherer 1997 Funding Corporation consist primarily of the
Refunding Lessor Notes issued with respect to the Facility Bonds
and, if additional loans are made to the Lessors by OPC Scherer
1997 Funding Corporation, additional Lessor Notes. The Refunding
Lessor Notes are, and such other Lessor Notes, if any, will be,
payable from basic rental and certain other payments made by
Oglethorpe to the Lessors under the Leases. OPC Scherer 1997
Funding Corporation is to function only as an agent of the
Lessors (and not as principal) with respect to the Facility Bonds
and to represent itself only as an agent of the Lessors (and not
as principal) in dealings with third parties relating to the
Facility Bonds. Neither Oglethorpe nor any Lessor or Equity
6
Investor holds any ownership interest in OPC Scherer 1997 Funding
Corporation, and no person affiliated with Oglethorpe, any Lessor
or Equity Investor is an officer, director or employee of OPC
Scherer 1997 Funding Corporation. (See "OPC SCHERER 1997 FUNDING
CORPORATION.")
Reporting Obligations... Oglethorpe is not subject to the reporting requirements of the
Securities Exchange Act of 1934, as amended. Oglethorpe, however,
has been filing periodic reports with the Commission since 1987
and intends to continue filing such reports, to the extent
permitted by the Commission, for so long as any of the Facility
Bonds are outstanding regardless of whether it is required to do
so. Oglethorpe is required to file with the Collateral Trust
Trustee copies of all periodic reports filed with the Commission
and will provide the Collateral Trust Trustee with copies of its
annual report containing audited financial statements.
Market for Exchange
Facility Bonds........ The Exchange Facility Bonds will not be listed on any securities
exchange and will not be quoted on the National Association of
Securities Dealers Automated Quotation System. As a result, there
can be no assurance that there will be a secondary market for the
Exchange Facility Bonds. Oglethorpe has been advised that
Goldman, Sachs & Co. and Morgan Stanley & Co. Incorporated, the
initial purchasers of the Private Facility Bonds, have heretofore
acted as market makers for the Private Facility Bonds. Each of
these market makers has informed Oglethorpe that it currently
intends to make a market in the Exchange Facility Bonds, but they
are not obligated to do so, and any such market making may be
discontinued at any time without notice. Accordingly, there can
be no assurance as to the development or liquidity of any market
for the Exchange Facility Bonds.
7
SUMMARY INFORMATION RELATING TO OGLETHORPE AND THE MEMBERS
Oglethorpe and the
Members............... Oglethorpe is an electric membership corporation engaged
primarily in the business of providing wholesale electric power
to its 39 retail electric distribution cooperative members (the
"Members"), which provide retail electric service to their
customers in the State of Georgia.
As with electric cooperatives generally, Oglethorpe and the
Members operate on a not-for-profit basis and design their rates
to recover their respective costs-of-service and to generate
margins sufficient to establish reasonable reserves and meet
financial coverage requirements.
Oglethorpe's principal executive offices are located at 2100 East
Exchange Place, Tucker, Georgia 30085-1349, and its telephone
number is (770) 270-7600.
(See "INTRODUCTION," "BUSINESS OF OGLETHORPE" and "THE MEMBERS OF
OGLETHORPE.")
Corporate
Restructuring......... Oglethorpe and the Members completed a corporate restructuring
(the "Corporate Restructuring") on March 11, 1997, in which
Oglethorpe was divided into three specialized operating companies
to respond to increasing competition and regulatory changes in
the electric industry. As part of the Corporate Restructuring,
Oglethorpe's transmission business was sold to, and is now owned
and operated by, Georgia Transmission Corporation (An Electric
Membership Corporation) ("GTC"), a recently formed Georgia
electric membership corporation. Oglethorpe's system operations
business was sold to, and is now owned and operated by, Georgia
System Operations Corporation ("GSOC"), a recently formed Georgia
nonprofit corporation. Oglethorpe continues to own and operate
its power supply business. Oglethorpe and the 39 Members are
members of GTC and GSOC. (See "BUSINESS OF OGLETHORPE--Corporate
Restructuring," "--Relationship with GTC" and "--Relationship
with GSOC.")
Consumers and
Service Area.......... Oglethorpe is the largest electric cooperative in the United
States in terms of operating revenues, assets, kilowatt-hour
sales and, through the Members, consumers served. The Members
serve approximately 1.2 million electric consumers (meters)
representing approximately 2.6 million people. The Members serve
a region covering approximately 40,000 square miles, which is
approximately 70% of the land area in the State of Georgia,
encompassing 150 of the State's 159 counties.
Sales by the Members in 1996 amounted to approximately 19.6
million megawatt-hours, with 72% to residential consumers, 26% to
commercial and industrial consumers and 2% to other consumers.
Pursuant to the Georgia Territorial Electric Service Act, which
was enacted in 1973 (the "Territorial Act"), the Georgia Public
Service Commission assigned substantially all areas in the State
of Georgia to specific retail suppliers. With limited exceptions,
the Members have the exclusive right to provide retail electric
service in their respective assigned territories,
8
which are predominantly outside of municipal limits. The chief
exception to this exclusivity is that electric suppliers may
compete for most new retail loads of 900 kilowatts or greater.
The Georgia Public Service Commission may not reassign territory
or transfer service except in limited circumstances provided by
the Territorial Act.
(See "THE MEMBERS OF OGLETHORPE--Service Area and Competition.")
Power Supply Business... Oglethorpe provides wholesale electric service to the Members
pursuant to long-term Wholesale Power Contracts described herein.
Oglethorpe supplies capacity and energy to the Members from a
combination of owned and leased generating plants and power
purchased under long-term contracts with power marketers and
other power suppliers.
GENERATION. Oglethorpe owns or leases undivided interests in
thirteen generating units currently in commercial operation.
These units provide Oglethorpe with a total of 3,335 MW of
nameplate capacity, consisting of 1,500.6 MW of coal-fired
capacity, 1,185 MW of nuclear-fueled capacity, 632.5 MW of pumped
storage hydroelectric capacity, 14.8 MW of oil-fired combustion
turbine capacity and 2.1 MW of conventional hydroelectric
capacity. (See "BUSINESS OF OGLETHORPE--Power Supply Business,"
"MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--General" and
"--Generating Facilities.")
POWER MARKETER ARRANGEMENTS. Oglethorpe utilizes long-term power
marketer arrangements to reduce the cost of power to the Members.
Oglethorpe has entered into power marketer agreements with LG&E
Energy Marketing Inc. ("LEM") effective January 1, 1997 for
approximately 50% of the load requirements of the Members and
with Morgan Stanley Capital Group Inc. ("Morgan Stanley")
effective May 1, 1997, with respect to 50% of the forecasted load
requirements of the Members. The LEM agreements are based on the
actual requirements of the Members during the contract term,
whereas the Morgan Stanley agreement represents a fixed supply
obligation.
Under these power marketer agreements, Oglethorpe purchases
energy at fixed prices covering a portion of the costs of energy
to its Members. LEM and Morgan Stanley, in turn, have certain
rights to market excess energy from the Oglethorpe system. All of
Oglethorpe's existing generating facilities and power purchase
arrangements are available for use by LEM and Morgan Stanley for
the term of the respective agreements. Oglethorpe continues to be
responsible for all the costs of its system resources but
receives revenue from LEM and Morgan Stanley for the use of the
resources.
(See "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES-- General"
and "--Power Marketer Arrangements.")
PURCHASED POWER. Oglethorpe purchases a total of approximately
1,250 MW of power pursuant to power purchase agreements with
Georgia Power Company, Big Rivers Electric Corporation, Entergy
Power, Inc. and Hartwell Energy Limited Partnership. Oglethorpe
has also contracted to purchase 275 MW of peaking capacity from
Florida Power Corporation
9
during the summer of 1998. (See "MEMBER REQUIREMENTS AND POWER
SUPPLY RESOURCES--Power Purchase and Sale Arrangements.")
TRANSMISSION. In connection with the Corporate Restructuring,
Oglethorpe sold its transmission business and assets to GTC. GTC
now provides transmission services to the Members for delivery of
the Members' power purchases from Oglethorpe, Southeastern Power
Administration and any other power suppliers. Oglethorpe has
entered into a transmission agreement with GTC for GTC to provide
transmission services for third party transactions and for
service to Oglethorpe's facilities.
GTC owns approximately 2,300 miles of transmission line and 450
substations of various voltages. GTC succeeded to Oglethorpe's
rights in the Integrated Transmission System, which consists of
transmission facilities owned by GTC, Georgia Power Company,
Municipal Electric Authority of Georgia and the City of Dalton,
Georgia. Common access to the Integrated Transmission System
enables its owners to use their combined resources to make
deliveries to or for their respective consumers, to provide
transmission service to third parties and to make off-system
purchases and sales.
(See "BUSINESS OF OGLETHORPE--Relationship with GTC.")
Wholesale Power
Contracts............. Oglethorpe and each of the Members have entered into
substantially similar Wholesale Power Contracts, each of which
extends through December 31, 2025. Under its Wholesale Power
Contract, a Member is unconditionally obligated on an express
"take-or-pay" basis for a fixed allocation of Oglethorpe's costs
for its existing generation and purchased power resources, as
well as the costs with respect to any future resources in which
such Member elects to participate. Each Wholesale Power Contract
permits a Member to take future incremental power requirements
either from Oglethorpe or other sources.
Each Member's cost responsibility under its Wholesale Power
Contract is based on agreed-upon fixed percentage capacity
responsibilities ("PCRs"). PCRs have been assigned for all of
Oglethorpe's existing generation and purchased power resources.
PCRs for any future resource will be assigned only to Members
choosing to participate in that resource. The Wholesale Power
Contracts provide that each Member is jointly and severally
responsible for all costs and expenses of all existing generation
and purchased power resources, as well as for any future
resources that are approved by 75% of Oglethorpe's Board of
Directors and 75% of the Members. For resources so approved in
which less than all Members participate, costs are shared first
among the participating Members, and if all participating Members
default, each non-participating Member is expressly obligated to
pay a proportionate share of such default.
(See "BUSINESS OF OGLETHORPE--Wholesale Power Contracts" and
"MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES-- Power Marketer
Arrangements.")
10
Rate Regulation
and Rates............. MORTGAGE INDENTURE RATE COVENANT. The Mortgage Indenture requires
Oglethorpe, subject to any necessary regulatory approval, to
establish and collect rates which, together with other revenues
of Oglethorpe, are reasonably expected to yield an MFI Ratio
described herein for each fiscal year equal to at least 1.10. MFI
Ratio is determined by dividing the sum of (i) net margins of
Oglethorpe (after certain defined adjustments), (ii) interest
charges, whether capitalized or expensed, on all indebtedness
secured under the Mortgage Indenture or by a lien equal or prior
to the lien of the Mortgage Indenture, including amortization of
debt discount and expense or premium but excluding interest
charges on indebtedness assumed by GTC ("Interest Charges"), and
(iii) any amount included in net margins for accruals for federal
or state income taxes by Interest Charges. (See "BUSINESS OF
OGLETHORPE--Electric Rates" and "MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS--General--RATES AND FINANCIAL COVERAGE REQUIREMENTS.")
FORMULARY RATE AND PRIOR PERIOD ADJUSTMENT MECHANISM. The
formulary rate established by Oglethorpe in the rate schedule to
the Wholesale Power Contracts employs a rate methodology under
which all categories of costs are specifically separated as
components of the formula to determine Oglethorpe's revenue
requirements. The rate schedule also implements the
responsibility for fixed costs assigned to each Member (I.E., the
PCR).
The rate schedule formula also includes a prior period adjustment
("PPA") mechanism designed to ensure that Oglethorpe achieves the
minimum 1.10 MFI Ratio. The PPA provides for the retention of
margins within a range from a 1.10 MFI Ratio to a 1.20 MFI Ratio.
Amounts, if any, by which Oglethorpe fails to achieve a 1.10 MFI
Ratio would be accrued as of December 31 of the applicable year
and collected from the Members during the period April through
December of the following year. Amounts, if any, by which
Oglethorpe exceeds the maximum 1.20 MFI Ratio would be charged
against revenues as of December 31 of the applicable year and
refunded to the Members during the period April through December
of the following year.
(See "BUSINESS OF OGLETHORPE--Electric Rates" and "MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS--General--RATES AND FINANCIAL COVERAGE REQUIREMENTS.")
RATE REGULATION OF OGLETHORPE. Under the Mortgage Indenture and
related loan contract with the Rural Utilities Service ("RUS"),
adjustments to Oglethorpe's rates to reflect changes in
Oglethorpe's budgets are not subject to RUS approval, except in
limited circumstances. Changes to the rate schedule under the
Wholesale Power Contracts are subject to RUS approval.
Oglethorpe's rates are not subject to the approval of any other
federal or state agency or authority, including the Georgia
Public Service Commission.
11
RATE REGULATION OF MEMBERS. Through provisions in its loan
documents, RUS exercises control and supervision over the rates
for the sale of power of the 34 Members that borrow from it. The
RUS mortgages of such Members require them to design rates with a
view to maintaining an average Times Interest Earned Ratio of not
less than 1.50 and an average Debt Service Coverage Ratio of not
less than 1.25 for the two highest out of every three successive
years.
Five Members have prepaid their RUS indebtedness and are no
longer RUS borrowers. Each of these Members now has a rate
covenant with its current lender.
Although the setting of the retail rates of the Members is not
subject to approval by any federal or state agency or authority
other than, where applicable, RUS, the Territorial Act prohibits
the Members from unreasonable discrimination in the setting of
rates.
(See "THE MEMBERS OF OGLETHORPE--Rate Regulation of Members.")
Competition............. The electric utility industry in the United States is undergoing
fundamental change and is becoming increasingly competitive. (See
"MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS--Competition.")
12
SUMMARY FINANCIAL DATA
The following table presents summary historical and pro forma financial data
of Oglethorpe. The summary historical financial data presented as of the end of
and for each year in the three-year period ended December 31, 1996, have been
derived from the audited financial statements of Oglethorpe included in this
Prospectus. The historical financial statements of Oglethorpe as of and for the
fiscal years ended December 31, 1996, and December 31, 1995, have been audited
by Coopers & Lybrand L.L.P., independent public accountants. The historical
financial statements of Oglethorpe as of and for the fiscal year ended December
31, 1994, have been audited by Arthur Andersen LLP, independent public
accountants. The summary historical financial data presented in the following
table as of and for the twelve-month period ended September 30, 1997, are
derived from the unaudited financial statements of Oglethorpe also contained in
this Prospectus which, in the opinion of Oglethorpe's management, include all
adjustments (constituting only normal recurring adjustments) necessary for a
fair presentation of the unaudited financial information. Due to the Corporate
Restructuring, the historical results of operations and financial condition
reflect operations as a combined power supply, transmission and system
operations company through March 31, 1997 and operations solely as a power
supply company thereafter. The results of operations for the twelve months ended
September 30, 1997 are not necessarily indicative of the results of operations
for a fiscal year. The summary pro forma statement of operations data for the
twelve months ended September 30, 1997, and the year ended December 31, 1996,
give effect to the Corporate Restructuring as if it had occurred at October 1,
1996, and January 1, 1996, respectively. The summary pro forma financial data
are provided for informational purposes only and are not necessarily indicative
of Oglethorpe's results of operations had the Corporate Restructuring actually
occurred as of such date and are not intended to project Oglethorpe's results of
operations for any future period. These data should be read in conjunction with
the financial statements of Oglethorpe and the notes thereto included in this
Prospectus, "BUSINESS OF OGLETHORPE--Corporate Restructuring," "UNAUDITED PRO
FORMA CONDENSED FINANCIAL DATA" and "MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS."
PRO FORMA HISTORICAL
------------------------------- ---------------------------------------------------
TWELVE MONTHS YEAR TWELVE MONTHS
ENDED ENDED ENDED YEAR ENDED DECEMBER 31,
SEPTEMBER 30, DECEMBER 31, SEPTEMBER 30, ----------------------------------
1997 1996 1997 1996 1995 1994
--------------- -------------- --------------- ---------- ---------- ----------
(DOLLARS IN THOUSANDS)
STATEMENT OF OPERATIONS DATA:
Operating revenues........... $ 1,009,245 $ 995,710 $ 1,069,813 $1,101,437 $1,149,561 $1,056,082
Operating expenses........... 776,648 758,834 812,162 818,688 840,884 768,675
Operating margin............. 232,597 236,876 257,651 282,749 308,677 287,407
Net margin................... 8,023 18,414 9,600 21,752 22,258 23,082
DECEMBER 31,
SEPTEMBER 30, ----------------------------------
1997 1996 1995 1994
-------------- ---------- ---------- ----------
(DOLLARS IN THOUSANDS)
BALANCE SHEET DATA:
Electric plant, net...................................... $3,624,291 $4,376,381 $4,471,762 $4,519,228
Total assets............................................. 4,527,280 5,362,175 5,438,496 5,346,330
Long-term debt, excluding amounts due within one year.... 3,171,511 4,052,470 4,207,320 4,128,080
Obligation under capital leases, long-term............... 289,825 293,682 296,478 303,749
Other obligations........................................ 51,325 41,685 -- --
Patronage capital and membership fees(1)................. 321,771 356,229 338,891 309,496
- ------------------------
(1) Patronage capital currently constitutes all of Oglethorpe's equity. See Note
1 to the Financial Statements included in this Prospectus.
13
SELECTED DEFINITIONS
When used herein the following terms will have the meanings indicated below:
TERM MEANING
- -------------------- ----------------------------------------------------------------------
ADSCR............... Annual Debt Service Coverage Ratio
AFUDC............... Allowance For Funds Used During Construction
BPSA................ Block Power Sale Agreement
CFC................. National Rural Utilities Cooperative Finance Corporation
DSC................. Debt Service Coverage Ratio
EMCs................ Electric Membership Cooperatives
EPI................. Entergy Power, Inc.
FERC................ Federal Energy Regulatory Commission
FFB................. Federal Financing Bank
GPC................. Georgia Power Company
GPSC................ Georgia Public Service Commission
GSOC................ Georgia System Operations Corporation
GTC................. Georgia Transmission Corporation (An Electric Membership Corporation)
ITS................. Integrated Transmission System
ITSA................ Revised and Restated Integrated Transmission System Agreement
kWh................. Kilowatt-hours
LEM................. LG&E Energy Marketing Inc.
Members............. The 39 retail distribution cooperatives that are members of Oglethorpe
MEAG................ Municipal Electric Authority of Georgia
MFI................. Margins for Interest
MW.................. Megawatts
MWh................. Megawatt-hours
NRC................. Nuclear Regulatory Commission
PCBs................ Pollution Control Revenue Bonds
PCR................. Percentage Capacity Responsibility
PPA................. Prior Period Adjustment
PURPA............... Public Utility Regulatory Policies Act
RUS................. Rural Utilities Service
SEPA................ Southeastern Power Administration
SONOPCO............. Southern Nuclear Operating Company
TIA................. Trust Indenture Act of 1939, as amended
TIER................ Times Interest Earned Ratio
TVA................. Tennessee Valley Authority
14
INTRODUCTION
OGLETHORPE POWER CORPORATION
Oglethorpe Power Corporation (An Electric Membership Corporation)
("Oglethorpe") is a Georgia electric membership corporation incorporated in 1974
and headquartered in metropolitan Atlanta. Oglethorpe is owned by its 39 retail
electric distribution cooperative members (the "Members"), which, in turn, are
owned by their retail consumers. Oglethorpe is the largest electric cooperative
in the United States in terms of operating revenues, assets, kilowatt-hour
("kWh") sales and, through the Members, consumers served. (See "BUSINESS OF
OGLETHORPE.")
As discussed below, the Facility Bonds described herein will be payable from
and secured by basic rentals and certain other amounts to be paid by Oglethorpe
to the Lessors under several leases relating to Plant Robert W. Scherer Unit No.
2 ("Scherer Unit No. 2").
SCHERER UNIT NO. 2
Scherer Unit No. 2 is an 818 megawatt ("MW") coal-fired, steam electric
generating unit located in Monroe County near Forsyth, Georgia. It was placed in
commercial operation in February 1984. Scherer Unit No. 2 is one of four units
in operation located at the Robert W. Scherer Plant ("Plant Scherer") which are
of similar size and design. On December 30, 1985, Oglethorpe sold its entire 60%
undivided ownership interest in Scherer Unit No. 2 as part of the Sale and
Leaseback Transactions described herein. The purchasers are leasing their
respective interests back to Oglethorpe. The remaining 40% interest in Scherer
Unit No. 2 is owned by Georgia Power Company ("GPC") (8.4%), Municipal Electric
Authority of Georgia ("MEAG") (30.2%) and the City of Dalton, Georgia ("Dalton")
(1.4%).
SALE AND LEASEBACK TRANSACTIONS
On December 30, 1985, in four separate transactions (the "Sale and Leaseback
Transactions"), Oglethorpe sold its entire 60% undivided ownership interest in
Scherer Unit No. 2 to four separate owner trusts (the "Lessors") established by
four different institutional investors (the "Equity Investors"). Each Lessor
holds its respective undivided ownership interest in Scherer Unit No. 2 for the
benefit of its respective Equity Investor. Each Lessor has leased its respective
undivided ownership interest back to Oglethorpe on a long-term net lease basis
under a separate lease. Wilmington Trust Company and NationsBank, N.A., as
successor by merger to The Citizens and Southern National Bank, acting through
its agent, The Bank of New York, currently serve as co-owner trustees for each
of the four Lessors.
Oglethorpe received total proceeds of $395,000,000 from the Lessors for the
undivided ownership interests in Scherer Unit No. 2 sold pursuant to the Sale
and Leaseback Transactions. Such proceeds were used by Oglethorpe primarily to
repay financing for Scherer Unit No. 2 provided by the Federal Financing Bank
(the "FFB"). Of the total consideration, the Lessors severally borrowed an
aggregate of $275,446,000 on a nonrecourse basis from CoBank, ACB ("CoBank"),
formerly known as Columbia Bank for Cooperatives, which borrowings were
evidenced by four promissory notes (the "CoBank Lessor Notes"), each issued
under a separate trust indenture. The Lessors financed the remaining aggregate
of $119,554,000 of the purchase price for Oglethorpe's undivided ownership
interest in Scherer Unit No. 2 with funds contributed as equity by the Equity
Investors.
On October 20, 1986, three of the Lessors repaid their respective CoBank
Lessor Notes issued in the Sale and Leaseback Transactions with the proceeds of
a loan from OPC Scherer Funding Corporation to each such Lessor following a
public offering of debt obligations of OPC Scherer Funding Corporation. The
loans to such Lessors by OPC Scherer Funding Corporation were nonrecourse to the
Lessors and were evidenced by promissory notes (the "1986 Lessor Notes") issued
under three of the trust indentures. Approximately $9,858,500 of the proceeds of
the 1986 Lessor Notes was paid to the Equity Investors as a partial repayment of
their equity investments.
15
On December 17, 1997, OPC Scherer 1997 Funding Corporation A ("OPC Scherer
1997 Funding Corporation") issued $224,702,000 aggregate principal amount of
Serial Facility Bonds Due June 30, 2011 (the "Private Facility Bonds"). OPC
Scherer 1997 Funding Corporation loaned the proceeds of the offering of the
Private Facility Bonds to the Lessors, who used such funds and certain other
funds provided by Oglethorpe to prepay in full the CoBank Lessor Note and the
three 1986 Lessor Notes. OPC Scherer Funding Corporation applied the payments on
the 1986 Lessor Notes to redeem the outstanding public debt issued in 1986.
ABSENCE OF CASH PROCEEDS
This offering (the "Exchange Offer") of Serial Facility Bonds Due June 30,
2011 (the "Exchange Facility Bonds") is intended to satisfy certain obligations
of Oglethorpe under an Exchange and Registration Rights Agreement (the
"Registration Rights Agreement"), which grants holders of Private Facility Bonds
certain exchange and registration rights. Neither Oglethorpe nor OPC Scherer
1997 Funding Corporation will receive any cash proceeds from the issuance of the
Exchange Facility Bonds offered hereby. The Lessors have agreed to pay the
expenses of the Exchange Offer. The Private Facility Bonds surrendered in
exchange for the Exchange Facility Bonds will be retired and canceled and cannot
be reissued. The Exchange Facility Bonds and any Private Facility Bonds not
exchanged in the Exchange Offer are sometimes referred to herein collectively as
the "Facility Bonds."
SECURITY AND SOURCE OF PAYMENT FOR THE FACILITY BONDS
The Facility Bonds will be issued under a Collateral Trust Indenture, dated
as of December 1, 1997 (the "Collateral Trust Indenture"), among OPC Scherer
1997 Funding Corporation, Oglethorpe and SunTrust Bank, Atlanta, as indenture
trustee (in such capacity, the "Collateral Trust Trustee"). Pursuant to the
Collateral Trust Indenture, the Facility Bonds will be payable from, and secured
by a pledge and assignment of, a nonrecourse note issued by each Lessor
(collectively, the "Refunding Lessor Notes") under a separate Amended and
Restated Indenture of Trust, Deed to Secure Debt and Security Agreement, each
dated as of December 1, 1997 (the "Lease Indentures"), between the respective
Lessor and the respective trustee of each Lease Indenture (the "Lease Indenture
Trustees"). The Refunding Lessor Notes issued by the Lessors will equal in the
aggregate the principal amount of the Facility Bonds and have been pledged to
the Collateral Trust Trustee.
As described below, the source of payments on the Refunding Lessor Notes is
amounts payable by Oglethorpe under four separate leases amended in connection
with the offering of the Private Facility Bonds pursuant to which each Lessor
leases its respective undivided ownership interest in Scherer Unit No. 2 (the
"Leases"). The Refunding Lessor Notes issued with respect to the Facility Bonds
will be payable on such dates and in such amounts as are required to pay in full
the principal of and premium, if any, and interest on the Facility Bonds when
due. The Facility Bonds will constitute, in effect, a nonrecourse borrowing by
and on behalf of the Lessors, secured by the Lessors' interests in Scherer Unit
No. 2 and Oglethorpe's obligations to the Lessors under the Leases (as more
fully described below and herein).
The Refunding Lessor Note of each Lessor is secured under its Lease
Indenture by, among other things, a lien on and security interest in (i) such
Lessor's interest in its Lease with Oglethorpe, including the rights of such
Lessor to receive all basic rental and certain other payments thereunder (other
than Excepted Payments as defined therein); (ii) such Lessor's undivided
ownership interest in Scherer Unit No. 2; and (iii) such Lessor's rights under
the Support Agreements described herein. Each Lease requires that basic rental
and certain other payments be made by Oglethorpe in such amounts and at such
times as will always provide for the payment of the principal of and premium, if
any, and interest on all Lessor Notes (as described herein) issued by the
related Lessor, including such Lessor's Refunding Lessor Notes, when due,
whether at maturity, upon redemption or otherwise. The Refunding Lessor Notes
are without recourse to the general credit of any Lessor or Equity Investor. As
such, the only
16
sources of payment for the Refunding Lessor Notes, and thus for the Facility
Bonds, will be the basic rentals and certain other payments to be made by
Oglethorpe to the Lessors under the Leases and, if ultimately required, the
proceeds of collateral securing such obligations. Each such Lease is a net lease
pursuant to which Oglethorpe is unconditionally obligated to make all payments
thereunder without any right of counterclaim, setoff, deduction or defense.
However, the Facility Bonds will not be, and the Refunding Lessor Notes are not,
direct obligations of or guaranteed by Oglethorpe. For information with respect
to certain factors that may affect the foregoing, see "DESCRIPTION OF THE
FACILITY BONDS-- Considerations Relating to Security."
Subject to certain exceptions described herein, the Lease Indenture Trustee
is entitled to exercise applicable remedies on behalf of the holder of each
Refunding Lessor Note in the event of a default thereunder. Holders of the
Facility Bonds will be entitled, through the Collateral Trust Trustee as holder
of the Refunding Lessor Notes, to direct the Lease Indenture Trustees with
respect to matters relating to such exercise of remedies as permitted by the
Lease Indentures. (See "DESCRIPTION OF THE FACILITY BONDS--Voting of Lessor
Notes.")
Subject to the limitations described below, additional notes of each Lessor
("Additional Notes"; together with the Refunding Lessor Notes, the "Lessor
Notes") are permitted to be issued under each Lessor's Lease Indenture (i) to
refinance any previously issued Lessor Notes, including the Refunding Lessor
Notes, and to finance all costs and expenses in connection therewith; (ii) to
provide funds in connection with certain requirements of the related Tax
Indemnification Agreement described herein; and (iii) to provide funds for all
or any portion of any addition or improvement to Scherer Unit No. 2 ("Capital
Improvements").
No Additional Notes to be issued for the purpose set forth in (ii) above may
be issued if the aggregate principal amount of all Lessor Notes outstanding
under the applicable Lease Indenture (including the proposed Additional Notes)
exceeds 80% of the purchase price for the acquisition of such Lessor's undivided
interest in Scherer Unit No. 2 ("Lessor's Cost").
No Additional Notes to be issued for the purpose set forth in (iii) above
may be issued: (1) if the aggregate principal amount of all Lessor Notes issued
and outstanding under such Lease Indenture (including the proposed Additional
Notes) exceeds an amount equal to 80% of the sum of (A) the Lessor's Cost, (B)
such Lessor's share of the cumulative cost of all Capital Improvements
theretofore incorporated or installed during the term of the Lease and financed
by such Lessor or with Lessor Notes, and (C) such Lessor's share of the cost of
the Capital Improvements proposed to be financed with such Additional Notes; or
(2) if the aggregate principal amount of all Additional Notes issued under such
Lease Indenture for Capital Improvements (including the proposed Additional
Notes) exceeds an amount equal to 80% of the sum of (A) such Lessor's share of
the cumulative cost of all Capital Improvements theretofore incorporated or
installed during the term of the Lease and (B) the cost of the Capital
Improvements proposed to be financed with such Additional Notes. Moreover, the
aggregate principal amount of all Lessor Notes issued under all Lease Indentures
for the purpose set forth in (iii) above may not exceed $125,000,000.
In addition, before Additional Notes may be issued for the purposes set
forth in (ii) and (iii) above, the applicable Lease Indenture Trustee must give
ten days notice to the holders of the related Lessor Notes of the proposed
issuance of Additional Notes. No Additional Notes may be issued if, during such
ten day period, such holders of Lessor Notes notify such Lease Indenture Trustee
that certain requirements for issuing Additional Notes have not been met and
direct such Lease Indenture Trustee not to allow the issuance of such Additional
Notes.
For further information with respect to the source of payment for the
Facility Bonds and the provisions of the Collateral Trust Indenture and the
Lease Indentures relating thereto, see "DESCRIPTION OF THE FACILITY BONDS" and
"DESCRIPTION OF THE LEASE INDENTURES."
17
OPC SCHERER 1997 FUNDING CORPORATION
OPC Scherer 1997 Funding Corporation is a special purpose corporation
incorporated in Delaware on May 28, 1997, for the purpose of facilitating the
refinancing of the respective undivided ownership interest of each Lessor in
Scherer Unit No. 2. The business of OPC Scherer 1997 Funding Corporation is
restricted by its certificate of incorporation (which cannot be amended without
the consent of the Lease Indenture Trustees) to the issuance and sale of the
Private Facility Bonds, application of the proceeds thereof, the issuance of the
Exchange Facility Bonds and completion of the Exchange Offer and, possibly, the
issuance of other indebtedness, the proceeds of which would be used to make
loans to the Lessors to finance, among other things, additions or improvements
to Scherer Unit No. 2. The assets of OPC Scherer 1997 Funding Corporation
consist of (i) the Refunding Lessor Notes issued with respect to the Facility
Bonds and, if additional loans are made to the Lessors by OPC Scherer 1997
Funding Corporation, additional Lessor Notes and (ii) $1,000 in cash,
representing the equity capital contributed by its sole shareholder. The
Refunding Lessor Notes, and such other Lessor Notes, if any, will be payable
from basic rental and certain other payments made by Oglethorpe to the Lessors
under the Leases. OPC Scherer 1997 Funding Corporation is to function only as an
agent of the Lessors (and not as principal) with respect to the Facility Bonds
and to represent itself only as an agent of the Lessors (and not as principal)
in dealings with third parties relating to the Facility Bonds.
The sole shareholder of OPC Scherer 1997 Funding Corporation is the Scherer
Trust, a Massachusetts charitable trust. J H Holdings Corporation, a
Massachusetts corporation, is the trustee of the Scherer Trust. J.H. Management
Corporation, a Massachusetts corporation, is the sole beneficiary of the Scherer
Trust. All of the stock of J H Holdings Corporation and J.H. Management
Corporation is held by the 1960 Trust, an independent charitable organization
qualified under Section 501(c)(3) of the Internal Revenue Code, and operated for
the benefit of a Massachusetts charitable institution. Neither Oglethorpe nor
any Lessor or Equity Investor holds any ownership interest in OPC Scherer 1997
Funding Corporation, J H Holdings Corporation or J.H. Management Corporation,
and no person affiliated with Oglethorpe, any Lessor or Equity Investor is an
officer, director or employee of OPC Scherer 1997 Funding Corporation, J H
Holdings Corporation or J.H. Management Corporation.
18
FLOW OF FUNDS FOR DEBT SERVICE PAYMENTS ON THE FACILITY BONDS
[CHART]
19
BUSINESS OF OGLETHORPE
GENERAL
Oglethorpe is a Georgia electric membership corporation incorporated in 1974
and headquartered in metropolitan Atlanta. Oglethorpe is owned by its 39
Members, who, in turn, are owned by their retail consumers. Oglethorpe is the
largest electric cooperative in the United States in terms of operating
revenues, assets, kWh sales and, through the Members, consumers served.
Oglethorpe has approximately 170 employees, after reflecting the effect of a
recent corporate restructuring and a business alliance transaction. (See
"Corporate Restructuring" and "Relationship with Intellisource" herein.)
As with cooperatives generally, Oglethorpe operates on a not-for-profit
basis. Oglethorpe's principal business is providing wholesale electric power to
the Members. (See "Power Supply Business" herein.) The Members are local
consumer-owned distribution cooperatives providing retail electric service on a
not-for-profit basis. In general, the customer base of the Members consists of
residential, commercial and industrial consumers within specific geographic
areas. The Members serve approximately 1.2 million electric consumers (meters)
representing approximately 2.6 million people. For information on the Members,
see "THE MEMBERS OF OGLETHORPE."
Oglethorpe's mailing address is 2100 East Exchange Place, Post Office Box
1349, Tucker, Georgia 30085-1349, and its telephone number is (770) 270-7600.
COOPERATIVE PRINCIPLES
Cooperatives like Oglethorpe are business organizations owned by their
members, which are also either their wholesale or retail customers. 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. Cooperatives may make sales to
non-members, the effect of which is generally to reduce costs to members. Today,
cooperatives operate throughout the United States in such diverse areas as
utilities, agriculture, irrigation, insurance and credit.
All cooperatives are based on similar business principles and legal
foundations. Generally, an electric cooperative designs its rates to recover its
cost-of-service and plans to collect a reasonable amount of revenues in excess
of expenses (I.E., margins) to increase its patronage capital, which is the
equity component of its capitalization. Any such margins, which are considered
capital contributions (I.E., equity) from the members, are held for the accounts
of the members without interest and returned to them when the board of directors
of the cooperative deems it prudent to do so. The timing and amount of any
actual return of capital to the members depends on the financial goals of the
cooperative and the cooperative's loan and security agreements.
CORPORATE RESTRUCTURING
Oglethorpe and the Members completed a corporate restructuring (the
"Corporate Restructuring") on March 11, 1997, in which Oglethorpe was divided
into three specialized operating companies to respond to increasing competition
and regulatory changes in the electric industry. As part of the Corporate
Restructuring, Oglethorpe's transmission business was sold to and is now owned
and operated by Georgia Transmission Corporation (An Electric Membership
Corporation) ("GTC"), a recently formed Georgia electric membership corporation.
Oglethorpe's system operations business was sold to and is now owned and
operated by Georgia System Operations Corporation ("GSOC"), a recently formed
Georgia nonprofit corporation. Oglethorpe continues to own and operate its power
supply business.
The purchase price GTC paid Oglethorpe for the transmission business was
based on an appraisal of the fair market value of such business, as determined
by an independent appraiser, and was approximately $709 million. The purchase
price was paid primarily by GTC's assumption of a portion
20
(approximately 16.86%) of Oglethorpe's long-term secured debt in an amount equal
to approximately $686 million. Approximately $541 million of this debt (payable
to the Rural Utilities Service ("RUS"), FFB and CoBank) became the sole
obligation of GTC, and Oglethorpe was released from all liability with regard to
this debt. The remaining $145 million of debt assumed by GTC relates to
Oglethorpe's pollution control revenue bonds ("PCBs"). While GTC assumed and
agreed to pay this $145 million of debt, Oglethorpe was not legally released
from its obligation to repay this debt. For financial reporting purposes, this
debt is not shown on Oglethorpe's balance sheet and is shown on Oglethorpe's
capitalization table as being assumed by GTC. (See "UNAUDITED PRO FORMA
CONDENSED FINANCIAL DATA," "SELECTED FINANCIAL DATA," "CAPITALIZATION" and the
Financial Statements of Oglethorpe and the notes thereto included in this
Prospectus.) The remainder of the purchase price was paid by GTC from cash
obtained through a loan from National Rural Utilities Cooperative Finance
Corporation ("CFC") and the assumption of approximately $2 million of other
Oglethorpe liabilities. Oglethorpe also made a special patronage capital
distribution of approximately $49 million to the Members which was used by the
Members to establish equity in and to provide initial working capital to GTC.
Oglethorpe and the 39 Members are the owners and members of GTC. GTC now
provides transmission services to the Members, Oglethorpe and third parties. GTC
has succeeded to all of Oglethorpe's rights and obligations with respect to the
Integrated Transmission System ("ITS"). (See "Relationship with GTC" herein for
further discussion of the ITS.)
The system operations business and assets sold to GSOC consist of the system
control center and related energy control and revenue metering systems
equipment. The purchase price totaled approximately $9.4 million and was paid by
(i) GSOC's assumption of Oglethorpe's obligations under an existing note held by
the RUS, (ii) delivery of a purchase money note payable to Oglethorpe, and (iii)
the assumption of certain other liabilities of Oglethorpe. Oglethorpe, the
Members and GTC are the owners and members of GSOC. GSOC now operates the system
control center and provides system operations services to the Members,
Oglethorpe and GTC.
Oglethorpe continues to operate its power supply business. Oglethorpe
retained all of its owned and leased generation assets and, as of September 30,
1997, had total assets of approximately $4.5 billion and total long-term debt of
approximately $3.5 billion. Oglethorpe also continues to administer its power
purchase contracts and provide marketing support functions to the Members. (See
"Power Supply Business" herein and "MEMBER REQUIREMENTS AND POWER SUPPLY
RESOURCES.")
Effective with the Corporate Restructuring, the Members amended Oglethorpe's
Bylaws to implement a new governance structure with an 11-member board of
directors consisting of six directors elected from the Members, four independent
outside directors and Oglethorpe's President and Chief Executive Officer. This
smaller board replaced Oglethorpe's former 39-member board comprised of
directors nominated from and by each Member. (See "MANAGEMENT" for further
information.)
Contemporaneously with the Corporate Restructuring, Oglethorpe replaced its
prior Consolidated Mortgage and Security Agreement, dated as of September 1,
1994, by and among Oglethorpe and the United States of America, acting through
the Administrator of the RUS, and certain other mortgagees (the "RUS Mortgage"),
with an Indenture, dated as of March 1, 1997, from Oglethorpe to SunTrust Bank,
Atlanta ("SunTrust"), as trustee (as supplemented, the "Mortgage Indenture"). As
did the RUS Mortgage, the Mortgage Indenture constitutes a lien on substantially
all of the owned tangible and certain intangible property of Oglethorpe. (See
"Electric Rates" herein and "MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS--General--RATES AND FINANCIAL COVERAGE
REQUIREMENTS" for further discussion of the revenue requirements of the Mortgage
Indenture.)
Immediately after the Corporate Restructuring, Oglethorpe's corporate name
was changed from "Oglethorpe Power Corporation (An Electric Membership
Generation & Transmission Corporation)" to
21
"Oglethorpe Power Corporation (An Electric Membership Corporation)" to reflect
that it no longer provides transmission services.
In connection with the Corporate Restructuring, Oglethorpe agreed to remove
the costs of its marketing services business from its general rates and recover
these costs on a fee-for-services basis beginning in 1998. Oglethorpe has
created a stock subsidiary, EnerVision, Inc., Tailored Energy Solutions, to
which it may transfer its marketing services business, which includes 36
full-time and 12 part-time employees. Further, all or part of this subsidiary
may be sold to third parties. Oglethorpe does not expect any of these potential
actions to have a material effect on its financial condition or results of
operations.
POWER SUPPLY BUSINESS
Oglethorpe provides wholesale electric service to the 39 Members pursuant to
long-term, take-or-pay Wholesale Power Contracts described herein that obligate
the Members on a joint and several basis to pay rates sufficient to pay all the
costs of owning and operating Oglethorpe's power supply business. (See
"Wholesale Power Contracts" herein.) Oglethorpe supplies capacity and energy to
the Members from a combination of owned and leased generating plants and power
purchased under long-term contracts with other power suppliers and power
marketers. GTC provides transmission services to the
Members for delivery of the Members' power purchases.
Oglethorpe owns or leases undivided interests in thirteen generating units
currently in commercial operation. These units provide Oglethorpe with a total
of 3,335 MW of nameplate capacity, consisting of 1,500.6 MW of coal-fired
capacity, 1,185 MW of nuclear-fueled capacity, 632.5 MW of pumped storage
hydroelectric capacity, 14.8 MW of oil-fired combustion turbine capacity and 2.1
MW of conventional hydroelectric capacity. Oglethorpe's generating units consist
of 30% undivided interests in the Edwin I. Hatch Plant ("Plant Hatch"), the Hal
B. Wansley Plant ("Plant Wansley") and the Alvin W. Vogtle Plant ("Plant
Vogtle"), a 60% undivided interest in the Robert W. Scherer Unit No. 1 ("Scherer
Unit No. 1"), a 60% undivided interest in Scherer Unit No. 2, a 100% interest in
the Tallassee Project at the Walter W. Harrison Dam ("Tallassee") and a 74.61%
undivided interest in the Rocky Mountain Pumped Storage Hydroelectric Facility
("Rocky Mountain"). Plant Hatch consists of two nuclear-fueled units, with
nameplate ratings of 810 MW and 820 MW, respectively. Plant Wansley consists of
two coal-fired units, each with a nameplate rating of 865 MW. Plant Wansley also
includes a 49.2 MW oil-fired combustion turbine. Plant Vogtle consists of two
nuclear-fueled units, each with a nameplate rating of 1,160 MW. Plant Scherer
consists of four coal-fired units, each with a nameplate rating of 818 MW, with
Oglethorpe having an interest only in Scherer Unit No. 1 and Scherer Unit No. 2.
Tallassee is a conventional hydroelectric facility with a nameplate rating of
2.1 MW. Rocky Mountain is a 3 unit pumped storage hydroelectric facility with a
nameplate rating of 847.8 MW. (See "MEMBER REQUIREMENTS AND POWER SUPPLY
RESOURCES--General" and "--Generating Facilities--GENERAL.")
Participants in Plants Hatch, Wansley and Vogtle and Scherer Units No. 1 and
No. 2 also include MEAG, Dalton and GPC. GPC serves as operating agent for these
units. GPC is also a participant in Rocky Mountain which is operated by
Oglethorpe.
Oglethorpe utilizes long-term power marketer arrangements to reduce the cost
of power to the Members. Oglethorpe has entered into power marketer agreements
with LG&E Energy Marketing Inc. ("LEM") effective January 1, 1997, for
approximately 50% of the load requirements of the Members and with Morgan
Stanley Capital Group Inc. ("Morgan Stanley") effective May 1, 1997, with
respect to 50% of the forecasted load requirements of the Members. The LEM
agreements are based on the actual requirements of the Members during the
contract term, whereas the Morgan Stanley agreement represents a fixed supply
obligation. Under these power marketer agreements, Oglethorpe purchases energy
at fixed prices covering a portion of the costs of energy to its Members. LEM
and Morgan Stanley, in turn, have certain rights to market excess energy from
the Oglethorpe system. All of Oglethorpe's existing
22
generating facilities and power purchase arrangements are available for use by
LEM and Morgan Stanley for the term of the respective agreements. Oglethorpe
continues to be responsible for all the costs of its system resources but
receives revenue from LEM and Morgan Stanley for the use of the resources. (See
"MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--General" and "--Power Marketer
Arrangements.")
Oglethorpe purchases a total of approximately 1,250 MW of power pursuant to
power purchase agreements with GPC, Big Rivers Electric Corporation ("Big
Rivers"), Entergy Power, Inc. ("EPI"), and Hartwell Energy Limited Partnership
("Hartwell"). Oglethorpe has also contracted to purchase 275 MW of peaking
capacity from Florida Power Corporation during the summer of 1998. (See "MEMBER
REQUIREMENTS AND POWER SUPPLY RESOURCES--Power Purchase and Sale Arrangements.")
WHOLESALE POWER CONTRACTS
In connection with the Corporate Restructuring, Oglethorpe and each of the
Members entered into substantially similar Amended and Restated Wholesale Power
Contracts, dated August 1, 1996 (the "Wholesale Power Contracts"), each of which
extends through December 31, 2025. Each Wholesale Power Contract permits a
Member to take future incremental power requirements either from Oglethorpe or
other sources. Under its Wholesale Power Contract, a Member is unconditionally
obligated on an express "take-or-pay" basis for a fixed allocation of
Oglethorpe's costs for its existing generation and purchased power resources, as
well as the costs with respect to any future resources in which such Member
elects to participate. Each Wholesale Power Contract specifically provides that
the Member must make payments whether or not power is delivered and whether or
not a plant has been sold or is otherwise unavailable. Oglethorpe is obligated
to use its reasonable best efforts to operate, maintain and manage its resources
in accordance with prudent utility practices. The Wholesale Power Contracts
provide that Oglethorpe will be responsible for power supply planning, resource
procurement and sales of capacity and energy for Members unless a Member
notifies Oglethorpe that it does not want Oglethorpe to provide those services
to it.
Each Member's cost responsibility under its Wholesale Power Contract is
based on agreed-upon fixed percentage capacity responsibilities ("PCRs"). PCRs
have been assigned for all of Oglethorpe's existing generation and purchased
power resources. PCRs for any future resource will be assigned only to Members
choosing to participate in that resource. The Wholesale Power Contracts provide
that each Member will be jointly and severally responsible for all costs and
expenses of all existing generation and purchased power resources, as well as
for any future resources (whether or not such Member has elected to participate
in such future resource) that are approved by 75% of Oglethorpe's Board of
Directors and 75% of the Members. For resources so approved in which less than
all Members participate, costs are shared first among the participating Members,
and if all participating Members default, each non-participating Member is
expressly obligated to pay a proportionate share of such default.
The Wholesale Power Contracts contain covenants by each Member (i) to
establish, maintain and collect rates and charges for the service of its
electric system, and (ii) to conduct its business in a manner which will produce
revenues and receipts at least sufficient to enable the Member to pay to
Oglethorpe, when due, all amounts payable by the Member under its Wholesale
Power Contract and to pay any and all other amounts payable from, or which might
constitute a charge or a lien upon, the revenues and receipts derived from its
electric system, including all operation and maintenance expenses and the
principal of, premium, if any, and interest on all indebtedness related to the
Member's electric system.
See "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES" for a description of
the Members' demand and energy requirements and the related power supply
resources. See also "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--Power
Marketing Arrangements--RELATED AGREEMENTS" regarding supplemental agreements to
the Wholesale Power Contracts relating to the power marketer agreements.
23
ELECTRIC RATES
Each Member is required to pay Oglethorpe for capacity and energy furnished
under its Wholesale Power Contract in accordance with rates established by
Oglethorpe. Oglethorpe reviews its rates at such intervals as it deems
appropriate but is required to do so at least once every year. Oglethorpe is
required to revise its rates as necessary so that the revenues derived from such
rates, together with its revenues from all other sources, will be sufficient,
but only sufficient to pay all costs of its system, including operating and
maintenance costs, the cost of purchased power, the cost of transmission
services, and principal and interest on all indebtedness (including capital
lease obligations) of Oglethorpe, all costs associated with decommissioning or
otherwise retiring any generating facility, and to provide for the establishment
and maintenance of reasonable reserves. Rates are also required to be
established so as to enable Oglethorpe to comply with all financial requirements
under the Mortgage Indenture. (See "MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS--General--RATES AND FINANCIAL
COVERAGE REQUIREMENTS.")
Under the Mortgage Indenture, Oglethorpe is required, subject to any
necessary regulatory approval, to establish and collect rates which are
reasonably expected, together with other revenues of Oglethorpe, to yield an MFI
Ratio described herein for each fiscal year equal to at least 1.10. Margins for
Interest ("MFI") is defined in the Mortgage Indenture to be the sum of net
margins of Oglethorpe (which includes revenues of Oglethorpe subject to refund
at a later date but excludes provisions for (i) non-recurring charges to income,
including the non-recoverability of assets or expenses, except to the extent
Oglethorpe determines to recover such charges in rates, and (ii) refunds of
revenues collected or accrued subject to refund) plus interest charges, whether
capitalized or expensed, on all indebtedness secured under the Mortgage
Indenture or by a lien equal or prior to the lien of the Mortgage Indenture,
including amortization of debt discount and expense or premium but excluding
interest charges on indebtedness assumed by GTC ("Interest Charges"), plus any
amount included in net margins for accruals for federal or state income taxes
imposed on income after deduction of interest expense. MFI takes into account
any item of net margin, loss, gain or expenditure of any affiliate or subsidiary
of Oglethorpe only if Oglethorpe has received such net margins or gains as a
dividend or other distribution from such affiliate or subsidiary or if
Oglethorpe has made a payment with respect to such losses or expenditures. "MFI
Ratio" is the ratio of MFI to total Interest Charges for a given period. (See
"MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS-- General--RATES AND FINANCIAL COVERAGE REQUIREMENTS.")
The formulary rate established by Oglethorpe in the rate schedule to the
Wholesale Power Contracts employs a rate methodology under which all categories
of costs are specifically separated as components of the formula to determine
Oglethorpe's revenue requirements. The rate schedule also implements the
responsibility for fixed costs assigned to each Member (I.E., the PCR). The
monthly charges for capacity and other non-energy charges are based on
Oglethorpe's annual budget. Such capacity and other non-energy charges may be
adjusted by the Board of Directors, if necessary, during the year through an
adjustment to the annual budget. Energy charges reflect the pass-through of
actual energy costs whether incurred from generation or purchased power
resources or under the power marketing arrangements.
The rate schedule formula also includes a prior period adjustment ("PPA")
mechanism designed to ensure that Oglethorpe achieves the minimum 1.10 MFI
Ratio. The PPA provides for the retention of margins within a range from a 1.10
MFI Ratio to a 1.20 MFI Ratio. Amounts, if any, by which Oglethorpe fails to
achieve a minimum 1.10 MFI Ratio would be accrued as of December 31 of the
applicable year and collected from the Members during the period April through
December of the following year. Amounts, if any, by which Oglethorpe exceeds the
maximum 1.20 MFI Ratio would be charged against revenues as of December 31 of
the applicable year and refunded to the Members during the period April through
December of the following year. The rate schedule formula is intended to provide
for the collection of revenues which, together with revenues from all other
sources, are equal to all costs and
24
expenses recorded by Oglethorpe, plus amounts necessary to achieve at least the
minimum 1.10 MFI Ratio.
Under the terms of Oglethorpe's prior RUS Mortgage, all rate revisions by
Oglethorpe were subject to the approval of RUS. Under the Mortgage Indenture and
related loan contract with RUS, however, adjustments to Oglethorpe's rates to
reflect changes in Oglethorpe's budgets are not subject to RUS approval, except
for any reduction in rates in a fiscal year following a fiscal year in which
Oglethorpe has failed to meet the minimum 1.10 MFI Ratio set forth in the
Mortgage Indenture. Changes to the rate schedule under the Wholesale Power
Contracts are subject to RUS approval. Oglethorpe's rates are not subject to the
approval of any other federal or state agency or authority, including the
Georgia Public Service Commission (the "GPSC").
For information regarding future rates, see "MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS--General--RATES AND
FINANCIAL COVERAGE REQUIREMENTS."
RELATIONSHIP WITH GTC
GTC purchased and is operating the transmission system as described in
"Corporate Restructuring" herein. Oglethorpe and the 39 Members are members of
GTC. GTC provides transmission services to the Members for delivery of the
Members' power purchases from Oglethorpe, Southeastern Power Administration
("SEPA") and any other power suppliers. GTC also provides transmission services
to Oglethorpe and third parties. Oglethorpe has entered into a transmission
agreement with GTC to provide transmission services for third party transactions
and for service to Oglethorpe's headquarters and the administration building at
Rocky Mountain.
In connection with the Corporate Restructuring, GTC and the Members entered
into Member Transmission Service Agreements (the "Member Transmission
Agreements") under which GTC provides transmission service to the Members
pursuant to a transmission tariff. The Member Transmission Agreements have a
minimum term for network service for current load until December 31, 2025. After
an initial ten-year term, load growth above 1995 requirements may, with notice
to GTC, be served by others. The Member Transmission Agreements provide that if
a Member elects to purchase a part of its network service elsewhere, it must pay
appropriate stranded costs to protect the other Members from any rate increase
that could otherwise occur. Under the Member Transmission Agreements, Members
have the right to design, construct and own new distribution substations.
The Member Transmission Agreements provide that the Members are responsible,
on a joint and several basis, for all of GTC's costs relating to its
transmission business. The Member Transmission Agreements contain express
covenants of the Members to set and collect retail rates sufficient to allow the
Members to meet their respective obligations under the Member Transmission
Agreements. The rate formula set forth in the transmission tariff is intended to
recover all costs and expenses paid or incurred by GTC. The rate expressly
includes in the description of costs to be recovered all principal and interest
on indebtedness of GTC (including any indebtedness of Oglethorpe assumed by
GTC). The rate further expressly provides for GTC to earn sufficient margins to
satisfy the requirements of its new mortgage indenture, which is substantially
similar to Oglethorpe's Mortgage Indenture.
The GTC transmission tariff and associated Member Transmission Agreements
were developed to be consistent with federal transmission policy as expressed in
Order 888 of the Federal Energy Regulatory Commission ("FERC"). FERC's Order 888
mandates open access to essentially all transmission systems in order to promote
competition in the bulk power markets and provides that non-regulated utilities
(such as Oglethorpe and GTC) must provide access to their transmission systems
on reciprocal terms and conditions in order to obtain transmission from
FERC-regulated utilities. The transmission tariff and Member Transmission
Agreements have been designed to facilitate the operation of GTC in the new
regulatory environment and, accordingly, provide for GTC to serve on a
nondiscriminatory basis
25
both member and non-member customers on terms intended to meet FERC's
reciprocity requirement. For information regarding a FERC filing relating to GTC
and Oglethorpe, see "Legal Proceedings" herein.
GTC owns approximately 2,300 miles of transmission line and 450 substations
of various voltages. In connection with the Corporate Restructuring, GTC
succeeded to Oglethorpe's rights in the ITS, which consists of transmission
facilities owned by GTC, GPC, MEAG and Dalton. Through agreements, common access
to the combined facilities that compose the ITS enables the owners to use their
combined resources to make deliveries to or for their respective consumers, to
provide transmission service to third parties and to make off-system purchases
and sales.
GTC's rights and obligations with respect to the ITS are governed by the
Revised and Restated Integrated Transmission System Agreement with GPC (the
"ITSA"), which was assigned to GTC in connection with the Corporate
Restructuring. The ITSA provides for the transmission and distribution of
electric energy in the State of Georgia, other than in certain counties, and for
bulk power transactions, through use of the ITS. The ITS was established in
order to obtain the benefits of a coordinated development of the parties'
transmission facilities and to make it unnecessary for any party to construct
duplicative facilities. The ITS consists of all transmission facilities,
including land, owned by the parties on the date the ITSA became effective and
those thereafter acquired, which are located in the State of Georgia (other than
in the excluded counties) and which are used or usable to transmit power of a
certain minimum voltage and to transform power of a certain minimum voltage and
a certain minimum capacity (the "Transmission Facilities"). GPC has entered into
agreements with MEAG and Dalton that are substantially similar to the ITSA, and
GPC may enter into such agreements with other entities. The ITSA will remain in
effect through December 31, 2012 and, if not then terminated by five years'
prior written notice by either party, will continue until so terminated.
The ITSA is administered by a committee (the "Joint Committee") composed of
two representatives from each of GTC, GPC, MEAG and Dalton. Each year, the Joint
Committee determines a four-year plan of additions to the Transmission
Facilities that will reflect the current and anticipated future transmission
requirements of the parties. Each ITS participant is generally required to
maintain an original cost investment in the Transmission Facilities in
proportion to their respective Peak Loads (as defined in the ITSA).
GTC and GPC are parties to a Transmission Facilities Operation and
Maintenance Contract (the "Transmission Operation Contract"), under which GPC
provides System Operator Services (as defined in the Transmission Operation
Contract) for GTC. In addition, GPC is required to provide such supervision,
operation and maintenance supplies, spare parts, equipment and labor for the
operation, maintenance and construction of Transmission Facilities as may be
specified by GTC. GPC is also required to perform certain emergency work under
the Transmission Operation Contract. GTC is permitted, upon notice to GPC, to
perform, or contract with others for the performance of, certain services
performed by GPC. Absent termination or amendment of the Transmission Operation
Contract, however, GPC will continue to perform System Operator Services for
GTC. The term of the Transmission Operation Contract will continue from year to
year unless terminated by either party upon four years' notice. GTC is required
to pay its proportionate share of the cost for the services provided by GPC.
RELATIONSHIP WITH GSOC
Oglethorpe, the 39 Members and GTC are members of GSOC. GSOC now owns and
operates the system control center and provides system operations services to
the Members, Oglethorpe and GTC. GTC has contracted with GSOC to provide certain
transmission system operation services including reliability monitoring,
switching operations, and the real-time management of the transmission system.
26
RELATIONSHIP WITH GPC
Oglethorpe's relationship with GPC is a significant factor in several
aspects of Oglethorpe's business. GPC is one of Oglethorpe's principal suppliers
of purchased power, and Oglethorpe is one of GPC's largest customers. All of
Oglethorpe's co-owned generating facilities, except Rocky Mountain, are operated
by GPC on behalf of itself as a co-owner and as agent for the other co-owners.
GPC and Oglethorpe, through the Members, are competitors in the State of Georgia
for electric service to new customers that have a choice of supplier under the
Georgia Territorial Electric Service Act, which was enacted in 1973 (the
"Territorial Act"). For further information regarding the various relationships
and agreements with GPC, see "THE MEMBERS OF OGLETHORPE--Service Area and
Competition," "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--Power Purchase
and Sale Arrangements--POWER PURCHASES FROM GPC," "--Other Power Purchase and
Sale Arrangements--OTHER POWER SYSTEM ARRANGEMENTS," "--Generating
Facilities--FUEL SUPPLY," "CO-OWNERS OF THE PLANTS AND THE PLANT
AGREEMENTS--Co-Owners of the Plants--GEORGIA POWER COMPANY" and "--The Plant
Agreements."
RELATIONSHIP WITH RUS
Historically, federal loan programs administered by RUS have provided the
principal source of financing for electric cooperatives. Loans guaranteed by RUS
and made by FFB have been a major source of funding for Oglethorpe. However, in
recent years, there have been legislative, administrative and budgetary
initiatives intended to reduce or, in some cases, eliminate federal funding for
electric cooperatives. In any event, Oglethorpe does not have any new generation
facilities under construction, and Oglethorpe's management does not anticipate
the need for loans for construction of any new capacity well into the future.
(See "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES-- Power Marketer
Arrangements" for a discussion of the long-term power marketer arrangements.)
In connection with the Corporate Restructuring, Oglethorpe replaced its RUS
Mortgage with the Mortgage Indenture, which, like the RUS Mortgage, constitutes
a lien on substantially all of the owned tangible and certain intangible
property of Oglethorpe. Oglethorpe also entered into a new loan contract with
RUS in connection with the Mortgage Indenture. Under the new loan contract, RUS
has retained approval rights over certain significant actions and arrangements,
including, without limitation, (i) significant additions to or dispositions of
system assets, (ii) significant power purchase and sale contracts, (iii) changes
to the Wholesale Power Contracts, including the rate schedule contained therein,
(iv) changes to plant ownership and operating agreements and (v) in limited
circumstances, issuance of additional secured debt. The extent of RUS's approval
rights under the new loan contract with Oglethorpe is substantially less than
the supervision and control RUS has traditionally exercised over borrowers under
its standard loan and security documentation. In addition, the Mortgage
Indenture improves Oglethorpe's ability to borrow funds in the public capital
markets. (See "THE MEMBERS OF OGLETHORPE--Members' Relationship with RUS" for a
discussion of the impact of changes in the RUS lending program on the Members.)
RELATIONSHIP WITH INTELLISOURCE
In conjunction with the Corporate Restructuring and as a part of its
continuing efforts to reduce costs, effective February 1, 1997, Oglethorpe
implemented a business alliance with Intellisource, Inc., a national provider of
outsourcing services. Pursuant to an agreement with Intellisource, approximately
150 support services division employees of Oglethorpe in the areas of
accounting, auditing, communications, human resources, facility management,
purchasing, telecommunications and information technology became employees of
Intellisource. Oglethorpe, GTC and GSOC are key customers of Intellisource and
are being served on-site by the managers and employees of Oglethorpe's former
support services division.
27
LEGAL PROCEEDINGS
On June 17, 1997, PECO Energy Company--Power Team ("PECO") filed an
application with FERC pursuant to Section 211 of the Federal Power Act
requesting FERC to compel Oglethorpe and/or GTC to provide PECO with 250 MW of
firm point-to-point transmission service from the Tennessee Valley Authority
("TVA")-ITS interface to the Florida-ITS interface for an initial three-year
period, with an automatic roll-over provision. PECO also seeks $10,000 per day
in penalties from Oglethorpe and/or GTC, alleging bad faith and delays in
negotiations. In their response to FERC, GTC and Oglethorpe contend that they
negotiated with PECO in good faith, and thus there is no reasonable basis for
imposing the penalties sought by PECO. GTC also responded that it does not have
firm "available transfer capability" at the TVA-ITS interface to fulfill PECO's
request, after taking into account the need to protect system reliability,
existing firm commitments, and use of the TVA-ITS interface to serve "native
load," in accordance with North American Electric Reliability Council
guidelines. In the event GTC is ordered by FERC to provide the requested
service, PECO would be required to compensate GTC at rates set by FERC in the
order. As a consequence of any such order, power purchased by Oglethorpe for
delivery through the TVA-ITS interface would probably be curtailed, and could
result in higher purchased power cost than would otherwise be the case. Although
FERC transmission pricing policy is designed to ensure that a transmission
provider is fully compensated for the cost of providing transmission service,
potentially including opportunity cost, there can be no assurance that rates
ordered by FERC for service to PECO would fully compensate GTC, Oglethorpe and
the Members for the use of the transmission system and for any resulting
increase in the cost of power.
Oglethorpe is a party to various other actions and proceedings incident to
its normal business. Liability in the event of final adverse determinations in
any of these matters is either covered by insurance or, in the opinion
Oglethorpe's management, after consultation with counsel, should not in the
aggregate have a material adverse effect on the financial position or results of
operations of Oglethorpe.
28
UNAUDITED PRO FORMA CONDENSED FINANCIAL DATA
The following unaudited pro forma condensed statements of revenues and
expenses for the year ended December 31, 1996, and the twelve months ended
September 30, 1997, are based on the historical financial statements of
Oglethorpe included in this Prospectus, adjusted to give effect to the Corporate
Restructuring effective April 1, 1997, as if it had occurred at January 1, 1996,
and October 1, 1996, respectively. Therefore, the unaudited pro forma condensed
statement of revenues and expenses for the twelve months ended September 30,
1997, reflects operations of Oglethorpe solely as a power supply company after
the Corporate Restructuring for the six months ended September 30, 1997. For
information regarding the Corporate Restructuring, see "BUSINESS OF
OGLETHORPE--Corporate Restructuring."
The unaudited pro forma condensed financial data and accompanying notes
should be read in conjunction with the financial statements of Oglethorpe and
the notes thereto included in this Prospectus and "MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS." The unaudited pro
forma financial data and accompanying notes are provided for informational
purposes only. They are not necessarily indicative of what Oglethorpe's results
of operations would have been if the Corporate Restructuring had actually
occurred as of the dates indicated and are not intended to project Oglethorpe's
results of operations for any future period, nor do they give effect to any
matters other than those described in the notes thereto. However, the unaudited
pro forma condensed financial data contain, in the opinion of management, all
adjustments necessary for a fair presentation thereof.
29
PRO FORMA CONDENSED STATEMENT OF REVENUES AND EXPENSES
FOR THE YEAR ENDED DECEMBER 31, 1996
(UNAUDITED)
OGLETHORPE PRO FORMA OGLETHORPE
HISTORICAL ADJUSTMENTS PRO FORMA
------------ ----------- ----------
(DOLLARS IN THOUSANDS)
OPERATING REVENUES:
Sales to Members.................................................................... $1,023,094 $ (95,938)(1) $927,156
Sales to non-Members................................................................ 78,343 (9,789)(2) 68,554
------------ ----------- ----------
TOTAL OPERATING REVENUES.......................................................... 1,101,437 (105,727) 995,710
------------ ----------- ----------
OPERATING EXPENSES:
Fuel................................................................................ 206,524 -- 206,524
Production.......................................................................... 129,178 -- 129,178
Purchased power..................................................................... 229,089 -- 229,089
Power delivery...................................................................... 18,216 (18,216)(3) --
Depreciation and amortization....................................................... 163,130 (25,122)(4) 138,008
Taxes other than income taxes....................................................... 30,262 (7,534)(5) 22,728
Other operating expenses............................................................ 42,289 (8,982)(6) 33,307
------------ ----------- ----------
TOTAL OPERATING EXPENSES.......................................................... 818,688 (59,854) 758,834
------------ ----------- ----------
OPERATING MARGIN...................................................................... 282,749 (45,873) 236,876
------------ ----------- ----------
OTHER INCOME (EXPENSE):
Interest income..................................................................... 23,485 (3,356)(7) 20,129
Amortization of deferred margins.................................................... 32,047 (2,711)(8) 29,336
Allowance for equity funds used during construction................................. 238 (124)(9) 114
Other............................................................................... 9,564 706(10) 10,270
------------ ----------- ----------
TOTAL OTHER INCOME................................................................ 65,334 (5,485) 59,849
------------ ----------- ----------
INTEREST CHARGES:
Interest on long-term debt and other obligations.................................... 328,907 (49,365)(11) 279,542
Allowance for debt funds used during construction................................... (2,576) 1,345(9) (1,231)
------------ ----------- ----------
NET INTEREST CHARGES.............................................................. 326,331 (48,020) 278,311
------------ ----------- ----------
NET MARGIN............................................................................ $ 21,752 $ (3,338)(12) $ 18,414
------------ ----------- ----------
------------ ----------- ----------
SEE ACCOMPANYING NOTES TO UNAUDITED PRO FORMA CONDENSED STATEMENTS
OF REVENUES AND EXPENSES.
30
PRO FORMA CONDENSED STATEMENT OF REVENUES AND EXPENSES
FOR THE TWELVE MONTHS ENDED SEPTEMBER 30, 1997
(UNAUDITED)
OGLETHORPE PRO FORMA OGLETHORPE
HISTORICAL ADJUSTMENTS PRO FORMA
------------ ----------- ----------
(DOLLARS IN THOUSANDS)
OPERATING REVENUES:
Sales to Members................................................................... $1,019,430 $ (55,473)(1) $963,957
Sales to non-Members............................................................... 50,383 (5,095)(2) 45,288
------------ ----------- ----------
TOTAL OPERATING REVENUES....................................................... 1,069,813 (60,568) 1,009,245
------------ ----------- ----------
OPERATING EXPENSES:
Fuel............................................................................... 200,858 -- 200,858
Production......................................................................... 139,645 -- 139,645
Purchased power.................................................................... 254,996 -- 254,996
Power delivery..................................................................... 10,210 (10,278)(3) (68)
Depreciation and amortization...................................................... 149,891 (14,303)(4) 135,588
Taxes other than income taxes...................................................... 27,309 (3,933)(5) 23,376
Other operating expenses........................................................... 29,253 (7,000)(6) 22,253
------------ ----------- ----------
TOTAL OPERATING EXPENSES....................................................... 812,162 (35,514) 776,648
------------ ----------- ----------
OPERATING MARGIN..................................................................... 257,651 (25,054) 232,597
------------ ----------- ----------
OTHER INCOME (EXPENSE):
Interest income.................................................................... 27,049 (218)(7) 26,831
Amortization of deferred margins................................................... 7,927 (717)(8) 7,210
Allowance for equity funds used during construction................................ 182 (120)(9) 62
Other.............................................................................. 14,180 724(10) 14,904
------------ ----------- ----------
TOTAL OTHER INCOME............................................................. 49,338 (331) 49,007
------------ ----------- ----------
INTEREST CHARGES:
Interest on long-term debt and other obligations................................... 299,353 (24,538)(11) 274,815
Allowance for debt funds used during construction.................................. (1,964) 730(9) (1,234)
------------ ----------- ----------
NET INTEREST CHARGES........................................................... 297,389 (23,808) 273,581
------------ ----------- ----------
NET MARGIN........................................................................... $ 9,600 $ (1,577)(12) $ 8,023
------------ ----------- ----------
------------ ----------- ----------
SEE ACCOMPANYING NOTES TO UNAUDITED PRO FORMA CONDENSED STATEMENTS
OF REVENUES AND EXPENSES.
31
NOTES TO UNAUDITED PRO FORMA CONDENSED STATEMENTS
OF REVENUES AND EXPENSES
(1) The adjustment to sales to Members includes revenues based on estimates of
the transmission portion of rates charged to the Members and an allocation
of the portion of rates related to transmission-related overhead costs.
(2) The adjustment to sales to non-Members represents actual
transmission-related sales.
(3) The adjustment to power delivery includes actual operation and maintenance
costs of transmission and an allocation of related overhead costs.
(4) The adjustment to depreciation and amortization is an estimate of
depreciation and amortization of the transmission and system operations
assets sold to GTC and GSOC, respectively, primarily based on the estimated
depreciation and amortization of Oglethorpe's transmission assets.
(5) The adjustment to taxes other than income taxes is an estimate of taxes on
the transmission and system operations assets sold to GTC and GSOC,
respectively, based on the ratio of the estimated depreciation and
amortization of Oglethorpe's transmission assets to total depreciation and
amortization of Oglethorpe's assets.
(6) The adjustment to other operating expenses is primarily an allocation of
overhead costs related to transmission.
(7) The adjustment to interest income is primarily based on the ratio of
investments of GTC and GSOC acquired in the Corporate Restructuring to
total investments of Oglethorpe, GTC and GSOC as of April 1, 1997.
(8) The adjustment to amortization of deferred margins is based on a ratio of
the estimated transmission Member revenues determined by the method
described in Note 1 above to total Member capacity revenues.
(9) The adjustment to allowance for equity and debt funds used during
construction is based on a ratio of construction work in progress of the
transmission and system operations businesses to total construction work in
progress for the period then ended.
(10) The adjustment to other includes net expenses identified as related to the
transmission business.
(11) The adjustment to interest on long-term debt and other obligations is based
on a ratio of debt assumed by GTC and GSOC in the Corporate Restructuring
to total debt of Oglethorpe, GTC and GSOC as of April 1, 1997.
(12) The adjustment to net margin includes (i) 7% of the estimated interest on
debt relating to the transmission and system operations businesses for the
appropriate period ending December 31, 1996, in order to meet Oglethorpe's
Times Interest Earned Ratio of 1.07 (see "MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS"), and (ii) net
margins based on pro forma operations (as a result of applying the
methodologies described in Notes 1 through 11 above) for the three months
ended March 31, 1997.
32
SELECTED FINANCIAL DATA
The following table presents selected historical financial data of
Oglethorpe. The financial data presented as of the end of and for each year in
the five-year period ended December 31, 1996, have been derived from the audited
financial statements of Oglethorpe. The financial statements of Oglethorpe as of
and for the years ended December 31, 1996 and 1995 have been audited by Coopers
& Lybrand L.L.P., independent public accountants. The financial statements of
Oglethorpe as of and for the years ended December 31, 1994, 1993 and 1992 have
been audited by Arthur Andersen LLP, independent public accountants. Balance
Sheets at December 31, 1996 and 1995, and the related Statements of Revenues and
Expenses, Patronage Capital and Cash Flows for the years ended December 31,
1996, 1995 and 1994 and notes thereto are included in this Prospectus. The
financial data presented in the following table as of and for the twelve-month
period ended September 30, 1997, are derived from the unaudited financial
statements of Oglethorpe also included in this Prospectus which, in the opinion
of Oglethorpe's management, include all adjustments (constituting only normal
recurring adjustments) necessary for a fair presentation of the unaudited
financial information. Due to the Corporate Restructuring, the results of
operations and financial condition reflect operations as a combined power
supply, transmission and system operations company through March 31, 1997, and
operations solely as a power supply company thereafter. The results of
operations for the twelve months ended September 30, 1997, are not necessarily
indicative of the results of operations for a fiscal year. These data should be
read in conjunction with the financial statements of Oglethorpe and the notes
thereto included in this Prospectus, "BUSINESS OF OGLETHORPE--Corporate
Restructuring," "UNAUDITED PRO FORMA CONDENSED FINANCIAL DATA" and "MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS."
TWELVE MONTHS
ENDED YEAR ENDED DECEMBER 31,
SEPTEMBER 30, ----------------------------------------------------------
1997 1996 1995 1994 1993 1992
------------- ---------- ---------- ---------- ---------- ----------
(DOLLARS IN THOUSANDS, EXCEPT RATIOS AND REVENUES PER KILOWATT-HOUR)
STATEMENT OF OPERATIONS DATA:
OPERATING REVENUES:
Sales to Members.............................. $1,019,430 $1,023,094 $1,030,797 $ 930,875 $ 899,720 $ 816,000
Sales to non-Members.......................... 50,383 78,343 118,764 125,207 200,940 268,763
------------- ---------- ---------- ---------- ---------- ----------
TOTAL OPERATING REVENUES.................... 1,069,813 1,101,437 1,149,561 1,056,082 1,100,660 1,084,763
------------- ---------- ---------- ---------- ---------- ----------
OPERATING EXPENSES:
Fuel.......................................... 200,858 206,524 219,062 203,444 176,342 167,288
Production.................................... 139,645 129,178 133,858 132,723 129,972 115,915
Purchased power............................... 254,996 229,089 264,844 227,477 271,970 230,510
Depreciation and amortization................. 149,891 163,130 139,024 131,056 128,060 126,047
Taxes......................................... 27,309 30,262 27,561 24,741 25,148 19,634
Other operating expenses...................... 39,463 60,505 56,535 49,234 44,876 50,578
------------- ---------- ---------- ---------- ---------- ----------
TOTAL OPERATING EXPENSES.................... 812,162 818,688 840,884 768,675 776,368 709,972
------------- ---------- ---------- ---------- ---------- ----------
OPERATING MARGIN................................ 257,651 282,749 308,677 287,407 324,292 374,791
OTHER INCOME, NET............................... 49,338 65,334 33,710 40,795 38,741 45,928
NET INTEREST CHARGES............................ (297,389) (326,331) (320,129) (305,120) (350,652) (393,247)
------------- ---------- ---------- ---------- ---------- ----------
MARGIN BEFORE CUMULATIVE EFFECT OF CHANGE IN
ACCOUNTING PRINCIPLE.......................... 9,600 21,752 22,258 23,082 12,381 27,472
CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING FOR
INCOME TAXES.................................. -- -- -- -- 13,340 --
------------- ---------- ---------- ---------- ---------- ----------
NET MARGIN...................................... $ 9,600 $ 21,752 $ 22,258 $ 23,082 $ 25,721 $ 27,472
------------- ---------- ---------- ---------- ---------- ----------
------------- ---------- ---------- ---------- ---------- ----------
33
TWELVE MONTHS
ENDED YEAR ENDED DECEMBER 31,
SEPTEMBER 30, ----------------------------------------------
1997 1996 1995
----------------- ------------------ ------------------
(DOLLARS IN THOUSANDS, EXCEPT RATIOS AND REVENUES PER KILOWATT-HOUR)
ENERGY SUPPLY (MEGAWATT-
HOURS):
Generated................... 17,609,459 17,866,143 18,402,839
Purchased................... 6,347,414 6,606,931 5,738,634
----------------- ------------------ ------------------
Available for sale.......... 23,956,873 24,473,074 24,141,473
----------------- ------------------ ------------------
----------------- ------------------ ------------------
MEMBER REVENUE PER KWH SOLD... 5.03 CENTS 5.11 CENTS 5.53 CENTS
----------------- ------------------ ------------------
----------------- ------------------ ------------------
RATIO OF EARNINGS TO FIXED
CHARGES(1)(2)............... 1.03 1.07 1.07
----------------- ------------------ ------------------
----------------- ------------------ ------------------
BALANCE SHEET DATA (END OF
PERIOD):
ELECTRIC PLANT, NET:
In service................ $ 3,611,232 $ 4,345,200 $ 4,436,009
Construction work in
progress................ 13,059 31,181 35,753
----------------- ------------------ ------------------
Total electric plant,
net................... $ 3,624,291 $ 4,376,381 $ 4,471,762
----------------- ------------------ ------------------
----------------- ------------------ ------------------
TOTAL ASSETS.................. $ 4,527,280 $ 5,362,175 $ 5,438,496
----------------- ------------------ ------------------
----------------- ------------------ ------------------
CAPITALIZATION:
Long-term debt, excluding
amounts due within one
year...................... $ 3,171,511 $ 4,052,470 $ 4,207,320
Obligation under capital
leases, long-term......... 289,825 293,682 296,478
Other obligations........... 51,325 41,685 --
Patronage capital and
membership fees........... 321,771 356,229 338,891
----------------- ------------------ ------------------
Total capitalization...... $ 3,834,432 $ 4,744,066 $ 4,842,689
----------------- ------------------ ------------------
----------------- ------------------ ------------------
PROPERTY ADDITIONS............ $ 74,367 $ 93,704 $ 138,921
----------------- ------------------ ------------------
----------------- ------------------ ------------------
1994 1993 1992
------------------ ------------------ ------------------
ENERGY SUPPLY (MEGAWATT-
HOURS):
Generated................... 16,924,038 14,575,920 13,805,683
Purchased................... 4,381,087 7,620,815 6,233,262
------------------ ------------------ ------------------
Available for sale.......... 21,305,125 22,196,735 20,038,945
------------------ ------------------ ------------------
------------------ ------------------ ------------------
MEMBER REVENUE PER KWH SOLD... 5.65 CENTS 5.47 CENTS 5.55 CENTS
------------------ ------------------ ------------------
------------------ ------------------ ------------------
RATIO OF EARNINGS TO FIXED
CHARGES(1)(2)............... 1.07 1.07 1.08
------------------ ------------------ ------------------
------------------ ------------------ ------------------
BALANCE SHEET DATA (END OF
PERIOD):
ELECTRIC PLANT, NET:
In service................ $ 3,980,439 $ 4,054,956 $ 4,122,411
Construction work in
progress................ 538,789 450,965 322,628
------------------ ------------------ ------------------
Total electric plant,
net................... $ 4,519,228 $ 4,505,921 $ 4,445,039
------------------ ------------------ ------------------
------------------ ------------------ ------------------
TOTAL ASSETS.................. $ 5,346,330 $ 5,323,890 $ 5,359,597
------------------ ------------------ ------------------
------------------ ------------------ ------------------
CAPITALIZATION:
Long-term debt, excluding
amounts due within one
year...................... $ 4,128,080 $ 4,058,251 $ 4,095,796
Obligation under capital
leases, long-term......... 303,749 303,458 302,061
Other obligations........... -- -- --
Patronage capital and
membership fees........... 309,496 289,982 264,261
------------------ ------------------ ------------------
Total capitalization...... $ 4,741,325 $ 4,651,691 $ 4,662,118
------------------ ------------------ ------------------
------------------ ------------------ ------------------
PROPERTY ADDITIONS............ $ 206,345 $ 235,285 $ 232,283
------------------ ------------------ ------------------
------------------ ------------------ ------------------
- ------------------------
(1) It should be noted that Oglethorpe does not take this ratio into account in
setting its rates since its rates are not intended to produce a profit or
provide a return on equity. Rates are designed to achieve a level of
coverage of fixed charges that is generally less than that sought to be
achieved by investor-owned utilities. Oglethorpe is, however, required under
the Mortgage Indenture to establish and collect rates which are reasonably
expected to yield an MFI for each fiscal year equal to at least 1.10 times
total interest charges during such fiscal year on all indebtedness secured
under the Mortgage Indenture. For information on the computation of MFI see
"MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS--General--RATES AND FINANCIAL COVERAGE REQUIREMENTS."
(2) For computation of these ratios (i) earnings consist of net margin before
income taxes and extraordinary items plus fixed charges less undistributed
earnings attributable to Oglethorpe's investments and (ii) fixed charges
consist of interest on all indebtedness and the estimated interest factor of
rental expense.
34
CAPITALIZATION
The capitalization of Oglethorpe, as of September 30, 1997, is shown below.
The information presented below is derived from the unaudited financial
statements of Oglethorpe and notes thereto included elsewhere in this Prospectus
and should be read in conjunction therewith.
The proceeds of the Private Facility Bonds were used to refund certain
nonrecourse debt of the Lessors incurred in connection with the Sale and
Leaseback Transactions. Accordingly, the issuance of the Private Facility Bonds
did not change the capitalization of Oglethorpe since the Private Facility Bonds
are not direct obligations of Oglethorpe and since the debt refunded by the
Private Facility Bonds was already recorded as a portion of the obligations
under capital leases. The Exchange Facility Bonds are offered in exchange for
the Private Facility Bonds and will not result in any increase in the
outstanding debt of Oglethorpe.
OUTSTANDING
-----------------------
(UNAUDITED)
(DOLLARS IN THOUSANDS)
LONG-TERM DEBT(1):
Mortgage notes payable to the Federal Financing Bank (FFB) at interest rates varying from 5.20% to
8.43% (average rate of 6.87% at September 30, 1997), due in quarterly installments through 2023...... $ 2,472,601
Mortgage notes payable to the Rural Utilities Service (RUS) at an interest rate of 5%, due in monthly
installments through 2021............................................................................ 14,586
Mortgage notes issued in conjunction with the sale by public authorities of pollution control revenue
bonds (PCBs):
- Series 1992A
Serial bonds, 5.35% to 6.80%, due serially from 1998 to 2012..................................... 124,690
- Series 1993
Serial bonds, 3.75% to 5.25%, due serially from 1998 through 2013................................ 36,380
- Series 1993A
Adjustable tender bonds, 4.10%, due 2016(2)...................................................... 199,690
- Series 1993B
Serial bonds, 3.75% to 5.05%, due serially from 1998 through 2008................................ 126,935
- Series 1994
Serial bonds, 5.45% to 7.125%, due serially from 1998 through 2015............................... 10,035
Term bonds, 7.15%, due 2021...................................................................... 11,550
- Series 1994A
Adjustable tender bonds, 4.10%, due 2019(2)...................................................... 122,740
- Series 1994B
Serial bonds, 5.45% to 6.45%, due serially from 1998 through 2005................................ 11,140
- Series 1997A
Adjustable tender bonds, 3.60%, due December 1, 1997(3).......................................... 216,925
Unsecured notes issued in conjunction with the sale by public authorities of pollution control revenue
bonds:
- Series 1996
Adjustable rate bonds, 3.88% through October 1997, due in 2017................................... 37,885
CoBank, ACB notes payable:
- Headquarters note payable: fixed at 6.97% through October 1997, due in quarterly installments
through January 1, 2009........................................................................... 4,478
- Mortgage note payable: fixed at 6.50% through September 1997, due in bimonthly installments through
November 1, 2018.................................................................................. 1,847
- Mortgage note payable: fixed at 6.50% through October 1997, due in bimonthly installments through
September 1, 2019................................................................................. 7,070
------------
Total long-term debt................................................................................... 3,398,552
Less: Mortgage notes issued in conjunction with the sale by public authorities of PCBs assumed by
GTC.................................................................................................. (145,045)
------------
Total long-term debt, net.............................................................................. 3,253,507
Less: Long-term debt due within one year............................................................... (81,996)
------------
TOTAL LONG-TERM DEBT, EXCLUDING AMOUNT DUE WITHIN ONE YEAR............................................... 3,171,511
OTHER LONG-TERM LIABILITIES:
Obligation under capital leases, long-term............................................................. 289,825
Obligation under Rocky Mountain transactions, long-term................................................ 51,325
EQUITIES
Patronage capital and membership fees.................................................................. 321,771
------------
TOTAL CAPITALIZATION..................................................................................... $ 3,834,432
------------
------------
- --------------------------
(1) All notes secured under the Mortgage Indenture are designated as mortgage
notes. Reference is made to Note 5 of Notes to Financial Statements herein
for information as to maturities of Oglethorpe's long-term debt.
(2) Oglethorpe has entered into interest rate swap arrangements with respect to
these mortgage notes for the purpose of obtaining a fixed rate. The fixed
swap rate is 5.67% for the Series 1993A bonds and is 6.01% for the Series
1994A bonds.
(3) The Series 1997A bonds were refunded in October 1997 by Series 1997B bonds
due May 28, 1998. (See "MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS--Financial Condition--REFINANCING
TRANSACTIONS.")
35
MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
GENERAL
CORPORATE RESTRUCTURING
Oglethorpe and the Members completed the Corporate Restructuring on March
11, 1997, in which Oglethorpe was divided into three specialized operating
companies to respond to increasing competition and regulatory changes in the
electric industry. As part of the Corporate Restructuring, Oglethorpe's
transmission business was sold to, and is now owned and operated by, GTC.
Oglethorpe's system operations business was sold to, and is now owned and
operated by, GSOC. Oglethorpe continues to own and operate its power supply
business. Oglethorpe retained all of its owned and leased generation assets.
Oglethorpe also continues to administer its power purchase contracts and provide
marketing support functions to the Members. (See "BUSINESS OF
OGLETHORPE--Corporate Restructuring.")
MARGINS AND PATRONAGE CAPITAL
Oglethorpe operates on a not-for-profit basis and, accordingly, seeks only
to generate revenues sufficient to recover its cost of service and to generate
margins sufficient to establish reasonable reserves and meet certain financial
coverage requirements. Revenues in excess of current period costs in any year
are designated as net margin in Oglethorpe's statements of revenues and expenses
and patronage capital. Retained net margins are designated on Oglethorpe's
balance sheets as patronage capital, which is allocated to each of the Members
on the basis of its electricity purchases from Oglethorpe. Since its formation
in 1974, Oglethorpe has generated a positive net margin in each year.
Oglethorpe's equity ratio (patronage capital and membership fees divided by
total capitalization) increased from 7.0% at December 31, 1995 to 7.5% at
December 31, 1996 and to 8.4% at September 30, 1997.
In connection with the Corporate Restructuring, Oglethorpe made a $49
million special patronage capital distribution to the Members which was used by
the Members to establish equity in and to provide initial working capital to
GTC, resulting in a decrease in patronage capital from $356 million at December
31, 1996, to $322 million at September 30, 1997.
Patronage capital constitutes the principal equity of Oglethorpe. Any
distributions of patronage capital are subject to the discretion of the Board of
Directors. Under Oglethorpe's patronage capital retirement policy, margins are
to be returned to the Members 30 years after the year in which the margins are
earned. Pursuant to such policy, no patronage capital would be retired until
2010, at which time the 1979 patronage capital would be returned, subject to
Mortgage Indenture requirements.
Under the Mortgage Indenture, distributions of patronage capital are no
longer subject to the approval of RUS, but are subject to certain restrictions
set forth therein. Oglethorpe is prohibited by the Mortgage Indenture from
making any distribution of patronage capital to the Members if, at the time
thereof or after giving effect thereto, (i) an event of default exists under the
Mortgage Indenture, (ii) Oglethorpe's equity as of the end of the immediately
preceding fiscal quarter is less than 20% of Oglethorpe's total capitalization,
or (iii) the aggregate amount expended for distributions on or after the date on
which Oglethorpe's equity first reaches 20% of Oglethorpe's total capitalization
exceeds 35% of Oglethorpe's aggregate net margins earned after such date. This
last restriction, however, will not apply if, after giving effect to such
distribution, Oglethorpe's equity as of the end of the immediately preceding
fiscal quarter is not less than 30% of Oglethorpe's total capitalization.
36
RATES AND FINANCIAL COVERAGE REQUIREMENTS
Pursuant to the Wholesale Power Contracts, Oglethorpe is required to design
capacity and energy rates that generate sufficient revenues to recover all costs
as described in such contracts, to establish and maintain reasonable margins and
to meet its financial coverage requirements. Oglethorpe reviews its capacity
rates at least annually to ensure that its fixed costs are being adequately
recovered and, if necessary, adjusts its rates to meet its net margin goals.
Oglethorpe's energy rate is established to recover actual fuel and variable
operations and maintenance costs. Under the Mortgage Indenture, Oglethorpe's
rates are not subject to RUS approval except in limited circumstances.
The capacity rate applied by Oglethorpe throughout 1994 utilized a
proportional allocation of fixed costs based on the previous year's billing
demand for each Member. Consequently, the 1994 rate produced capacity revenues
which were virtually unaffected by 1994 factors. In 1995, Oglethorpe implemented
two additional capacity rate options in an effort to provide greater flexibility
to the Members. These options allocated fixed costs using billing determinants
of the current year. These rates produced differing monthly amounts of capacity
revenues throughout 1995 and introduced some variability and uncertainty as to
the level of revenues and margins to be received. Due to extreme weather
conditions and other factors, the 1995 rates options produced $2.5 million of
revenues in excess of budgeted amounts. Such excess amounts were returned to the
Members in 1996.
Under a capacity rate mechanism effective throughout 1996, each Member was
responsible for an assigned share of fixed costs based on an agreed-upon
allocation. Under this approach, capacity costs were collected in equal monthly
amounts. This interim rate mechanism was extended through March 31, 1997 until
the new rate schedule became effective under the Wholesale Power Contracts on
April 1, 1997. This new rate schedule implements on a long-term basis the
assignment of responsibility for fixed costs. The monthly charges for capacity
and other non-energy charges are based on a rate formula using the Oglethorpe
budget. Such capacity and other non-energy charges may be adjusted by the Board
of Directors, if necessary, during the year through an adjustment to the annual
budget. Energy charges are based on actual energy costs, whether incurred from
generation or purchased power resources or under the power marketing
arrangements.
Under the Mortgage Indenture, Oglethorpe is required, subject to any
necessary regulatory approval, to establish and collect rates which are
reasonably expected, together with other revenues of Oglethorpe, to yield an MFI
Ratio for each fiscal year equal to at least 1.10. MFI Ratio is determined by
dividing the sum of (i) Oglethorpe's net margins (after certain defined
adjustments), (ii) Interest Charges and (iii) any amount included in net margins
for accruals for federal or state income taxes by Interest Charges. The
definition of MFI takes into account any item of net margin, loss, gain or
expenditure of any affiliate or subsidiary of Oglethorpe only if Oglethorpe has
received such net margins or gains as a dividend or other distribution from such
affiliate or subsidiary or if Oglethorpe has made a payment with respect to such
losses or expenditures.
The rate schedule also includes a PPA mechanism designed to ensure that
Oglethorpe achieves the minimum 1.10 MFI Ratio. The PPA provides for the
retention of margins within a range from a 1.10 MFI Ratio to a 1.20 MFI Ratio.
Amounts, if any, by which Oglethorpe fails to achieve a minimum 1.10 MFI Ratio
would be accrued as of December 31 of the applicable year and collected from the
Members during the period April through December of the following year. Amounts,
if any, by which Oglethorpe exceeds the maximum 1.20 MFI Ratio would be charged
against revenues as of December 31 of the applicable year and refunded to the
Members during the period April through December of the following year. The rate
schedule formula is intended to provide for the collection of revenues which,
together with revenues from all other sources, are equal to all costs and
expenses recorded by Oglethorpe, plus amounts necessary to achieve at least the
minimum 1.10 MFI Ratio. (See "BUSINESS OF OGLETHORPE--Electric Rates.")
37
The MFI Ratio requirement went into effect upon the substitution of the
Mortgage Indenture for the prior RUS Mortgage. For comparative purposes only,
the pro forma MFI Ratio for 1996 would have been 1.09. Oglethorpe's rates are
now set to meet an MFI Ratio of 1.10 on an annual basis.
Prior to 1997, Oglethorpe utilized a Times Interest Earned Ratio ("TIER") as
the basis for establishing its annual net margin goal. The RUS Mortgage required
Oglethorpe to implement rates that were designed to maintain an annual TIER of
not less than 1.05. Oglethorpe's Board of Directors set an annual net margin
goal to be the amount required to produce a TIER of 1.07 in 1994 through 1996.
In addition to the TIER requirement under the RUS Mortgage, Oglethorpe was also
required under the RUS Mortgage to implement rates designed to maintain a Debt
Service Coverage Ratio ("DSC") of not less than 1.0 and an Annual Debt Service
Coverage Ratio ("ADSCR") of not less than 1.25. Oglethorpe always met or
exceeded the TIER, DSC and ADSCR requirements of the RUS Mortgage. (See
"BUSINESS OF OGLETHORPE--Electric Rates.")
TIER is determined by dividing the sum of Oglethorpe's net margin plus
interest on long-term debt (including interest charged to construction) by
Oglethorpe's interest on long-term debt (including interest charged to
construction). DSC is determined by dividing the sum of Oglethorpe's net margin
plus interest on long-term debt (including interest charged to construction)
plus depreciation and amortization (excluding amortization of nuclear fuel and
debt discount and expense) by Oglethorpe's interest and principal payable on
long-term debt (including interest charged to construction). ADSCR is determined
by dividing the sum of Oglethorpe's net margin plus interest on long-term debt
(excluding interest charged to construction) plus depreciation and amortization
(excluding amortization of nuclear fuel and debt discount and expense) by
Oglethorpe's interest and principal payable on long-term debt secured under the
RUS Mortgage (excluding interest charged to construction).
RESULTS OF OPERATIONS
HISTORICAL FACTORS AFFECTING FINANCIAL PERFORMANCE
Oglethorpe has utilized both long-term contractual arrangements with GPC and
a rate mechanism utilizing deferred margins to allow for a gradual absorption of
costs of generating plants into rates over several years. As of May 31, 1995,
Oglethorpe's Members have fully absorbed into rates additional responsibility
for the cost of its ownership interests in Plant Vogtle Units No. 1 and No. 2,
and as of December 31, 1996, Oglethorpe's Members have fully absorbed into rates
the costs of Rocky Mountain.
Contractual arrangements with GPC provided that Oglethorpe sell to GPC a
declining percentage of Oglethorpe's entitlement to the capacity and energy of
certain co-owned generating plants during the initial seven to ten years of
operation of such units (the "GPC Sell-back"). As of May 31, 1995, the GPC
Sell-back expired for all units. The historical ability of Oglethorpe to sell
power from new units to GPC under the GPC Sell-back enabled Oglethorpe to
moderate the effects of the higher costs associated with new generating units on
Oglethorpe's cost of service and, therefore, on the rates charged to Members.
Furthermore, the GPC Sell-back enabled Oglethorpe to obtain the generating
capacity needed to serve anticipated increases in Member loads while minimizing
the risks and costs of excess generating capacity.
Prior to the completion of the first unit of Plant Vogtle in 1987,
Oglethorpe's Board of Directors implemented policies that resulted in the
gradual absorption of the costs of Plant Vogtle by the Members. In each of the
years 1985 through 1995, Oglethorpe exceeded its net margin goal. The Board
adopted resolutions in each of these years requiring that these excess margins
be retained and used to mitigate rate increases associated with Plant Vogtle
and, subsequently, with Rocky Mountain. In each year beginning with 1989, a
portion of these margins was returned to the Members through billing credits.
(See Note 1 of Notes to Financial Statements.) As of December 31, 1996, all
amounts previously retained have been returned to the Members and this rate
mechanism ended.
38
CORPORATE RESTRUCTURING
As a result of the Corporate Restructuring, the Condensed Statements of
Revenues and Expenses for the twelve months ended September 30, 1997 reflect
operations as a combined power supply, transmission and system operations
company through March 31, 1997, and operations solely as a power supply company
thereafter. Although the Corporate Restructuring was completed on March 11,
1997, pursuant to the restructuring agreement among Oglethorpe, GTC and GSOC,
all transmission-related and systems operations-related revenues were assigned
to Oglethorpe, and all transmission-related and systems operations-related costs
were paid or reimbursed by Oglethorpe during the period March 11, 1997 through
March 31, 1997. Decreases in operating revenues, power delivery expenses,
depreciation and amortization, taxes other than income taxes, operating margin
and net interest charges from 1996 to 1997 are primarily attributable to the
Corporate Restructuring.
POWER MARKETER ARRANGEMENTS
Oglethorpe is utilizing long-term power marketer arrangements to reduce the
cost of power to the Members. Oglethorpe has entered into power marketer
agreements with LEM effective January 1, 1997, for approximately 50% of the load
requirements of the Members and with Morgan Stanley, effective May 1, 1997, with
respect to 50% of the Members' forecasted load requirements. The LEM agreements
are based on the actual requirements of the Members during the contract term,
whereas the Morgan Stanley agreement represents a fixed supply obligation. Under
these power marketer agreements, Oglethorpe purchases energy at fixed prices
covering a portion of the costs of energy to its Members. LEM and Morgan
Stanley, in turn, have certain rights to market excess energy from the
Oglethorpe system. All of Oglethorpe's existing generating facilities and power
purchase arrangements are available for use by LEM and Morgan Stanley for the
term of the respective agreements. Oglethorpe continues to be responsible for
all of the costs of its system resources but receives revenue from LEM and
Morgan Stanley for the use of the resources. (See "MEMBER REQUIREMENTS AND POWER
SUPPLY RESOURCES--General" and "--Power Marketer Arrangements.")
Oglethorpe utilized short-term power marketer arrangements during 1996. The
initial agreement was with Enron Power Marketing, Inc. ("EPMI") and was in place
January through August. From September through December 1996, another power
marketer arrangement was utilized with Duke/Louis Dreyfus L.L.C. ("DLD"). Under
each of the agreements, the power marketer was required to provide to Oglethorpe
at a favorable fixed rate all the energy needed to meet the Members'
requirements and Oglethorpe was required to provide to the power marketer at
cost, subject to certain limitations, upon request, all energy available from
Oglethorpe's total power resources. Under both agreements, Oglethorpe continued
to operate the power supply system and continued to dispatch the generating
resources to ensure system reliability.
OPERATING REVENUES
Oglethorpe's operating revenues are derived from sales of electric services
to the Members and non-Members. Revenues from Members are collected pursuant to
wholesale power contracts and are a function of the demand for power by the
Members' consumers and Oglethorpe's cost of service. (See "OPERATING EXPENSES"
herein.) Historically, most of Oglethorpe's non-Member revenues resulted from
various plant operating agreements with GPC as discussed below. However, in
recent years, an increasing amount of non-Member revenues has been derived by
off-system sales to other utilities and power marketers. Although total revenues
have only varied slightly from January 1, 1994 to September 30, 1997, the
scheduled reduction of the GPC Sell-back has resulted in the planned decrease of
non-Member revenues from GPC of about $45 million. As expected, the capacity and
energy no longer being sold to GPC have been used by Oglethorpe to meet
increased Member requirements.
In addition to increasing sales to Members, Oglethorpe achieved reductions
in fixed and operating costs, which mitigate the need to recover from the
Members costs which were previously recovered through sales to GPC. The
refinancing transactions discussed under "Financial Condition--REFINANCING
TRANSACTIONS" herein resulted in a reduction in gross interest charges from $330
million in 1994 to $308
39
million in 1996, or a 7% decrease in that fixed cost component of the capacity
rates. Gross interest charges decreased in the twelve months ended September 30,
1997 to $275 million primarily as a result of the debt assumed by GTC in
connection with the Corporate Restructuring.
SALES TO MEMBERS. Revenues from sales to Members decreased by 0.4% for the
twelve months ended September 30, 1997 compared to the year ended December 31,
1996, decreased by 0.7% in 1996 compared to 1995 and increased 10.7% in 1995
compared to 1994. These changes reflect both cost-related and volume-related
factors. For the twelve months ended September 30, 1997 compared to the year
1996, capacity revenues decreased by $68 million primarily as a result of the
transfer of the transmission business in connection with the Corporate
Restructuring. This decrease in capacity revenues was offset by a $69 million
increase in energy revenues primarily because the short-term power marketer
arrangements with DLD and EPMI allowed Oglethorpe to pass through significant
savings during the first nine months of 1996 (see the discussion of purchased
power under "OPERATING EXPENSES" herein). The 1996 revenues decreased compared
to 1995 due to the pass-through of savings in energy costs, which more than
offset higher capacity revenue requirements and the effect of increased amounts
of energy sold. The increase in revenues between 1995 and 1994 was due to higher
capacity revenue requirements and additional amounts of energy sold, which more
than offset savings in energy costs (see the discussion of savings in fuel and
purchased power costs under "OPERATING EXPENSES" herein).
As non-Member revenues from GPC have declined, Oglethorpe's Member capacity
revenues have increased to reflect the recovery of the fixed costs which had
previously been recovered from GPC through the GPC Sell-back. (See the
discussion of this type of revenues under "OPERATING REVENUES-- SALES TO
NON-MEMBERS" herein.) Member capacity revenues in 1996 and 1995 were also
affected by additional fixed costs related to the commercial operation of Rocky
Mountain beginning in June 1995. Since April 1, 1997, Member capacity revenues
have declined due to the reduced level of fixed costs to be recovered from the
Members by Oglethorpe relating to the transmission business transferred to GTC
in connection with the Corporate Restructuring.
The energy portion of Member revenues per kWh increased 23.7% in the twelve
months ended September 30, 1997 compared to 1996, declined 13.2% in 1996
compared to 1995 and declined 7.6% in 1995 compared to 1994. Actual energy costs
are passed through to the Members such that energy revenues equal energy costs.
The increase in the twelve months ended September 30, 1997 resulted from the $69
million increase in net energy costs discussed above. The decrease in 1996
resulted from savings of approximately $32 million in energy costs (compared to
budget) achieved under the power marketer arrangements in effect during 1996. In
1995, the decrease reflected savings in fuel and production costs and lower
average purchased power costs.
The following table summarizes the amounts of kWh sold to Members and
revenues per kWh during each of the past three years and the twelve months ended
September 30, 1997:
CENTS PER
KILOWATT-HOURS KILOWATT-HOUR
-------------- -----------------
(IN THOUSANDS)
Twelve Months
Ended September 30, 1997.................. 20,148,077 5.03 CENTS(1)
1996........................................ 19,807,101 5.11
1995........................................ 18,442,153 5.53
1994........................................ 16,285,127 5.65
- ------------------------
(1) Excludes revenues related to the transmission business effective April 1,
1997.
Member sales have been affected by weather conditions during the twelve
months ended September 30, 1997 and during two of the prior three years. In
spite of mild weather in 1997, kWh sales to Members increased by 1.7% compared
to 1996. Member sales increased 7.4% in 1996 despite a
40
summer in which temperatures were lower than 1995, due to continued growth in
the Member systems' service territories. In 1995, prolonged hot weather
increased sales, while in 1994 record-breaking rainfall amounts statewide
moderated Member sales.
SALES TO NON-MEMBERS. Sales of electric services to non-Members were
primarily made pursuant to contractual arrangements with GPC and from energy
sales to other utilities and power marketers. The following table summarizes the
amounts of non-Member revenues from these sources for the past three years and
the twelve months ended September 30, 1997:
TWELVE MONTHS
ENDED
SEPTEMBER 30, 1997 1996 1995 1994
--------------------- --------- --------- ---------
(DOLLARS IN THOUSANDS)
GPC--plant operating agreements.... $ -- $ -- $ 10,096 $ 45,392
GPC--power supply arrangements..... 15,678 13,703 43,226 26,280
ITS transmission agreements........ 5,095 9,789 12,614 10,974
Sales to power marketers........... 10,557 15,895 -- --
Sales to other utilities........... 19,053 38,956 52,828 42,561
-------- --------- --------- ---------
Total.............................. $ 50,383 $ 78,343 $ 118,764 $ 125,207
-------- --------- --------- ---------
-------- --------- --------- ---------
Revenues from sales to non-Members declined in the twelve months ended
September 30, 1997 compared to the year ended December 31, 1996, in 1996
compared to 1995 and in 1995 compared to 1994. The first source of non-Member
revenue was plant operating agreements with GPC. The elimination of the revenues
from the plant operating agreements was due to the scheduled conclusion,
effective June 1, 1995, of the GPC Sell-back with respect to Plant Vogtle.
The second source of non-Member revenues was power supply arrangements with
GPC. These revenues were derived, for the most part, from energy sales arising
from dispatch situations whereby GPC caused co-owned coal-fired generating
resources to be operated when Oglethorpe's system did not require all of its
contractual entitlement to the generation. These revenues compensated Oglethorpe
for its costs because, under the operating agreements (before the agreements
were recently amended as discussed below), Oglethorpe was responsible for its
share of fuel costs any time a unit operated. Revenues from sales of this type
to GPC were higher in the twelve months ended September 30,1997 compared to
1996, lower in 1996 compared to 1995 and were higher in 1995 compared to 1994.
In 1997, the power marketers and Oglethorpe retained less of the output from
Plant Wansley than in 1996. In 1996, the power marketers elected to retain more
of the output from Plant Wansley than in 1995. In 1995, Oglethorpe retained less
of its share of the output from Plant Wansley units than in 1994 because the
added cost associated with emission allowances made those units less attractive
than certain purchased resources. The 1994 revenues reflect that Oglethorpe
retained much of its share of the output from Plant Scherer and Plant Wansley
units because the lower average fuel costs made those units more attractive than
certain purchased resources. Emission allowances for Plant Wansley were not
required in 1994. (See the discussion under "OPERATING EXPENSES" below of the
lower average fuel costs of the coal-fired generating units in 1996 and 1995.)
Pursuant to the amendments to the Plant Scherer ownership and operating
agreements, Oglethorpe elected to separately dispatch its ownership interest in
Plant Scherer beginning May 1, 1994. Thereafter, Plant Scherer ceased to be a
source of this type of sales transaction. Pursuant to similar amendments to the
Plant Wansley operating agreement, Oglethorpe began separately dispatching its
ownership interest in Plant Wansley beginning May 1, 1997; therefore, this type
of sale to GPC has ended.
The third source of non-Member revenues was primarily payments from GPC for
use of the ITS and related transmission interfaces. GPC compensated Oglethorpe
to the extent that Oglethorpe's percentage of investment in the ITS exceeded its
percentage use of the system. In such case, Oglethorpe was
41
entitled to compensation for the use of its investment by the other ITS
participants. As a result of the Corporate Restructuring, all of the revenues in
this category have accrued to GTC since April 1, 1997. The change in revenues
for 1996 through 1994 resulted from normal variations of Oglethorpe's investment
percentages and its use of the system.
Under the LEM and Morgan Stanley power marketer arrangements, and
previously, under the EPMI and DLD power marketer arrangements, sales to the
power marketers represented the net energy transmitted on behalf of LEM, Morgan
Stanley, EPMI and DLD off-system on a daily basis from Oglethorpe's total
resources. Such energy was sold to LEM, EPMI and DLD at Oglethorpe's cost,
subject to certain limitations, and to Morgan Stanley at a contractually fixed
price. The volume of sales to power marketers depends primarily on the power
marketers' decisions for servicing their load requirements.
Sales to other utilities in the twelve months ended September 30, 1997
represent sales made directly by Oglethorpe. Oglethorpe sells for its own
account any energy available from the portion of its resources dedicated to
Morgan Stanley that is not scheduled by Morgan Stanley pursuant to its power
marketer arrangements. (See "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--
Power Marketer Arrangements--MORGAN STANLEY AGREEMENT.") Sales to other
utilities were initiated by EPMI and DLD in 1996. In 1996, where the power
marketer did not have a contractual relationship with the purchaser and
Oglethorpe did, Oglethorpe recorded the sale and credited the revenues to the
power marketer in its monthly billing. In 1995 and 1994, these sales were made
by Oglethorpe directly to other utilities.
OPERATING EXPENSES
Oglethorpe's operating expenses decreased 0.8% in the twelve months ended
September 30, 1997 compared to 1996, decreased 2.6% in 1996 compared to 1995 and
increased 9.4% in 1995 compared to 1994. The overall decrease in operating
expenses for 1997 compared to 1996 was primarily attributable to the expenses
relating to the transmission business assumed by GTC in connection with the
Corporate Restructuring. However, the decrease in fuel expense and the increase
in production operations and maintenance costs were unaffected by the Corporate
Restructuring. The decrease in operating expenses in 1996 compared to 1995 was
primarily attributable to energy cost savings achieved under the short-term
power marketer arrangements offset somewhat by an increase in depreciation and
amortization. The increase in operating expenses in 1995 compared to 1994 was
primarily attributable to a 13% increase in kWhs sold to Members and
non-Members. In addition, depreciation and amortization, sales, and
administrative and general expenses were also higher.
Fuel costs decreased in the twelve months ended September 30, 1997 partly as
a result of lower generation and partly as a result of the difference in the mix
of generation, with more nuclear and less fossil generation. Fossil generation
decreased primarily due to a maintenance outage during February and March 1997
at Scherer Unit No. 1. The higher nuclear generation during the twelve months
ended September 30, 1997 compared to 1996 was achieved as a result of having
three refueling outages in 1996 compared to two in the twelve months ended
September 30, 1997. Conversely, the increase in production operations and
maintenance costs was partly attributable to the maintenance outage at Scherer
Unit No. 1. In addition, effective January 1, 1996, the costs of nuclear
refueling outages are deferred and amortized over the 18-month period following
the outage. Such change in accounting resulted in a $12.9 million deferral of
maintenance costs in 1996 in relation to the comparable period of 1997. The
decrease in total fuel costs in 1996 as compared to 1995 resulted partly from
unplanned outages at Plant Scherer and Plant Wansley Unit No. 1 and partly from
the power marketer electing to dispatch the fossil units less. These factors
resulted in 3.1% lower fossil generation in 1996 compared to 1995. The increase
in total fuel costs in 1995 versus 1994 resulted from 23% higher generation at
Plant Scherer. The continued use of lower-priced western coal combined with a
greater reliance on a favorable spot market for coal resulted in a per unit fuel
cost decrease for Plant Scherer of 5% in 1995 from 1994 levels. Because of the
decline in fuel cost per kWh at Plant Scherer, the usage of the units increased
42
significantly. Oglethorpe retained significantly less of its output from Plant
Wansley in 1995 compared to 1994 primarily as a result of relatively higher
costs compared to Plant Scherer due to its emission allowance requirement and
due to cost reductions at Plant Scherer discussed above.
Purchased power cost increased 11.3% in the twelve months ended September
30, 1997 compared to 1996. A total of 3.9% fewer megawatt-hours ("MWhs") were
purchased in the twelve months ended September 30, 1997 compared to 1996.
Consequently, average purchased power cost increased by 15.9%. As noted below,
significant energy cost savings were realized in 1996 from the EPMI and DLD
power marketer arrangements. Purchased power cost decreased by 14% in 1996
compared to 1995 and increased by 16% in 1995 compared to 1994. Lower purchased
power costs were achieved in 1996 despite the 15% increase in energy purchases
in 1996 from 1995 levels. The 1996 cost reduction was due to (1) energy cost
savings of $32 million realized from the short-term power marketer arrangements
and (2) reductions in purchased power capacity costs due to (a) proceeds of
$10.8 million from the settlement of a lawsuit with GPC and (b) savings
resulting from the elimination effective September 1, 1996, of a 250 MW
component block (coal-fired units) of the Block Power Sale Agreement between
Oglethorpe and GPC (the "BPSA"). In 1995, the 13% higher kWh sales, including
the increased Member sales and sales to GPC pursuant to power supply
arrangements (see the discussion under "OPERATING REVENUES" above), resulted in
higher utilization of purchased power resources. Energy purchases increased 31%
in 1995 compared to 1994.
Purchased power expenses for the year 1994 compared to the twelve months
ended September 30, 1997 reflect the cost of capacity and energy purchases under
various long-term power purchase agreements. These long-term agreements have, in
some cases, take-or-pay minimum energy requirements. For 1994 through September
30, 1997, Oglethorpe utilized its energy from these purchase power agreements in
excess of the take-or-pay requirements. Oglethorpe's power purchases from these
agreements amounted to approximately $173 million in 1997, $191 million in 1996,
$207 million in 1995 and $183 million in 1994. (For a discussion of the power
purchase agreements, see Note 9 of Notes to Financial Statements.) The increase
in depreciation and amortization in 1996 was partly due to a full year of
depreciation on Rocky Mountain which began commercial operation in June 1995 and
to $14 million of Board- approved accelerated amortization of deferred charges
of the discontinued Pickens County pumped storage hydroelectric project. All
remaining unamortized charges related to this project were expensed in 1996.
The decrease in other operating expenses for the twelve months ended
September 30, 1997 compared to 1996 was due primarily to the transfer of
administrative and general expenses relating to the transmission and system
operations business in connection with the Corporate Restructuring. Sales,
administrative and general expenses increased in 1995 as compared to 1994
primarily resulting from increased marketing efforts in support of the Members.
OTHER INCOME
Interest income increased for the twelve months ended September 30, 1997
compared to 1996, 1996 compared to 1995 and 1995 compared to 1994. Interest
income was higher in the twelve months ended September 30, 1997 as a result of
higher earnings from the decommissioning fund and partly due to income from the
deposits from the Rocky Mountain transactions. The deposits were made in
December 1996 and January 1997. In 1996, interest income was higher due to
higher average investment balances. In 1995, interest income increased partly
due to higher short-term interest rates and due to higher investment returns in
the decommissioning trust fund.
43
In 1996, Oglethorpe utilized all remaining amounts available ($32 million)
under its deferred margin rate mechanism, and, as scheduled, this mechanism
ended. Likewise, deferred margins of $16 million and $18 million were amortized
as credits against Member revenue requirements in 1995 and 1994, respectively,
to mitigate the rate impact of increased capacity costs related to Plant Vogtle
and Rocky Mountain. Also, in 1995 and 1994, Oglethorpe's Board of Directors
authorized the retention of approximately $14 million and $9 million,
respectively, in excess of the 1.07 TIER margin requirement as deferred margins
under the mechanism. (See Note 1 of Notes to Financial Statements for a
discussion of deferred margins and amortization of deferred margins.) The
decrease in amortization of deferred gains in 1996 and 1995 as compared to 1994
resulted from the completion of amortization in September 1994 of a gain on the
sale of Plant Scherer common facilities. (Also see Note 1 of Notes to Financial
Statements for a discussion of the sale.)
INTEREST CHARGES
Net interest charges for the twelve months ended September 30, 1997
decreased compared to 1996 primarily due to the debt assumed by GTC in
connection with the Corporate Restructuring. Net interest charges increased in
1996 compared to 1995 and in 1995 compared to 1994. The increases were due to
the decrease in allowance for debt funds used during construction ("AFUDC") in
1996 compared to 1995 and 1995 compared to 1994 as a result of the three units
of Rocky Mountain becoming commercially operable in June and July 1995. The
continued decrease in gross interest on long-term debt and capital leases in
1996 and 1995 was due to the refinancing efforts discussed under "Financial
Condition--REFINANCING TRANSACTIONS" below. The increase in other interest
expense in 1995 compared to 1994 was due to higher investment returns in the
decommissioning trust fund. (See Note 1 of Notes to Financial Statements for
explanation of Oglethorpe's accounting for decommissioning gains and losses.)
NET MARGIN
Net margin for the twelve months ended September 30, 1997 was $9.6 million
compared to $21.8 million for 1996. This decrease in net margin was the result
of certain nonrecurring expenses and capacity revenue adjustments reflected in
the fourth quarter of 1996. As noted above, the accelerated amortization of
deferred charges of the discontinued Pickens County pumped storage hydroelectric
project and other rate making adjustments resulted in a net loss for the quarter
of $4.5 million. After reflecting these fourth quarter adjustments, 1996 net
margin was consistent with the TIER margin requirement. For calendar
year-to-date 1997, net margin of $14.1 million is currently sufficient to meet
the MFI margin requirements. Oglethorpe has always met or exceeded its margin
requirements.
FINANCIAL CONDITION
GENERAL
The principal changes in Oglethorpe's financial condition from January 1,
1996 to September 30, 1997, were due to property additions, reductions in the
cost of capital and a special patronage capital distribution. Property additions
totaled $94 million and $74 million, respectively, for the year ended December
31, 1996 and twelve months ended September 30, 1997. These property additions
were funded primarily with funds from operations.
A decrease in the cost of capital was achieved through the refinancing of
$106 million of long-term debt during 1996 and the prepayment of an additional
$116 million of long-term debt in March 1997. The average interest rate on
long-term debt decreased from 6.76% at December 31, 1995 to 6.56% at December
31, 1996, and further to 6.43% at September 30, 1997. (For a further discussion
of the refinancing transactions, see "REFINANCING TRANSACTIONS" and "ROCKY
MOUNTAIN LEASE TRANSACTIONS" herein.)
44
Finally, Oglethorpe's equity was reduced by $49 million due to a special
patronage capital distribution made to the Members in conjunction with the
Corporate Restructuring.
CAPITAL REQUIREMENTS
As part of its ongoing capital planning, Oglethorpe forecasts expenditures
required for generation facilities and other capital projects. The table below
details these expenditure forecasts for 1998 through 2000. Actual construction
costs may vary from the estimates listed below because of factors such as
changes in business conditions, fluctuating rates of load growth, environmental
requirements, design changes and rework required by regulatory bodies, delays in
obtaining necessary federal and other regulatory approvals, construction delays,
and cost of capital, equipment, material and labor.
CAPITAL EXPENDITURES
GENERATING NUCLEAR GENERAL
YEAR PLANT(1) FUEL PLANT AFUDC(2) TOTAL
- ---------------------------------- ----------- --------- ----------- ----------- ---------
(DOLLARS IN THOUSANDS)
1998.............................. $ 15,303 $ 35,337 $ 1,940 $ 1,290 $ 53,870
1999.............................. 13,147 33,301 1,875 1,800 50,123
2000.............................. 10,916 39,780 1,931 1,800 54,427
----------- --------- ----------- ----------- ---------
Total............................. $ 39,366 $ 108,418 $ 5,746 $ 4,890 $ 158,420
----------- --------- ----------- ----------- ---------
----------- --------- ----------- ----------- ---------
- ------------------------
(1) Consists of capital expenditures required for replacements and additions to
facilities in service and compliance with environmental regulations.
(2) Allowance for funds used during construction of generation and general plant
facilities.
Currently, Oglethorpe does not have any new generation facilities under
construction, and management does not anticipate the need for construction of
any new capacity well into the future. (See "MEMBER REQUIREMENTS AND POWER
SUPPLY RESOURCES--Future Power Resources.")
Oglethorpe's investment in electric plant, net of depreciation, was
approximately $3.6 billion as of September 30, 1997 and $4.4 billion as of
December 31, 1996. The reduction in net plant was primarily due to the transfer
of assets to GTC and GSOC in connection with the Corporate Restructuring.
Expenditures for property additions during 1996 amounted to $94 million, of
which $91 million was provided from operations. These expenditures were
primarily for additions and replacements to generation and transmission
facilities.
In addition to the funds needed for capital expenditures, approximately $286
million will be required over the next three years (1998-2000) for current
sinking fund requirements and maturities of long-term debt. Of this amount, $221
million, or 77%, relates to the repayment of RUS and FFB debt. Excluded from
these amounts is the amount of debt assumed by GTC and GSOC as part of the
Corporate Restructuring. (See "BUSINESS OF OGLETHORPE--Corporate Restructuring"
and Note 5 of Notes to Financial Statements for further discussion regarding
long-term debt maturities.)
LIQUIDITY AND SOURCES OF CAPITAL
In the past, Oglethorpe has obtained the majority of its long-term financing
from RUS-guaranteed loans funded by FFB. Oglethorpe has also obtained a
substantial portion of its long-term financing requirements from tax-exempt
PCBs.
In addition, Oglethorpe's operations have consistently provided a sizable
contribution to its funding of capital requirements, such that internally
generated funds have provided interim funding or long-term
45
capital for nuclear fuel reloads, new generation, transmission and general plant
facilities, replacements and additions to existing facilities, and retirement of
long-term debt. Oglethorpe anticipates that it will meet its future capital
requirements through 2000 primarily with funds generated from operations and, if
necessary, with short-term borrowings.
To meet short term cash needs and liquidity requirements, Oglethorpe had, as
of September 30, 1997, (i) approximately $60 million in cash and temporary cash
investments, (ii) $96 million in other short term investments and (iii) up to
$300 million total available under the following credit facilities ($92 million
of which was in use):
SHORT-TERM CREDIT FACILITIES AMOUNT
- ------------------------------------------------------------- -------------
Commercial Paper............................................. $ 250,000,000
Committed lines of credit:
SunTrust................................................... $ 30,000,000
Uncommitted lines of credit:
CFC........................................................ $ 50,000,000
Under its commercial paper program, Oglethorpe may issue commercial paper
not to exceed $250 million outstanding at any one time. The commercial paper is
backed 100% by committed lines of credit provided by a group of banks for which
SunTrust acts as agent. The maximum amount that can be outstanding at any one
time under the commercial paper program and the other lines of credit totals
$300 million due to certain restrictions contained in the SunTrust committed
line of credit agreement. Oglethorpe expects this maximum amount to increase in
December 1997 to $330 million due to a $30 million increase in the amount of its
commercial paper program. As of September 30, 1997, $92 million of commercial
paper was outstanding which was issued to fund the defeasance of certain PCBs in
conjunction with the Corporate Restructuring. (See "REFINANCING TRANSACTIONS"
below for a further discussion of this defeasance.)
REFINANCING TRANSACTIONS
Over the past few years, Oglethorpe has implemented a program to reduce its
interest costs by refinancing a sizable portion of its high-interest rate PCB
and FFB debt. Since the first transaction was completed in June 1992, Oglethorpe
has refinanced $1.1 billion in PCB debt and $1.2 billion in FFB debt. Oglethorpe
has also prepaid another $222 million of FFB debt, including a prepayment of $92
million of FFB debt on March 13, 1997 in connection with the Rocky Mountain
transactions described herein and a prepayment of $25 million of FFB debt on
April 1, 1997 in connection with the Corporate Restructuring. (See Note 5 of
Notes to Financial Statements.) The net result of these transactions has been to
reduce the average interest rate on Oglethorpe's total long-term debt from 8.83%
at December 31, 1991 to 6.43% at September 30, 1997.
In connection with the Corporate Restructuring, Oglethorpe defeased
approximately $92 million in principal amount of Series 1992 PCBs. Initially
these bonds have been defeased through the issuance of commercial paper.
Oglethorpe expects to refinance the commercial paper issuance with medium-term
notes or PCBs at some point in the future.
Also, in connection with the Corporate Restructuring, Oglethorpe refinanced
approximately $217 million in principal amount of Series 1992A PCBs through the
issuance of refunding bonds having a nine-month maturity (the "Series 1997A
Bonds"), which were in turn refunded through the issuance of bonds maturing on
May 28, 1998 (the "Series 1997B Bonds"). Payment of principal and interest on
the Series 1997B Bonds is insured by a municipal bond insurance policy issued by
Ambac Assurance Corporation. Oglethorpe is required by Ambac Assurance
Corporation to maintain liquidity during the term of the Series 1997B Bonds in
an amount equal to $222 million. Oglethorpe expects to refund the Series 1997B
Bonds through the issuance of long-term bonds.
46
INTEREST RATE SWAP TRANSACTIONS
To refinance high-interest rate PCBs, Oglethorpe entered into two interest
rate swap transactions with a swap counterparty, AIG Financial Products Corp.
("AIG-FP"), which were designed to create a contractual fixed rate of interest
on $322 million of variable rate PCBs. These transactions were entered into in
early 1993 on a forward basis, pursuant to which approximately $200 million of
variable rate PCBs were issued on November 30, 1993 and approximately $122
million of variable rate PCBs were issued on December 1, 1994. Oglethorpe is
obligated to pay the variable interest rate that accrues on these PCBs; however,
the swap arrangements provide a mechanism for Oglethorpe to achieve a
contractual fixed rate which is lower than Oglethorpe would have obtained had it
issued fixed rate bonds. Oglethorpe's use of financial derivatives is for the
purpose of mitigating business risks and is not for speculative purposes.
Oglethorpe's use of derivatives is limited to these two swap transactions.
In connection with GTC's assumption of liability on a portion of the PCBs
pursuant to the Corporate Restructuring, commencing April 1, 1997, GTC assumed
and agreed to pay 16.86% of any amounts due from Oglethorpe under these swap
arrangements, including the net swap payments and termination payments described
below. Should GTC fail to make such payments under the assumption, Oglethorpe
remains obligated for the full amount of such payments.
Under the swap arrangements, Oglethorpe is obligated to make periodic
payments to AIG-FP based on a notional principal amount equal to the aggregate
principal amount of the bonds outstanding during the period and a contractual
fixed rate ("Fixed Rate"), and AIG-FP is obligated to make periodic payments to
Oglethorpe based on a notional principal amount equal to the aggregate principal
amount of the bonds outstanding during the period and a variable rate equal to
the variable rate of interest accruing on the bonds during the period ("Variable
Rate"). These payment obligations are netted, such that if the Variable Rate is
less than the Fixed Rate, Oglethorpe makes a net payment to AIG-FP. Likewise, if
the Variable Rate is higher than the Fixed Rate, Oglethorpe receives a net
payment from AIG-FP. Thus, although changes in the Variable Rate affect whether
Oglethorpe is obligated to make payments to AIG-FP or is entitled to receive
payments from AIG-FP, the effective interest rate Oglethorpe pays with respect
to the PCBs is not affected by changes in interest rates. The Fixed Rate for the
$200 million of variable rate bonds issued in 1993 is 5.67% and the Fixed Rate
for the $122 million of variable rate bonds issued in 1994 is 6.01%. For the
three years ended December 31, 1994, 1995 and 1996, Oglethorpe has made in
connection with both interest rate swap arrangements combined net swap payments
to AIG-FP of $6.0 million, $6.4 million and $8.2 million, respectively.
The swap arrangements extend for the life of these PCBs. If the swap
arrangements were to be terminated while the PCBs are still outstanding,
Oglethorpe or AIG-FP may owe the other party a termination payment depending on
a number of factors, including whether the fixed rate then being offered under
comparable swap arrangements is higher or lower than the Fixed Rate. Under the
terms of the swap agreements, AIG-FP has limited rights to terminate the swaps
only upon the occurrence of specified events of default or a reduction in
ratings on Oglethorpe's PCBs, without credit enhancement, to a level that is
below investment grade. Oglethorpe estimates that its maximum aggregate
liability (net of GTC's assumed percentage) for termination payments under both
swap arrangements had such payments been due on September 30, 1997 would have
been approximately $31 million.
In connection with these interest rate swap arrangements, Oglethorpe (but
not GTC) is obligated to maintain minimum liquidity in an amount equal to 25% of
the principal amount of the variable rate refunding bonds outstanding. As of
September 30, 1997, the minimum liquidity requirement equaled $81 million and
will decrease proportionately as such bonds are retired as a result of scheduled
sinking fund payments.
ROCKY MOUNTAIN LEASE TRANSACTIONS
Oglethorpe completed, in two separate closings on December 31, 1996 and
January 3, 1997, lease transactions for its 74.61% undivided ownership interest
in Rocky Mountain. Under the terms of these
47
transactions, Oglethorpe leased the facility to three institutional investors
for the useful life of the facility, who in turn leased it back to Oglethorpe
for a term of 30 years. Rocky Mountain is subject to the lien of the Mortgage
Indenture. The leasehold interest transferred is subject and subordinate to such
lien. Oglethorpe will continue to control and operate the plant during the
leaseback term, and will exercise its fixed price purchase option at the end of
the leaseback period so as to retain all other rights of ownership with respect
to the plant if it is advantageous for Oglethorpe to exercise such option. As a
result of these transactions, Oglethorpe received net present value cash
benefits of approximately $96 million which is being recorded as a deferred
credit and will be recognized in income over the term of the leaseback.
Approximately $92 million was used for the early retirement of FFB debt and
approximately $4 million was used to pay alternative minimum taxes on the
transactions. The combination of the debt prepayment and the amortized gain will
result in an estimated $11 million in annual savings through 2001, and
additional savings in declining amounts for the remaining 25 years of the lease.
In connection with these transactions, Oglethorpe is obligated to maintain
minimum liquidity of $50 million.
COMPETITION
The electric utility industry in the United States is undergoing fundamental
change and is becoming increasingly competitive. This change is promoted by the
Energy Policy Act, recently adopted and proposed policies from FERC regarding
transmission access and pricing, state deregulation initiatives, increased
consolidation and mergers of electric utilities, the proliferation of power
marketers and independent power producers, surplus generation in certain
regional markets and other factors.
Several states are in the process of implementing varying forms of "retail
wheeling" (the transmission of power for a third party directly to a retail
customer) and most others are in the various stages of considering retail
competition. Proposed federal legislation could mandate retail wheeling in every
state. No legislation related to retail wheeling has yet been enacted in
Georgia, and, currently, no bill is pending in the Georgia legislature which
would amend the Georgia Territorial Electric Service Act (the "Territorial Act")
or otherwise affect the exclusive right of the Members to supply power to their
current service territories. In 1997, the staff of the GPSC conducted a series
of workshops to solicit views from the various parties impacted by electric
industry restructuring and to discuss potential resolutions of these issues. The
GPSC staff anticipates presenting a report to the GPSC that will identify
electric industry restructuring issues, potential resolutions and the views of
the parties who participated in the workshops. The GPSC does not have the
authority under Georgia law to order retail wheeling or amend the Territorial
Act. Oglethorpe and the Members participated in the GPSC staff workshops and are
actively monitoring and studying legislative initiatives in Congress and in
other states to take advantage of the experiences of cooperatives and other
utilities in other states to protect their interests in future legislative
activities in Georgia.
Under current Georgia law, the Members generally have the exclusive right to
provide retail electric service in their respective territories. Since 1973,
however, Georgia has permitted limited competition among electric utilities
located in Georgia for sales of electricity to certain large commercial or
industrial customers. Pursuant to the Territorial Act, the owner of any new
facility may receive electric service from the power supplier of its choice if
the facility is located outside of municipal limits and has a connected demand
upon initial full operation of 900 kilowatts or more. (See "THE MEMBERS--Service
Area and Competition.") The Members, with Oglethorpe's support, are actively
engaged in competition with other retail electric suppliers for these new
commercial and industrial loads. While the competition for 900 kilowatt loads
represents only limited competition in Georgia, this competition has given
Oglethorpe and the Members the opportunity to develop resources and strategies
to operate in an increasingly competitive market.
Over the past years, Oglethorpe has taken several steps to prepare for and
adapt to the fundamental changes which have occurred or are likely to occur in
the electric utility industry and to reduce the possibility of incurring
stranded costs. Most importantly, Oglethorpe completed the Corporate
Restructuring and divided itself into generation, transmission and system
operations companies in order to
48
better serve its Members in a deregulated and competitive environment. (See
"General--CORPORATE RESTRUCTURING" herein.) Since 1992, Oglethorpe also has
pursued an interest cost reduction program. As a result of this program,
Oglethorpe has prepaid $222 million of FFB debt and refinanced $1.1 billion of
PCB debt and $1.2 billion of FFB debt. These steps have reduced Oglethorpe's
interest costs significantly. (See "Financial Condition--REFINANCING
TRANSACTIONS" herein.)
Oglethorpe and the Members also amended the Wholesale Power Contracts in
connection with the Corporate Restructuring. The Wholesale Power Contracts
provide that the Members are jointly and severally responsible for all costs and
expenses of all of the generation and purchased power resources of Oglethorpe
existing on March 11, 1997, as well as certain future power resources. (See
"BUSINESS OF OGLETHORPE--Wholesale Power Contracts.") Each Wholesale Power
Contract specifically provides that the Member must make payments whether or not
power has been delivered and whether or not a plant has been sold or is
otherwise unavailable. The formulary rate established by Oglethorpe in the rate
schedule to the Wholesale Power Contracts employs a rate methodology under which
all categories of costs are specifically separated as components of a formula to
determine Oglethorpe's revenue requirements. The rate schedule also allocates to
the Members the responsibility for all of Oglethorpe's fixed costs. Oglethorpe's
charges under the Wholesale Power Contracts may be adjusted by the Board of
Directors. With respect to Oglethorpe, the RUS has retained certain approval
rights over the changes to the Wholesale Power Contracts, including the rate
schedule. (See "General--RATES AND FINANCIAL COVERAGE REQUIREMENTS" herein.) As
a result of these contractual agreements, the Members ultimately are liable for
the existing power resources of Oglethorpe.
Oglethorpe has also entered into arrangements with power marketers to obtain
the value that can be brought by power marketers and to provide for future load
requirements without taking all the risk associated with traditional suppliers.
(See "Results of Operations--POWER MARKETER ARRANGEMENTS" herein.)
Oglethorpe and the Members continue to consider and evaluate a wide array of
other potential actions to reduce costs and to maintain their competitiveness in
anticipation of future competition. These activities on the part of Oglethorpe
and the Members are in various stages of study or preliminary consideration.
Many Members are now providing or considering proposals to provide
non-traditional products and services such as telecommunications and other
services. Depending on the nature of future competition in Georgia, there could
be reasons for the Members to separate their physical distribution business from
their energy business, or otherwise restructure their current businesses to
operate effectively under retail competition. Oglethorpe continues to seek to
identify and evaluate opportunities to reduce the cost of wholesale power to the
Members.
Oglethorpe currently defers certain costs of providing services to the
Members pursuant to Statement of Financial Accounting Standards ("SFAS") No. 71,
"Accounting for the Effects of Certain Types of Regulation." Note 1 of Notes to
Financial Statements in Oglethorpe's Annual Report on Form 10-K for the fiscal
year ended December 31, 1996, sets forth the regulatory assets and liabilities
reflected on Oglethorpe's balance sheet as of December 31, 1996. Regulatory
assets represent probable future revenues to Oglethorpe associated with certain
costs which will be recovered from Members through the rate-making process.
Regulatory liabilities represent probable future reduction in revenues
associated with amounts that are to be credited to Members through the
rate-making process. (See "General-- RATES AND FINANCIAL COVERAGE REQUIREMENTS"
herein.) In the event that Oglethorpe is no longer subject to the provisions of
SFAS No. 71, Oglethorpe would be required to write off regulatory assets and
liabilities. In addition, Oglethorpe would be required to determine any
impairment to other assets, including plant, and write down the assets, if
impaired, to their fair value.
At this time, Oglethorpe cannot predict the outcome of the various
developments that may lead to increased competition in the electric utility
industry or the effect of such developments on Oglethorpe or the Members.
49
MISCELLANEOUS
DECOMMISSIONING COSTS
The staff of the Securities and Exchange Commission (the "Commission") has
questioned certain of the current accounting practices of the electric utility
industry regarding the recognition, measurement and classification of
decommissioning costs for nuclear generating facilities in financial statements
of electric utilities. In response to these questions, the Financial Accounting
Standards Board has issued an Exposure Draft of a proposed Statement on
"Accounting for Certain Liabilities Related to Closure or Removal of Long-Lived
Assets". The proposed Statement would require the recognition of the entire
obligation for decommissioning at its present value as a liability in the
financial statements. Rate-regulated utilities would also recognize an
offsetting asset for differences in the timing of recognition of the costs of
decommissioning for financial reporting and rate-making purposes. Oglethorpe's
management does not believe that this proposed Statement would have an adverse
effect on results of operations due to its current and future ability to recover
decommissioning costs through rates.
Beginning in years 2014 through 2029, it is expected that Plant Hatch and
Plant Vogtle units will begin the decommissioning process. The expected timing
of payments for decommissioning costs will extend for a period of 9 to 14 years.
Oglethorpe's management does not expect such payments to have an adverse impact
on liquidity or capital resources due to available amounts which have been set
aside in reserves for this purpose.
INFLATION
As with utilities generally, inflation has the effect of increasing the cost
of Oglethorpe's operations and construction program. Operating and construction
costs have been less affected by inflation over the last few years because rates
of inflation have been relatively low.
YEAR 2000 ISSUE
Many information systems have been designed to function based on years that
begin with "19". Oglethorpe expects that by the year 2000 it will have adapted
its systems, to the extent it considers necessary, to process years that begin
with "20", and does not expect that the year 2000 issue will have a material
adverse effect on its financial condition or results of operations.
FORWARD-LOOKING STATEMENTS AND ASSOCIATED RISKS
This Prospectus contains forward-looking statements, including statements
regarding, among other items, (i) anticipated trends in Oglethorpe's business
and (ii) Oglethorpe's future liquidity requirements and capital resources. These
forward-looking statements are based largely on Oglethorpe's expectations and
are subject to a number of risks and uncertainties, certain of which are beyond
Oglethorpe's control. For factors that could cause actual results to differ
materially from those anticipated by these forward-looking statements, see
"Competition" herein and "CERTAIN FACTORS AFFECTING THE ELECTRIC UTILITY
INDUSTRY." In light of these risks and uncertainties, there can be no assurance
that events anticipated by the forward-looking statements contained in this
Prospectus will in fact transpire.
50
THE MEMBERS OF OGLETHORPE
SERVICE AREA AND COMPETITION
The Members are listed below and include 39 of the 42 electric distribution
cooperatives in the State of Georgia.
Altamaha EMC Habersham EMC Planters EMC
Amicalola EMC Hart EMC Rayle EMC
Canoochee EMC Irwin EMC Satilla Rural EMC
Carroll EMC Jackson EMC Sawnee EMC
Central Georgia EMC Jefferson EMC Slash Pine EMC
Coastal EMC Lamar EMC Snapping Shoals EMC
Cobb EMC Little Ocmulgee EMC Sumter EMC
Colquitt EMC Middle Georgia EMC Three Notch EMC
Coweta-Fayette EMC Mitchell EMC Tri-County EMC
Excelsior EMC Ocmulgee EMC Troup EMC
Flint EMC Oconee EMC Upson County EMC
Grady EMC Okefenoke Rural EMC Walton EMC
GreyStone Power Corporation, Pataula EMC Washington EMC
an EMC
The Members serve approximately 1.2 million electric consumers (meters)
representing approximately 2.6 million people. The Members serve a region
covering approximately 40,000 square miles, which is approximately 70% of the
land area in the State of Georgia, encompassing 150 of the State's 159 counties.
Sales by the Members in 1996 amounted to approximately 19.6 million MWh, with
72% to residential consumers, 26% to commercial and industrial consumers and 2%
to other consumers. The Members are the principal suppliers for the power needs
of rural Georgia. While the Members do not serve any major cities, portions of
their service territories are in close proximity to urban areas and are
experiencing substantial growth due to the expansion of urban areas, including
metropolitan Atlanta, into suburban areas and the growth of suburban areas into
neighboring rural areas. The Members have experienced average annual compound
growth rates from 1994 through 1996 of 5% in number of consumers, 9% in MWh
sales and 7% in electric revenues.
The Territorial Act regulates the service rights of all retail electric
suppliers in the State of Georgia. Pursuant to the Territorial Act, the GPSC
assigned substantially all areas in the State to specified retail suppliers.
With limited exceptions, the Members have the exclusive right to provide retail
electric service in their respective territories, which are predominately
outside of the municipal limits existing at the time the Territorial Act was
enacted in 1973. The chief exception to this rule of exclusivity is that
electric suppliers may compete for most new retail loads of 900 kilowatts or
greater. The GPSC may reassign territory only if it determines that an electric
supplier has breached the tenets of public convenience and necessity. The GPSC
may transfer service for specific premises only if: (i) the GPSC determines,
after joint application of electric suppliers and proper notice and hearing,
that the public convenience and necessity require a transfer of service from one
electric supplier to another; or (ii) the GPSC finds, after proper notice and
hearing, that an electric supplier's service to a premise is not adequate or
dependable or that its rates, charges, service rules and regulations
unreasonably discriminate in favor of or against the consumer utilizing such
premises and the electric utility is unwilling or unable to comply with an order
from GPSC regarding such service.
Since 1973, unlike in the electric utility industry in general, the
Territorial Act has allowed limited competition among electric utilities in
Georgia by allowing the owner of any new facility located outside of municipal
limits and having a connected demand upon initial full operation of 900
kilowatts or greater to receive electric service from the retail supplier of its
choice. The Members, with Oglethorpe's support,
51
are actively engaged in competition with other retail electric suppliers for
these new commercial and industrial loads. The number of commercial and
industrial loads served by the Members continues to increase annually. While the
competition for 900 kilowatt loads represents only limited competition in
Georgia, this competition has given Oglethorpe and the Members the opportunity
to develop resources and strategies to operate in an increasingly competitive
market.
The electric utility industry in the United States is undergoing fundamental
change and is becoming increasingly competitive. (See "MANAGEMENT'S DISCUSSION
AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS--Competition.")
From time to time, utilities are approached by other parties interested in
purchasing their systems. Some of the Members have been approached in the past
by third parties indicating an interest in purchasing their systems. The
Wholesale Power Contracts provide that a Member may not dissolve, liquidate or
otherwise wind up its affairs without Oglethorpe's approval. The Member may not
consolidate or merge with any person or reorganize or change the form of its
business organization from an electric membership corporation or sell, transfer,
lease or otherwise dispose of all or substantially all of its assets to any
person, whether in a single transaction or series of transactions, unless
either: (i) the transaction is approved by Oglethorpe or (ii) other specified
conditions are satisfied including, but not limited to, an assumption agreement
by the transferee, satisfactory to Oglethorpe, containing an assumption by the
transferee of the performance and observance of every covenant and condition of
the Member under the Wholesale Power Contract, and certifications of accountants
as to certain specified financial requirements of the transferee (taking into
account the transfer).
COOPERATIVE STRUCTURE
The Members are cooperatives that operate their systems on a not-for-profit
basis. Accumulated margins derived after payment of operating expenses and
provision for depreciation constitute patronage capital of the consumers of the
Members. Refunds of accumulated patronage capital to the individual consumers
may be made from time to time subject to limitations contained in mortgages
between the Members and RUS or loan documents with other lenders. The RUS
mortgages generally prohibit such distributions unless, after any such
distribution, the Member's total equity will equal at least 40% (30% in the case
of Members, if any, that have the new form of RUS loan documents) of its total
assets, except that distributions may be made of up to 25% of the margins and
patronage capital received by the Member in the preceding year (provided that
equity is at least 20% in the case of Members, if any, that have the new form of
RUS loan documents). (See "Members' Relationship with RUS" herein.)
Oglethorpe is a membership corporation, and the Members are not subsidiaries
of Oglethorpe. Except with respect to the obligations of the Members under each
Member's Wholesale Power Contract with Oglethorpe and Oglethorpe's rights under
such contracts to receive payment for power and energy supplied, Oglethorpe has
no legal interest in, or obligations in respect of, any of the assets,
liabilities, equity, revenues or margins of the Members. (See "BUSINESS OF
OGLETHORPE--Wholesale Power Contracts.") The revenues of the Members are not
pledged as security to Oglethorpe but are the source from which moneys are
derived by the Members to pay for power supplied by Oglethorpe under the
Wholesale Power Contracts. Revenues of the Members are, however, pledged under
their respective RUS mortgages or loan documents with other lenders.
RATE REGULATION OF MEMBERS
Through provisions in the loan documents securing loans to the Members, RUS
exercises control and supervision over the rates for the sale of power of the 34
Members that borrow from it. The RUS mortgages of such Members require them to
design rates with a view to maintaining an average TIER of
52
not less than 1.50 and an average DSC of not less than 1.25 for the two highest
out of every three successive years.
Although the setting of the rates of the Members is not subject to approval
by any federal or state agency or authority other than RUS, the Territorial Act
prohibits the Members from unreasonable discrimination in the setting of rates,
charges, service rules or regulations and requires the Members to obtain GPSC
approval of long-term borrowings.
Snapping Shoals EMC, Mitchell EMC, Troup EMC, Walton EMC and Cobb EMC have
prepaid their RUS indebtedness and are no longer RUS borrowers. Each of these
Members now has a rate covenant with its current lender. Other Members may also
pursue this option. To the extent that a Member who is not an RUS borrower
engages in wholesale sales or transmission in interstate commerce, it would be
subject to regulation by FERC under the Federal Power Act.
MEMBERS' RELATIONSHIP WITH RUS
Through provisions in the loan documents securing loans to the Members, RUS
also exercises control and supervision over the Members that borrow from it in
such areas as accounting, borrowings, construction and acquisition of
facilities, and the purchase and sale of power.
Historically, federal loan programs providing direct loans from RUS to
electric cooperatives have been a major source of funding for the Members.
However, in recent years, there have been legislative, administrative and
budgetary initiatives intended to reduce or, in some cases, eliminate federal
funding for electric cooperatives. In addition, the RUS loan and guarantee
programs have been characterized by the imposition of increasingly problematic
terms and conditions and extended delays in access to necessary funding. RUS has
adopted new standard forms of mortgages and loan contracts for distribution
borrowers the stated purpose of which is to update and modernize the loan and
security documentation employed by RUS. Distribution borrowers are required to
adopt these new forms as a condition to receiving new loans from RUS.
Recent changes and proposals for further changes have made the direct loan
program administered by RUS more costly. The Rural Electrification Loan
Restructuring Act of 1993 eliminated the long-standing 5% loan program and
substituted a new program, the interest rates for which are based on rates being
paid on municipal bonds with comparable maturities. Certain borrowers with
either low consumer density or higher-than-average rates and lower-than-average
consumer income are still eligible for special loans at 5%. The future cost,
availability and amount of RUS direct and guaranteed loans which may be
available to the Members cannot be predicted.
MEMBERS RELATIONSHIP WITH GTC AND GSOC
For information about the Members' relationship with GTC and GSOC, see
"BUSINESS OF OGLETHORPE--Relationship with GTC" and "--Relationship with GSOC."
CONTRACTS WITH SEPA
In addition to energy received from Oglethorpe under the Wholesale Power
Contracts, the Members purchase hydroelectric power under contracts with SEPA.
In 1996, the aggregate SEPA allocation to the Members was 542 MW plus associated
energy, representing approximately 11% of total Member peak demand and
approximately 5% of total Member energy requirements. New 20-year contracts
between each of the Members and SEPA have recently been executed. The provisions
of the new contracts are essentially the same as the existing contracts with a
few exceptions. Each Member must schedule its energy allocation, and each Member
has designated Oglethorpe to perform this function. Pursuant to a separate
agreement, Oglethorpe will schedule, through GSOC, the Members' SEPA power
deliveries. Further, each Member may be required, if certain conditions are met,
to contribute funds for capital
53
improvements for Corps of Engineers projects from which its allocation is
derived in order to retain the allocation. GTC delivers the Members' SEPA
purchases under its network tariff and contract with each Member. The new
contracts are subject to RUS approval. The amount of capacity and energy
available from SEPA is not expected to increase in an amount sufficient to serve
a material portion of the projected growth in the Members' requirements. (See
"BUSINESS OF OGLETHORPE--Wholesale Power Contracts" and "MEMBER REQUIREMENTS AND
POWER SUPPLY RESOURCES--Member Demand and Energy Requirements" and the table
thereunder.)
During 1996, legislative proposals were made that would have resulted in the
privatization of several of the federal power marketing administrations, in
particular SEPA. Ultimately, no proposal for the privatization of the power
marketing administrations was passed by Congress. The President's Budget for
fiscal year 1998 does not include any proposals to privatize the federal power
marketing administrations. The ultimate outcome of this issue in Congress cannot
be predicted with certainty.
54
MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES
GENERAL
Oglethorpe supplies capacity and energy to the Members from a combination of
owned and leased generating plants and from power purchased under long-term
contracts with other power suppliers and power marketers. Oglethorpe owns or
leases 3,335 MW of nameplate capacity, consisting of 1,500.6 MW of coal-fired
capacity, 1,185 MW of nuclear-fueled capacity, 632.5 MW of pumped storage
hydroelectric capacity, 14.8 MW of oil-fired combustion turbine capacity and 2.1
MW of conventional hydroelectric capacity. (See "Generating Facilities--GENERAL"
and "Generating Facilities--PLANT PERFORMANCE" herein for a description of
Oglethorpe's generating facilities.) These resources are generally scheduled and
dispatched so as to minimize the operating cost of Oglethorpe's system. However,
Oglethorpe has entered into long-term arrangements with power marketers to
better utilize its resources to reduce the cost of capacity and energy delivered
to the Members, in part by giving certain dispatch rights to the power
marketers. (See "Power Marketer Arrangements" herein.)
MEMBER DEMAND AND ENERGY REQUIREMENTS
The following table shows the aggregate peak demand and energy requirements
of the Members for the years 1994 through 1996 and the twelve months ended
September 30, 1997, and also shows the amounts of such requirements supplied by
Oglethorpe and SEPA. For the years 1994 through 1996, demand and energy
requirements increased at an average annual compound growth rate of 13.2% and
9.7%, respectively.
DEMAND (MW) ENERGY REQUIREMENTS (MWH)
--------------------------------------------- ------------------------------------------
TOTAL SUPPLIED BY SUPPLIED BY TOTAL SUPPLIED BY SUPPLIED BY
REQUIREMENTS(1) OGLETHORPE(2) SEPA(3) REQUIREMENTS OGLETHORPE(2) SEPA(3)
--------------- ------------- ----------- ------------ ------------- -----------
1994.......................... 3,938 3,396 542 17,278,812 16,285,127 993,685
1995.......................... 4,850 4,308 542 19,403,703 18,442,153 961,550
1996.......................... 5,045 4,503 542 20,793,864 19,807,101 986,763
Twelve months ended
September 30, 1997.......... 5,252 4,710 542 20,388,886 20,148,077 912,295
- ------------------------------
(1) System peak demand of the Members measured at the Members' delivery points
(net of system losses). The significant increase in peak demand from 1994 to
1995 was due in large part to a mild summer in 1994.
(2) Includes purchased power. (See "Power Marketer Arrangements," "Other Power
Purchase and Sale Arrangements--POWER PURCHASES FROM GPC" and "Other Power
Purchase and Sale Arrangements--OTHER POWER PURCHASES" herein.)
(3) Supplied by SEPA through existing contracts with the Members. (See "THE
MEMBERS OF OGLETHORPE--Contracts with SEPA.")
In 1996, Cobb EMC and Jackson EMC accounted for approximately 12.5% and
11.2% of Oglethorpe's total revenues, respectively. For the twelve months ended
September 30, 1997, Cobb EMC and Jackson EMC accounted for approximately 12.8%
and 11.5% of Oglethorpe's total revenues, respectively. None of the other
Members accounted for as much as 10% of Oglethorpe's total revenues in 1996 or
the twelve months ended September 30, 1997. Due to greater than average growth
rates, certain of Oglethorpe's customers, including its larger customers such as
Cobb EMC and Jackson EMC, have historically accounted for an increasing
percentage of Oglethorpe's total revenues. However, under the new Wholesale
Power Contracts described above, a Member may choose to supply all or a portion
of its increased requirements with purchases from other suppliers. Although the
Members have contracted for significant portions of their anticipated future
needs by participating in Oglethorpe's power marketer agreements, certain of the
Members' future needs during the terms of the power marketer agreements could
still be purchased from other suppliers. (See "Power Marketer Arrangements"
herein.)
55
SEASONAL VARIATIONS
The demand for energy by the Members is influenced by seasonal weather
conditions. Historically, Oglethorpe's peak demand has occurred during the
months of June through August. (See "BUSINESS OF OGLETHORPE--Electric Rates.")
Energy revenues track energy costs as they are incurred and also fluctuate month
to month. Capacity revenues reflect the recovery of Oglethorpe's fixed costs,
which do not vary significantly from month to month; therefore, capacity charges
are billed and capacity revenues are recognized in equal monthly amounts.
POWER MARKETER ARRANGEMENTS
In 1996, Oglethorpe began utilizing power marketer arrangements to reduce
the cost of power to the Members. It has entered into long-term power marketer
agreements with LEM for approximately 50% of the load requirements of the
Members and with Morgan Stanley with respect to 50% of the Members' forecasted
load requirements. The LEM agreements are based on the actual requirements of
the Members during the contract term, whereas the Morgan Stanley agreement
represents a fixed supply obligation. Generally, these arrangements reduce the
cost of supplying power to the Members by limiting the risk of fuel cost
variations and unit availability, by providing a guaranteed benefit for the use
of excess resources and by providing future power needs at a fixed price. All of
Oglethorpe's existing generating facilities and power purchase arrangements are
available for use by LEM and Morgan Stanley for the term of the respective
agreements. Oglethorpe continues to be responsible for all of the costs of its
system resources but receives revenue, as described below, from LEM and Morgan
Stanley for the use of the resources.
LEM AGREEMENTS
Effective January 1, 1997, Oglethorpe entered into power marketer agreements
with LEM for 50% of the load requirements of the Members. Under the agreements,
LEM is obligated to deliver, and Oglethorpe is obligated to take, approximately
50% of the load requirements of the participating Members less the load
requirements for certain customers who have the right to choose electric
suppliers, plus 50% of the delivery obligations under Oglethorpe's existing firm
power off-system sale contracts. For certain smaller customer choice loads, LEM
is obligated to deliver, if Oglethorpe requests, 50% of the associated load
requirements. Oglethorpe has the option of purchasing the energy requirements
for any customer choice load from another supplier. Oglethorpe is obligated to
sell and LEM is obligated to buy 50% of the output of each participating
Member's PCR share of the "must run" units (primarily nuclear units). Oglethorpe
is also obligated to make available the same share of all other resources, which
LEM may schedule. LEM does not have the right to the output of upgrades to these
resources. LEM pays Oglethorpe the costs associated with the energy taken,
subject to certain adjustments. Oglethorpe must pay LEM a contractually
specified price for each MWh purchased.
The LEM agreement relating to 37 of the 39 Members has a term extending
through 2011. With one year's notice, Oglethorpe has the right to terminate the
LEM agreement beginning in 2002. With 18 months' notice, LEM has the right to
terminate the LEM agreement beginning in 2005. The LEM agreement relating to the
other two Members has a term extending through 1999.
LEM is a subsidiary of LG&E Energy Corp., a Kentucky corporation, which is a
diversified energy services holding company. LG&E Energy Corp. is subject to the
informational requirements of the Securities Exchange Act of 1934, as amended,
and, in accordance therewith, files reports and other information with the
Commission.
56
MORGAN STANLEY AGREEMENT
Effective May 1, 1997, Oglethorpe entered into a power marketer agreement
with Morgan Stanley with respect to 50% of the Members' forecasted load
requirements. The agreement obligates Oglethorpe to purchase fixed quantities of
energy at fixed prices. Each Member selected a term for its obligation, as well
as the portion of its forecasted requirements to be purchased as a fixed
quantity. Oglethorpe is obligated to sell and Morgan Stanley is obligated to buy
50% of the output, in contractually fixed amounts, of each Member's PCR share
(for the term and portion selected) of the "must run" units (primarily nuclear
units). Oglethorpe is also obligated to make available the same share of all
other resources, in contractually fixed amounts, which Morgan Stanley may
schedule for each 24-hour day. This schedule is set the day prior based on
availability limitations in the contract. Morgan Stanley pays a contractually
fixed amount each month and an amount for the scheduled energy based on
contractually fixed prices. The agreement has a term extending to March 31,
2005, but the purchases for certain Members decline to zero prior to that date.
Oglethorpe plans to manage the portion of the system resources covered by the
Morgan Stanley agreement through scheduling and dispatching such resources.
Oglethorpe will also make purchases and sales to balance the fixed purchase
obligation against the actual requirements and to optimize the use of the
resources after receiving the daily schedule from Morgan Stanley.
Morgan Stanley is a subsidiary of Morgan Stanley, Dean Witter, Discover &
Co., a diversified investment banking and financial services company. Morgan
Stanley, Dean Witter, Discover & Co. is subject to the informational
requirements of the Securities Exchange Act of 1934, as amended, and, in
accordance therewith, files reports and other information with the Commission.
RELATED AGREEMENTS
Oglethorpe has contracted with GTC to provide available transmission
services to deliver to the border of the ITS any energy sold to LEM or Morgan
Stanley, as well as any other wholesale power purchase. Each Member will use its
Member Transmission Agreement for delivery of energy purchased by Oglethorpe
from LEM, Morgan Stanley and others.
In connection with the LEM and Morgan Stanley arrangements, each Member has
entered into supplemental agreements to its Wholesale Power Contract. The
supplemental agreements are the vehicle through which Oglethorpe and the Members
assure that the Members receive the benefits of and support the obligations for
the power marketer arrangements under the Wholesale Power Contracts.
Each Member has approved the agreements with LEM and Morgan Stanley as
"future resources" under the Wholesale Power Contracts. Accordingly, each Member
has a PCR for each of the LEM and Morgan Stanley agreements and all costs
incurred by Oglethorpe under such agreements are recovered from the Members
under the Wholesale Power Contracts on a joint and several basis. To this
extent, the Members have elected, under the Wholesale Power Contracts, to
purchase a substantial portion of their future requirements from Oglethorpe.
(See "Future Power Resources" herein and "BUSINESS OF OGLETHORPE--Wholesale
Power Contracts.")
POWER PURCHASE AND SALE ARRANGEMENTS
POWER PURCHASES FROM GPC
Oglethorpe purchases 750 MW of capacity and associated energy from GPC on a
take-or-pay basis under the BPSA, which extends through December 31, 2003. The
capacity purchases under the BPSA are from four Component Blocks (as defined in
the BPSA), composed of two Component Blocks of 250 MW each (coal-fired units)
and two Component Blocks of 125 MW each (combustion turbine units). The capacity
in one or more Component Blocks may, however, be less than the MW stated above,
as the result of scheduled retirement of units or retirements due to force
majeure events. Although Oglethorpe
57
may not increase its capacity purchases under the BPSA, it may reduce or extend
its purchases of one or more Component Blocks upon proper notice to GPC.
Oglethorpe has given notice of its intent to reduce its purchases by two 250 MW
Component Blocks (coal-fired units) effective September 1, 1998 and September 1,
1999. Also, pursuant to its long-term power marketer agreements with LEM,
Oglethorpe has committed to continue reducing its purchases from GPC as
permitted under the BPSA and thus will no longer purchase any energy under the
BPSA effective September 1, 2001. (See "Power Marketer Arrangements" herein for
a discussion of the LEM agreement.)
OTHER POWER PURCHASES
Oglethorpe purchases 100 MW of capacity from each of EPI and Big Rivers,
under agreements extending through June and July 2002, respectively. The
availability of capacity under the EPI contract is dependent on the availability
of two specific generating units available to EPI. TVA provides the transmission
service to deliver the power from the Big Rivers electric system to the ITS. TVA
and Southern Company Services, as agent for Alabama Power Company and
Mississippi Power Company, provide the transmission service necessary to deliver
the power from EPI to the ITS. (See Note 9 of Notes to Financial Statements.)
Oglethorpe also has a contract through 2019 to purchase approximately 300 MW
of capacity from Hartwell, a partnership owned 50% by NGC Corporation and 50% by
American National Power, Inc., a subsidiary of National Power, PLC. This
capacity is provided by two 150 MW gas-fired turbine generating units on a site
near Hartwell, Georgia. Oglethorpe intends to use the units for peaking capacity
but has the right to dispatch the units fully. Prior to the merger of Destec
Energy, Inc. and NGC Corporation, Oglethorpe notified Hartwell that Oglethorpe's
rights under the power purchase agreement to consent to the merger or to
exercise its rights of first refusal to purchase equity interests in the
partnership would be triggered by the merger. Hartwell, however, refused to
recognize Oglethorpe's rights, and Oglethorpe is currently seeking to resolve
the issues regarding its rights of consent and first refusal.
In addition to the purchases from GPC, Big Rivers, EPI and Hartwell,
Oglethorpe also purchases small amounts of capacity and energy from "qualifying
facilities" under the Public Utility Regulatory Policies Act of 1978 ("PURPA").
Under a waiver order from FERC, Oglethorpe historically made all purchases the
Members would have otherwise been required to make under PURPA and Oglethorpe
was relieved of its obligation to sell certain services to "qualifying
facilities" so long as the Members make those sales. Oglethorpe historically
provided the Members with the necessary services to fulfill these sale
obligations. Purchases by Oglethorpe from such qualifying facilities provided
0.2% of Oglethorpe's energy requirements for the Members in 1996. As a result of
the Corporate Restructuring, the Members may make such purchases in the future
instead of Oglethorpe.
Finally, Oglethorpe has contracted with Florida Power Corporation to
purchase 275 MW of peaking capacity during the summer of 1998.
LONG-TERM POWER SALES
Oglethorpe has an agreement to sell 100 MW of base capacity to Alabama
Electric Cooperative beginning June 1, 1998, and extending through December 31,
2005. During the term of the power marketer agreements, LEM and Morgan Stanley
will be responsible for supplying Oglethorpe with sufficient power to fulfill
these power sales.
OTHER POWER SYSTEM ARRANGEMENTS
Oglethorpe has interchange, transmission and/or short-term capacity and
energy purchase or sale agreements with over 60 utilities, power marketers and
other power suppliers. The agreements provide variously for the purchase and/or
sale of capacity and energy and/or for the purchase of transmission service. The
development of and access to the ITS and the interconnections with other
utilities are key
58
elements in Oglethorpe's ability to make off-system sales and purchases through
its transmission contract with GTC and to compete in an increasingly competitive
market.
GENERATING FACILITIES
GENERAL
The following table sets forth certain information with respect to the
generating facilities in which Oglethorpe currently has ownership or leasehold
interests, all of which are in commercial operation. Plant Hatch, Plant Wansley,
Plant Vogtle and Scherer Unit No. 1 and Scherer Unit No. 2 are co-owned by
Oglethorpe, GPC, MEAG and Dalton. GPC is the operating agent for each of these
co-owned plants. Rocky Mountain is co-owned by Oglethorpe and GPC, and
Oglethorpe is the operating agent. Oglethorpe is the sole owner of Tallassee.
(See "CO-OWNERS OF THE PLANTS AND THE PLANT AGREEMENTS--The Plant Agreements.")
OGLETHORPE'S
SHARE OF
NAMEPLATE COMMERCIAL LICENSE
TYPE OF PERCENTAGE CAPACITY OPERATION EXPIRATION
FACILITIES FUEL INTEREST(1) (MW) DATE DATE
- ------------------------------------------------------------ -------------- ---------- ------------ ---------- ----------
Plant Hatch (near Baxley, Ga.)
Unit No. 1................................................ Nuclear 30 243.0 1975 2014
Unit No. 2................................................ Nuclear 30 246.0 1979 2018
Plant Vogtle (near Waynesboro, Ga.)
Unit No. 1................................................ Nuclear 30 348.0 1987 2027
Unit No. 2................................................ Nuclear 30 348.0 1989 2029
Plant Wansley (near Carrollton, Ga.)
Unit No. 1................................................ Coal 30 259.5 1976 N/A(2)
Unit No. 2................................................ Coal 30 259.5 1978 N/A(2)
Combustion Turbine........................................ Oil 30 14.8 1980 N/A(2)
Plant Scherer (near Forsyth, Ga.)
Unit No. 1................................................ Coal 60 490.8 1982 N/A(2)
Unit No. 2................................................ Coal 60 490.8 1984 N/A(2)
Tallassee (near Athens, Ga.)................................ Hydro 100 2.1 1986 2023
Rocky Mountain (near Rome, Ga.)............................. Pumped Storage 74.61 632.5 1995 2027
Hydro
------------
Total Ownership 3,335.0
------------
------------
- ------------------------
(1) The 60% interest in Scherer Unit No. 2 is leased under leases that expire in
2013, subject to options to renew for a total of 8.5 years. The 74.61%
interest in Rocky Mountain is leased under leases that expire in 2016.
Oglethorpe has an ownership interest in all of the other facilities. (See
"INTRODUCTION--Sale and Leaseback Transactions" and "CO-OWNERS OF THE PLANTS
AND THE PLANT AGREEMENTS--The Plant Agreements--ROCKY MOUNTAIN.")
(2) Coal-fired units and combustion turbines do not operate under operating
licenses similar to those granted to nuclear units by the Nuclear Regulatory
Commission and to hydroelectric plants by FERC.
59
PLANT PERFORMANCE
The following table sets forth certain operating performance information of
each of the major generating facilities in which Oglethorpe currently has
ownership or leasehold interests:
EQUIVALENT AVAILABILITY(1) CAPACITY FACTOR(2)
---------------------------------- ----------------------------------
TWELVE MONTHS TWELVE MONTHS
ENDED ENDED
SEPTEMBER 30, SEPTEMBER 30,
UNIT 1997 1996 1995 1994 1997 1996 1995 1994
- -------------------------------------------------- ------------- ---- ---- ---- ------------- ---- ---- ----
Plant Hatch
Unit No. 1...................................... 98% 83% 98% 84% 98% 83% 100% 85%
Unit No. 2...................................... 86 97 75 78 86 99 75 79
Plant Vogtle
Unit No. 1...................................... 87 80 98 86 87 80 98 86
Unit No. 2...................................... 96 88 89 91 97 89 90 91
Plant Wansley
Unit No. 1...................................... 88 88 90 92 56 58 56 62
Unit No. 2...................................... 92 91 89 88 58 62 56 58
Plant Scherer
Unit No. 1...................................... 76 92 95 97 59 74 73 64
Unit No. 2...................................... 88 84 97 85 74 72 85 60
Rocky Mountain(3)
Unit No. 1...................................... 99 94 83 N/A 15 15 16 N/A
Unit No. 2...................................... 96 95 92 N/A 11 13 15 N/A
Unit No. 3...................................... 97 95 92 N/A 16 10 16 N/A
- ------------------------
(1) Equivalent Availability is a measure of the percentage of time that a unit
was available to generate if called upon, adjusted for periods when the unit
is partially derated from the "maximum dependable capacity" rating.
(2) Capacity Factor is a measure of the output of a unit as a percentage of the
maximum output, based on the "maximum dependable capacity" rating, over the
period of measure.
(3) Rocky Mountain Commercial Operation Dates: Unit 1--July 24, 1995; Unit
2--June 19, 1995; Unit 3--June 1, 1995. This information was calculated
beginning from the commercial operation date for each unit. As a pumped
storage plant, Rocky Mountain primarily operates in peaking service.
The nuclear refueling cycle for Plants Hatch and Vogtle exceeds twelve
months. Therefore, in some calendar years the units at these plants are not
taken out of service for refueling, resulting in higher levels of equivalent
availability and capacity factor.
FUEL SUPPLY
COAL. Coal for Plant Wansley is currently purchased under long-term
contracts and in spot market transactions. As of September 30, 1997, there was a
17-day coal supply at Plant Wansley based on nameplate rating.
Low-sulfur "compliance" coal for Scherer Units No. 1 and No. 2 is purchased
under long-term contracts and in spot market transactions. As of September 30,
1997, the coal stockpile at Plant Scherer contained a 26-day supply based on
nameplate rating. During 1994, Plant Scherer was converted to burn both
sub-bituminous and bituminous coals, and a separate stockpile of sub-bituminous
coal was built in addition to the stockpile of bituminous coal.
60
Coal inventories are lower at Plants Wansley and Scherer primarily due to
recent problems associated with rail transportation and the seasonal demands of
summer. The rail transportation providers expect operations to return to normal
by the beginning of 1998. Should deliveries of coal be subject to ongoing delay
or disruption, there is a potential for upward price pressure on such coal with
a consequent possibility of increased prices for energy.
The Plant Scherer and Wansley ownership and operating agreements were
amended in 1993 and 1996, respectively, to allow each co-owner (i) to dispatch
separately its respective ownership interest in conjunction with contracting
separately for long-term coal purchases procured by GPC and (ii) to procure
separately long-term coal purchases. Pursuant to the amendments, Oglethorpe
implemented separate dispatch of Plant Scherer in 1994 and at Plant Wansley in
May 1997. Oglethorpe continues to use GPC as its agent for fuel procurement.
To take advantage of these changes at Plants Scherer and Wansley, Oglethorpe
formed a wholly owned subsidiary, Black Diamond Energy, Inc., to acquire rail
cars. This subsidiary has purchased or leased 299 rail cars. Oglethorpe entered
into an initial 15-year lease with this subsidiary which obligates Oglethorpe to
pay all of the ownership and operating expenses of the subsidiary relating to
the rail cars during the lease term.
For information relating to the impact that the Clean Air Act will have on
Oglethorpe, see "CERTAIN FACTORS AFFECTING THE ELECTRIC UTILITY
INDUSTRY--Environmental and Other Regulations."
NUCLEAR FUEL. GPC, as operating agent, has the responsibility to procure
nuclear fuel for Plants Hatch and Vogtle. GPC has contracted with Southern
Nuclear Operating Company ("SONOPCO"), a subsidiary of The Southern Company
specializing in nuclear services, to operate these plants, including nuclear
fuel procurement. (See "CO-OWNERS OF THE PLANTS AND PLANT AGREEMENTS--The Plant
Agreements.") SONOPCO employs both spot purchases and long-term contracts to
satisfy nuclear fuel requirements. The nuclear fuel supply and related services
are expected to be adequate to satisfy current and future nuclear generation
requirements.
FUTURE POWER RESOURCES
Under the Wholesale Power Contracts, Oglethorpe provides joint planning
services for all participating Members. A Member may elect not to have
Oglethorpe provide joint planning, procurement or bulk power marketing services.
Although the existing long-term power marketer arrangements with LEM and Morgan
Stanley provide substantially all of the Members' requirements during their
contract terms, Oglethorpe will continue to offer these planning services for
requirements beyond the contract terms as well as for evaluation of contract
options and balancing of actual requirements against fixed purchase obligations.
Consequently, Oglethorpe has forecasted that peak requirements for the Members
may exceed contracted purchases over the next several years and has issued a
request for proposals for an aggregate of 100 MW to 1,100 MW to supply these
additional requirements. All Members currently participate in joint planning.
61
CO-OWNERS OF THE PLANTS AND THE PLANT AGREEMENTS
CO-OWNERS OF THE PLANTS
Plants Hatch, Vogtle, Wansley and Scherer Units No. 1 and No. 2 are co-owned
by Oglethorpe, GPC, MEAG and Dalton, and Rocky Mountain is co-owned by
Oglethorpe and GPC. Each such co-owner owns, and Oglethorpe owns or leases,
undivided interests in the amounts shown in the following table (which excludes
the Plant Wansley combustion turbine). Oglethorpe is the operating agent for
Rocky Mountain. GPC is the operating agent for each of the other plants. (See
"The Plant Agreements" herein.)
NUCLEAR COAL-FIRED
-------------------------- -----------------------------
PLANT PLANT PLANT SCHERER UNITS
HATCH VOGTLE WANSLEY NO. 1 & NO. 2
------------ ------------ ------------ ---------------
% MW(1) % MW(1) % MW(1) % MW(1)
----- ----- ----- ----- ----- ----- ----- -----
Oglethorpe........................................ 30.0 489 30.0 696 30.0 519 60.0(2) 982
GPC............................................... 50.1 817 45.7 1,060 53.5 926 8.4 137
MEAG.............................................. 17.7 288 22.7 527 15.1 261 30.2 494
Dalton............................................ 2.2 36 1.6 37 1.4 24 1.4 23
----- ----- ----- ----- ----- ----- ----- -----
Total............................................. 100.0 1,630 100.0 2,320 100.0 1,730 100.0 1,636
----- ----- ----- ----- ----- ----- ----- -----
----- ----- ----- ----- ----- ----- ----- -----
PUMPED STORAGE
------------------
ROCKY
MOUNTAIN
------------------ TOTAL
% MW(1) MW(1)
-------- ----- -----
Oglethorpe........................................ 74.61(2) 633 3,319
GPC............................................... 25.39 215 3,155
MEAG.............................................. -- -- 1,570
Dalton............................................ -- -- 120
-------- ----- -----
Total............................................. 100.00 848 8,164
-------- ----- -----
-------- ----- -----
- ------------------------
(1) Based on nameplate ratings.
(2) Oglethorpe leases its interest in Scherer Unit No. 2 and Rocky Mountain
pursuant to long-term net leases.
GEORGIA POWER COMPANY
GPC is a wholly owned subsidiary of The Southern Company, a registered
holding company under the Public Utility Holding Company Act, and is engaged
primarily in the generation and purchase of electric energy and the
transmission, distribution and sale of such energy within the State of Georgia
at retail in over 600 communities (including Athens, Atlanta, Augusta, Columbus,
Macon, Rome and Valdosta), as well as in rural areas, and at wholesale to
Oglethorpe, MEAG and three municipalities. GPC is the largest supplier of
electric energy in the State of Georgia. (See "BUSINESS OF OGLETHORPE--
Relationship with GPC.") GPC is subject to the informational requirements of the
Securities Exchange Act of 1934, as amended, and, in accordance therewith, files
reports and other information with the Commission.
MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA
MEAG, an instrumentality of the State of Georgia, was created for the
purpose of providing electric capacity and energy to those political
subdivisions of the State of Georgia that owned and operated electric
distribution systems at that time. MEAG, also known as MEAG Power, has entered
into power sales contracts with each of 48 cities and one county in the State of
Georgia. Such political subdivisions, located in 39 of the State's 159 counties,
collectively serve approximately 270,000 electric customers.
CITY OF DALTON, GEORGIA
The City of Dalton, located in northwest Georgia, supplies electric capacity
and energy to consumers in Dalton, and presently serves more than 10,000
residential, commercial and industrial customers.
62
THE PLANT AGREEMENTS
HATCH, WANSLEY, VOGTLE AND SCHERER
SUMMARY OF OWNERSHIP AND OPERATING AGREEMENTS. Oglethorpe's rights and
obligations with respect to Plants Hatch, Wansley, Vogtle and Scherer are
contained in a number of contracts between Oglethorpe and GPC and, in some
instances, MEAG and Dalton. Oglethorpe is a party to four Purchase and Ownership
Participation Agreements ("Ownership Agreements") under which it acquired from
GPC a 30% undivided interest in each of Plants Hatch, Wansley and Vogtle, a 60%
undivided interest in Scherer Units No. 1 and No. 2 and a 30% undivided interest
in those facilities at Plant Scherer intended to be used in common by Scherer
Units No. 1, No. 2, No. 3 and No. 4 (the "Scherer Common Facilities").
Oglethorpe has also entered into four Operating Agreements ("Operating
Agreements") relating to the operation and maintenance of Plants Hatch, Wansley,
Vogtle and Scherer, respectively. The Ownership Agreements and Operating
Agreements relating to Plants Hatch and Wansley are two-party agreements between
Oglethorpe and GPC. The Ownership Agreements and Operating Agreements relating
to Plants Vogtle and Scherer are agreements among Oglethorpe, GPC, MEAG and
Dalton. The parties to each Ownership Agreement and Operating Agreement are
referred to as "Participants" with respect to each such agreement.
SALE AND LEASEBACK TRANSACTIONS. In connection with the Sale and Leaseback
Transactions, Oglethorpe assigned its rights with respect to Scherer Unit No. 2
under the Ownership Agreement and Operating Agreement for that Unit to the
Lessors, who assigned such rights back to Oglethorpe for the term of the Leases.
Oglethorpe retained all of its rights as a Participant under those agreements
relating to Scherer Unit No. 1 and to the Scherer Common Facilities. In
addition, GPC, MEAG and Dalton agreed that, during the term of the Leases,
Oglethorpe would be treated as the owner of the undivided ownership interests of
the Lessors in Scherer Unit No. 2 and would continue to possess all the rights
and obligations of a Participant with respect to such interests, including the
right to vote and give consents under both agreements. (In the following
discussion, references to Participants "owning" a specified percentage of
interests include Oglethorpe's rights as a deemed owner with respect to its
leased interests in Scherer Unit No. 2.) The Ownership Agreement and Operating
Agreement for Scherer Units No. 1 and No. 2 also were amended to allow separate
voting with respect to each of such Units and the Scherer Common Facilities. The
Sale and Leaseback Transactions agreements also provide that Oglethorpe will
discharge all obligations relating to the undivided ownership interests of the
Lessors in Scherer Unit No. 2 during the term of the Leases, and that Oglethorpe
will continue as a Participant under the Ownership Agreement and Operating
Agreement with respect to such interests in Scherer Unit No. 2. At the
expiration of the Leases, the Lessors would become Participants under the
Ownership Agreement and Operating Agreement with respect to their undivided
ownership interests in Scherer Unit No. 2 if Oglethorpe does not purchase such
interests. (See "INTRODUCTION--Sale and Leaseback Transactions" and Note 4 of
Notes to Financial Statements.)
GPC'S RESPONSIBILITIES AS AGENT. The Ownership Agreements appoint GPC as
agent with sole authority and responsibility for, among other things, the
planning, licensing, design, construction, renewal, addition, modification and
disposal of Plants Hatch, Vogtle, Wansley and Scherer Units No. 1 and No. 2 and
the Scherer Common Facilities. The Operating Agreements gives GPC, as agent,
sole authority and responsibility for the management, control, maintenance and
operation of the plant to which it relates and provides for the use of power and
energy from such plant and the sharing of the costs thereof by the parties
thereto in accordance with their respective interests therein. In performing its
responsibilities under the Ownership and Operating Agreements, GPC is required
to comply with prudent utility practices. GPC's liabilities with respect to its
duties under the Ownership and Operating Agreements are limited by the terms
thereof.
OGLETHORPE'S PAYMENT OBLIGATIONS. Under the Ownership Agreements,
Oglethorpe is obligated to pay a percentage of capital costs of the respective
plants, as incurred, equal to the percentage interest
63
which it owns or leases at each plant. GPC has responsibility for budgeting
capital expenditures subject to, in the case of Scherer Units No. 1 and No. 2,
certain limited rights of the Participants to disapprove capital budgets
proposed by GPC and to substitute alternative capital budgets and, in the case
of Plants Hatch and Vogtle, the right of any co-owner to disapprove large
discretionary capital improvements.
As noted above, Oglethorpe continues to be liable for capital costs related
to the undivided ownership interests of the Lessors in Scherer Unit No. 2 during
the term of the Leases. Thereafter, unless Oglethorpe purchases such interests,
the Lessors will be liable to the other Participants for all such costs other
than costs associated with the disposal, retirement and salvaging of Scherer
Unit No. 2. Under agreements relating to the Sale and Leaseback Transactions,
the Equity Investors have agreed to reimburse Oglethorpe for a portion of the
costs of disposal, retirement and salvaging determined pursuant to a formula in
such agreements.
REMEDIES FOR NON-PAYMENT. The Hatch and Wansley Ownership and Operating
Agreements provide that, should Oglethorpe fail to make any payment when due,
interest would be added to the overdue amount and Oglethorpe would indemnify GPC
for any damages arising out of Oglethorpe's failure to make timely payment. In
addition, GPC has the right, but not the obligation, to make any payment of
principal or interest due and owing from Oglethorpe to the FFB or the RUS in
respect of financing Oglethorpe's obligations under the respective Ownership
Agreements and to be reimbursed, with interest, therefor by Oglethorpe.
The Scherer and Vogtle Ownership and Operating Agreements provide that,
should a Participant fail to make any payment when due, among other things, such
non-paying Participant's rights to output of capacity and energy would be
suspended, and, in certain circumstances, the other Participants would have the
right to acquire all or a part of the non-paying Participant's ownership
interest in Plant Vogtle or the unit or units and common facilities at Plant
Vogtle. The other Participants also have the right under the Scherer Ownership
Agreement, but not the obligation, to make any payment of principal or interest
(or rent or any other payment) due the FFB or the RUS (or any lessor or lessor's
lender) in respect of a financing of Oglethorpe's obligations under the
respective Ownership Agreements and to be reimbursed, with interest, by
Oglethorpe.
The Scherer Ownership Agreement also provides that a transferee of the
possession of an interest in Scherer Units No. 1 or No. 2 will have the right to
cure a default by its transferor. GPC has agreed to notify the Lessors of any
failure by Oglethorpe to pay its obligations under the Ownership Agreement. If a
Lessor cures such default within five days after receiving such notice, the
payment will be deemed made by the Lessor and no interest will be due from the
Lessor, although Oglethorpe will remain liable. The other Participants have the
option, if a Lessor continues so to cure such default by Oglethorpe for six
months and does not declare a Lease Event of Default, to require the Lessor to
offer to the other Participants a lease of the Lessor's undivided ownership
interest. Where a Participant which owns an interest in Scherer Unit No. 1 or
No. 2 defaults with respect to an obligation relating to the Scherer Common
Facilities or facilities used in common by such Units, such default shall give
the other Participants the same rights to deny the defaulting Participant its
share of the output of capacity and energy from the Unit or Units which it owns.
Oglethorpe has never failed to make any payments when due under the various
Ownership Agreements.
MANAGEMENT OF PLANTS. In 1990, the co-owners of Plants Hatch and Vogtle
entered into the Nuclear Managing Board Agreement which amended the Plant Hatch
and Plant Vogtle Ownership and Operating Agreements, primarily with respect to
GPC's reporting requirements, but did not alter GPC's role as agent with respect
to the nuclear plants. In 1993, the co-owners entered into the Amended and
Restated Nuclear Managing Board Agreement (the "Amended and Restated NMBA")
which provides for a managing board (the "Nuclear Managing Board") to coordinate
the implementation and administration of the Plant Hatch and Plant Vogtle
Ownership and Operating Agreements, provides for increased
64
rights for the co-owners regarding certain decisions and allows GPC to contract
with a third party for the operation of the nuclear units. Upon approval in
March 1997 by the Nuclear Regulatory Commission (the "NRC") of GPC's application
to add SONOPCO to the operating license of each unit of Plants Hatch and Vogtle
and designate SONOPCO as the operator, the Nuclear Operating Agreement between
GPC and SONOPCO, which the co-owners had previously approved, became effective.
In connection with the amendments to the Plant Scherer Ownership and Operating
Agreements, the co-owners of Plant Scherer entered into the Plant Scherer
Managing Board Agreement which provides for a managing board (the "Plant Scherer
Managing Board") to coordinate the implementation and administration of the
Plant Scherer Ownership and Operating Agreements and provides for increased
rights for the co-owners regarding certain decisions, but does not alter GPC's
role as agent with respect to Plant Scherer.
ALIENATION AND ASSIGNMENT OF OWNERSHIP INTERESTS. The parties to the Hatch,
Vogtle and Wansley Ownership Agreements have rights to transfer ownership
interests subject to first refusal rights of the other parties, subject to
certain conditions. Except with the consent of Participants owning at least an
aggregate 95% interest in Scherer Units No. 1 and No. 2, no Participant in such
Units may sell or otherwise transfer any portion of its interest in such Units
or the Scherer Common Facilities without first offering such portion to the
other Participants (on a pro rata basis). No such sale or transfer by GPC shall
relieve it of its obligation to act as agent under the Scherer Ownership
Agreement and Operating Agreement.
GPC, MEAG and Dalton unanimously consented to the Sale and Leaseback
Transactions to the extent required by the Scherer Ownership Agreement. They
also consented to the exercise by Oglethorpe of any of its options to renew the
Leases or to purchase the undivided ownership interests of the Lessors subject
to any required approval of RUS. (See "DESCRIPTION OF THE LEASES--Purchase and
Renewal Options.") In addition, in the event Oglethorpe does not exercise such
options, GPC, MEAG and Dalton may do so on the same terms and conditions. The
obligation of the Lessors to attempt to lease the undivided ownership interests
prior to the exercise of any of their remedies under the respective Leases also
is subject to this right of first refusal. (See "DESCRIPTION OF THE LEASE
INDENTURES--Rights of Lessors to Cure and Purchase Lessor Notes" and
"DESCRIPTION OF THE LEASES--Events of Default.")
PLANT SCHERER COAL STOCKPILE AND INVENTORIES. Oglethorpe retained ownership
of a 60% undivided interest in the fossil fuel (the "Coal Stockpile") and
non-capital assets ("Inventories") at Plant Scherer following the Sale and
Leaseback Transactions. GPC, MEAG, and Dalton agreed that Oglethorpe may sell to
the Lessors upon the termination of the Leases, if Oglethorpe does not purchase
their interests in Scherer Unit No. 2, a portion of the Coal Stockpile and
Inventories allocable to such interests. The Lessor may offset against the
purchase price any amounts which it has paid to cure a default by Oglethorpe
under the Ownership Agreement or Operating Agreement.
OGLETHORPE'S ENTITLEMENT TO OUTPUT. The Operating Agreements provide that
Oglethorpe is entitled to a percentage of the net capacity and net energy output
of each plant or unit equal to its percentage undivided interest owned or leased
in such plant or unit. GPC, as agent, schedules and dispatches Plants Hatch and
Vogtle. Pursuant to amendments to the plant agreements, Oglethorpe began
separately dispatching its ownership share of Scherer Units No. 1 and No. 2 in
1993 and of Plant Wansley in 1997. (See "MEMBER REQUIREMENTS AND POWER SUPPLY
RESOURCES--Generating Facilities--FUEL SUPPLY.")
RESPONSIBILITY FOR OPERATING COSTS. Except as otherwise provided, each
party is responsible for a percentage of Operating Costs (as defined in the
Operating Agreements) and fuel costs of each plant or unit equal to the
percentage of its undivided interest which is owned or leased in such plant or
unit. For Scherer Units No. 1 and No. 2 and for Plant Wansley, each party will
be responsible for its fuel costs and for variable Operating Costs in proportion
to the net energy output for its ownership interest, while responsibility for
fixed Operating Costs will continue to be equal to the percentage undivided
ownership
65
interest which is owned or leased in such unit. GPC is required to furnish
budgets for Operating Costs, fuel plans and scheduled maintenance plans subject
to, in the case of Scherer Units No. 1 and No. 2, certain limited rights of the
Participants to disapprove such budgets proposed by GPC and to substitute
alternative budgets. The Ownership Agreements and Operating Agreements provide
that, should a Participant fail to make any payment when due, among other
things, such nonpaying Participant's rights to output of capacity and energy
would be suspended.
TERMS. The Operating Agreement for Plant Hatch will remain in effect with
respect to Hatch Units No. 1 and No. 2 until 2009 and 2012, respectively. The
Operating Agreement for Plant Vogtle will remain in effect with respect to each
unit at Plant Vogtle until 2018. The Operating Agreement for Plant Wansley will
remain in effect with respect to Wansley Units No. 1 and No. 2 until 2016 and
2018, respectively. The Operating Agreement for Scherer Units No. 1 and No. 2
will remain in effect with respect to Scherer Units No. 1 and No. 2 until 2022
and 2024, respectively. Upon termination of each Operating Agreement, following
any extension agreed to by the parties, GPC will retain such powers as are
necessary in connection with the disposition of the property of the applicable
plant, and the rights and obligations of the parties shall continue with respect
to actions and expenses taken or incurred in connection with such disposition.
ROCKY MOUNTAIN
SUMMARY OF ROCKY MOUNTAIN OWNERSHIP AND OPERATING AGREEMENTS. Oglethorpe's
rights and obligations with respect to Rocky Mountain are contained in several
contracts between Oglethorpe and GPC, the co-owners of Rocky Mountain (the
"Co-Owners"). Pursuant to Rocky Mountain Pumped Storage Hydroelectric Ownership
Participation Agreement, by and between Oglethorpe and GPC (the "Rocky Mountain
Ownership Agreement"), Oglethorpe initially acquired a 3% undivided interest in
Rocky Mountain which interest increased as Oglethorpe expended funds to complete
construction of Rocky Mountain. The final ownership percentages for Rocky
Mountain are Oglethorpe 74.61% and GPC 25.39%. In connection with this
acquisition, Oglethorpe and GPC also entered into the Rocky Mountain Pumped
Storage Hydroelectric Project Operating Agreement (the "Rocky Mountain Operating
Agreement").
OGLETHORPE'S RESPONSIBILITIES AS AGENT. The Rocky Mountain Ownership
Agreement appoints Oglethorpe as agent with sole authority and responsibility
for, among other things, the planning, licensing, design, construction,
operation, maintenance and disposal of Rocky Mountain. The Rocky Mountain
Operating Agreement gives Oglethorpe, as agent, sole authority and
responsibility for the management, control, maintenance and operation of Rocky
Mountain.
PAYMENT OBLIGATIONS. In general, each Co-Owner is responsible for payment
of its respective ownership share of all Operating Costs and Pumping Energy
Costs (as defined in the Rocky Mountain Operating Agreement) as well as costs
incurred as the result of any separate schedule or independent dispatch. A
Co-Owner's share of net available capacity and net energy is the same as its
respective ownership interest under the Rocky Mountain Ownership Agreement.
Oglethorpe and GPC have each elected to schedule separately their respective
ownership interests. The Rocky Mountain Operating Agreement will terminate in
2035.
REMEDIES FOR NON-PAYMENT. The Rocky Mountain Ownership and Operating
Agreements provide that, should a Co-Owner fail to make any payment when due,
among other things, such non-paying Co-Owner's rights to output of capacity and
energy or to exercise any other right of a Co-Owner would be suspended until all
amounts due, together with interests, had been paid. The capacity and energy of
a non-paying Co-Owner may be purchased by a paying Co-Owner or sold to a third
party.
ALIENATION AND ASSIGNMENT OF OWNERSHIP INTERESTS. Except with the consent
of Co-Owners owning at least an aggregate 95% interest in Rocky Mountain, no
Co-Owner may sell or otherwise
66
transfer any portion of its interests in Rocky Mountain without first offering
such portion to the other Co-Owner. No such sale or transfer by Oglethorpe shall
relieve it of its obligations to act as agent under the Rocky Mountain Ownership
and Operating Agreements.
ROCKY MOUNTAIN LEASE TRANSACTIONS. In late 1996 and early 1997, Oglethorpe
completed lease transactions for its 74.61% undivided ownership interest in
Rocky Mountain. Under the terms of these transactions, Oglethorpe leased the
facility to three institutional investors for the useful life of the facility,
who in turn leased it back to Oglethorpe for a term of 30 years. Oglethorpe will
continue to control and operate Rocky Mountain during the leaseback term, and it
will exercise its fixed price purchase option at the end of the leaseback period
so as to retain all other rights of ownership with respect to the plant if it is
advantageous for Oglethorpe to exercise such option.
67
CERTAIN FACTORS AFFECTING THE ELECTRIC UTILITY INDUSTRY
GENERAL
The electric utility industry has been and in the future will continue to be
affected by a number of factors which could have an impact on the financial
condition of an electric utility such as Oglethorpe. These factors likely would
affect individual utilities in different ways. Such factors include, among
others: (i) the transition to increasing competition in the generation of
electricity and the corresponding increase in competition from other suppliers
of electricity, (ii) fluctuations in the market price for electricity, (iii)
effects of compliance with rapidly changing environmental, licensing and
regulatory requirements, (iv) regulatory and other changes in national and state
energy policy, including open access transmission, (v) uncertain access to low
cost capital for replacement of aging fixed assets, (vi) increases in operating
costs, including the cost of fuel for the generation of electric energy, (vii)
recovery of the cost of existing facilities, (viii) fluctuations in demand,
including rates of load growth and changes in competitive market share, (ix)
unbundling of services and corresponding corporate and functional restructurings
by electric utility companies, and (x) the effects of conservation and energy
management on the use of electric energy. These factors present an increasing
challenge to companies in the electric utility industry, including Oglethorpe
and the Members, to reduce costs, improve the management of resources and
respond to the changing environment. (See "Environmental and Other Regulations"
herein, "BUSINESS OF OGLETHORPE--Corporate Restructuring," "MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS--Competition," "MEMBER REQUIREMENTS AND POWER SUPPLY
RESOURCES--General" and "--Other Power Purchase and Sale Arrangements--OTHER
POWER PURCHASES.")
COMPETITION
The electric utility industry in the United States is undergoing fundamental
change and is becoming increasingly competitive. (See "MANAGEMENT'S DISCUSSION
AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS--Competition.")
ENVIRONMENTAL AND OTHER REGULATIONS
GENERAL
As is typical for electric utilities, Oglethorpe is subject to various
federal, state and local air and water quality requirements which, among other
things, regulate emissions of pollutants, such as particulate matter, sulfur
oxides and nitrogen oxides into the air and discharges of other pollutants,
including heat, into waters of the United States. Oglethorpe is also subject to
federal, state and local waste disposal requirements that regulate the manner of
transportation, storage and disposal of various types of waste.
In general, environmental requirements are becoming increasingly stringent.
New requirements may substantially increase the cost of electric service, by
requiring changes in the design or operation of existing facilities or changes
or delays in the location, design, construction or operation of new facilities.
Failure to comply with these requirements could result in the imposition of
civil and criminal penalties as well as the complete shutdown of individual
generating units not in compliance. There is no assurance that Oglethorpe's
units will always remain subject to the regulations currently in effect or will
always be in compliance with future regulations.
Compliance with environmental standards will continue to be reflected in
Oglethorpe's capital expenditures and operating costs. Based on the current
status of regulatory requirements, Oglethorpe does not anticipate that any
capital expenditures or operating expenses associated with its compliance with
current laws and regulations will have a material effect on its results of
operations or its financial condition. Oglethorpe's direct capital costs to
achieve compliance with environmental requirements are expected to be an
aggregate of approximately $250,000 for 1997, 1998 and 1999.
68
CLEAN AIR ACT
Environmental concerns of the public, the scientific community and Congress
have resulted in the enactment of legislation that has had and will continue to
have a significant impact on the electric utility industry. In particular, on
November 15, 1990, legislation was enacted (the "1990 Amendments") that
substantially revised the Clean Air Act. One of the principal purposes of the
1990 Amendments is to improve air quality by reducing the emissions of sulfur
dioxide and nitrogen oxides from affected utility units, which include the
coal-fired units that generate electric power at Plants Wansley and Scherer.
These sulfur dioxide reductions are being imposed through a sulfur dioxide
emission allowance trading program. An emission allowance, which gives the
holder the authority to emit one ton of sulfur dioxide during a calendar year,
is transferable and can be bought, sold or banked for use in the years following
its issuance. Allowances are issued by the U.S. Environmental Protection Agency
("EPA") to impose limited reductions on certain affected units in Phase I
(1995-1999) and more stringent reductions on all affected units in Phase II
(after the year 1999). After 1999, aggregate emissions of sulfur dioxide from
all units subject to this program will be capped at 8.9 million tons per year.
Oglethorpe is now complying with this program by using lower-sulfur fuel at
Plant Wansley. After 1999, Oglethorpe could use a variety of options for
compliance at Plants Wansley and Scherer, including the use of emission
allowances (issued, banked or purchased, if needed), fuel-switching or
installation of flue gas desulfurization equipment.
A number of recently finalized regulations, proposed regulations, petitions
and on-going studies could result in more stringent controls on all emissions,
including utility emissions. The most significant of these appear to be the
following. First, because nitrogen oxides are considered to be a precursor to
ozone, coupled with the fact that metropolitan Atlanta is classified as a
"serious nonattainment area" with regard to the ozone National Ambient Air
Quality Standards ("NAAQS"), EPA and the State of Georgia may impose further
limits on emissions of nitrogen oxides at Plants Wansley and/or Scherer. Second,
EPA has tightened the NAAQS for both ozone and particulate matter, an action
that could affect any source that emits nitrogen oxides and sulfur dioxide,
including utility units. Court challenges to both standards are now being made.
Third, EPA has issued a proposed regulation for the regional control of ozone
which, if implemented as proposed, could require substantial reductions in
nitrogen oxides emissions from Plants Wansley and Scherer. Fourth, EPA has
proposed a new regional haze program, an action that could affect any source
that emits nitrogen oxides or sulfur dioxide and that may contribute to the
degradation of visibility in mandatory federal Class I areas, including utility
units. Fifth, various Northeastern states have filed petitions under the Clean
Air Act asking EPA to set more stringent nitrogen oxides limits on sources that
are significantly contributing to ozone nonattainment in their own states.
Georgia was named in only one of these petitions. Sixth, although EPA has
decided not to impose a new NAAQS for sulfur dioxide, that decision has been
appealed, so it is still possible that a new short-term standard for sulfur
dioxide could be established. Finally, the 1990 Amendments require that several
studies be conducted regarding the health effects from power plant emissions of
certain hazardous air pollutants. These studies will be used in making decisions
on whether additional controls of utility emissions of such pollutants are
necessary.
Depending on the final outcome of these developments, and the implementation
approach selected by EPA and the State of Georgia, significant capital
expenditures and increased operation expenses could be incurred by Oglethorpe
for the continued operation of Plants Wansley and/or Scherer. The power marketer
arrangements generally do not provide for the recovery from the power marketers
of increased environmental costs. (See "MEMBER REQUIREMENTS AND POWER SUPPLY
RESOURCES--Power Marketer Arrangements.") Because of the uncertainty associated
with these various developments, Oglethorpe cannot now predict the effect that
any of these potential requirements may have on the operations of Plants Wansley
and/or Scherer.
69
Compliance with the requirements of the Clean Air Act may also require
increased capital or operating expenses on the part of GPC. Any increases in
GPC's capital or operating expenses may cause an increase in the cost of power
purchased from GPC. (See "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--Power
Purchase and Sale Arrangements--POWER PURCHASES FROM GPC.")
NUCLEAR REGULATION
Oglethorpe is subject to the provisions of the Atomic Energy Act of 1954, as
amended (the "Atomic Energy Act"), which vests jurisdiction in the NRC over the
construction and operation of nuclear reactors, particularly with regard to
certain public health, safety and antitrust matters. The National Environmental
Policy Act has been construed to expand the jurisdiction of the NRC to consider
the environmental impact of a facility licensed under the Atomic Energy Act.
Plants Hatch and Vogtle are being operated under licenses issued by the NRC. All
aspects of the operation and maintenance of nuclear power plants are regulated
by the NRC. From time to time, new NRC regulations require changes in the
design, operation and maintenance of existing nuclear reactors. Operating
licenses issued by the NRC are subject to revocation, suspension or
modification, and the operation of a nuclear unit may be suspended if the NRC
determines that the public interest, health or safety so requires. The operating
licenses issued for each unit of Plants Hatch and Vogtle expire in 2014 and 2018
and 2027 and 2029, respectively.
Pursuant to the Nuclear Waste Policy Act of 1982, as amended, the Federal
government has the regulatory responsibility for the final disposition of
commercially produced high-level radioactive waste materials, including spent
nuclear fuel. Such Act requires the owner of nuclear facilities to enter into
disposal contracts with the Department of Energy ("DOE") for such material.
These contracts require each such owner to pay a fee, which is currently one
dollar per MWh for the net electricity generated and sold by each of its
reactors. Oglethorpe is a party to agreements with DOE regarding Plants Hatch
and Vogtle. Plants Hatch and Vogtle currently have on-site spent fuel storage
capacity. Based on normal operations and retention of all spent fuel in the
reactor, it is anticipated that existing on-site pool capacity would be
sufficient until 2003 and 2008, respectively, to accept the number of spent fuel
assemblies that would normally be removed from the reactor during a refueling.
Contracts with the DOE have been executed to provide for the permanent disposal
of spent nuclear fuel produced at Plants Hatch and Vogtle. The services to be
provided by DOE are scheduled to begin in 1998; however, the DOE has stated that
permanent nuclear waste storage facilities will not be available by that date,
and it is uncertain when they will be available. If DOE does not begin receiving
the spent fuel from Plant Hatch in 2003 or from Plant Vogtle in 2008,
alternative methods of spent fuel storage will be needed. Activities for adding
dry cast storage capacity at Plant Hatch by as early as 1999 are in progress.
(See Note 1 of Notes to Financial Statements regarding nuclear fuel cost.)
For information concerning nuclear insurance, see Note 8 of Notes to
Financial Statements. For information regarding NRC's regulation relating to
decommissioning of nuclear facilities and regarding DOE's assessments pursuant
to the Energy Policy Act for decontamination and decommissioning of nuclear fuel
enrichment facilities, see Note 1 of Notes to Financial Statements.
OTHER ENVIRONMENTAL REGULATION
In 1993, EPA issued a ruling confirming the non-hazardous status of coal
ash. That ruling may apply, however, only to situations where those wastes are
not co-managed, I.E., not mixed with other wastes. Pursuant to court order, EPA
has until 1998 to classify co-managed utility wastes as either hazardous or
non-hazardous. If the wastes are classified as hazardous, substantial additional
costs for the management of such wastes might be required of Oglethorpe,
although the full impact would depend on the subsequent development of
requirements pertaining to these wastes.
70
Oglethorpe is subject to other environmental statutes including, but not
limited to, the Clean Water Act, the Georgia Water Quality Control Act, the
Georgia Hazardous Site Response Act, the Toxic Substances Control Act, the
Resource Conservation & Recovery Act, the Endangered Species Act, the
Comprehensive Environmental Response, Compensation and Liability Act, the
Emergency Planning and Community Right to Know Act, and to the regulations
implementing these statutes. Oglethorpe does not believe that compliance with
these statutes and regulations will have a material impact on its financial
condition or results of operations. Changes to any of these laws, some of which
are being reviewed by Congress, could affect many areas of Oglethorpe's
operations. Although compliance with new environmental legislation could have a
significant impact on Oglethorpe, those impacts cannot be fully determined at
this time and would depend in part on the final legislation and the development
of implementing regulations.
The scientific community, regulatory agencies and the electric utility
industry are continuing to examine the issues of global warming and the possible
health effects of electromagnetic fields. While no definitive scientific
conclusions have been reached regarding these issues, it is possible that new
laws or regulations pertaining to these matters could increase the capital and
operating costs of electric utilities, including Oglethorpe or entities from
which Oglethorpe purchases power. In addition, the potential for liability
exists from lawsuits that might be brought alleging damages from electromagnetic
fields.
71
MANAGEMENT
BOARD OF DIRECTORS AND SENIOR OFFICERS
As part of the Corporate Restructuring, Oglethorpe amended its Bylaws to
provide for an eleven member board of directors consisting of six directors
elected from the Members (the "Member Directors"), four independent outside
directors (the "Outside Directors") and Oglethorpe's President and Chief
Executive Officer. Each Member Director must be a director or general manager of
an Oglethorpe Member. Five of the six Member Directors must be located in each
of five geographical regions of the State of Georgia. The sixth Member Director
is elected statewide. None of the four Outside Directors may be a director,
officer or employee of Oglethorpe or any Member. All eleven directors are
nominated by representatives from each Member whose weighted nomination is based
on the number of retail customers served by each Member. After nomination, the
directors are elected by a majority vote of each Member, voting on a one-Member,
one-vote basis.
The Bylaws provide for staggering the terms of the Member Directors and
Outside Directors by dividing the number of directors into three groups. As
noted below, some of the directors were elected to an initial term of one year,
some two years and some three years. As these initial terms expire, directors
will thereafter be elected for a term of three years.
Oglethorpe is managed and operated under the direction of a President and
Chief Executive Officer, who is appointed by the Board of Directors. The Senior
Officers and Directors of Oglethorpe are as follows:
NAME AGE POSITION
- ----------------------------------------- --- ----------------------------------------------------------------
J. Calvin Earwood........................ 55 Chairman of the Board of Directors, Member Director,
Statewide
T. D. Kilgore............................ 49 President and Chief Executive Officer and Director
Clarence D. Mitchell..................... 44 Senior Vice President, Power Supply
Thomas A. Smith.......................... 43 Senior Financial Officer
Nelson G. Hawk........................... 47 Senior Vice President and Group Executive, Marketing
Larry N. Chadwick........................ 56 Member Director, Northwest Region
Benny W. Denham.......................... 67 Member Director, Southwest Region and Vice Chairman
Sammy M. Jenkins......................... 71 Member Director, Southeast Region
Mac F. Oglesby........................... 65 Member Director, Northeast Region and Treasurer
J. Sam L. Rabun.......................... 66 Member Director, Central Region
Ashley C. Brown.......................... 51 Outside Director
Newton A. Campbell....................... 69 Outside Director
Wm. Ronald Duffey........................ 56 Outside Director
John S. Ranson........................... 68 Outside Director
J. Calvin Earwood is the Chairman of the Board and is the Member Director
elected statewide. Mr. Earwood has served as an executive officer of Oglethorpe
since March 1984 (from March 1984 to July 1986, as Vice President; from July
1986 to March 1989, as Vice Chairman of the Board; and since March 1989, as
Chairman of the Board). Mr. Earwood has served on the Board of Directors of
Oglethorpe since March 1981. His present term will expire in March 2000. He was
previously a member of the Operations Review Committee. From 1965 through 1982,
Mr. Earwood was a salesman and part owner of Builders Equipment Company. Since
January 1983, he has been the owner and President of Sunbelt Fasteners, Inc.,
which sells specialty tools and fasteners to the commercial construction trade.
He is also Vice Chairman of the Board of Directors of both Community Trust
Financial Services and Community Trust Bank in Hiram, Georgia and a Director of
GreyStone Power Corporation.
72
T. D. Kilgore is the President and Chief Executive Officer of Oglethorpe and
has served as a senior officer of Oglethorpe since July 1984 (from July 1984 to
July 1986, as Division Manager, Power Supply; July 1986 to July 1991, as Senior
Vice President, Power Supply; and since July 1991, as President and Chief
Executive Officer). He also currently serves as the President and Chief
Executive Officer and as a director of both GTC and GSOC. Mr. Kilgore has over
20 years of experience in the electric utility industry, including five years in
senior management positions with Arkansas Power & Light Co. and seven years as a
civilian employee with the Department of the Army in positions ranging from
reliability engineering to construction management. Mr. Kilgore has served on
various industry committees including Electric Power Research Institute's Board
of Directors and its Advanced Power Systems Division and Coal System Division
Advisory Committees. He has also served on the Boards of Directors of the U.S.
Committee for Energy Awareness, the Advanced Reactor Corporation, on the Edison
Electric Institute's Power Plant Availability Improvement Task Force and the
Nuclear Power Oversight Committee. Mr. Kilgore currently serves on the Board of
Directors of the Georgia Chamber of Commerce and on the National Rural Electric
Cooperative Association's Power and Generation Committee. Mr. Kilgore has a
Bachelor of Science degree in Mechanical Engineering from the University of
Alabama, where he has been recognized as a Distinguished Engineering Fellow, and
a Masters of Engineering degree in industrial engineering from Texas A&M.
Clarence D. Mitchell is the Senior Vice President, Power Supply and has
served as a senior officer of Oglethorpe since January 1995. Prior to that time,
Mr. Mitchell served as Assistant to the Senior Vice President for Generation
from February 1994 to December 1994; Manager of Corporate Planning from
September 1992 to January 1994; Manager of Construction from January 1992 to
August 1992; Program Director of Technical Services (environmental, survey and
mapping, land acquisition and R&D) from January 1989 to December 1991; and from
April 1981 to December 1988 held various positions in the generation area,
including supervisor, project engineer and generation engineer. Before coming to
Oglethorpe, Mr. Mitchell spent four years as a field engineer with General
Electric Company and worked various installation and maintenance projects
related to coal, nuclear, gas and oil-fired generation. Mr. Mitchell has a
Masters of Science degree in Management from Georgia State University, a
Bachelor of Science degree in Mechanical Engineering from Georgia Institute of
Technology and a Bachelor of Science degree in Interdisciplinary Science from
Morehouse College. Mr. Mitchell is presently the Oglethorpe representative on
both the Nuclear Managing Board and the Plant Scherer Managing Board. (For
information about the Managing Boards see "CO-OWNERS OF THE PLANTS AND THE PLANT
AGREEMENTS--The Plant Agreements.") Mr. Mitchell also serves as a Trustee of the
Foundation of the Southern Polytechnic State University.
Thomas A. Smith is the Senior Financial Officer and has served as a senior
officer of Oglethorpe since August 1997. He previously served as Vice President,
Finance of Oglethorpe from 1986 to 1990, Manager of Finance from 1983 to 1986
and Manager, Financial Services from 1979 to 1983. From 1990 to 1997, Mr. Smith
was Senior Vice President of the Rural Utility Banking Group of CoBank, where he
managed the bank's eastern division, rural utilities. Mr. Smith is a Certified
Public Accountant, has a Master of Science degree in Industrial
Management-Finance from the Georgia Institute of Technology, a Master of Science
degree in Analytical Chemistry from Purdue University and a Bachelor of Arts
degree in Mathematics and Chemistry from Catawba College.
Nelson G. Hawk is the Senior Vice President and Group Executive, Marketing
and has served as a senior officer of Oglethorpe since February 1994,
responsible for Market Planning, Economic Development, Commercial/Industrial
Marketing and Pricing, Commercial/Industrial Services, and Residential
Marketing. Prior to coming to Oglethorpe, Mr. Hawk spent almost 24 years with
the Florida Power & Light Company and related subsidiaries, serving as Director
of Regulatory Affairs from October 1993 to January 1994, Director of Market
Planning from July 1991 to September 1993, and as Director of Strategic Business
from April 1989 to June 1991. Mr. Hawk has a wide range of utility management
experience in energy management, finance, strategic planning, marketing, system
planning, quality
73
assurance, and distribution engineering. Mr. Hawk is a board member of the
Georgia Electrification Council, Inc. and the Georgia Partnership for Excellence
in Education, and served on the board of directors as well as President of the
National Association of Energy Services Companies (NAESCO), a national trade
association, during the late 1980s. Mr. Hawk is a registered Professional
Engineer in Florida and has a Bachelor of Science degree in Electrical
Engineering from the Georgia Institute of Technology and a Master of Business
Administration degree from Florida International University.
Larry N. Chadwick is the Member Director from the Northwest Region. He has
been the owner of Chadwick's Hardware in Woodstock, Georgia since 1983. He has
served on the Board of Directors of Oglethorpe since July 1989. His present term
will expire in March 1999. Mr. Chadwick is an engineer, with experience in the
design of hydrogen gas plants. He is Chairman of the Board of Cobb EMC.
Benny W. Denham is the Vice Chairman of the Board and is the Member Director
from the Southwest Region. He has served on the Board of Directors of Oglethorpe
since December 1988. His present term will expire in March 1998. He was
previously the Vice-Chairman of the Executive Committee and a member of the
Power Planning and Technical Advisory Committee. Mr. Denham has been co-owner of
Denham Farms in Turner County, Georgia since 1980. He served on the Turner
County Commission from 1980 to 1990, and was Chairman for six of those years.
Mr. Denham is a Director of Community National Bank in Ashburn, Georgia and a
Director of Irwin EMC.
Sammy M. Jenkins is the Member Director from the Southeast Region. He has
been a self-employed farmer for over 20 years. In addition, from 1973 to 1995,
he was President of Jenkins Ford Tractor Co., Inc., a seller of farm machinery.
He has served on the Board of Directors of Oglethorpe since March 1988. His
present term will expire in March 1999. He was Vice Chairman of the Board of
Oglethorpe from March 1989 to March 1990.
Mac F. Oglesby is the Member Director from the Northeast Region and the
Treasurer of Oglethorpe. He served as Assistant Secretary-Treasurer of the Board
of Directors of Hart EMC from July 1986 through December 1987, when he was
appointed President of the Board. He has served on the Board of Directors of
Oglethorpe since February 1987. His present term will expire in March 2000. Mr.
Oglesby was a U.S. Postal Service Rural Carrier for 30 years until he retired in
1991.
J. Sam L. Rabun is the Member Director from the Central Region. He has been
the owner and operator of a farm in Jefferson County, Georgia since 1979. He is
also a 50% owner of R&R Livestock Farms, Inc. He has served on the Board of
Directors of Oglethorpe since March 1993. His present term will expire in March
1998. Mr. Rabun served as the President of the Board of Jefferson EMC from 1993
to 1996, was employed as General Manager from 1974 to 1979 and as Office Manager
and Accountant from 1970 to 1974.
Ashley C. Brown is an Outside Director. He has served on the Board of
Directors of Oglethorpe since March 1997. His present term will expire in March
1999. He has been Executive Director of the Harvard Electricity Policy Group at
Harvard University's John F. Kennedy School of Government since 1993. In
addition, he is a consultant to the law firm of LeBouef, Lamb, Greene and
MacRae. From April 1983 through April 1993, Mr. Brown served as Commissioner of
the Public Utilities Commission of Ohio. Prior to his appointment to the Ohio
Commission, he was Coordinator and Counsel of the Montgomery County, Ohio, Fair
Housing Center. From 1979 to 1981, he was Managing Attorney for the Legal Aid
Society of Dayton (Ohio), Inc. From 1977 to 1979, he was Legal Advisor of the
Miami Valley Regional Planning Commission in Dayton, Ohio. In addition, Mr.
Brown has extensive teaching experience in public schools and universities and
has published widely in the field of utility regulation. Mr. Brown has a law
degree from the University of Dayton School of Law, a Master of Arts degree from
the University of Cincinnati, and a Bachelor of Science degree from Bowling
Green State University.
Newton A. Campbell is an Outside Director. He has served on the Board of
Directors of Oglethorpe since March 1997. His term will expire in March 2000. He
retired in January 1994 as Chairman and Chief
74
Executive Officer of Burns & McDonnell Engineering Company after serving 41
years with the firm. Mr. Campbell directed the overall operations of Burns &
McDonnell from 1982 until his retirement. From 1976 through 1982, he served as
Vice President and General Manager of the Power Division, and was responsible
for directing the company's work in the planning and design of fossil fueled
power generation facilities, high voltage transmission systems, and other power
related facilities. Mr. Campbell has been involved in feasibility, planning and
financial studies for numerous new and existing public and privately owned
electric utilities during various phases of their organization and development.
He also has considerable experience in conceptual studies, design, and project
management for large electric utility generation, transmission, substation and
distribution facilities throughout the United States. Mr. Campbell received a
Master of Business Administration degree from the University of Missouri at
Kansas City with a concentration in finance. He also holds a Bachelor of Science
degree in Electrical Engineering from the University of Illinois. Mr. Campbell
is a Director of UMB Financial Corporation in Kansas City, Missouri.
Wm. Ronald Duffey is an Outside Director. He has served on the Board of
Directors of Oglethorpe since March 1997. His term will expire in March 1998.
Mr. Duffey is the President and Chief Executive Officer and a director of
Peachtree National Bank in Peachtree City, Georgia, a wholly owned subsidiary of
Synovus Financial Corp. Prior to his employment in 1985 with Peachtree National
Bank, Mr. Duffey served as Executive Vice President and Member of the Board of
Directors for First National Bank in Newnan, Georgia. He holds a Bachelor of
Business Administration from Georgia State College with a concentration in
finance and has completed banking courses at the Banking School of the South,
the American Bankers Association School of Bank Investments, and The Stonier
Graduate School of Banking, Rutgers University.
John S. Ranson is an Outside Director. He has served on the Board of
Directors of Oglethorpe since March 1997. His term will expire in March 1999. He
has been the President of Ranson Municipal Consultants, L.L.C. in Wichita,
Kansas since 1994. From 1990 to 1994, Mr. Ranson was Chairman of Ranson Capital
Corp. an investment banking firm. Mr. Ranson has approximately 40 years
experience in the investment banking business. His public finance clients have
included the Kansas Local Utility Improvement Authority, the Kansas Municipal
Energy Agency, the Kansas Municipal Gas Agency, and the Kansas City (Kansas)
Board of Public Utilities. Mr. Ranson received his Bachelor of Science in
Business Administration from the University of Kansas (Lawrence, Kansas) and
attended the Navy Supply Corps School in Bayonne, New Jersey.
75
SUMMARY COMPENSATION TABLE
The following table sets forth, for Oglethorpe's President and Chief
Executive Officer and the other five most highly compensated senior executives,
all compensation paid or accrued for services rendered in all capacities during
the years ended December 31, 1996, 1995 and 1994. Amounts included in the table
under "Bonus" represent payments based on an incentive compensation policy. All
amounts paid under this policy are fully at risk each year and are earned based
upon the achievement of corporate goals and each individual's contribution to
achieving those goals. In conjunction with this policy, base salaries are
targeted below the market valuations for similar positions and remain fairly
stable unless the job content changes.
ANNUAL
COMPENSATION
NAME AND ---------------------- ALL OTHER
PRINCIPAL POSITION YEAR SALARY BONUS (1) COMPENSATION
- ----------------------------------------- --------- --------- ----------- --------------
T. D. Kilgore............................ 1996 $ 265,627 $ 0 $ 6,246(2)
President and Chief Executive Officer 1995 235,000 10,000 6,012
1994 224,997 0 6,758
W. Clayton Robbins (3)................... 1996 144,460 17,112 5,425(2)
Sr. Vice President, Support Services 1995 142,310 10,631 4,716
1994 140,366 11,946 4,986
Nelson G. Hawk........................... 1996 142,535 16,530 5,246(2)
Sr. Vice President, Marketing 1995 140,000 10,899 4,589
1994 116,005 9,620 32,821
Clarence D. Mitchell..................... 1996 133,369 17,112 3,887(2)
Sr. Vice President, Power Supply 1995 110,058 7,776 4,251
1994 91,705 5,765 3,354
Wiley H. Sanders (4)..................... 1996 123,750 9,340 82,715(2)(4)
Vice President, Transmission 1995 135,000 9,295 5,703
1994 119,785 12,737 25,178
Eugen Heckl (5).......................... 1996 99,480 16,734 117,245(2)(5)
Sr. Vice President, Finance 1995 142,114 13,174 7,651
1994 142,114 13,919 7,600
- ------------------------
(1) All executives listed above, except Mr. Kilgore, participate in an incentive
compensation program. Mr. Kilgore's compensation is governed solely by the
Board of Directors.
(2) Includes contributions made in 1996 by Oglethorpe under the 401(k)
Retirement Savings Plan on behalf of Messrs. Kilgore, Robbins, Hawk,
Mitchell, Sanders and Heckl of $4,750, $4,072, $4,446, $2,969, $3,654 and
$2,958, respectively; and insurance premiums paid on term life insurance on
behalf of Messrs. Kilgore, Robbins, Hawk, Mitchell, Sanders and Heckl of
$1,496, $1,353, $800, $918, $2,831 and $2,200, respectively.
(3) In conjunction with the Corporate Restructuring, Mr. Robbins ceased to be a
senior executive of Oglethorpe as of January 31, 1997. Mr. Robbins now
serves as Vice President of Intellisource's Southeast operations, including
support services to Oglethorpe, GTC and GSOC. (See "BUSINESS OF
OGLETHORPE--Relationship with Intellisource" for further discussion.)
(4) Mr. Sanders retired from Oglethorpe as of November 30, 1996. Mr. Sanders'
1996 compensation includes accrued severance benefits of $59,114, payment of
accrued vacation and sick benefits of $4,998 and relocation costs of
$12,118.
(5) Mr. Heckl elected to retire from Oglethorpe under the provisions of an early
retirement program as of September 11, 1996. Mr. Heckl's 1996 compensation
includes severance benefits of $65,258, retirement-related contributions to
his deferred compensation account of $34,938 and payment of accrued vacation
and sick benefits of $11,891.
76
PENSION PLAN TABLE
YEARS OF CREDITED SERVICE
-----------------------------------------------------
AVERAGE COMPENSATION 5 10 15 20 25
- -------------------------------------------- --------- --------- --------- --------- ---------
$ 50,000.................................... $ 4,228 $ 8,456 $ 12,684 $ 16,911 $ 21,139
75,000.................................... 6,728 13,456 20,184 26,911 33,639
100,000.................................... 9,228 18,456 27,684 36,911 46,139
125,000.................................... 11,728 23,456 35,184 46,911 58,639
150,000.................................... 14,228 28,456 42,684 56,911 71,139
175,000.................................... 16,728 33,456 50,184 66,911 83,639
200,000.................................... 19,228 38,456 57,684 76,911 96,139
225,000.................................... 21,728 43,456 65,184 86,911 108,639
250,000.................................... 24,228 48,456 72,684 96,911 121,139
275,000.................................... 26,728 53,456 80,184 106,911 133,639
The preceding table shows estimated annual straight life annuity benefits
payable upon retirement to persons in specified compensation and
years-of-service classifications assuming such persons had attained age 65 and
retired during 1996. For purposes of calculating pension benefits, compensation
is defined as total salary and bonus, as shown in the above Summary Compensation
Table. Because covered compensation changes each year, the estimated pension
benefits for the classifications above will also change in future years. The
above pension benefits are not subject to any deduction for Social Security or
other offset amounts.
As of December 31, 1996, the years of credited service under the Pension
Plan for the individuals listed in the Summary Compensation Table are as
follows:
YEARS OF
NAME CREDITED SERVICE
- ----------------------------------------------------------------- ---------------------
Mr. Kilgore...................................................... 11
Mr. Robbins...................................................... 10
Mr. Hawk......................................................... 1
Mr. Mitchell..................................................... 15
Mr. Sanders...................................................... 1
Mr. Heckl........................................................ 20
COMPENSATION OF DIRECTORS
Under a policy adopted by the Board of Directors in March 1997, Oglethorpe
pays its Outside Directors a fee of $5,500 per Board meeting for four meetings
in a year; a fee of $1,000 per Board meeting will be paid for the remaining
other Board meetings in a year. Outside Directors are also paid $1,000 per day
for attending committee meetings, annual meetings of the Members or other
official meetings of Oglethorpe. Member Directors are paid a fee of $1,000 per
Board meeting and $300 per day for attending committee meetings, annual meetings
of the Members or other official business of Oglethorpe. In addition, Oglethorpe
reimburses all Directors for out-of-pocket expenses incurred in attending a
meeting. All Directors are paid $50 per day when participating in meetings by
conference call. The Chairman of the Board is paid an additional 20% of his
Director's fee per Board meeting for time involved in preparing for the
meetings.
77
In 1996, Oglethorpe paid its Directors a fee of $200 for meetings attended
or $50 for participating in meetings by conference call, and reimbursed
Directors for out-of-pocket expenses incurred in attending a meeting. The
Chairman of the Board was also paid at least one day's per diem of $200 each
month for time involved in carrying out his official duties in addition to the
regularly scheduled Board meetings.
EMPLOYMENT CONTRACTS
Effective January 1, 1996, Oglethorpe entered into an employment agreement
with its President and Chief Executive Officer. The agreement extends to
December 31, 1999. Pursuant to the agreement, Mr. Kilgore's base salary and
bonus will be determined by Oglethorpe's Board, with annual base salary being at
least $240,000. Under the agreement, if Oglethorpe terminates Mr. Kilgore's
employment without cause, he will be entitled to a severance payment equal to
all salary and benefits he would have received between the date of termination
to the end of the agreement. If Oglethorpe terminates Mr. Kilgore's employment
without cause or meaningfully reduces his stated duties or prerogatives within
three months prior to or 24 months subsequent to a Change in Control of
Oglethorpe (as defined in the agreement), such severance payment will not be
less than two times Mr. Kilgore's annual base salary on the date of termination
or the date on which his duties or prerogatives are reduced, whichever is
applicable. If such reduction in duties occurs, Mr. Kilgore will be entitled to
severance regardless whether he is terminated or resigns. If Mr. Kilgore
voluntarily separates himself from Oglethorpe, he will be prohibited from
working with a competitor of Oglethorpe for a period of one year thereafter and
will be paid an amount equal to his then current salary, bonus and benefits for
such period.
COMPENSATION COMMITTEE INTERLOCKS AND INSIDER PARTICIPATION
E. J. Martin, Jr., J. Calvin Earwood, John B. Floyd, Jr., and J. G. McCalmon
served as members of the Oglethorpe Human Resources Management Committee which
functioned as Oglethorpe's compensation committee for 1996. Mr. Earwood has
served as an executive officer of Oglethorpe since 1984 and has served as the
Chairman of the Board since 1989.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
T. D. Kilgore is the President and Chief Executive Officer and a Director of
Oglethorpe, GTC and GSOC. Oglethorpe plans to make payments to GSOC for system
operations services in 1997 of approximately $5.4 million, which is 56% of
GSOC's budgeted revenues. (See "BUSINESS OF OGLETHORPE--Corporate
Restructuring.")
78
THE EXCHANGE OFFER
PURPOSE AND EFFECT OF THE EXCHANGE OFFER
The Private Facility Bonds were sold by OPC Scherer 1997 Funding Corporation
on December 17, 1997, and were subsequently resold to qualified institutional
buyers pursuant to Rule 144A under the Securities Act of 1933, as amended (the
"Securities Act"). In connection with the offering of Private Facility Bonds,
Oglethorpe and OPC Scherer 1997 Funding Corporation entered into the
Registration Rights Agreement, which requires, among other things, that on or
before June 15, 1998, Oglethorpe (i) will file with the Commission a
registration statement under the Securities Act with respect to an issue of new
bonds of OPC Scherer 1997 Funding Corporation identical in all material respects
to the Private Facility Bonds, (ii) use its best efforts to cause such
registration statement to become effective under the Securities Act and (iii)
upon the effectiveness of that registration statement, offer to the holders of
the Private Facility Bonds the opportunity to exchange their Private Facility
Bonds for a like principal amount of such new bonds, which would be issued
without a restrictive legend and may be reoffered and resold by the holder
without restrictions or limitations under the Securities Act (other than any
such holder that is an "affiliate" of Oglethorpe within the meaning of Rule 405
under the Securities Act). A copy of the Registration Rights Agreement has been
filed as an exhibit to the Registration Statement of which this Prospectus is a
part. The term "holder" with respect to the Exchange Offer means any person in
whose name the Private Facility Bonds are registered on the books of the Bond
Registrar (as defined in the Collateral Trust Indenture) or any other person who
has obtained a properly completed bond power from the registered holder.
Because the Exchange Offer is for any and all Private Facility Bonds, the
number of Private Facility Bonds tendered and exchanged in the Exchange Offer
will reduce the principal amount of Private Facility Bonds outstanding.
Following the consummation of the Exchange Offer, holders of the Private
Facility Bonds who did not tender their Private Facility Bonds will not have any
further registration rights under the Registration Rights Agreement, and such
Private Facility Bonds will continue to be subject to certain restrictions on
transfer. Because Oglethorpe anticipates that most holders of Private Facility
Bonds will elect to exchange such Private Facility Bonds for Exchange Facility
Bonds due to the absence of restrictions on the resale of Exchange Facility
Bonds under the Securities Act, Oglethorpe anticipates that the liquidity of the
market for any Private Facility Bonds remaining after the consummation of the
Exchange Offer may be substantially limited.
TERMS OF THE EXCHANGE OFFER
Oglethorpe, and OPC Scherer 1997 Funding Corporation acting at the direction
of Oglethorpe, will conduct the Exchange Offer. Upon the terms and subject to
the conditions set forth in this Prospectus and in the accompanying Letter of
Transmittal (the "Letter of Transmittal"), OPC Scherer 1997 Funding Corporation
will accept any and all Private Facility Bonds validly tendered and not
withdrawn prior to 5:00 p.m. New York City time, on the Expiration Date
described herein. OPC Scherer 1997 Funding Corporation will issue $1,000
principal amount of Exchange Facility Bonds in exchange for each $1,000
principal amount of outstanding Private Facility Bonds accepted in the Exchange
Offer. Holders may tender some or all of their Private Facility Bonds pursuant
to the Exchange Offer. However, Private Facility Bonds may be tendered only in
integral multiples of $1,000.
Holders of the Private Facility Bonds do not have any approval or
dissenters' rights in connection with the Exchange Offer. Oglethorpe intends to
conduct the Exchange Offer in accordance with the provisions of the Registration
Rights Agreement and the applicable requirements of the Securities Act and the
rules and regulations of the Commission thereunder.
The form and terms of the Exchange Facility Bonds will be the same as the
form and terms of the Private Facility Bonds except that (i) the Exchange
Facility Bonds will be registered under the Securities Act and hence will not
bear legends restricting the transfer thereof, (ii) the holders of the Exchange
79
Facility Bonds will not be entitled to registration rights under the
Registration Rights Agreement, which rights are being fulfilled by and will
terminate upon consummation of the Exchange Offer, and (iii) the Exchange
Facility Bonds will not contain any provision for additional interest in the
event of certain defaults in obligations of Oglethorpe relating to the Exchange
Offer. The Exchange Facility Bonds will evidence the same debt as the Private
Facility Bonds and will be entitled to the benefits of the Collateral Trust
Indenture. The Exchange Facility Bonds and any Private Facility Bonds not
exchanged in the Exchange Offer will be deemed a single series under the
Collateral Trust Indenture.
OPC Scherer 1997 Funding Corporation shall be deemed to have accepted
validly tendered Private Facility Bonds when, as and if OPC Scherer 1997 Funding
Corporation has given oral or written notice thereof to the Exchange Agent. The
Exchange Agent will act as agent for the tendering holders for the purpose of
receiving the Exchange Facility Bonds from OPC Scherer 1997 Funding Corporation.
Holders who tender Private Facility Bonds in the Exchange Offer will not be
required to pay brokerage commissions or fees or, subject to the instructions in
the Letter of Transmittal, transfer taxes with respect to the exchange of
Private Facility Bonds pursuant to the Exchange Offer. The Lessors will pay all
charges and expenses, other than transfer taxes in certain circumstances, in
connection with the Exchange Offer. See "--Fees and Expenses."
EXPIRATION DATE; EXTENSIONS; AMENDMENTS
The term "Expiration Date" shall mean 5:00 p.m., New York City time, on
, 1998, unless Oglethorpe, in its sole discretion, extends the Exchange
Offer, in which case the term "Expiration Date" shall mean the latest date and
time to which the Exchange Offer is extended.
To extend the Exchange Offer, Oglethorpe will notify the Exchange Agent of
any extension by oral or written notice, followed by a public announcement
thereof no later than 9:00 a.m., New York City time, on the next business day
after the previously scheduled expiration date.
Oglethorpe reserves the right, in its reasonable judgment, (a)(i) to
instruct OPC Scherer 1997 Funding Corporation to delay accepting any Private
Facility Bonds, (ii) to extend the Exchange Offer or (iii) to terminate the
Exchange Offer, if any of the conditions set forth below under "--Conditions"
shall not have been satisfied, by giving oral or written notice of such delay,
extension or termination to the Exchange Agent or (b) to amend the terms of the
Exchange Offer in any manner. Any such delay in acceptance, extension,
termination or amendment will be followed as promptly as practicable by a public
announcement thereof. If the Exchange Offer is amended in a manner determined by
Oglethorpe to constitute a material change, Oglethorpe will promptly disclose
such amendment by means of a prospectus supplement that will be distributed to
the registered holders, and, depending upon the significance of the amendment
and the manner of disclosure to the registered holders, Oglethorpe will extend
the Exchange Offer for a period of five to ten business days if the Exchange
Offer would otherwise expire during such five to ten business-day period.
Without limiting the manner in which Oglethorpe may choose to make public
announcement of any delay, extension, amendment or termination of the Exchange
Offer, Oglethorpe shall have no obligation to publish, advertise or otherwise
communicate any such public announcement, other than by making a timely release
to an appropriate news agency.
INTEREST ON EXCHANGE FACILITY BONDS AND THE PRIVATE FACILITY BONDS
The Exchange Facility Bonds will bear interest from the later of the date of
issuance of the Private Facility Bonds and the most recent interest payment date
to which interest on such Private Facility Bonds has been paid. Accordingly,
holders of Private Facility Bonds that are accepted for exchange will not
receive interest on the Private Facility Bonds that is accrued but unpaid at the
time of tender, but such interest will be payable on the Exchange Facility Bonds
on the first interest payment date after the
80
Expiration Date. Interest on the Exchange Facility Bonds will be payable
semiannually on each June 30 and December 31, commencing on June 30, 1998.
PROCEDURES FOR TENDERING
Only a holder of Private Facility Bonds may tender such Private Facility
Bonds in the Exchange Offer. To tender in the Exchange Offer, a holder must (i)
complete, sign and date the Letter of Transmittal, or a facsimile thereof, have
the signatures thereon guaranteed if required by the Letter of Transmittal and
mail or otherwise deliver such Letter of Transmittal or such facsimile, together
with any other required documents, to the Exchange Agent so as to be received by
the Exchange Agent at the address set forth below prior to 5:00 p.m., New York
City time, on the Expiration Date and (ii) deliver the Private Facility Bonds to
OPC Scherer 1997 Funding Corporation by book-entry transfer in accordance with
the procedures described below. Confirmation of such book-entry transfer must be
received by the Exchange Agent prior to the Expiration Date.
The tender by a holder and the acceptance thereof by OPC Scherer 1997
Funding Corporation will constitute an agreement between such holder and OPC
Scherer 1997 Funding Corporation in accordance with the terms and subject to the
conditions set forth herein and in the Letter of Transmittal.
THE METHOD OF DELIVERY OF THE LETTER OF TRANSMITTAL AND ALL OTHER REQUIRED
DOCUMENTS TO THE EXCHANGE AGENT IS AT THE ELECTION AND RISK OF THE HOLDER.
INSTEAD OF DELIVERY BY MAIL, IT IS RECOMMENDED THAT HOLDERS USE AN OVERNIGHT OR
HAND DELIVERY SERVICE. IN ALL CASES, SUFFICIENT TIME SHOULD BE ALLOWED TO ASSURE
DELIVERY TO THE EXCHANGE AGENT BEFORE THE EXPIRATION DATE. NO LETTER OF
TRANSMITTAL SHOULD BE SENT TO OGLETHORPE OR OPC SCHERER 1997 FUNDING
CORPORATION. HOLDERS MAY REQUEST THEIR RESPECTIVE BROKERS, DEALERS, COMMERCIAL
BANKS, TRUST COMPANIES OR NOMINEES TO EFFECT THE ABOVE TRANSACTIONS FOR SUCH
HOLDERS.
Any beneficial owners whose Private Facility Bonds are registered in the
name of a broker, dealer, commercial bank, trust company or other nominee and
who wishes to tender should contact the registered holder promptly and instruct
such registered holder to tender on such beneficial owner's behalf.
Signatures on the Letter of Transmittal or a notice of withdrawal, as the
case may be, must be guaranteed by an Eligible Institution described herein
unless the Private Facility Bonds tendered pursuant thereto are tendered (i) by
a registered holder who has not completed the box entitled "Special Registration
Instructions" or "Special Delivery Instructions" on the Letter of Transmittal or
(ii) for the account of an Eligible Institution. In the event that signatures on
a Letter of Transmittal or a notice of withdrawal, as the case may be, are
required to be guaranteed, such guarantee must be by a member firm of a
registered national securities exchange or of the National Association of
Securities Dealers, Inc., a commercial bank or trust company having an office or
correspondent in the United States or an "eligible guarantor institution" within
the meaning of Rule 17Ad-15 under the Exchange Act (each an "Eligible
Institution").
If the Letter of Transmittal is signed by a person other than the registered
holder of any Private Facility Bonds listed therein, such holder must deliver to
the Exchange Agent a properly completed bond power, signed by such registered
holder as such holder's name is registered on the books of the Bond Registrar
with the signature thereon guaranteed by an Eligible Institution. If the Letter
of Transmittal or bond powers are signed by trustees, executors, administrators,
guardians, attorneys-in-fact, officers of corporations or others acting in a
fiduciary or representative capacity, such persons should so indicate when
signing, and unless waived by Oglethorpe, evidence satisfactory to Oglethorpe of
their authority to so act must be submitted with the Letter of Transmittal.
81
Oglethorpe understands that the Exchange Agent will make a request promptly
after the date of this Prospectus to establish accounts with respect to the
Private Facility Bonds at The Depository Trust Company ("DTC") for the purpose
of facilitating the Exchange Offer, and subject to the establishment thereof,
any financial institution that is a participant in DTC's system may make
book-entry delivery of the Private Facility Bonds by causing DTC to transfer
such Private Facility Bonds into the Exchange Agent's account with respect to
the Private Facility Bonds in accordance with DTC's procedures for such transfer
period. Although delivery of the Private Facility Bonds may be effected through
book-entry transfer into the Exchange Agent's account at DTC, an appropriate
Letter of Transmittal properly completed and duly executed with any required
signature guarantee and all other required documents must in each case be
transmitted to and received or confirmed by the Exchange Agent at its address
set forth below on or prior to the Expiration Date, or, if the guaranteed
delivery procedures described below are complied with, within the time period
provided under such procedures. DELIVERY OF DOCUMENTS TO DTC DOES NOT CONSTITUTE
DELIVERY TO THE EXCHANGE AGENT.
All questions as to the validity, form, eligibility (including time of
receipt), acceptance of tendered Private Facility Bonds and withdrawal of
tendered Private Facility Bonds will be determined by Oglethorpe in its sole
discretion, which determination will be final and binding. Oglethorpe reserves
the absolute right to instruct OPC Scherer 1997 Funding Corporation to reject
any and all Private Facility Bonds not properly tendered or any Private Facility
Bonds OPC Scherer 1997 Funding Corporation's acceptance of which would, in the
opinion of counsel for Oglethorpe, be unlawful. Oglethorpe also reserves the
right to waive any defects, irregularities or conditions of tender as to
particular Private Facility Bonds. Oglethorpe's interpretation of the terms and
conditions of the Exchange Offer (including the instructions in the Letter of
Transmittal) will be final and binding on all parties. Unless waived, any
defects or irregularities in connection with tenders of Private Facility Bonds
must be cured within such time as Oglethorpe shall determine. Although
Oglethorpe intends to notify holders of defects or irregularities with respect
to tenders of Private Facility Bonds, none of Oglethorpe, OPC Scherer 1997
Funding Corporation, the Exchange Agent or any other person shall incur any
liability for failure to give such notification. Tenders of Private Facility
Bonds will not be deemed to have been made until such defects or irregularities
have been cured or waived. Any Private Facility Bonds received by the Exchange
Agent that are not properly tendered and as to which the defects or
irregularities have not been cured or waived will be returned by the Exchange
Agent to the tendering holders, unless otherwise provided in the Letter of
Transmittal, as soon as practicable following the Expiration Date.
GUARANTEED DELIVERY PROCEDURES
Holders of Private Facility Bonds who wish to tender their Private Facility
Bonds and (i) who cannot deliver the Letter of Transmittal or any other
documents required by the Letter of Transmittal to the Exchange Agent or (ii)
who cannot comply with the procedures for book-entry transfer of their Private
Facility Bonds, prior to the Expiration Date, may effect a tender if:
(a) the tender is made through an Eligible Institution;
(b) prior to the Expiration Date, the Exchange Agent receives from such
Eligible Institution a properly completed and duly executed Notice of
Guaranteed Delivery (by facsimile transmission, mail or hand delivery)
setting forth the name and address of the holder, the principal amount of
Private Facility Bonds tendered, stating that the tender is being made
thereby and guaranteeing that, within three New York Stock Exchange trading
days after the Expiration Date, the Letter of Transmittal (or facsimile
thereof), together with a confirmation of book-entry transfer of such
Private Facility Bonds into the Exchange Agent's account at DTC and any
other documents required by the Letter of Transmittal, will be deposited by
the Eligible Institution with the Exchange Agent; and
(c) such properly completed and executed Letter of Transmittal (or
facsimile thereof), as well as a confirmation of book-entry transfer of such
Private Facility Bonds into the Exchange Agent's
82
account at DTC and all other documents required by the Letter of
Transmittal, are received by the Exchange Agent within three New York Stock
Exchange trading days after the Expiration Date.
Upon request to the Exchange Agent, a Notice of Guaranteed Delivery will be
sent to holders who wish to tender their Private Facility Bonds according to the
guaranteed delivery procedures set forth above.
WITHDRAWALS OF TENDERS
Except as otherwise provided herein, tenders of Private Facility Bonds may
be withdrawn at any time prior to 5:00 p.m., New York City time, on the
Expiration Date.
To withdraw a tender of Private Facility Bonds in the Exchange Offer, a
written or facsimile transmission notice of withdrawal must be received by the
Exchange Agent at is address set forth herein prior to 5:00 p.m., New York City
time, on the Expiration Date. Any such notice of withdrawal must (i) specify the
name of the person having deposited the Private Facility Bonds to be withdrawn
(the "Depositor"), (ii) identify the Private Facility Bonds to be withdrawn
(including the name and number of the account at DTC to be credited), (iii) be
signed by the holder in the same manner as the original signature on the Letter
of Transmittal by which such Private Facility Bonds were tendered (including any
required signature guarantees) or be accompanied by documents of transfer
sufficient to have the Bond Registrar register the transfer of such Private
Facility Bonds into the name of the person withdrawing the tender and (iv)
specify the name in which any such Private Facility Bonds are to be registered,
if different from that of the Depositor. All questions as to the validity, form
and eligibility (including time or receipt) of such notices will be determined
by Oglethorpe, whose determination shall be final and binding on all parties.
Any Private Facility Bonds so withdrawn will be deemed not have been validly
tendered for purposes of the Exchange Offer and no Exchange Facility Bonds will
be issued with respect thereto unless the Private Facility Bonds so withdrawn
are validly retendered. Any Private Facility Bonds which have been tendered but
which are not accepted for exchange will be returned to the holder thereof
without cost to such holder as soon as practicable after withdrawal, rejection
of tender or termination of the Exchange Offer. Properly withdrawn Private
Facility Bonds may be retendered by following one of the procedures described
above under "--Procedures for Tendering" at any time prior to the Expiration
Date.
CONDITIONS
Notwithstanding any other term of the Exchange Offer, OPC Scherer 1997
Funding Corporation shall not be required to accept for exchange, or to exchange
Exchange Facility Bonds for any Private Facility Bonds, and Oglethorpe may
terminate or amend the Exchange Offer as provided herein before the acceptance
of such Private Facility Bonds, if:
(a) any law, statute, rule, regulation or interpretation by the staff of
the Commission is proposed, adopted or enacted, which, in the reasonable
judgment of Oglethorpe, might materially impair the ability of Oglethorpe or
OPC Scherer 1997 Funding Corporation to proceed with the Exchange Offer or
materially impair the contemplated benefits of the Exchange Offer to
Oglethorpe; or
(b) any governmental approval has not been obtained, which approval
Oglethorpe shall, in its reasonable judgment, deem necessary for the
consummation of the Exchange Offer as contemplated hereby.
If Oglethorpe determines in its reasonable judgment that any of the above
conditions are not satisfied, Oglethorpe may (i) instruct OPC Scherer 1997
Funding Corporation to refuse to accept any Private Facility Bonds and return
all tendered Private Facility Bonds to the tendering holders, (ii) extend the
Exchange Offer and instruct OPC Scherer 1997 Funding Corporation to retain all
Private Facility Bonds tendered prior to the expiration of the Exchange Offer,
subject, however, to the rights of holders to
83
withdraw such Private Facility Bonds (see "--Withdrawals of Tenders") or (iii)
waive such unsatisfied conditions with respect to the Exchange Offer and
instruct OPC Scherer 1997 Funding Corporation to accept all properly tendered
Private Facility Bonds which have not been withdrawn. If such waiver constitutes
a material change to the Exchange Offer, Oglethorpe will promptly disclose such
waiver by means of a prospectus supplement that will be distributed to the
registered holders, and, depending upon the significance of the waiver and the
manner of disclosure to the registered holders, Oglethorpe will extend the
Exchange Offer for a period of five to ten business days if the Exchange Offer
would otherwise expire during such five to ten business-day period.
EXCHANGE AGENT
____________________________ will act as Exchange Agent for the Exchange
Offer.
Questions and requests for assistance, requests for additional copies of
this Prospectus or of the Letter of Transmittal for the Private Facility Bonds
and requests for copies of Notice of Guaranteed Delivery should be directed to
the Exchange Agent, addressed as follows:
By mail or delivery services:
----------------------------------------------------
----------------------------------------------------
----------------------------------------------------
----------------------------------------------------
By hand delivery:
----------------------------------------------------
----------------------------------------------------
----------------------------------------------------
By facsimile (Eligible Institutions only):
(______) ______-______
For telephone inquiries:
(______) ______-______
FEES AND EXPENSES
The expense of the Exchange Offer will be borne by the Lessors. The
principal solicitation is being made by mail; however, additional solicitations
may be made by telegraph, telephone, facsimile or in person by officers and
regular employees of Oglethorpe and its affiliates or the Exchange Agent.
Oglethorpe has not retained a dealer-manager in connection with the Exchange
Offer and neither Oglethorpe nor the Lessors will make any payments to brokers
or other persons soliciting acceptances of the Exchange Offer. The Lessors,
however, will pay the Exchange Agent reasonable and customary fees for its
services and will reimburse it for its reasonable out-of-pocket expenses in
connection therewith and pay other registration expenses, including fees and
expenses of the Collateral Trust Trustee, filing fees, blue sky fees and
printing and distribution expenses.
The Lessors will generally pay all transfer taxes, if any, applicable to the
exchange of the Private Facility Bonds pursuant to the Exchange Offer. If,
however, tendered Private Facility Bonds are registered
84
in the name of any person other than the person signing the Letter of
Transmittal, or if a transfer tax is imposed for any reason other than the
exchange of the Private Facility Bonds pursuant to the Exchange Offer, then the
amount of any such transfer taxes (whether imposed on the registered holder or
any other person) will be payable by the tendering holder.
ACCOUNTING TREATMENT
The Exchange Facility Bonds will be recorded at the same carrying value as
the Private Facility Bonds, which is the aggregate principal amount, as
reflected in Oglethorpe's accounting records on the date of exchange.
Accordingly, no gain or loss for accounting purposes will be recognized in
connection with the Exchange Offer. The expenses of the Exchange Offer will be
amortized over the term of the Exchange Facility Bonds.
RESALE OF EXCHANGE FACILITY BONDS
Based on interpretations by the staff of the Commission set forth in
no-action letters issued to third parties in other transactions, Oglethorpe
believes that the Exchange Facility Bonds issued pursuant to the Exchange Offer
in exchange for Private Facility Bonds may be offered for resale, resold and
otherwise transferred by any holder of such Exchange Facility Bonds (other than
any such holder who is an "affiliate" of Oglethorpe within the meaning of Rule
405 under the Securities Act) without compliance with the registration and
prospectus delivery provisions of the Securities Act, provided that such
Exchange Facility Bonds are acquired in the ordinary course of such holder's
business and such holder does not intend to participate, and has no arrangement
or understanding with any person to participate, in the distribution of such
Exchange Facility Bonds. Any holder who tenders in the Exchange Offer with the
intention to participate, or for the purpose of participating, in a distribution
of the Exchange Facility Bonds or who is an affiliate of Oglethorpe may not rely
on the position of the staff of the Commission enunciated in Exxon Capital
Holdings Corporation (available April 13, 1989) and Morgan Stanley & Co.,
Incorporated (available June 5, 1991), or similar no-action letters, and, in the
absence of an exemption therefrom, must comply with the registration and
prospectus delivery requirements of the Securities Act in connection with any
secondary resale transaction. In addition, any such resale transaction should be
covered by an effective registration statement containing the selling security
holders information required by Item 507 of Regulation S-K of the Securities
Act. Each broker-dealer that receives Exchange Facility Bonds for its own
account in exchange for Private Facility Bonds, where such Private Facility
Bonds were acquired by such broker-dealer as a result of market making
activities or other trading activities, may be deemed a statutory underwriter
and must acknowledge that it will deliver a prospectus in connection with any
resale of such Exchange Facility Bonds.
By tendering in the Exchange Offer, each holder will represent to Oglethorpe
that, among other things, (i) the Exchange Facility Bonds acquired pursuant to
the Exchange Offer are being obtained in the ordinary course of business of the
person receiving such Exchange Facility Bonds, whether or not such person is a
holder, (ii) neither the holder nor any such other person has an arrangement or
understanding with any person to participate in the distribution of such
Exchange Facility Bonds and (iii) the holder and such other person acknowledge
that if they participate in the Exchange Offer for the purpose of distributing
the Exchange Facility Bonds (a) they must, in the absence of an exemption
therefrom, comply with the registration and prospectus delivery requirements of
the Securities Act in connection with any resale of the Exchange Facility Bonds
and cannot rely on the no-action letters referenced above and (b) failure to
comply with such requirements in such instance could result in such holder
incurring liability under the Securities Act. Further, by tendering in the
Exchange Offer, each holder that may be deemed an "affiliate" (as defined under
Rule 405 of the Securities Act) of Oglethorpe will represent to Oglethorpe that
such holder understands and acknowledges that the Exchange Facility Bonds may
not be offered for resale, resold or otherwise transferred by that holder
without registration under the Securities Act or an exemption therefrom.
85
CONSEQUENCES OF FAILURE TO EXCHANGE
As a result of completing this Exchange Offer, Oglethorpe will have
fulfilled certain of its obligations under the Registration Rights Agreement,
and holders of Private Facility Bonds who do not tender their Private Facility
Bonds will not have any further registration rights under the Registration
Rights Agreement or otherwise. Accordingly, any holder of Private Facility Bonds
that does not exchange that holder's Private Facility Bonds for Exchange
Facility Bonds will continue to hold such Private Facility Bonds and will be
entitled to all the same rights and will be subject to the same limitations
applicable thereto under the Collateral Trust Indenture, except to the extent
that such rights, by their terms, terminate or cease to have further
effectiveness as a result of the Exchange Offer.
The Private Facility Bonds that are not exchanged for Exchange Facility
Bonds pursuant to the Exchange Offer will remain restricted securities.
Accordingly, such Private Facility Bonds may be resold only (i) so long as the
Private Facility Bonds are eligible for resale pursuant to Rule 144A, to a
person who such holder reasonably believes is a qualified institutional buyer
within the meaning of Rule 144A under the Securities Act (acquiring for its own
account or for the account of a qualified institutional buyer) in a transaction
meeting the requirements of Rule 144A, (ii) pursuant to an exemption from
registration under the Securities Act provided by Rule 144 thereunder (if
available), (iii) to an institutional accredited investor within the meaning of
Rule 501(a)(1),(2),(3) or (7) of Regulation D under the Securities Act in a
transaction exempt from the registration requirements of the Securities Act (if
available), subject to the right of Oglethorpe to require the delivery of an
opinion of counsel, certification and/or other information satisfactory to it,
or (iv) pursuant to an effective Registration Statement under the Securities
Act, in each case in accordance with any applicable securities laws of the
states of the United States and other jurisdictions.
Oglethorpe has no present plans to acquire any Private Facility Bonds that
are not tendered in the Exchange Offer or to file a registration statement to
permit resales of any untendered Private Facility Bonds.
OTHER
Participation in the Exchange Offer is voluntary and holders should
carefully consider whether to tender their Private Facility Bonds. Holders of
the Private Facility Bonds are urged to consult their financial and tax advisors
in making their decisions on what action to take with respect to the Exchange
Offer.
86
DESCRIPTION OF THE FACILITY BONDS
The statements under this caption are summaries and do not purport to be
complete. Each summary is qualified in its entirety by reference to the
Collateral Trust Indenture, the Registration Rights Agreement and the Facility
Bonds, copies of which have been filed as an exhibit to the Registration
Statement of which this Prospectus is a part. (See "AVAILABLE INFORMATION.")
Upon the effectiveness of the Exchange Offer Registration Statement described
herein, the Collateral Trust Indenture will be subject to and governed by the
Trust Indenture Act of 1939, as amended (the "TIA"). Each summary is further
qualified in its entirety by reference to the TIA, including the definitions of
certain terms and those terms made a part of the Collateral Trust Indenture by
reference to the TIA. Capitalized terms used under this caption but not
otherwise defined shall have the meanings set forth in the Collateral Trust
Indenture.
GENERAL
The form and terms of the Exchange Facility Bonds will be the same as the
form and terms of the Private Facility Bonds except that (i) the Exchange
Facility Bonds will be registered under the Securities Act and hence will not
bear legends restricting the transfer thereof, (ii) the holders of the Exchange
Facility Bonds will not be entitled to registration rights under the
Registration Rights Agreement, which rights are being fulfilled by and will
terminate upon consummation of the Exchange Offer, and (iii) the Exchange
Facility Bonds will not contain any provision for additional interest in the
event of certain defaults in obligations of Oglethorpe relating to the Exchange
Offer. The Exchange Facility Bonds will evidence the same debt as the Private
Facility Bonds and will be entitled to the benefits of the Collateral Trust
Indenture. The Exchange Facility Bonds and any Private Facility Bonds not
exchanged in the Exchange Offer will be deemed a single series under the
Collateral Trust Indenture, and are sometimes collectively referred to herein as
the "Facility Bonds."
The Facility Bonds will be issued under the Collateral Trust Indenture among
OPC Scherer 1997 Funding Corporation, Oglethorpe and SunTrust Bank, Atlanta, as
Collateral Trust Trustee. The Facility Bonds are limited to an aggregate
principal amount of $224,702,000 of 6.974% Serial Facility Bonds Due June 30,
2011. The Facility Bonds will bear interest from the later of the date of
issuance of the Private Facility Bonds or the most recent interest payment date
to which interest on such Private Facility Bonds has been paid. Interest is
payable semiannually on June 30 and December 31 in each year, commencing June
30, 1998, to the person in whose name such Facility Bond is registered at the
close of business on the June 15 or December 15, as the case may be, next
preceding such interest payment date, subject to certain exceptions. If any
scheduled payment date for a Facility Bond is not a Business Day, payment will
be made on the next Business Day with the same effect as though made on the date
due. Interest on any overdue principal and premium, if any, and (to the extent
permitted by applicable law) any overdue interest shall be paid, on demand, from
the due date thereof at the lesser of (i) 2% above the greater of (A) the
published base rate of Citibank, N.A., in effect from time to time and (B)
6.974%, and (ii) the highest amount permitted by applicable law. Interest on the
Facility Bonds will be computed on the basis of a 360-day year of twelve 30-day
months. (Collateral Trust Indenture, Sections 2.01, 2.07 and 1.13.)
The Facility Bonds will be issued in book-entry-only form as described under
"Book-Entry-Only System" below. So long as the Facility Bonds are subject to the
book-entry-only system of registration and transfer described under the
"Book-Entry-Only System" below, all payments with respect to principal of and
premium, if any, and interest on such Facility Bonds will be made to DTC. If the
Facility Bonds are not subject to such book-entry-only system, the principal of
and premium (if any) and interest on the Facility Bonds will be payable at the
Collateral Trust Trustee's corporate trust office: SunTrust Bank, Atlanta, c/o
First Chicago Trust Company, 14 Wall Street, New York, New York 10005 (the
"Collateral Trust Trustee's New York Office"), except that payment of interest
will be made by check mailed to the address of the person entitled thereto as
shown in the Bond Register. (Collateral Trust Indenture, Sections 2.01 and
2.07.)
87
If the Facility Bonds are no longer subject to such book-entry-only system,
the Facility Bonds are to be issued in fully registered form without coupons in
denominations of $1,000 or any integral multiple thereof and the Facility Bonds
may be surrendered for registration of transfer or exchange for Facility Bonds
of the same series at the Collateral Trust Trustee's New York Office. No service
charge will be required of any Bondholder participating in any transfer or
exchange of Facility Bonds in respect of such transfer or exchange, but payment
may be required of any tax or other governmental charges that may be imposed in
connection therewith. (Collateral Trust Indenture, Sections 2.02 and 2.05.)
SINKING FUND REDEMPTION
The Collateral Trust Indenture will provide for the redemption of the
Facility Bonds, on a pro rata basis, through operation of a sinking fund on each
of the dates set forth below (other than maturity dates), at the principal
amount thereof, together with interest accrued to the redemption date, on not
less than 20 and not more than 60 days' notice by mail. The principal amounts of
the Facility Bonds to be redeemed on such dates, as well as the principal
amounts payable on the final maturity date, are set forth opposite such dates.
(Collateral Trust Indenture, Sections 6.05 and 7.01.)
FACILITY BONDS
--------------
June 30, 1998............................................... $ 0
December 31, 1998........................................... 6,555,000
June 30, 1999............................................... 0
December 31, 1999........................................... 11,112,000
June 30, 2000............................................... 0
December 31, 2000........................................... 11,719,000
June 30, 2001............................................... 0
December 31, 2001........................................... 12,064,000
June 30, 2002............................................... 0
December 31, 2002........................................... 14,067,000
June 30, 2003............................................... 0
December 31, 2003........................................... 16,117,000
June 30, 2004............................................... 3,513,000
December 31, 2004........................................... 13,719,000
June 30, 2005............................................... 3,651,000
December 31, 2005........................................... 14,564,000
June 30, 2006............................................... 5,485,000
December 31, 2006........................................... 15,371,000
June 30, 2007............................................... 23,883,000
December 31, 2007........................................... 0
June 30, 2008............................................... 25,453,000
December 31, 2008........................................... 0
June 30, 2009............................................... 20,383,000
December 31, 2009........................................... 0
June 30, 2010............................................... 17,724,000
December 31, 2010........................................... 0
June 30, 2011............................................... 9,322,000
The amortization schedules for the Refunding Lessor Notes are designed to
match the sinking fund schedules for the Facility Bonds. In the event that there
has been any partial redemption of Facility Bonds (other than pursuant to the
sinking fund), the principal amounts of Facility Bonds to be redeemed pursuant
to the sinking fund schedules indicated above after any such redemption shall be
adjusted in a manner which will preserve the relationship between such
amortization schedules and the sinking fund schedules for the remaining
outstanding Facility Bonds. (Collateral Trust Indenture, Section 7.01.)
88
OPTIONAL REDEMPTION
The Facility Bonds will not be subject to optional redemption prior to
maturity. Except in the case of sinking fund payments as provided above or in
the case of certain events resulting in mandatory redemption as provided below,
the Facility Bonds may not be redeemed, in whole or in part, prior to maturity.
SPECIAL MANDATORY REDEMPTION AT PAR
The Facility Bonds will be subject to mandatory redemption at par, in whole
or in part as indicated below, on not less than 20 nor more than 60 days' notice
by mail, at the principal amount thereof, together with interest accrued to the
redemption date, at such times as any Refunding Lessor Note is to be prepaid in
accordance with the terms of the respective Lease Indentures, but only if such
prepayment is made under one of the following circumstances, as certified to the
Collateral Trust Trustee by Oglethorpe and the Lessor whose Refunding Lessor
Note is being prepaid:
(a) EVENT OF LOSS RELATING TO SCHERER UNIT NO. 2. The Facility Bonds will be
redeemed in whole in connection with a prepayment of the Refunding Lessor Notes
with the proceeds of the payment by Oglethorpe of Stipulated Loss Value under
the Leases upon the occurrence of any of the following:
(i) the loss of Scherer Unit No. 2, in its entirety or substantially in
its entirety, due to destruction or, in the good faith and reasonable
opinion of Oglethorpe, damage beyond economic repair (Collateral Trust
Indenture, Section 6.01(b)(i)(A));
(ii) the receipt of insurance proceeds based upon an actual or
constructive total loss with respect to Scherer Unit No. 2 (Collateral Trust
Indenture, Section 6.01(b)(i)(B)); and
(iii) Scherer Unit No. 2, the Scherer Unit No. 2 Site or the Scherer
Common Facilities (in their entirety or a substantial portion of any thereof
such that the then remaining portion cannot practically be utilized for the
purposes intended) shall have been condemned or otherwise permanently
rendered unfit for normal use, confiscated or seized, or title thereto or
use thereof shall have been requisitioned by any governmental authority and,
in the case of any such requisition, Oglethorpe shall have lost the use or
possession of substantially all of Scherer Unit No. 2 or the Scherer Unit
No. 2 Site for a period exceeding 48 months. (Collateral Trust Indenture,
Section 6.01(b)(i)(C).) (See "DESCRIPTION OF THE LEASES--Events of Loss.")
(b) OBSOLESCENCE TERMINATION. The Facility Bonds will be redeemed in whole
in connection with a prepayment of the Refunding Lessor Notes resulting from an
election by Oglethorpe to exercise its rights of early termination under each
Lease as a result of the adoption by its Board of Directors of a resolution
determining that (i) the leased undivided interests in Scherer Unit No. 2 are
surplus to the requirements of Oglethorpe or (ii) Scherer Unit No. 2 is
economically obsolete. (Collateral Trust Indenture, Section 6.01(b)(i)(D).) (See
"DESCRIPTION OF THE LEASES--Optional Termination for Obsolescence.")
(c) REGULATION. Subject to certain exceptions, the Facility Bonds will be
redeemed in a principal amount equal to the principal amount of the Refunding
Lessor Note prepaid as a result of the payment by Oglethorpe of amounts required
or permitted under any Lease in the event that (i) solely by reason of the Sale
and Leaseback Transactions and without regard to any other activities or
transactions, the Lessor under such Lease, the related Equity Investor or any of
their affiliates (A) becomes subject to regulation pursuant to the Public
Utility Holding Company Act of 1935 or the Federal Power Act or (B) becomes
subject to regulation under certain provisions of state and federal laws
pertaining to the regulation of public utilities as such (other than regulation
under which the obligations of such Lessor or such affiliate may be discharged
by Oglethorpe pursuant to the applicable Lease and which Oglethorpe has not
failed timely to discharge) unless (w) in the case of regulation under the
Public Utility Holding Company Act of 1935 or the Federal Power Act such
regulation shall not be materially adverse with respect to such Lessor in the
reasonable judgment of such Lessor, (x) in either case, such regulation results
from an ownership or leasehold interest in any other electric generation
facility or transmission
89
facility acquired on or after December 30, 1985, or any such person was subject
to such regulation prior to such date or prior to becoming a Lessor or Equity
Investor, (y) in either case, such person has waived in writing the treatment of
such regulation as an event requiring Oglethorpe to make any payments, or (z) in
either case, Oglethorpe, at its sole cost and expense, is contesting such
regulation, subject to certain conditions; or (ii) the Lessor under such Lease
or the related Equity Investor shall become subject to regulation pursuant to
the Public Utility Holding Company Act of 1935 or the Federal Power Act and, as
a result thereof, (A) such Lease is deemed to be a contract for the sale by such
Lessor of electric energy to Oglethorpe under Section 205 or 206 of the Federal
Power Act, (B) Oglethorpe shall become subject to regulation which is contrary
to the terms of any agreement to which Oglethorpe is a party or applicable law
to which Oglethorpe is subject relating to the generation, transmission,
production or sale of electric power or steam energy, or (C) Oglethorpe shall
become subject to regulation which would not otherwise be applicable to
Oglethorpe and which Oglethorpe, in its reasonable judgment, determines to be
materially adverse to it and action shall not have been taken within 60 days to
eliminate such regulation. (Collateral Trust Indenture, Section 6.01(b)(ii)(A)
and (B).) (See "DESCRIPTION OF THE LEASES-- Events of Loss.")
(d) BURDENSOME TAX INDEMNITY; CHANGE IN TAX LAW. The Facility Bonds will be
redeemed in a principal amount equal to the principal amount of the Refunding
Lessor Note prepaid as a result of the exercise by Oglethorpe of its option
under any Lease to purchase the undivided ownership interest of a Lessor in
Scherer Unit No. 2 in the event that a tax indemnity becomes payable to such
Lessor's related Equity Investor under the Tax Indemnification Agreement between
Oglethorpe and such Equity Investor as a result of a change in tax laws enacted
by the 99th Congress or a final determination that such undivided interest
constitutes "public utility property" (as such term is defined in the Code),
but, in the case of a change in tax law, only if the aggregate of the present
value of increases in basic rent payable under such Lessor's Lease resulting
from such indemnity payment would exceed 4% of Lessor's Cost. (Collateral Trust
Indenture, Section 6.01(b)(ii)(C).) (See "DESCRIPTION OF THE LEASES--Purchase
and Renewal Options.")
(e) CERTAIN CAPITAL IMPROVEMENTS. The Facility Bonds will be redeemed in a
principal amount equal to the principal amount of the Refunding Lessor Note
prepaid as a result of the exercise by Oglethorpe of its option under any Lease
to purchase the undivided ownership interest of the applicable Lessor in Scherer
Unit No. 2, which option may be exercised on any December 31 between December
31, 1997 and December 31, 2010, if (x) "scrubbers" or any similar capital
improvement intended to remove pollutants from the effluent discharged from the
boiler of Scherer Unit No. 2 are required by applicable law, (y) capital
improvements consisting of a single project are included in the Ownership
Agreement budget for Scherer Unit No. 2, 60% of the value of which (expressed in
December 30, 1985 dollars) equals or exceeds $100,000,000, or (z) capital
improvements are included in such budget in any two-year period, 60% of the
value of which (expressed in December 30, 1985 dollars) equals or exceeds
$50,000,000, and the related Equity Investor does not finance such improvements
through an equity investment. (Collateral Trust Indenture, Section
6.01(b)(ii)(D).) (See "DESCRIPTION OF THE LEASES-- Purchase and Renewal
Options.")
SPECIAL MANDATORY REDEMPTION WITH PREMIUM
The Facility Bonds will also be subject to mandatory redemption, in whole or
in part as indicated below, at the redemption prices set forth below, together
with interest accrued to the redemption date, as follows:
(a) PURCHASE OPTIONS. The Facility Bonds will be redeemed in a principal
amount equal to the principal amount of the applicable Refunding Lessor Note
prepaid in connection with the exercise by Oglethorpe of its option under any
Lease to purchase the undivided ownership interest of the Lessor thereunder,
which option may be exercised on December 31, 2000, December 31, 2005, or
December 31, 2010. (Collateral Trust Indenture, Section 6.01(a)(i).) Such
redemption will be made on not less
90
than 20 nor more than 60 days' notice by mail. (Collateral Trust Indenture,
Section 6.05.) (See "DESCRIPTION OF THE LEASES--Purchase and Renewal Options.")
(b) DECOMMISSIONING OF SCHERER UNIT NO. 2. The Facility Bonds will be
redeemed in whole in connection with a prepayment of the Refunding Lessor Notes
with the proceeds of the payment by Oglethorpe of Stipulated Loss Values under
the Leases upon the occurrence of the permanent decommissioning and retiring
from commercial service of Scherer Unit No. 2. (Collateral Trust Indenture,
Section 6.01(a)(ii).) Such redemption will be made on not less than 20 nor more
than 60 days' notice by mail. (Collateral Trust Indenture, Section 6.05.) (See
"DESCRIPTION OF THE LEASES--Events of Loss.")
(c) DEFAULT UNDER LESS THAN ALL LEASE INDENTURES. The Facility Bonds will be
redeemed in part on the third Business Day following receipt by the Collateral
Trust Trustee of any amount recovered by the Collateral Trust Trustee in respect
of the Facility Bonds in excess of $5,000,000 as the result of the exercise of
remedies by the Collateral Trust Trustee in respect of defaulted Refunding
Lessor Notes in accordance with the Collateral Trust Indenture under
circumstances in which less than all Refunding Lessor Notes are in default. The
principal amount of Facility Bonds to be redeemed on any such date will be equal
to the amounts so recovered on or prior to the third Business Day immediately
preceding such redemption date and not theretofore applied toward the redemption
of Facility Bonds on such date, reduced by any premium payable and the interest
on the Facility Bonds being redeemed on such date. (Collateral Trust Indenture,
Section 6.01(a)(iii).) Notice of such redemption will be given by telephone,
telex, telecopier or other electronic or wire transmission as promptly as
practicable after amounts in excess of $5,000,000 are so recovered, confirmed by
mail. (Collateral Trust Indenture, Section 6.05.) (See "Events of Default,
Notice and Waiver" below.)
(d) DETERMINATION THAT UNDIVIDED INTEREST IS SURPLUS. The Facility Bonds
will be redeemed in a principal amount equal to the principal amount of the
Refunding Lessor Notes prepaid in connection with an election by Oglethorpe to
exercise its rights of early termination under less than all the Leases, as a
result of the adoption by its Board of Directors of a resolution determining
that the undivided ownership interest covered by the Lease or Leases being
terminated is surplus to the requirements of Oglethorpe. (Collateral Trust
Indenture, Section 6.01(a)(iv).) Such redemption will be made on not less than
20 nor more than 60 days' notice by mail. (Collateral Trust Indenture, Section
6.05.) (See "DESCRIPTION OF THE LEASES--Optional Termination for Obsolescence.")
(e) REDEMPTION PRICES. The Facility Bonds subject to mandatory redemption as
described in paragraphs (a) through (d) above on the following dates shall be
redeemed at the following redemption prices (expressed as a percentage amount),
together with interest accrued to the redemption date:
TWELVE MONTHS REDEMPTION
PERIOD BEGINNING PRICE
- ------------------------------------------------------------------------------ -------------
January 1, 1998............................................................... 106.974%
January 1, 1999............................................................... 106.438
January 1, 2000............................................................... 105.901
January 1, 2001............................................................... 105.365
January 1, 2002............................................................... 104.828
January 1, 2003............................................................... 104.292
January 1, 2004............................................................... 103.755
January 1, 2005............................................................... 103.219
January 1, 2006............................................................... 102.682
January 1, 2007............................................................... 102.146
January 1, 2008............................................................... 101.609
January 1, 2009............................................................... 101.073
January 1, 2010............................................................... 100.536
January 1, 2011............................................................... 100.000
91
SELECTION OF FACILITY BONDS TO BE REDEEMED
If less than all of the Facility Bonds are to be redeemed, other than
through operation of the sinking fund, the Facility Bonds to be redeemed will be
selected, not more than 60 days prior to the redemption date, by the Collateral
Trust Trustee as follows: the Collateral Trust Trustee will select for
redemption an aggregate principal amount of Facility Bonds equal to the
aggregate amounts of principal which are being prepaid, or in respect of which
amounts have been recovered, such selection to be made pro rata as among all
Facility Bonds; provided that the Collateral Trust Trustee shall make such
adjustments as it shall deem necessary so that the principal amount of the
Facility Bonds from any holder shall be $1,000 or any integral multiple thereof.
(Collateral Trust Indenture, Sections 6.04 and 7.02.)
SECURITY AND SOURCE OF PAYMENT FOR THE FACILITY BONDS
OPC Scherer 1997 Funding Corporation was formed for the exclusive purpose of
facilitating the financing of Scherer Unit No. 2 and has only nominal equity
capital. As such, the source of payments of principal of and premium, if any,
and interest on the Facility Bonds will be derived from payments made on the
Refunding Lessor Notes issued by the Lessors pursuant to their respective Lease
Indentures. The aggregate principal amount of the Refunding Lessor Notes to be
delivered to the Collateral Trust Trustee equals the aggregate principal amount
of the Facility Bonds. The payment schedules for the Refunding Lessor Notes are
structured to coincide as to dates and amounts with the payment schedules for
the Facility Bonds. Each of these schedules, in turn, is structured to coincide
as to dates and amounts with the rental payment dates under the Leases. As
described below, Oglethorpe's obligation to pay rent pursuant to the Leases
provides the sources of payment for the Refunding Lessor Notes. Accordingly,
subject to the matters discussed below under "Considerations Relating to
Security," the timely payment of the principal of and premium, if any, and
interest of the Refunding Lessor Notes of the Lessors will provide for the
payment in full of the principal of and premium, if any, and interest on the
Facility Bonds when due.
Each Lease is a net lease under which Oglethorpe is unconditionally
obligated to make basic rental and certain other payments at least sufficient to
provide for the payments of the Lessor Notes of the Lessor which is a party to
such Lease, without any right of counterclaim, setoff, deduction or defense on
the part of Oglethorpe. Each Lease, by its terms, requires that rent be paid by
Oglethorpe in such amounts and at such times as will always provide for the
payment of the principal of and premium, if any, and interest on all such Lessor
Notes when due. As such, the expected sources of payment for the Refunding
Lessor Notes, and thus for the Facility Bonds, are the payments to be made by
Oglethorpe under the Leases, subject to the matters discussed below under
"Consideration Relating to Security."
The Refunding Lessor Notes were issued under separate Lease Indentures by
the Lessors without recourse to the general credit of any Lessor or its Equity
Investor. The Refunding Lessor Note of each Lessor are secured under a separate
Lease Indenture by, among other things: (i) a lien on and security interest in
each Lessor's respective undivided ownership interest in Scherer Unit No. 2;
(ii) each Lessor's rights under its Lease, including the right to receive all
rents payable thereunder other than amounts which constitute Excepted Payments;
and (iii) each Lessor's rights under the related Support Agreements, which are
designed to provide to such Lessor such additional resources, services and
facilities as are necessary or desirable to operate Scherer Unit No. 2 for a
period from the expiration of such Lessor's Lease to the end of the estimated
useful life of Scherer Unit No. 2. The Support Agreements provide for (x) the
common use of certain facilities which are necessary for the operation of all
generating units located at the Scherer Unit No. 2 Site and the operation of
Scherer Unit No. 2 following the expiration or earlier termination (other than
in connection with an Event of Loss) of any Lease and (y) the lease to the
Lessors of portions of the real property comprising the Scherer Unit No. 2 Site
(including the property upon which Scherer Unit No. 2 is located).
92
Subject to the limitations described below, Additional Notes will be
permitted to be issued under each Lessor's Lease Indenture (i) for the purpose
of refinancing any previously issued Lessor Notes, including the Refunding
Lessor Notes; (ii) to provide funds in connection with certain requirements of
the related Tax Indemnification Agreement; and (iii) to provide funds for
Capital Improvements. No Additional Notes to be issued for the purposes set
forth in (ii) above may be issued if the aggregate principal amount of all
Lessor Notes outstanding under such Lease Indenture (including the proposed
Additional Notes) exceeds 80% of Lessor's Cost. No Lessor Notes to be issued for
the purpose set forth in (iii) above may be issued: (1) if the aggregate
principal amount of all Lessor Notes issued and outstanding under such Lease
Indenture (including the proposed Additional Notes) exceeds an amount equal to
80% of the sum of (A) the Lessor's Cost, (B) such Lessor's share of the
cumulative cost of all additions and improvements theretofore incorporated or
installed in Scherer Unit No. 2 during the term of the Lease and financed by
such Lessor or with Lessor Notes, and (C) such Lessor's share of the cost of the
additions and improvements proposed to be financed with such Additional Notes;
or (2) if the aggregate principal amount of all Additional Notes issued under
such Lease Indenture for the purpose set forth in (iii) above (including the
proposed Additional Notes) exceeds an amount equal to 80% of the sum of (A) such
Lessor's share of the cumulative cost of all additions and improvements
theretofore incorporated or installed in Scherer Unit No. 2 during the term of
the Lease and (B) the cost of the additions and improvements proposed to be
financed with such Additional Notes. Moreover, the aggregate principal amount of
all Lessor Notes issued under all Lease Indentures for the purpose set forth in
(iii) above may not exceed $125,000,000. As a further condition to the issuance
of Additional Notes for the purposes set forth in (ii) and (iii) above, at least
10 days must have passed from the time the applicable Lease Indenture Trustee
shall have given notices to holders of the related Lessor Notes of the proposed
issuance of such Additional Notes, and the holders of such Lessor Notes shall
not have notified such Lease Indenture Trustee that certain requirements for
issuing Additional Notes have not been met and directed such Lease Indenture
Trustee not to allow the issuance of such Additional Notes.
CONSIDERATIONS RELATING TO SECURITY
As described above, the Refunding Lessor Notes have been pledged and
assigned to the Collateral Trust Trustee as security for the Facility Bonds. Set
forth below are certain factors which may affect the ability of the Collateral
Trust Trustee to realize upon the security afforded by such notes.
POSSIBLE REJECTION OF LEASES BY A TRUSTEE IN BANKRUPTCY
Under Georgia law, it is likely that the Leases will be viewed as leases of
real, rather than personal, property. Under Section 502(b)(6) of the Bankruptcy
Reform Act of 1978 (the "Bankruptcy Code"), a claim by a lessor for damages
resulting from the termination of a lease of real property in connection with
bankruptcy proceedings affecting the lessee may be limited to an amount equal to
the rent reserved under the lease, without acceleration, for the greater of one
year or 15 percent (but not more than three years) of the remaining term of the
lease, plus rent already due but unpaid. A lease of real property would not be
subject to the foregoing limitations, however, if it constituted a "financing
lease" within the meaning of the Bankruptcy Act. Although the issue has not been
definitively addressed by the courts, a court reasonably could conclude that the
Leases constitute "financing leases" for purposes of the Bankruptcy Code.
To the extent that the Leases were held not to constitute "financing
leases," however, if Oglethorpe or its trustee elected to reject the Leases in
connection with a bankruptcy or reorganization proceeding involving Oglethorpe,
Oglethorpe might not be required to pay the full amount of rental payments
thereunder and the resulting claims of the Lease Indenture Trustees, as
assignees of the Lessors, for damages resulting from such rejection of the
Leases may be limited to an amount less than the then outstanding principal
amount of the Lessor Notes and, consequently, less than the outstanding
principal amount of the Facility Bonds. It should be noted that rejection of the
Leases by Oglethorpe or its trustee
93
in such a bankruptcy proceeding would deprive Oglethorpe or such trustee of the
use of the interest in Scherer Unit No. 2 represented by such rejected Leases
and any revenues which could be derived from the sale of the output of such Unit
allocable to such interest. If, on the other hand, the Leases were held to
constitute "financing leases," no such limitations would apply and the Lessors
would have available to them all of the remedies described under "DESCRIPTION OF
THE LEASES--Events of Default."
MORTGAGE INDENTURE
All of the revenues of Oglethorpe, including revenues derived under the
Wholesale Power Contracts with its Members, are subject to the first mortgage
lien of the Mortgage Indenture. In the event of a default by Oglethorpe under
the Mortgage Indenture, the Mortgage Indenture Trustee could take steps which
might result in a diversion of all or a portion of such revenues from payment of
the obligations of Oglethorpe under the Leases.
BOOK-ENTRY-ONLY SYSTEM
GENERAL
The following description of the operations and procedures of DTC is
provided solely as a matter of convenience. These operations and procedures are
solely within the control of DTC and are subject to change from time to time.
Neither Oglethorpe nor OPC Scherer 1997 Funding Corporation takes responsibility
for these operations and procedures and urges investors to contact DTC or its
participants directly to discuss these matters.
The Facility Bonds will be issued only in book-entry-only form in
denominations of $1,000 principal amount and integral multiples thereof. The
Exchange Facility Bonds issued in exchange for Private Facility Bonds currently
evidenced by one or more fully registered global certificates initially will be
represented by one or more certificates in registered, global form without
interest coupons. The global certificates will be deposited upon issuance with
the Collateral Trust Trustee as custodian for DTC in New York, New York and
registered in the name of Cede & Co., as nominee for DTC, in each case for
credit to an account of a direct or indirect participant in DTC as described
below.
DTC is a limited purpose trust company organized under the New York Banking
Law, a "banking organization" within the meaning of the New York Banking Law, a
member of the Federal Reserve System, a "clearing corporation" within the
meaning of the New York Uniform Commercial Code, and a "clearing agency"
registered pursuant to the provisions of Section 17A of the Securities Exchange
Act of 1934, as amended (the "Exchange Act"). DTC holds securities that its
participants (the "Direct Participants") deposit with DTC. DTC also facilitates
the settlement among Direct Participants of securities transactions, such as
transfer and pledges, in deposited securities through electronic computerized
book-entry changes in Direct Participants' accounts, thereby eliminating the
need for physical movement of securities certificates. Direct Participants
include securities brokers and dealers, banks, trust companies, clearing
corporations and certain other organizations. DTC is owned by a number of its
Direct Participants and by the New York Stock Exchange, Inc., the American Stock
Exchange, Inc. and the National Association of Securities Dealers, Inc. Access
to the DTC system is also available to others, such as securities brokers and
dealers, banks and trust companies that clear through or maintain a custodial
relationship with a Direct Participant, either directly or indirectly (the
"Indirect Participants," and together with the Direct Participants, the
"Participants"). The rules applicable to DTC and its Participants are on file
with the Commission.
Purchases of Facility Bonds under the DTC system must be made by or through
Direct Participants, who will receive a credit for such Facility Bonds on DTC's
records. The ownership interest of each actual purchaser of each Facility Bond
(a "Beneficial Owner") is in turn to be recorded on the Direct and Indirect
Participant's records. Beneficial Owners will not receive written confirmation
from DTC of their
94
purchases, but Beneficial Owners are expected to receive written confirmations
providing details of the transaction, as well as periodic statements of their
holdings, from the Direct or Indirect Participant through whom such Beneficial
Owner entered into the transaction. Transfers of ownership interests in the
Facility Bonds are to be accomplished by entries made on the books of
Participants acting on behalf of Beneficial Owners. Beneficial Owners will not
receive nor have the right to receive physical delivery of certificates
representing their ownership interests in the Facility Bonds, and will not be or
be considered to be holders thereof under the Collateral Trust Indenture, except
as specifically provided in the Collateral Trust Indenture in the event the
book-entry-only system is discontinued.
So long as Cede & Co. is the registered owner of the Facility Bonds subject
to the book-entry-only system, as nominee for DTC, references herein to the
bondholders or registered owners or owners of such Facility Bonds shall mean
Cede & Co., as aforesaid, and shall not mean the beneficial owners of such
Facility Bonds, as the case may be.
To facilitate subsequent transfer, the Facility Bonds deposited by
Participants with DTC are registered in the name of DTC's partnership nominee,
Cede & Co. The deposit of Facility Bonds with DTC and their registration in the
name of Cede & Co. effect no change in beneficial ownership. DTC has no
knowledge of the actual Beneficial Owners of the Facility Bonds; DTC's records
reflect only the identity of the Direct Participants to whose accounts such
Facility Bonds are credited, which may or may not be the Beneficial Owners. The
Participants will remain responsible for keeping account of their holdings on
behalf of their customers.
Oglethorpe, OPC Scherer 1997 Funding Corporation and the Collateral Trust
Trustee may treat DTC (or its nominee) as the sole and exclusive owner of the
Facility Bonds registered in its name for the purpose of: payment of the
principal of or interest on such Facility Bonds; selecting such Facility Bonds
and portions thereof to be redeemed; giving any notice permitted or required to
be given to holders under the Collateral Trust Indenture, including any notice
of redemption; registering the transfer of the Facility Bonds; obtaining any
consent or other action to be taken by holders; and for all other purposes
whatsoever, and shall not be affected by any notice to the contrary. Oglethorpe,
OPC Scherer 1997 Funding Corporation and the Collateral Trust Trustee shall not
have any responsibility or obligation to any Direct Participant, any person
claiming a beneficial ownership interest in the Facility Bonds under or through
DTC or any Direct Participant, or any other person which is not shown on the
books of registration kept by the Bond Registrar as being a holder, with respect
to: the accuracy of any records maintained by DTC or any Direct or Indirect
Participant regarding ownership interests in the Facility Bonds; the payment by
DTC or any Direct or Indirect Participant of any amount in respect of the
principal of or interest on the Facility Bonds; the delivery to any Direct or
Indirect Participant or any Beneficial Owner of any notice which is permitted or
required to be given to holders under the Collateral Trust Indenture, including
any notice of redemption; the selection by DTC or any Direct or Indirect
Participant of any person to receive payment in the event of a partial
redemption of such Facility Bonds; or any consent given or other action taken by
DTC as an owner of the Facility Bonds.
Neither DTC nor Cede & Co. will consent or vote with respect to the Facility
Bonds. Under its usual procedures, DTC mails an Omnibus Proxy to the issuer as
soon as possible after the "record date." The Omnibus Proxy assigns Cede & Co.'s
consenting or voting rights to those Direct Participants to whose accounts
securities, such as the Facility Bonds, are credited on the record date
(identified in a listing attached to the Omnibus Proxy).
Except as described below, neither DTC nor Cede & Co. will take any action
to enforce covenants with respect to any security registered in the name of Cede
& Co. Under its current procedures, on the written instructions of a Direct
Participant, DTC will cause Cede & Co. to sign a demand to exercise certain
bondholder rights. In accordance with DTC's current procedures, Cede & Co. will
sign such document only as a record holder of the quantity of securities
referred to therein (which is to be specified in the Direct Participant's
request to DTC for such document) and not as record holder of all the
95
securities of that issue registered in the name of Cede & Co. Also, in
accordance with DTC's current procedures, all factual representations to the
issuer, the trustee or any other party to be made by Cede & Co. in such document
must be made to DTC and Cede & Co. by the Direct Participant in its request to
DTC.
For so long as the Facility Bonds are issued in book-entry-only form through
the facilities of DTC, any Beneficial Owner desiring to cause Oglethorpe, OPC
Scherer 1997 Funding Corporation or the Collateral Trust Trustee to comply with
any of its obligations with respect to the Facility Bonds, as the case may be,
must make arrangements with the Direct Participant or Indirect Participant
through whom such Beneficial Owner's ownership interest in the Facility Bonds is
recorded in order for the Direct Participant in whose DTC account such ownership
interest is recorded is make the request of DTC described above.
None of Oglethorpe, OPC Scherer 1997 Funding Corporation or the Collateral
Trust Trustee will have any obligation to the Direct Participants, the Indirect
Participants or the persons for whom they act as nominees with respect to DTC's
procedures or any procedures or arrangements between Direct Participants,
Indirect Participants and the persons for whom they act relating to the making
of any demand by Cede & Co. As the registered owner of Facility Bonds, the
adherence to such procedures or arrangements or the effectiveness of any action
taken pursuant to such procedures or arrangements.
Subject to the following considerations, beneficial interests in the
Facility Bonds will trade in DTC's Same-Day Funds Settlement System, and
secondary market trading activity in such interests will therefore settle in
immediately available funds. Oglethorpe expects that DTC, upon receipt of
payment of principal and interest in respect of a beneficial interest in the
Facility Bonds, will immediately credit Direct Participants' accounts with
payments in amounts proportional to their respective beneficial interests in the
principal amount of the Facility Bonds as shown on its records. Oglethorpe also
expects payments by Participants to Beneficial Owners will be governed by
standing instructions and customary practices, as is the case with securities
held for the accounts of customers in bearer form or registered in "street
name," and will be the responsibility of such Participant and not of DTC,
Oglethorpe, OPC Scherer 1997 Funding Corporation or the Collateral Trust
Trustee, subject to any statutory or regulatory requirements as may be in effect
from time to time. Payment of principal and interest to DTC is the
responsibility of the Collateral Trust Trustee, disbursement of such payments to
Direct Participants shall be the responsibility of DTC, and disbursement of such
payments to the Beneficial Owners shall be the responsibility of Direct and
Indirect Participants.
As long as the book-entry-only system is used for the Facility Bonds, the
Collateral Trust Trustee will give any notice of redemption or any other notices
required to be given to holders of the Facility Bonds only to DTC. Any failure
of DTC to advise any Direct Participant, or of any Direct Participant to notify
any Indirect Participant, or of any Direct or Indirect Participant to notify any
Beneficial Owner, of any such notice and its content or effect will not affect
the validity of the redemption of the Facility Bonds called for such redemption
or of any other action premised on such notice. Conveyance of notices and other
communications by DTC to Direct Participants, by Direct Participants to Indirect
Participants and by Direct and Indirect Participants to Beneficial Owners will
be governed by arrangements among them, subject to any statutory or regulatory
requirements as may be in effect from time to time. Beneficial Owners may desire
to make arrangements with a Direct or Indirect Participant so that all notices
of redemption or other communications to DTC which affect such Beneficial Owners
will be forwarded in writing by such Direct or Indirect Participant. If less
than all of the Facility Bonds are being redeemed, DTC's practice is to
determine by lot the amount of the interest of each Direct Participant to be
redeemed.
For every transfer and exchange of a beneficial ownership interest in the
Facility Bonds, a Beneficial Owner may be charged a sum sufficient to cover any
tax, fee or other governmental charge that may be imposed in relation thereto.
96
DISCONTINUATION OF THE BOOK-ENTRY-ONLY SYSTEM
DTC may determine to discontinue providing its service with respect to the
Facility Bonds at any time by giving reasonable notice to Oglethorpe, OPC
Scherer 1997 Funding Corporation or the Collateral Trust Trustee. In addition,
if Oglethorpe determines that: (i) DTC is unable to discharge its
responsibilities with respect to the Facility Bonds or (ii) continuation of the
system of book-entry- only transfers through DTC is not in the best interests of
the Beneficial Owners of the Facility Bonds or of Oglethorpe, Oglethorpe may
thereupon terminate the services of DTC with respect to the Facility Bonds. Upon
the resignation of DTC or determination of Oglethorpe that DTC is unable to
discharge its responsibilities, Oglethorpe may, within 30 days, appoint a
successor depository. If no such successor is appointed or Oglethorpe determines
to discontinue the book-entry-only system, Facility Bond certificates will be
delivered in fully registered form in authorized denominations to the
identifiable Beneficial Owners in replacement of such Beneficial Owners'
beneficial interests in the Facility Bonds. Transfer and exchanges of the
Facility Bonds shall thereafter be made as described herein under the caption
"General" above.
If the book-entry-only system is discontinued with respect to the Facility
Bonds, the persons to whom Facility Bonds certificates are delivered will be
treated as "bondholders" for all purposes of the Collateral Trust Indenture,
including without limitation the payment of principal and interest, the
redemption of such Facility Bonds and the giving to Oglethorpe, OPC Scherer 1997
Funding Corporation or the Collateral Trust Trustee of any notice, consent,
request or demand pursuant to the Collateral Trust Indenture for any purpose
whatsoever. In such event, principal and interest on the Facility Bonds, as
applicable, will be payable in the manner described under the caption "General"
above.
MERGER, CONSOLIDATION AND TRANSFER OF ASSETS
The certificate of incorporation of OPC Scherer 1997 Funding Corporation
provides, among other things, that OPC Scherer 1997 Funding Corporation shall
not, without the consent of each Lease Indenture Trustee, (i) dissolve or
liquidate, in whole or in part, or (ii) merge into or consolidate with, or sell
all or any part of its assets to, any person, firm, corporation, partnership or
other entity unless, in the case of a merger or consolidation, the surviving
corporation in such merger or the corporation resulting from such consolidation
shall have a certificate of incorporation containing identical provisions to
those of OPC Scherer 1997 Funding Corporation restricting the nature of its
business and purposes and its ability to take certain action, and, in the case
of a sale of assets, the acquiring corporation shall have assumed all the
liabilities and obligations of OPC Scherer 1997 Funding Corporation and shall
have such identical provisions in its certificate of incorporation. In addition,
OPC Scherer 1997 Funding Corporation has agreed in each of the Participation
Agreements and in the Collateral Trust Indenture that it will not amend those
provisions of its certificate of incorporation which restrict the nature of its
business and its purposes or restrict its activities or which provide for its
capitalization without the consent of the holders of not less than 66 2/3% in
aggregate principal amount of the Facility Bonds then outstanding. (Collateral
Trust Indenture, Section 5.08.)
97
EVENTS OF DEFAULT, NOTICE AND WAIVER
Events of Default under the Collateral Trust Indenture include: (a) default
in the payment of any principal of or premium, if any, or interest on any
Facility Bond, including any sinking fund payment, when it becomes due and
payable, and continuance of such default for a period of three Business Days;
(b) default in the performance, or breach, of any covenant of Oglethorpe or OPC
Scherer 1997 Funding Corporation contained in the Collateral Trust Indenture and
continuance of such default or breach for a period of 30 days after there has
been given, by registered or certified mail, to Oglethorpe and OPC Scherer 1997
Funding Corporation by the Collateral Trust Trustee, or to Oglethorpe, OPC
Scherer 1997 Funding Corporation and the Collateral Trust Trustee by the holders
of at least 25% in principal amount of outstanding Facility Bonds, a written
notice specifying such failure and requiring it to be remedied and stating that
such notice is a "NOTICE OF DEFAULT" under the Collateral Trust Indenture; (c)
the occurrence of an "Event of Default" under any Lease Indenture; and (d)
certain events of bankruptcy or insolvency involving OPC Scherer 1997 Funding
Corporation. (Collateral Trust Indenture, Section 8.01.) OPC Scherer 1997
Funding Corporation has agreed in the Collateral Trust Indenture that it will
not dissolve or liquidate or institute any proceedings to be adjudicated
bankrupt or insolvent or consent to the institution of bankruptcy or insolvency
proceedings against it. (Collateral Trust Indenture, Section 5.08.) Oglethorpe,
the Lessors, the Equity Investors, the Lease Indenture Trustees and the
Collateral Trust Trustee have agreed in the respective Participation Agreements
that none of them will file, or participate in the filing of, a petition seeking
reorganization, arrangement, adjustment or composition of or in respect of OPC
Scherer 1997 Funding Corporation or appointing a receiver, liquidator, assignee,
trustee, sequestrator (or other similar official) of OPC Scherer 1997 Funding
Corporation or of any substantial part of their respective properties, or
ordering the winding up or liquidation of their respective affairs.
Upon the occurrence of an Event of Default under the Collateral Trust
Indenture (except in the case of an Event of Default under any Lease Indenture),
the Collateral Trust Trustee may, and upon the direction of not less than a
majority in principal amount of the Facility Bonds outstanding shall, declare
all Facility Bonds due and payable. In the case of an Event of Default based on
an Event of Default under any Lease Indenture (including an Event of Default
which has resulted in a default in payment of the Facility Bonds) under
circumstances in which there has been an acceleration of the maturity of the
Refunding Lessor Notes issued under all the Lease Indentures, the Collateral
Trust Trustee also is required to declare all the Facility Bonds to be
immediately due and payable. However, no declaration will be made in the case of
a payment default which results directly from a failure by Oglethorpe to make a
payment under a Lease until such time as the Lessor has been given an
opportunity to exercise its rights, if any, to cure such default under the
related Lease Indenture, nor will a declaration be made if an Event of Default
occurs under a Lease Indenture under circumstances where an Event of Default has
not occurred and been continuing under all the Lease Indentures. (See "--Special
Mandatory Redemption with Premium" above and "DESCRIPTION OF THE LEASE
INDENTURES--Rights of Lessors to Cure and Purchase Lessor Notes.") In addition,
upon the happening and continuance of an Event of Default or a default under any
Lease Indenture or any Event of Loss with respect to Scherer Unit No. 2, if the
Collateral Trust Trustee is deemed to have notice thereof, the Collateral Trust
Trustee will be required to give notice to the Facility Bondholders of such fact
in accordance with the provisions of the Collateral Trust Indenture and,
thereafter, except as provided in the last sentence of this paragraph, each such
Facility Bondholder will have the right to direct the Collateral Trust Trustee,
as a holder of the Refunding Lessor Note issued under such Lease Indenture, to
vote the principal amount of such Refunding Lessor Note equal to the principal
amount of the Facility Bonds owned by such Facility Bondholder in favor of
directing the applicable Lease Indenture Trustee (a) to declare all Lessor
Notes, including the Refunding Lessor Note, issued under such Lease Indenture to
be immediately due and payable (to the extent not previously so declared), in
the case of an Event of Default under a Lease Indenture, and (b) to take other
specific action or refrain from taking action, or to exercise remedies, all as
permitted under the terms of such Lease Indenture. Under each Lease Indenture,
the applicable Lease Indenture Trustee will be required to act with respect to
such matters upon direction of the holders of a majority in principal
98
amount of all Lessor Notes outstanding thereunder which, until such time, if
any, that Additional Notes are issued under such Lease Indenture, will mean a
majority in aggregate principal amount of the Facility Bonds outstanding as a
result of the pass-through voting mechanism described above. To the extent an
Event of Default occurs under a Lease Indenture under circumstances where an
Event of Default has not occurred and been continuing under all the Lease
Indentures, the Collateral Trust Trustee will be required to take certain action
in respect of the Refunding Lessor Note then in default, including making demand
upon the applicable Lease Indenture Trustee for such Refunding Lessor Note (i)
to cause the principal of such defaulted Refunding Lessor Note to be declared
immediately due and payable, (ii) to terminate any Lease which is then in
default and demand redelivery of the related undivided ownership interest in
Scherer Unit No. 2, (iii) to demand payment from Oglethorpe of all rent then due
under any defaulted Lease, including a stipulated amount calculated to be at
least sufficient to pay such defaulted Refunding Lessor Note in full and (iv) to
commence appropriate legal proceedings against Oglethorpe for recovery of the
amounts demanded. (Collateral Trust Indenture, Sections 8.02, 9.02 and 3.03.)
No registered owner of any Facility Bond shall have any right to institute
any suit, action or proceeding in equity or at law for the foreclosure of the
Collateral Trust Indenture, for the appointment of a receiver or for the
enforcement of any remedy unless the Collateral Trust Trustee shall have been
notified of a continuing Event of Default, the holders of not less than 25% in
aggregate principal amount of Facility Bonds then outstanding shall have made
written request to the Collateral Trust Trustee and shall have offered indemnity
as provided in the Collateral Trust Indenture, the Collateral Trust Trustee
shall have failed to act for 60 days thereafter and no inconsistent direction
shall have been received from the holders of not less than a majority in
aggregate principal amount of the Facility Bonds outstanding during such 60 day
period. Nothing contained in the Collateral Trust Indenture, however, affects or
impairs the right of any Facility Bondholder to enforce the payment of the
principal of, or premium, if any, or interest on, any Facility Bond at and after
the maturity thereof. (Collateral Trust Indenture, Sections 8.09 and 8.11.)
Oglethorpe and OPC Scherer 1997 Funding Corporation will each be required to
deliver annually to the Collateral Trust Trustee a written statement of their
respective officers to the effect that all of their respective obligations under
the Collateral Trust Indenture during such year have been fulfilled, or if there
has been a default in the fulfillment of any such obligation, specifying each
such default and the nature and status thereof. (Collateral Trust Indenture,
Section 5.09.)
RESCISSION OF ACCELERATION
If, after the principal of the Facility Bonds has been declared to be due
and payable by an acceleration and before any sale of the pledged property, all
arrears of interest and the principal and premium, if any, on all the Facility
Bonds then outstanding which shall have become due and payable otherwise than by
acceleration and all other sums payable under the Collateral Trust Indenture are
paid, all other matters in default under the Collateral Trust Indenture have
been cured or waived and all charges of the Collateral Trust Trustee are paid,
then the holders of a majority in principal amount of the Facility Bonds
outstanding may rescind and annul such declaration and its consequences by
written notice to OPC Scherer 1997 Funding Corporation and the Collateral Trust
Trustee. Such annulment will be binding upon all holders of the Facility Bonds.
However, no such annulment will extend to or affect any subsequent default or
impair any right or remedy consequent thereon, and no such annulment can take
place unless all declarations of acceleration of Lessor Notes theretofore given
have been annulled in accordance with the terms of the Lease Indenture.
(Collateral Trust Indenture, Section 8.02.)
The Collateral Trust Trustee will be required to rescind any declaration of
acceleration of the principal of and interest on the Facility Bonds as a
consequence of an Event of Default under the Collateral Trust Indenture which
results from an "Event of Default" under any Lease and which results in the
subsequent acceleration of the Refunding Lessor Note issued under the related
Lease Indenture, if the declaration of the Refunding Lessor Note has been
rescinded in accordance with the terms of such
99
Lease Indenture and the conditions set forth in the immediately preceding
paragraph have been met. In case of any rescission, OPC Scherer 1997 Funding
Corporation, Oglethorpe, the Collateral Trust Trustee and the Facility
Bondholders will be restored to their former positions and rights, but no
rescission will extend to any subsequent or other default or Event of Default or
impair any right consequent thereon. (Collateral Trust Indenture, Section 8.02.)
VOTING OF LESSOR NOTES
The Collateral Trust Trustee, as holder of the Refunding Lessor Notes, will
have certain rights to vote and give consents and waivers in respect of such
Refunding Lessor Notes and the Lease Indentures. The Collateral Trust Indenture
provides that the Collateral Trust Trustee may not direct any action or cast any
votes as the holder of the Refunding Lessor Notes except that the Collateral
Trust Trustee will be required to take certain action (i) as described above
when a default has occurred under less than all the Lease Indentures and (ii) as
directed by Facility Bondholders. Upon receiving directions from Facility
Bondholders, all such directions must be given to the applicable Lease Indenture
Trustee, as permitted by the Lease Indentures. The principal amount of the
Refunding Lessor Notes directing any action or being voted for or against any
proposal or not being voted will be proportionate to the principal amount of
Facility Bonds taking the corresponding position. (Collateral Trust Indenture,
Section 3.03.)
SUPPLEMENTAL INDENTURES
OPC Scherer 1997 Funding Corporation, Oglethorpe and the Collateral Trust
Trustee may enter into indentures supplemental to the Collateral Trust Indenture
without the consent of, or notice to, the holders of the Facility Bonds for any
one or more of the following purposes: (i) to evidence the succession of another
corporation to Oglethorpe and the assumption by any such successor of the
covenants of Oglethorpe in the Collateral Trust Indenture, or to evidence the
succession of another corporation to OPC Scherer 1997 Funding Corporation and
the assumption by such successor of the covenants of OPC Scherer 1997 Funding
Corporation contained in the Collateral Trust Indenture and the Facility Bonds;
(ii) to add to the covenants of Oglethorpe or OPC Scherer 1997 Funding
Corporation, for the benefit of the holders of the Facility Bonds, or to
evidence the surrender of any right or power conferred in the Collateral Trust
Indenture upon Oglethorpe or OPC Scherer 1997 Funding Corporation; (iii) to
convey, transfer and assign to the Collateral Trust Trustee and to subject to
the lien of the Collateral Trust Indenture, additional properties or assets, and
to correct or amplify the description of any property at any time subject to the
lien of the Collateral Trust Indenture or better to assure, convey and confirm
to the Collateral Trust Trustee any property subject or required to be subject
to the lien of the Collateral Trust Indenture; (iv) to cure any ambiguity, to
correct or supplement any provision in the Collateral Trust Indenture which may
be defective or inconsistent with any other provision therein, or to make any
other provisions with respect to matters or questions arising under the
Collateral Trust Indenture, in each case so long as such action does not in the
opinion of Oglethorpe adversely affect the interests of the applicable Facility
Bondholders in any material respect; (v) to evidence the succession of a new
Collateral Trust Trustee; (vi) to provide for the issuance of one or more
additional series of bonds pursuant to the Collateral Trust Indenture; (vii) to
permit or facilitate the issuance of bonds in uncertificated form; (viii) to
change or eliminate any provision of the Collateral Trust Indenture, so long as
if such change or elimination shall materially adversely affect the interests of
the holders of any bonds, such change or elimination shall become effective with
respect to such bonds only when no such bonds remain Outstanding; or (ix) to
qualify the Collateral Trust Indenture under the TIA. In addition, OPC Scherer
1997 Funding Corporation, Oglethorpe and the Collateral Trust Trustee may enter
into indentures supplemental to the Collateral Trust Indenture without the
consent of, or notice to, the holders of the Facility Bonds if the TIA is
further amended after the date of execution of the Collateral Trust Indenture,
for the purpose of evidencing any such amendments that (i) require changes to or
the inclusion of additional provisions in the Collateral Trust Indenture or (ii)
permit changes to, or the elimination of, any provisions which as of the date of
execution of such Collateral Trust Indenture was
100
required by the TIA to be contained in the Collateral Trust Indenture.
(Collateral Trust Indenture, Sections 2.01 and 11.01.) The Collateral Trust
Indenture will provide for the issuance of additional bonds, in one or more
series, in connection with the issuance of additional Lessor Notes by the
Lessors under the Lease Indentures. If additional bonds are issued, all bonds
outstanding under the Collateral Trust Indenture including the Facility Bonds,
would be secured equally and ratably by all collateral pledged thereunder,
including the Refunding Lessor Notes and any additional Lessor Notes.
Exclusive of supplemental indentures for the purposes set forth in the
previous paragraph, the holders of not less than a majority in aggregate
principal amount of the Facility Bonds will have the right, from time to time,
to consent to and approve any supplemental indenture, except that, without
consent of the holders of all the Facility Bonds then outstanding affected
thereby, no such supplemental indenture may permit: (i) a change in the terms of
the Collateral Trust Indenture with respect to the time of payment of the
principal of, or any installment of interest on, or the dates or circumstances
of payment of premium, if any, on any Facility Bond or a reduction in the
principal amount of or the interest on or any premium payable upon any
redemption of any Facility Bond or change the place of payment where, or the
coin or currency in which, any Facility Bond or the premium or interest thereon
is payable, or impair the right to institute suit for the enforcement of any
such payment after the time of payment of the Facility Bond (or, in the case of
redemption, on or after the redemption date), or change the dates or amounts of
payment to be made through the operation of the sinking fund; (ii) the creation
of any lien prior or equal to the lien of the Collateral Trust Indenture with
respect to any of the Lessor Notes pledged thereunder, or terminate the lien of
the Collateral Trust Indenture on such Lessor Notes (except as permitted by the
Collateral Trust Indenture) or deprive any Facility Bondholder of the security
afforded by the Collateral Trust Indenture; (iii) a reduction in the percentage
in principal amount of the outstanding Facility Bonds, the consent of whose
holders is required for any such supplemental indenture, or the consent of whose
holders is required for any waiver provided for in the Collateral Trust
Indenture; or (iv) modification of the above provisions or the provisions of the
Collateral Trust Indenture dealing with the rights of holders of Facility Bonds
to institute any suit, action or proceeding at law or equity. (Collateral Trust
Indenture, Section 11.02.)
No supplemental indenture can become effective unless and until OPC Scherer
1997 Funding Corporation and Oglethorpe shall have consented to the execution
and delivery thereof.
DISCHARGE OF LIEN; DEFEASANCE
The Collateral Trust Indenture will cease to be of further effect when,
among other things, (i) either all Facility Bonds theretofore authenticated and
delivered have been delivered to the Collateral Trust Trustee for cancellation
or all the Facility Bonds not theretofore delivered to the Collateral Trust
Trustee for cancellation are deemed paid as described in the following paragraph
and (ii) all other sums then due and payable thereunder have been paid.
(Collateral Trust Indenture, Section 12.01.)
The Facility Bonds shall be deemed paid if OPC Scherer 1997 Funding
Corporation deposits with the Collateral Trust Trustee, in trust, money or U.S.
Government Obligations, or a combination thereof, which through the payment of
interest thereon and principal thereof in accordance with their terms will
provide money in an amount sufficient to pay all the principal (including any
mandatory sinking fund payments) of, and interest on, the Facility Bonds on the
dates such payments are due (including upon redemption if an irrevocable notice
of redemption has been given to the Collateral Trust Trustee) in accordance with
the terms of the Facility Bonds. To exercise such option, OPC Scherer 1997
Funding Corporation will be required to deliver to the Collateral Trust Trustee
an opinion of counsel nationally recognized in matters relating to Federal
income taxes to the effect that the deposit and related defeasance would not
cause the holders of the Facility Bonds to recognize income, gain or loss for
Federal income tax purposes. (Collateral Trust Indenture, Section 12.02.)
101
All obligations of OPC Scherer 1997 Funding Corporation for its covenants
under the Collateral Trust Indenture will be released, and the lien of the
Collateral Trust Indenture on the pledged Lessor Notes will be released, if OPC
Scherer 1997 Funding Corporation deposits with the Collateral Trust Trustee, in
trust, money or U.S. Government Obligations, or a combination thereof, which
through the payment of interest thereon and principal thereof in accordance with
their terms will provide money in an amount sufficient to pay all the principal
(including any mandatory sinking fund payments) of, and interest on, Facility
Bonds on the dates such payments are due (including upon redemption if an
irrevocable notice of redemption has been given to the Collateral Trust Trustee)
in accordance with the terms of the Facility Bonds. (Collateral Trust Indenture,
Section 12.03.)
THE COLLATERAL TRUST TRUSTEE
SunTrust Bank, Atlanta is the Collateral Trust Trustee under the Collateral
Trust Indenture. SunTrust Bank, Atlanta serves as the Mortgage Indenture Trustee
and as trustee for thirteen separate pollution control bond issues issued on
behalf of Oglethorpe.
The Collateral Trust Indenture provides that in the case of any Event of
Default under the Collateral Trust Indenture, the Collateral Trust Trustee must
exercise such of the rights and powers vested in it by the Collateral Trust
Indenture and must use the same degree of care and skill as a prudent man would
exercise under the circumstances in the conduct of his own affairs. The
Collateral Trust Trustee is not liable for any error of judgment made in good
faith unless the Collateral Trust Trustee was negligent in ascertaining the
pertinent facts, or any action taken or omitted to be taken by it in good faith
in accordance with the direction of the holders of a majority in principal
amount of Facility Bonds outstanding under the Collateral Trust Indenture.
Subject to such provision, the Collateral Trust Trustee is under no obligation
to exercise any of its rights and powers under the Collateral Trust Indenture at
the request of any holder of Facility Bonds unless such holder shall have
offered to the Collateral Trust Trustee reasonable security or indemnity. The
Collateral Trust Indenture provides that the Collateral Trust Trustee may
acquire and hold Facility Bonds and, subject to certain conditions, may
otherwise deal with Oglethorpe and OPC Scherer 1997 Funding Corporation with the
same rights it would have if it were not the Collateral Trust Trustee.
(Collateral Trust Indenture, Sections 9.01 and 9.03.)
102
DESCRIPTION OF THE LEASE INDENTURES
The statements under this caption are summaries and do not purport to be
complete. The summaries are qualified in their entirety by reference to the
Lease Indentures, a copy of the form of which has been filed as an exhibit to
the Registration Statement of which this Prospectus is a part. (See "AVAILABLE
INFORMATION.") Capitalized terms used in this section but not otherwise defined
shall have the meanings set forth in the Lease Indentures.
GENERAL
The Refunding Lessor Notes were issued under four separate Amended and
Restated Indentures of Trust, Deeds to Secure Debt and Security Agreements, each
dated December 1, 1997, between the respective Lessors and the respective Lease
Indenture Trustees (the "Lease Indentures"). The Refunding Lessor Notes were
issued by the Lessors to OPC Scherer 1997 Funding Corporation, and were pledged
and assigned by OPC Scherer 1997 Funding Corporation to the Collateral Trust
Trustee for the benefit of the holders of Private Facility Bonds and Exchange
Facility Bonds.
The Refunding Lessor Notes will be payable on such dates and bear interest
at rates sufficient to make payment in full of the principal of and premium, if
any, and interest on the Facility Bonds when due. The final payment date of each
Refunding Lessor Note corresponds to the maturity date of the Facility Bonds.
Each Refunding Lessor Note will bear interest at a rate corresponding to the
stated rate on the Facility Bonds.
LIEN AND NOTES; PAYMENTS
Under each Lease Indenture, a Lessor conveyed to the applicable Lease
Indenture Trustee a security interest and security title in the undivided
ownership interest of the Lessor in Scherer Unit No. 2; the interests of such
Lessor under the related Support Agreements, Lease and other operative
agreements, the rents and other payments due under such agreements (other than
Excepted Payments), the rights of such Lessor to exercise any election, option
or determination with respect to such documents as well as certain rights upon a
default under a Lease; all rents, profits issues, royalties, products, revenues
and other benefits from property subject to the Lease Indenture, including all
of such Lessor's rights thereto; any moneys and securities required to be
deposited with such Lease Indenture Trustee and held pursuant to such Lease
Indenture; all rights of such Lessor to restitution by Oglethorpe upon the
invalidity of contracts assigned by Oglethorpe to such Lessor and all other
property, rights and privileges acquired or held by the Lessor pursuant to any
such assigned contract under the Lease Indenture; and proceeds of the foregoing
(collectively, the "Lease Indenture Estate"), subject to certain rights of such
Lessor, including certain rights to cure defaults under the Lease Indentures.
Each Lease Indenture Estate secures the repayment of the related Lessor Notes
and any advances made by the applicable Lease Indenture Trustee to protect such
Lease Indenture Estate. Each Lease Indenture Trustee holds the respective Lease
Indenture Estate for the benefit of the holders of the related Lessor Notes,
including the Collateral Trust Trustee as holders of the related Refunding
Lessor Notes.
The terms of the Lessor Notes have been established by the Lease Indentures.
The principal amount of all Lessor Notes issued and outstanding under each of
the Lease Indentures may not exceed the product of $1,000,000,000 and a
fraction, the numerator of which is the related Lessor's percentage undivided
ownership interest in Scherer Unit No. 2 and the denominator of which is 60.
(Lease Indentures, Section 2.1.) Interest on any overdue principal and, to the
extent permitted by applicable law, interest thereon is to be paid at the
respective rates set forth in each such series of Refunding Lessor Notes. (Lease
Indentures, Section 2.4.) Payments are to be made solely from the Lease
Indenture Estate. Although each Lessor has agreed to punctually pay or cause to
be paid the principal of and premium, if any, and interest on all Lessor Notes
according to the applicable Lease Indenture, neither
103
such Lessor, the applicable Equity Investor nor the applicable Lease Indenture
Trustee has any obligation in respect of the Lessor Notes except from the Lease
Indenture Estate. (Lease Indentures, Section 2.5.) All payments are to be made
on the date such payment is due by mailing a check payable in New York Clearing
House funds or in the manner specified by the holder of each Lessor Note,
subject to certain conditions contained in the Lease Indentures. Each Refunding
Lessor Note provides that, unless otherwise directed by the holder thereof,
payments shall be made by wire transfer to the holder in immediately available
funds. A payment to be made by wire transfer may be made on the next business
day if funds are received by the Lease Indenture Trustee after 10:00 a.m., New
York City time. (Lease Indentures, Section 2.6.) Subject to other provisions of
the Lease Indentures discussed below, payments are to be applied first to
accrued interest (including interest on overdue principal and, to the extent
permitted by applicable law, overdue interest), then to principal and premium,
if any, then due under the Lessor Notes, and then, to the extent permitted by
the Lease Indentures, to the prepayment of principal and premium, if any. (Lease
Indentures, Section 2.7.)
PREPAYMENT
The Refunding Lessor Notes are prepayable in the circumstances described
above under "DESCRIPTION OF THE FACILITY BONDS--Special Mandatory Redemption at
Par" and "--Special Mandatory Redemption with Premium" and in connection with a
defeasance of the Facility Bonds. The redemption price in each such event will
be equal to the principal amount of the Refunding Lessor Notes plus the premium,
if any, and accrued interest on the Refunding Lessor Notes to the date fixed for
repayment, which amounts in the aggregate will equal the amount then payable on
the Facility Bonds. In addition, each Refunding Lessor Note are prepayable upon
the receipt of moneys by reason of acceleration of such Refunding Lessor Note
following an Event of Default under the respective Lease Indenture. Amounts
received by reason of a prepayment (other than by reason of acceleration upon a
default or by reason of Oglethorpe assuming the obligations and liabilities of
the applicable Lessor as a result of the applicable Lessor becoming subject to
certain regulations relating to public utilities) are to be applied first to
reimburse the applicable Lease Indenture Trustee for any unpaid fees and
expenses, then to pay the principal of and premium, if any, and interest on the
applicable Lessor Notes, ratably among the holders of such Lessor Notes, then to
make any indemnification payment to the holders of such Lessor Notes, and
finally to such Lessor for distribution to the related Equity Investors. (Lease
Indentures, Section 3.2.)
ADDITIONAL LESSOR NOTES
Additional Notes may be issued under and secured by each Lessor's Lease
Indenture, at any time or from time to time, (i) for the purpose of refinancing
any previously issued Lessor Notes, including the Refunding Lessor Notes,
subject to the terms of the Lease Indenture; (ii) to provide funds to the Equity
Investors in connection with certain requirements of the related Tax
Indemnification Agreement; and (iii) to provide funds for Capital Improvements.
Before any Additional Notes may be issued, each Lessor must deliver to the
related Lease Indenture Trustee, at least 15 days, but not more than 30 days,
prior to their issuance, a request and authorization to issue such Additional
Notes, setting forth the amount of such Additional Notes and a certification
that the terms of the Additional Notes are not inconsistent with the Lease
Indenture. All such Additional Notes will rank PARI PASSU with all other Lessor
Notes issued under such Lease Indenture and must be payable not later than the
last day of the basic term of the Leases. In the case of Additional Notes issued
for the purposes set forth in (ii) above, the aggregate principal amount of all
Lessor Notes, including the proposed additional Lessor Notes, issued and
outstanding may not exceed 80% of the Lessor's Cost. (See "DESCRIPTION OF THE
LEASES--Term and Rentals.") No Additional Notes to be issued for the purpose set
forth in (iii) above may be issued: (1) if the aggregate principal amount of all
Lessor Notes issued and outstanding under such Lease Indenture (including the
proposed Additional Notes) exceeds an amount equal to 80% of the sum of (A) the
Lessor's Cost, (B) such Lessor's share of the cumulative cost of all additions
and improvements
104
theretofore incorporated or installed in Scherer Unit No. 2 during the term of
the Lease and financed by such Lessor or with Lessor Notes, and (C) such
Lessor's share of the cost of the additions and improvements proposed to be
financed with such Additional Notes; or (2) if the aggregate principal amount of
all Additional Notes issued under such Lease Indenture for the purpose set forth
in (iii) above (including the proposed Additional Notes) exceeds an amount equal
to 80% of the sum of (A) such Lessor's share of the cumulative cost of all
additions and improvements theretofore incorporated or installed in Scherer Unit
No. 2 during the term of the Lease and (B) the cost of the additions and
improvements proposed to be financed with such Additional Notes. (Leases,
Section 10.2; Lease Indentures, Section 2.12.)
As a further condition to the issuance of Additional Notes for the purposes
set forth in (ii) and (iii) above, at least ten days must have passed from the
time the applicable Lease Indenture Trustee shall have given notice to holders
of the applicable Lessor Notes of the proposed issuance of such Additional
Notes, and the holders of a majority in principal amount of such Lessor Notes
shall not have notified such Lease Indenture Trustee that certain requirements
for issuing Additional Notes have not been met and directing such Lease
Indenture Trustee not to allow the issuance of such Additional Notes. (Lease
Indentures, Section 2.12.) In addition, in the case of Additional Notes issued
for the purposes set forth in (ii) and (iii) above, the Lease Indenture Trustee
shall have received a certificate of Lessee's independent public accountants
verifying the calculations set forth in the related Lease Indenture plus, in the
case of (iii), a certificate of an engineer, appraiser or other expert to the
effect that the fair market value of all Capital Improvements as of their
respective dates of incorporation or installation was not less than the cost of
such Capital Improvements as of such dates.
EVENTS OF DEFAULT
"Events of Default" under each Lease Indenture include: (i) any "Event of
Default" under the related Lease (other than the failure of Oglethorpe to pay
any Excepted Payment), subject to the rights of the related Lessor to cure
defaults in the payment of rent and to purchase Lessor Notes upon the occurrence
of an "Event of Default" by Oglethorpe under its Lease with such Lessor as
described below; (ii) a failure by such Lessor to make any payment in respect of
the principal of or premium, if any, or interest on the Lessor Notes within
three business days after the same shall have become due; (iii) a failure by the
Lessor or by Wilmington Trust Company or NationsBank, N.A., as successor by
merger to The Citizens and Southern National Bank, individually, to perform or
observe any covenant, condition or agreement to be performed or observed by it
under the Lease Indenture, to discharge any Lessor's liens or to give notice of
a change in its principal place of business, or a failure by the related Equity
Investor to remove any Equity Investor's liens or to remove the Lessor in
certain events, if any such failure shall continue for a period of 30 days after
notice thereof shall have been given to the related Lessor, Equity Investor and
Lessee by the related Lease Indenture Trustee, specifying such failure and
requiring it to be remedied; (iv) certain events of bankruptcy or insolvency
shall have occurred in respect of the trust established under the related Trust
Agreement or the related Equity Investor; and (v) the Lessor shall fail to pay
certain taxes not being contested in good faith and such failure continues for
20 business days after notice shall have been given to the Lessor. (Lease
Indentures, Section 4.1.)
RIGHTS OF LESSOR TO CURE AND PURCHASE LESSOR NOTES
Each Lease Indenture provides that an "Event of Default" thereunder that
results from a nonpayment of rent under the related Lease is to be deemed cured
if the Lessor thereunder shall have paid, within ten business days after receipt
by such Lessor and the related Equity Investor of notice or actual knowledge of
such nonpayment, an amount equal to the principal of or premium, if any, and
interest on the Lessor Notes then due (otherwise than by declaration of
acceleration), plus any interest on such amount on account of the delayed
payment thereof, unless, if such nonpayment is of basic rent, Oglethorpe shall
have failed to make all payments of basic rent (i) on three consecutive
semiannual
105
basic rent payment dates or (ii) on any six due dates during the term of the
Lease. (Lease Indentures, Section 4.3(a).) Each Lease Indenture also provides
that an Event of Default that results from the failure of Oglethorpe to perform
any other obligation relating to its interest in Scherer Unit No. 2 (including,
without limitation, the payment of all amounts other than basic rent required to
be paid by Oglethorpe) is deemed cured if the related Lessor shall have
performed such obligation within ten business days after receipt by such Lessor
of notice of the occurrence of such failure. (Lease Indentures, Section 4.3(b).)
Upon any such payment of rent or performance of Oglethorpe's obligations,
such Lessor shall be subrogated to the rights of the applicable Lease Indenture
Trustee and the holders of the applicable Lessor Notes to payment of rent from
Oglethorpe as reimbursement, to the extent set forth in such Lease Indenture,
but such Lessor shall not obtain any lien on the applicable Lease Indenture
Estate for such reimbursement. (Lease Indentures, Section 4.3(c).) Even if
Oglethorpe later pays such rent, the Lease Indenture Trustee shall not remit
such payment to such Lessor if any Lease Default or Event of Default has
occurred and is continuing or the payment of the principal of, and premium if
any, and interest on any Note is overdue.
If an "Event of Default" under any Lease Indenture based solely upon an
"Event of Default" under the related Lease has occurred and is continuing, and
if the related Lessor Notes have been accelerated and such acceleration has not
been rescinded, the related Lessor, within 20 days after receiving notice from
the related Lease Indenture Trustee of such acceleration, may give written
notice to such Lease Indenture Trustee of its intention to purchase all of such
Lessor Notes. Each holder of a Lessor Note issued by such Lessor then will be
required to sell such Lessor Note and its interest in such Lease Indenture to
such Lessor if (i) within ten business days after such notice, such Lessor
tenders an amount equal to all of the aggregate unpaid principal of and premium,
if any, and interest on all of the unpaid Lessor Notes issued by such Lessor
plus all other amounts, including interest on the overdue amounts, which would
then be payable to the holders of such Lessor Notes in the case of an Event of
Default under the Lease Indenture and (ii) such conveyance is not in violation
of applicable law. (Lease Indentures, Section 4.3(e).) All amounts so paid to
the Collateral Trust Trustee, as the holder of the Refunding Lessor Notes, will
be immediately applied to the payment of the Facility Bonds.
If an "Event of Default" has occurred under any Lease, the Lessor thereunder
also shall have the right to terminate that Lease and arrange for the
substitution of another party as lessee under a new lease substantially similar
to such Lease, subject to (i) any "Event of Default" under the related Lease
Indenture having been cured by such Lessor as described above, (ii) such
substituted lessee having assumed all of the obligations of Oglethorpe under
such Lease; (iii) such lessee being GPC, MEAG or Dalton or a person having an
assigned credit rating from Moody's Investors Service, Inc. or Standard & Poor's
Rating Services equal to or better than "A1" or "AA-," respectively, and (iv)
such lessee making an irrevocable commitment to assume the lease obligation
within two months after the occurrence of the "Event of Default" under such
Lease and actually assuming such obligation within six months of such
occurrence. In such event, such substituted lease shall be deemed the Lease
subject to the lien of applicable Lease Indenture. (Lease Indentures, Section
4.3(f).) Under each Lease, the applicable Lessor will be obligated to attempt to
lease its undivided ownership interest to GPC, MEAG, or Dalton or a utility with
a net worth of at least $200,000,000 or an electric cooperative with a net worth
of at least $25,000,000 for 30 days prior to the exercise of any of the Lessor's
remedies under such Lease. (See "DESCRIPTION OF THE LEASES--Events of Default.")
NOTICE OF EVENTS OF DEFAULT; ACTION BY TRUSTEE; WAIVER
Each Lease Indenture requires the related Lessor to give the related Lease
Indenture Trustee, Oglethorpe and the related Equity Investor prompt written
notice of each "Event of Default" or default under the related Lease Indenture
or Event of Loss with respect to Scherer Unit No. 2, to the extent it has actual
knowledge thereof. In the event a Lease Indenture Trustee has actual knowledge
of an "Event of Default" or default under the related Lease Indenture or such an
Event of Loss, such Lease Indenture
106
Trustee will be required to give prompt written notice thereof to the related
Lessor, Oglethorpe and each holder of a related Lessor Note, including the
Collateral Trust Trustee as holder of the Refunding Lessor Notes. Subject to the
terms of each Lease Indenture relating to the enforcement of remedies and the
rights of a Lease Indenture Trustee to indemnification in the taking of any
action, and further subject to the right of each Lessor to cure defaults and to
purchase its Lessor Notes as described above, a Lease Indenture Trustee will be
required to take such action (including the waiver of past defaults), or refrain
from taking such action, with respect to any such "Event of Default," default
under the related Lease Indenture or Event of Loss as it shall be directed by a
majority in interest of the Noteholders (a "Directive"), which, during such time
as the Refunding Lessor Notes are the only outstanding Lessor Notes, means a
majority in principal amount of the Facility Bonds. (See "DESCRIPTION OF THE
FACILITY BONDS--Voting of Lessor Notes.") If a Lease Indenture Trustee has not
received directions as above provided within 20 days after the mailing by such
Lease Indenture Trustee of notice of such "Event of Default," default under the
Lease Indenture or Event of Loss, such Lease Indenture Trustee may, but will not
be required to, take such action, or refrain from taking such action, as it
deems advisable in the best interests of holders of the related Lessor Notes,
subject to the subsequent receipt of a Directive from holders of Lessor Notes as
above provided. (Lease Indentures, Section 5.1.)
A Lease Indenture Trustee may, and upon receipt of a Directive shall, waive
any past "Event of Default" or default under the related Lease Indenture except
a default or an "Event of Default" (i) in the payment of the principal of or
premium, if any, or interest on any Lessor Note or (ii) in respect of a covenant
or provision of such Lease Indenture which under the Lease Indenture cannot be
modified or amended without the consent of each holder of a Lessor Note issued
under such Lease Indenture then outstanding. (Lease Indentures, Section 4.14.)
ACCELERATION; RESCISSION
If an "Event of Default" shall have occurred and be continuing under any
Lease Indenture, a Lease Indenture Trustee may, or upon receipt of a Directive
shall, declare the unpaid principal amount of all Lessor Notes under that Lease
Indenture, with accrued interest and premium, if any, thereon, to be due and
payable, subject to the right of the related Lessor to cure such "Event of
Default" as described above. (Lease Indentures, Section 4.2 and 5.1.) The
holders of such Lessor Notes by a Directive may rescind and annul any such
declaration at any time if (i) all amounts of principal of and premium, if any,
and interest which are then due and payable (otherwise than by declaration of
acceleration), together with interest on such overdue amounts and all other sums
payable (including all costs and expenses incurred in connection therewith),
shall have been paid and (ii) every other Event of Default under the Lease
Indenture shall have been remedied. (Lease Indentures, Section 4.4.)
REMEDIES
Each Lease Indenture provides that, if an "Event of Default" under such
Lease Indenture has occurred and is continuing, the related Lease Indenture
Trustee may exercise certain rights or remedies available to it under applicable
law, including the public sale under power of sale of the undivided ownership
interest in Scherer Unit No. 2 of the related Lessor and, if an "Event of
Default" under the related Lease has occurred, one or more of the remedies with
respect to such Lessor's undivided ownership interest in Scherer Unit No. 2
afforded to the Lessor by the Lease for "Events of Default" thereunder. (See
"DESCRIPTION OF THE LEASES--Events of Default".) Such remedies may be exercised
by a Lease Indenture Trustee to the exclusion of that Lessor and, to the extent
there is an "Event of Default" under that Lease, to the exclusion of Oglethorpe.
(Lease Indentures, Section 4.2.) Any undivided ownership interest in Scherer
Unit No. 2 sold in the exercise of such remedies will be sold free and clear of
any rights of those parties, including the rights of Oglethorpe under the Lease,
provided that no exercise of any remedies by the Lease Indenture Trustee may
affect the rights of Oglethorpe under the
107
Lease unless an "Event of Default"under the Lease has occurred and is
continuing. (Lease Indentures, Section 4.6.)
If an "Event of Default" under any Lease Indenture occurs and is continuing,
any sums held or received by the related Lease Indenture Trustee thereunder may
be applied to reimburse the Lease Indenture Trustee for any expense or other
loss incurred by it and to pay its fees and any other amounts due to such Lease
Indenture Trustee prior to any payments to holders of Lessor Notes. (Lease
Indentures, Section 3.3.) If the remaining amounts available are not sufficient
to pay the holders of Lessor Notes issued under such Lease Indenture in full,
they will be paid ratably, in proportion to the principal amounts of their
respective Lessor Notes.
RIGHTS OF LESSOR
The Lessor under each Lease at all times has, among other things, the right,
to the exclusion of the related Lease Indenture Trustee, to demand and receive
payment of, and to commence an action at law to obtain payment of, Excepted
Payments (but Lessor will have no remedy or right with respect to any such
payment against the related Lease Indenture Estate nor any right to collect any
such payment by the exercise of certain remedies specified in the related
Lease), to adjust Basic Rent, Stipulated Loss Value and Termination Values under
the related Lease (subject to certain limitations), and, in certain
circumstances, to exercise its rights with respect to appraisals. Any such
adjustments, however, shall not result in the amount of each basic rent payment
on each basic rent payment date being at least equal to the aggregate amount of
all principal, premium, if any, and accrued interest payable on such payment
date on all Lessor Notes then outstanding under such Lease Indenture or
Stipulated Loss Value and Termination Value (together with all other amounts
required to be paid by Lessee under the Lease in respect of any Event of Loss or
purchase of the Undivided Interest) than the amount sufficient, as of the date
of payment, to pay in full, the principal of, premium, if any, and interest on
all Lessor Notes outstanding on such date of payment. The Lessor also has the
right at all times, not to the exclusion of the related Lease Indenture Trustee,
to receive notices, opinions and other materials from Oglethorpe, to inspect
Scherer Unit No. 2, the Scherer Unit No. 2 Site and the Scherer Common
Facilities pursuant to the related Lease, to obtain additional insurance and, in
certain circumstances, to perform the obligations of Oglethorpe under such
Lease.
As long as the Lessor Notes have not been accelerated and a Lease Indenture
Trustee has not exercised its remedies under the related Lease Indenture, the
related Lessor may, to the exclusion of such Lease Indenture Trustee, exercise
its rights under the related Lease with respect to renewals, purchase options,
early termination, redelivery of the undivided ownership interest in Scherer
Unit No. 2, Supplemental Financings and, in certain circumstances, payment of
Stipulated Loss Value upon an Event of Loss. (See "DESCRIPTION OF THE
LEASES--Redelivery," "--Alterations and Improvements," "--Optional Termination
for Obsolescence," "--Purchase and Renewal Options" and "--Events of Loss.") In
such circumstances, such Lessor may also exercise certain other rights jointly
with the related Lease Indenture Trustee. A Lease Indenture Trustee may
terminate the exercise of any of the foregoing rights by notice to the related
Lessor if an "Event of Default" under the related Lease Indenture has occurred.
(Lease Indentures, Section 5.6.)
AMENDMENTS AND SUPPLEMENTS
Each Lease Indenture Trustee may amend or supplement its Lease Indenture
with the consent of the related Lessor but without the consent of the holders of
any Lessor Notes (including the Collateral Trust Trustee, as the holders of the
Refunding Lessor Notes), in order to (i) evidence the succession of any person
as Lessor or the appointment of any additional or successor Lease Indenture
Trustee; (ii) confirm or amplify the description of any property at any time
subject to the lien of such Lease Indenture or convey, transfer, assign,
mortgage or pledge any property to or with the Lease Indenture Trustee; (iii)
provide for and evidence the creation and issuance of Additional Notes in
accordance with
108
the terms of such Lease Indenture; (iv) cure any ambiguity in, correct or
supplement any defective or inconsistent provision of, or add to or modify any
other provisions and agreements in, such Lease Indenture in any manner that will
not in the judgment of the Indenture Trustee materially adversely affect the
interests of the holders of such Lessor Notes; (v) grant or confer upon such
Lease Indenture Trustee for the benefit of the holders of any Lessor Notes any
additional rights, remedies, powers, authority or security which may be lawfully
granted or conferred and which are not contrary or inconsistent with such Lease
Indenture; (vi) add to the covenants or agreements to be observed by the related
Lessor and which are not contrary to such Lease Indenture or surrender any right
or power of such Lessor with its consent; (vii) if required by applicable law,
qualify such Lease Indenture under the TIA; or (viii) enter into any indenture
or indentures supplemental thereto or any amendment, modification, supplement or
waiver or consent to any Operative Document so long as it shall not, in the
opinion of such Indenture Trustee, materially adversely effect the interest of
the holders of such Lessor Notes. (Lease Indentures, Section 8.2.)
Except as described in the preceding paragraph, no amendment or supplement
to a Lease Indenture or to any of the agreements forming a part of the security
for the Lessor Notes, including the related Lease and Support Agreements, may be
made except upon receipt of a Directive. In addition, the Lessor and the holders
of the Lessor Notes representing 100% of the outstanding principal amount of the
Lessor Notes (determined in the same manner as the determination of a
Directive), including the Collateral Trust Trustee, as holder of the Refunding
Lessor Notes, must consent to any amendment of such agreements which will (i)
modify the net lease nature of Oglethorpe's obligations, the quiet enjoyment
provisions of the related Lease, the restriction on liens under such Lease, the
definitions of default, "Event of Default," "Lease Default," "Lease Event of
Default," "Indenture Event of Default," "Indenture Default," "Majority in
Interest of Noteholders" and "Excepted Payments" or the percentage of
Noteholders required to take or approve any action under such Lease and related
Lease Indenture, or the percentage of holders of related Lessor Notes required
to direct the related Lease Indenture Trustee to take action or to consent to an
amendment; (ii) change the amount or time of payment under any Lessor Note or
change the rate or manner of calculation of interest payable thereunder; (iii)
modify or alter the manner of payment specified in the related Lease Indenture;
(iv) reduce, modify or amend the indemnities under the related Participation
Agreement; (v) change the nature, amount or timing of any payments due under the
related Lease; (vi) consent to any assignment of such Lease not permitted
thereby or any sublease by Oglethorpe or any reduction in Oglethorpe's
obligations thereunder; (vii) reduce the term of the related Lease or any
related Support Agreements; (viii) change the nonrecourse nature of the
obligations of the related Lessor; (ix) alter the effect of the consent to the
Sale and Leaseback Transactions of the RUS; or (x) otherwise in the judgment of
the Lease Indenture Trustee materially adversely affect the rights of any holder
of a Lessor Note, permit the creation of a lien on the Indenture Estate or
deprive the Noteholder of the benefit of the lien of the Lease Indenture. (Lease
Indentures, Section 8.1.)
LIMITATION OF LIABILITY OF LESSORS
The Refunding Lessor Notes which secure the Facility Bonds will not be
direct obligations of, or guaranteed by, Oglethorpe, any Equity Investor or
Wilmington Trust Company, NationsBank, N.A. or its agent, The Bank of New York.
None of the Equity Investors, Wilmington Trust Company, NationsBank, N.A. or its
agent, The Bank of New York, or any Lease Indenture Trustee will be liable to
any holder of a Refunding Lessor Note or a Facility Bond or, in the case of the
Equity Investors and Wilmington Trust Company and NationsBank, N.A. or its
agent, The Bank of New York to the Lease Indenture Trustees, for any amounts
payable under the Refunding Lessor Notes or, except as provided in the Lease
Indentures, for any liability under the Lease Indentures. All payments of
principal of and premium, if any, and interest on the Refunding Lessor Notes
will be made only from the assets subject to the lien of the respective
109
Lease Indentures or the income and proceeds received by the related Lease
Indenture Trustee therefrom (including basic rent and certain other amounts
payable by Oglethorpe under the Lease). (Lease Indentures, Section 2.5.)
DISCHARGE OF LIEN AND DEFEASANCE OF LESSOR NOTES
Each Lease Indenture provides that if the related Lessor Notes, including
the related Refunding Lessor Note, shall have become due and payable in
accordance with their terms or otherwise or when provision has been made for
such payment and the whole amount of the principal of and premium, if any, and
interest on such Lessor Notes then outstanding shall be paid and all other sums
secured by or otherwise required to be paid under the related Leases, then the
related Lease Indenture Trustee shall take all actions necessary to terminate
and discharge the lien created thereby. (Lease Indentures, Sections 5.3 and
9.1.) Upon such payment of any Lessor Note, such Lessor Note shall no longer be
secured by or entitled to the benefits of the related Lease Indenture. Lessor
Notes shall be deemed paid if there shall be deposited with the Lease Indenture
Trustee, in trust, money or U.S. Government Obligations, which will provide
moneys, without reinvestment, sufficient to pay the principal of and premium, if
any, and interest due on such Lessor Notes on and prior to the redemption date
or maturity date thereof.
LEASE INDENTURE TRUSTEES
The Bank of New York Trust Company of Florida, N.A., as successor trustee to
Wachovia Bank of Georgia, N.A., is the Lease Indenture Trustee under each of the
Lease Indentures. The Bank of New York, an affiliate of The Bank of New York
Trust Company of Florida, N.A., has guaranteed the obligations of The Bank of
New York Trust Company of Florida, N.A. If an "Event of Default" under any Lease
Indenture occurs and is continuing, any sums held or received by the related
Lease Indenture Trustee may be applied to the payment of obligations incurred by
such Lease Indenture Trustee prior to any payments to holders of the related
Lessor Notes. (Lease Indentures, Section 3.3.) Each Lease Indenture provides
that the related Lease Indenture Trustee shall not be answerable or accountable
under any circumstances, unless for its own willful misconduct or gross
negligence, and except for liabilities on account of representations, warranties
or covenants made by it in its individual capacity. Each Lease Indenture further
provides that, in the case of any "Event of Default" under such Lease Indenture,
the related Lease Indenture Trustee shall exercise such of the rights and
remedies vested in it by such Lease Indenture and shall use the same degree of
care in their exercise as a prudent man would exercise or use in the
circumstances in the conduct of his own affairs. (Lease Indentures, Section
6.1.)
110
DESCRIPTION OF THE LEASES
The statements under this caption are summaries and do not purport to be
complete. The summaries are qualified in their entirety by reference to the
Leases, a copy of the form of which has been filed as an exhibit to the
Registration Statement of which this Prospectus is a part. (See "AVAILABLE
INFORMATION.")
TERM AND RENTALS
The Lessors have acquired separate undivided ownership interests in Scherer
Unit No. 2 aggregating 60% of such unit and are leasing such interests to
Oglethorpe pursuant to separate Leases, each having a lease term expiring on
June 30, 2013, unless earlier terminated or extended as described below (40% of
such unit is owned by GPC, MEAG and Dalton). Basic rent is required to be paid
by Oglethorpe under the Leases in immediately available funds before 10:00 a.m.
local time at the place of payment on each June 30 and December 31, unless the
scheduled due date is not a business day, in which case such basic rent is
required to be paid in immediately available funds before 10:00 a.m. local time
on the next business day. (Leases, Section 3.6). The basic rent payable under
each Lease on each payment date is required to be at least equal to the
installment of principal and interest payable on such date on the Lessor Notes
of such Lessor. (Leases, Section 3.4). Except in the case of an Event of Loss, a
purchase of the undivided ownership interest by Oglethorpe, early termination of
the Lease or any event of default under the related Lease Indenture, each
payment of basic rent by Oglethorpe during such time as such Lease Indenture is
in effect will be made to the Lease Indenture Trustee and applied, first to the
payment of principal and interest due from a Lessor on its Lessor Notes on each
June 30 and December 31 (basic rent having commenced on December 31, 1985),
unless the scheduled payment date is not a business day, in which case such
payment is required to be made on the next business day. The balance of any
payment of basic rent under the Leases, after payment of the scheduled principal
and interest on the Lessor Notes and any unreimbursed fees or expenses of the
Lessor, will be paid to the respective Equity Investors, as beneficial owners of
undivided ownership interests in Scherer Unit No. 2. (Lease Indentures, Section
3.1.)
The amount of rent payable under each Lease is subject to adjustment if
additional Lessor Notes are issued (see "DESCRIPTION OF THE LEASE
INDENTURES--Additional Lessor Notes"), and if Oglethorpe is obligated to
indemnify the related Equity Investor under the Tax Indemnification Agreement
for a loss of tax benefits. In such event, a portion of the proceeds of such
increased loans would be retained by the related Equity Investor. The amount of
rent, as adjusted in any of the foregoing circumstances, must be sufficient at
all times to pay in full all amounts of principal of and premium, if any, and
interest on the related Lessor Notes when due and payable.
OWNERSHIP AGREEMENT AND OPERATING AGREEMENT
Scherer Unit No. 2 is operated by GPC, as agent for the owners of Scherer
Unit No. 2, pursuant to the Scherer Ownership Agreement and the Scherer
Operating Agreement. (See "CO-OWNERS OF THE PLANTS AND THE PLANT AGREEMENTS--The
Plant Agreements.") Oglethorpe assigned its rights with respect to Scherer Unit
No. 2 under the Scherer Ownership Agreement and the Scherer Operating Agreement
to the Lessors, who assigned such rights back to Oglethorpe for the term of the
Leases. GPC, MEAG and Dalton agreed that, during such term, Oglethorpe will be
treated as the owner of the undivided ownership interests of the Lessors in
Scherer Unit No. 2 and would continue to possess all of the rights and
obligations of a participant with respect to such interests. The Lessors will be
treated as participants under the Scherer Ownership Agreement or the Scherer
Operating Agreement only upon the termination of the Leases, if Oglethorpe does
not then purchase such interests. Until that time, Oglethorpe also is obligated
under the Participation Agreements not to consent to any amendment to such
agreements which would adversely effect the interests of the Lessors.
111
Under the Leases, Oglethorpe is obligated to perform and discharge all
indebtedness, obligations, and liabilities assessed against the undivided
ownership interests of the Lessors in Scherer Unit No. 2 pursuant to the Scherer
Operating Agreement and the Scherer Ownership Agreement. (Leases, Section 10.6).
Oglethorpe also is obligated under the Participation Agreements to perform and
comply with all the terms of such agreements and any other agreements relating
to the ownership and operation of Scherer Unit No. 2. (Participation Agreements,
Section 5.5(cc).)
REDELIVERY
Under the Leases, unless the undivided ownership interests of the Lessors in
Scherer Unit No. 2 are transferred to Oglethorpe pursuant to the Leases,
Oglethorpe is obligated to redeliver such interest to the Lessors, or to any
transferees or assignees of the Lessors, free and clear of all liens (other than
certain permitted liens) and in such condition as would result from Scherer Unit
No. 2 having been maintained during the term of the Leases in accordance with a
standard of care not less than "prudent utility practice," as defined in the
Scherer Ownership Agreement. If Scherer Unit No. 2 is not in such condition, the
sole remedy of each Lessor is to demand that Oglethorpe pay it an amount equal
to the actual decrease in the fair market sales value of its respective
undivided ownership interest in Scherer Unit No. 2 on such date, as determined
by qualified appraisers in the manner specified in the Leases, to the extent
attributable to the failure of such Unit to have been so maintained. The Leases
set forth objective standards relating to electric generating capacity,
availability for service and economic useful life, which, if met, will result in
Scherer Unit No. 2 being deemed to have been so maintained. (Leases, Section
7.1.)
NET LEASE
The obligations of Oglethorpe under each Lease are those of a lessee under a
"net lease". Payments of basic rent under the Leases by Oglethorpe are to be
made without notice or demand, and all rent is to be paid without counterclaim,
setoff, deduction, defense, and without abatement, suspension, deferment,
diminution, or reduction. (Leases, Section 3.8.)
ALTERATIONS AND IMPROVEMENTS
Alterations and improvements may be made to Scherer Unit No. 2 from time to
time pursuant to the provisions of the Scherer Ownership Agreement and the
Scherer Operating Agreement. Any such alterations and improvements will become
the property of the Lessors. (Leases, Section 10.1.) As described above,
Oglethorpe is obligated to make all payments due under such agreements,
including payments for its share of such alterations and improvements except to
the extent such costs may be financed by a Lessor through the issuance of
Additional Notes under the related Lease Indenture (a "Supplemental Financing").
Any Supplemental Financing is subject to the fulfillment of certain conditions,
including the following: (i) there shall be no more than one Supplemental
Financing in any calendar year, and the aggregate cost of the improvements
covered by such Supplemental Financing under all Leases must be at least
$3,000,000; (ii) the aggregate principal amount of all Lessor Notes issued and
outstanding under such Lease Indenture (including the proposed Additional Notes)
must not exceed an amount equal to 80% of the sum of (A) the Lessor's Cost, (B)
such Lessor's share of the cumulative cost of all additions and improvements
theretofore incorporated or installed in Scherer Unit No. 2 during the term of
the Lease and financed by such Lessor or with Lessor Notes, and (C) such
Lessor's share of the cost of the additions and improvements proposed to be
financed with such Additional Notes; (iii) the aggregate principal amount of all
Additional Notes issued under such Lease Indenture for additions and
improvements (including the proposed Additional Notes) must not exceed an amount
equal to 80% of the sum of (A) such Lessor's share of the cumulative cost of all
additions and improvements theretofore incorporated or installed in Scherer Unit
No. 2 during the term of the Lease and (B) the cost of the additions and
improvements proposed to be financed with such Additional Notes;
112
(iv) the total amount of all Supplemental Financings with respect to the
undivided ownership interests under all four Leases to and including the stated
termination date of the Leases must not exceed $125,000,000; (v) Oglethorpe's
then outstanding debt must be rated (or, if not rated, deemed by the related
Equity Investor to be) no less than "investment grade"; (vi) Oglethorpe must
indemnify the related Equity Investor against the loss of any available tax
benefits and against any adverse tax consequences; (vii) the additional Lessor
Notes must have a final maturity no later than June 30, 2013; (viii) no default
or event of default under the Leases shall have occurred and be continuing; and
(ix) the RUS must consent to such Supplemental Financing. (Leases, Section
10.2.) In the event of a Supplemental Financing, the rent shall be adjusted to
cover the additional debt service. (See "DESCRIPTION OF THE LEASES--Additional
Lessor Notes.")
INSURANCE
Property insurance and liability insurance are to be maintained with respect
to Scherer Unit No. 2 by GPC pursuant to the Scherer Ownership Agreement and the
Scherer Operating Agreement. As described above, under such agreements and the
Leases Oglethorpe is obligated to pay the portion of the cost of such insurance
attributable to the undivided ownership interests of the Lessors. Under the
Participation Agreements, Oglethorpe is obligated to monitor all insurance which
is so maintained, and to take any and all reasonable actions to assure that at
all times such insurance is maintained consistent with "prudent utility
practice," as defined in the Scherer Ownership Agreement. Oglethorpe also is to
monitor and maintain the endorsements in favor of the Lessors and the other
parties to the Participation Agreements. Under the Leases, the Lessors may
provide additional insurance for Scherer Unit No. 2. (Leases, Article 12.)
ASSIGNMENT, SUBLEASE AND TRANSFER
Except in connection with a merger, consolidation or transfer, conveyance or
lease of assets permitted by the Participation Agreements and except for the
assignment of its leasehold rights to the RUS and the other secured parties
under the Mortgage Indenture, Oglethorpe is not permitted to assign or transfer
or encumber (except for permitted liens) any of its rights or interests under
any of the Leases without the prior consent of the respective Lessors, except
that Oglethorpe is permitted to sublease its interests under the Leases without
such consent if such sublease (i) do not extend beyond June 30, 2013, (ii) do
not impair or diminish any of the rights of the respective Lessors or
obligations of Oglethorpe under the Leases and (iii) are expressly subject to
and subordinate to the provisions of the Leases and the related operative
documents. No such sublease shall relieve Oglethorpe of its obligations under
the applicable Lease. (Leases, Article 13.)
OPTIONAL TERMINATION FOR OBSOLESCENCE
In the absence of an event of default under a Lease, Oglethorpe has the
option, on at least 180 days' prior notice, to terminate any Lease on any
subsequent June 30 or December 31 specified in such notice (the "Termination
Date"), if the Board of Directors of Oglethorpe has adopted a resolution
determining that (i) the interest in Scherer Unit No. 2 subject to the Lease is
surplus to the requirements of Oglethorpe or (ii) Scherer Unit No. 2 is
economically obsolete. If, at the time Oglethorpe exercises the foregoing
option, Scherer Unit No. 1 has not been permanently decommissioned and retired
from commercial service, and Scherer Unit No. 2 is determined by appraisers
pursuant to procedures specified in the Leases to be technically superior or
identical to Scherer Unit No. 1, then it is a condition to the exercise of this
option that Oglethorpe shall have disposed of all of its ownership interest, if
any, in Scherer Unit No. 1.
If Oglethorpe has given such a termination notice, it is required, upon
request of the Lessor to which such notice has been given, to use its best
efforts to obtain cash bids for the purchase of such Lessor's undivided
ownership interest in Scherer Unit No. 2. Each Lessor has the right to elect to
retain its
113
undivided ownership interest in Scherer Unit No. 2, provided that it shall first
have paid to the holders of the related Lessor Notes the principal of and
premium, if any, and interest on such Lessor Notes to the proposed date of
prepayment. If a Lessor has not elected to retain its undivided ownership
interest, the Lessor is required to transfer its interest in Scherer Unit No. 2
and the Support Agreements for cash to the bidder which has submitted the
highest bid before the Termination Date. On the Termination Date, if any Lessor
has not elected to retain its undivided ownership interest, Oglethorpe also is
required to pay or deliver, as applicable to the Lessor (a) the excess, if any,
of the Termination Value as of such date over such sales price (after deducting
all expenses incurred by such Lessor in connection with such sale), (b) all
basic rent accrued and unpaid to and including the Termination Date, including
any premium due on the Lessor Notes which are being redeemed, (c) either (i) an
amount of moneys which will be sufficient to pay on the specified redemption
date (45 to 60 days following the Termination Date), interest to become due on
the Notes from the Termination Date to such redemption date, or (ii) U.S.
Government Obligations maturing no later than the business day prior to the
specified redemption date, the principal of and the interest on which when due
will provide moneys which, together with the moneys, if any, available therefor,
will be sufficient to pay, on the redemption date, interest due and to become
due on the Lessor Notes on and prior to the redemption date, and (d) all other
rent then due under the related Lease. Upon compliance by Oglethorpe with such
provision, its obligation to pay basic rent under the applicable Lease for any
period after the Termination Date shall cease and the term of such Lease shall
end on such Termination Date. If no sale occurs on the Termination Date (other
than as a result of a Lessor's election to retain its undivided ownership
interest in Scherer Unit No. 2) or Oglethorpe fails to comply in full with the
early termination provisions, such Lease will continue in full force and effect.
(Leases, Article 6.)
PURCHASE AND RENEWAL OPTIONS
Oglethorpe has the option under each of the Leases to purchase the Lessor's
undivided ownership interest in Scherer Unit No. 2 on the following dates, for a
purchase price payable in immediately available funds in an amount equal to the
greater of Stipulated Loss Value payable on the proposed purchase date or the
fair market sales value of the Lessor's undivided ownership interest in Scherer
Unit No. 2 on such date, in either case together with premium, if any, due on
the Lessor Notes: (1) on December 31, 2000, December 31, 2005, and December 31,
2010; and (2) on any December 31 between December 31, 1997 and December 31,
2010, if (x) "scrubbers" or any similar capital improvement intended to remove
pollutants from the effluent discharged from the boiler of Scherer Unit No. 2
are required by applicable law, (y) capital improvements are included in the
Scherer Ownership Agreement budget for Scherer Unit No. 2, 60% of the value of
which (expressed in December 30, 1985 dollars) equals or exceeds $100,000,000,
or (z) capital improvements are included in such budget within any two years,
60% of the value of which (expressed in December 30, 1985 dollars) equals or
exceeds $50,000,000, and the related Equity Investor does not finance such
improvements through an equity investment. Oglethorpe also has the option under
each Lease to purchase such undivided ownership interest on each June 30 during
the fixed rate renewal term (described below) at the purchase price specified
above. In the case of all of these options, fair market sales value is to be
determined by agreement between Oglethorpe and the Lessor and, failing
agreement, by independent appraisers pursuant to procedures specified in the
Leases. The option to purchase the undivided ownership interest under each Lease
on the dates in clause (1) is subject to 24 months notice of a tentative
election so to purchase, and at least 12 months irrevocable notice of the
election so to purchase. The option to purchase the undivided ownership
interests on the dates in clause (2) may be exercised on any June 30 or December
31 following a determination of fair market sales value as of such June 30 or
December 31.
Oglethorpe also has the option to purchase a Lessor's undivided ownership
interest in Scherer Unit No. 2 of any June 30 or December 31, after an indemnity
payment becomes due under a Tax Indemnification Agreement with such Lessor's
Equity Investor as a result of a final determination that such undivided
interest constitutes public utility property. The purchase price in such event
will be the greater
114
of the Termination Value payable on the purchase date or the fair market sales
value of the Lessor's undivided ownership interest in Scherer Unit No. 2 on such
date, in either case together with premium, if any, due on the Lessor Notes of
such Lessor. (Leases, Section 5.1.)
The foregoing options to purchase the undivided ownership interests or to
renew the Lease are subject to the rights of first refusal granted to the other
owners of Scherer Unit No. 2. The consent of such Co-Owners to the Leases
provides that Oglethorpe may exercise any of the foregoing options, but that, if
Oglethorpe does not do so, the other Co-Owners shall have the right to exercise
such options on substantially the same terms and conditions and at the same
time.
At the end of the basic term of each Lease, unless an "Event of Default"
under such Lease, shall have occurred and be continuing, Oglethorpe will have
the option to renew such Lease at a fixed rental for a period of at least 8.5
years, as determined pursuant to formulas set forth in such Lease unless a Lease
Event of Default. (Leases, Section 4.1.) Oglethorpe also will have the right at
the end of the basic term or any renewal term of a Lease, unless a Lease Event
of Default shall have occurred and be continuing to renew the term of such Lease
for a period of up to five years at the fair market rental value for such
undivided ownership interest in Scherer Unit No. 2, as determined by negotiation
between Oglethorpe and the Lessor and, failing agreement, by independent
appraisers pursuant to procedures specified in such Lease. (Leases, Sections
4.2, 4.3 and 4.4.) Oglethorpe also has the right at the end of the basic term or
any renewal term of a Lease to purchase the Lessor's undivided ownership
interest in Scherer Unit No. 2 at a purchase price equal to the fair market
sales value of such interest, determined in the manner described above. (Leases,
Section 5.1.)
EVENTS OF LOSS
An Event of Loss means any of the following events:
(i) The loss of Scherer Unit No. 2, in its entirety or substantially in
its entirety, due to theft, disappearance, destruction or damage beyond
economic repair;
(ii) The receipt of insurance proceeds based upon an actual or
constructive total loss with respect to Scherer Unit No. 2;
(iii) Scherer Unit No. 2, the Scherer Unit No. 2 Site, or the Scherer
Common Facilities having been condemned or otherwise permanently rendered
unfit for normal use, confiscated or seized, or title thereto or use thereof
having been requisitioned by any governmental authority and Oglethorpe
having lost the use or possession of substantially all of Scherer Unit No. 2
or the Site for a period exceeding 48 months;
(iv) The permanent decommissioning and retiring from commercial service
of Scherer Unit No. 2;
(v) With respect to any Lessor or Equity Investor, such Lessor or Equity
Investor or any affiliate of either of them, solely by reason of the Sale
and Leaseback Transactions and without regard to any of its other
activities, having become subject to regulation under any Federal or state
law relating to utilities or the generation, transmission, production, or
sale of electric power during the term of any Lease and prior to the time
that Oglethorpe ceases to be in possession of Scherer Until No. 2, unless
(A) such regulation results from the ownership or leasehold interest in any
other electric generation facility or transmission facility acquired on or
after December 30, 1985, or such Lessor, Equity Investor or affiliate was
subject to such regulation prior to such date or upon becoming a Lessor or
Equity Investor, (B) if such regulation is pursuant to any law other than
the Public Utility Holding Company Act of 1935, as amended, or the Federal
Power Act, as amended, and the effect of such regulation is not materially
adverse, in the reasonable judgment of the person subject to such
regulation, (C) such person has waived in writing the treatment of such
regulation as
115
an Event of Loss, or (D) Oglethorpe, at its sole cost and expense, is
contesting such regulation, subject to certain conditions; or
(vi) At Oglethorpe's election, if any Lessor or Equity Investor becomes
subject to the type of regulation described in (v) above under circumstances
described in the Leases and such Lessor or Equity Investor does not take
such action as may be necessary in order to cease to be so regulated within
60 days or does not transfer its undivided interest to a nonregulated entity
and, as a result thereof, (A) the Lease is deemed to be a contract for the
sale by such Lessor of electric energy to Oglethorpe under the Federal Power
Act, as amended, (B) Oglethorpe becomes subject to regulation which is
contrary to the terms of the Mortgage Indenture, its Member contracts, or
any other agreement to which it is a party or any applicable law, or (C)
Oglethorpe becomes subject to regulation which otherwise would not be
applicable, which regulation Oglethorpe, in its reasonable judgment,
determines to be materially adverse.
If an Event of Loss described in clauses (i), (ii), (iii) or (iv) occurs
with respect to Scherer Unit No. 2, Oglethorpe is required to pay to each Lessor
on the June 30 or December 31 (or, if such Event of Loss occurs within 90 days
of the next succeeding June 30 or December 31, the 90th day) following the date
of such Event of Loss, the Stipulated Loss Value of such Lessor's undivided
ownership interest in Scherer Unit No. 2, together with certain additional
amounts. In the case of an Event of Loss described in clauses (v) and (vi), such
payment will made only to the Lessor with respect to which the Event of Loss has
occurred. If Oglethorpe pays the Stipulated Loss Value to a Lessor, together
with the additional amounts then required to be paid (which in all circumstances
will be in excess of the principal of and premium, if any, and interest on the
Lessor Notes of such Lessor then outstanding), the lien of the related Lease
Indenture and Lease of the Lessor's undivided ownership interest in Scherer Unit
No. 2, shall be terminated, title thereto shall be transferred to or upon the
order of Oglethorpe, the obligation of Oglethorpe thereafter to make rental
payments with respect to such interest in Scherer Unit No. 2 will cease, and the
aggregate of the Stipulated Loss Value and other payments made by Oglethorpe
shall be applied as provided in the Lease Indenture to the prepayment of the
Lessor Notes. (Leases, Section 11.1; Lease Indentures, Section 3.2.)
Notwithstanding the foregoing, upon the occurrence of an Event of Loss described
in clause (v) above, Oglethorpe may elect, upon the satisfaction of certain
conditions specified in each Lease Indenture, to assume all of the liabilities
and obligations of the Lessor under the related Lease Indenture. Upon such
assumption, all such liabilities and obligations shall be made fully recourse to
Oglethorpe, and Oglethorpe's obligation to pay such Stipulated Loss Value and
other amounts shall be reduced by the principal amount of and accrued interest
on the Lessor Notes so assumed and not otherwise due on the date of such
payment. (Lease Indentures, Section 2.10(a).)
EVENTS OF DEFAULT
"Events of Default" under each Lease include, among other things: (i)
failure by Oglethorpe to pay basic rent within three business days after the
same shall have become due; (ii) the failure to pay Stipulated Loss Value or
Termination Value, together with premium, if any, on the Lessor Notes of the
related Lessor, within ten business days after the same becomes due; (iii) the
failure to pay any amount payable by Oglethorpe under the Scherer Ownership
Agreement, the Scherer Operating Agreement or certain related documents upon the
earlier of ten days after such payment becomes due or the enforcement by any
Co-Owner or the operator of Scherer Unit No. 2 under the Scherer Operating
Agreement of the right to deny Oglethorpe the output of capacity or energy
derived from Scherer Unit No. 2; (iv) the failure to pay any other amount
payable under the Lease within fifteen business days after demand therefor; (v)
the failure by Oglethorpe to perform or observe any material covenant or
agreement under the Lease or any other operative document (except the related
Tax Indemnification Agreement) and the continuance of such failure for a period
of 60 days after notice; (vi) any representation or warranty made by Oglethorpe
in any related operative document (except the related Tax Indemnification
Agreement) shall prove to have been incorrect in any material respect when made,
and shall remain
116
material and uncured; (vii) certain events of bankruptcy or insolvency shall
have occurred with respect to Oglethorpe; (viii) an Event of Default under the
Mortgage Indenture shall have occurred and be continuing and, as a result
thereof, any remedy permitted pursuant to the Mortgage Indenture shall have been
exercised; or (ix) any judgment or order for the payment of money in excess of
$10,000,000 shall be rendered against Oglethorpe, and enforcement proceedings
shall have been commenced and Oglethorpe shall not have bonded or otherwise set
aside on its books adequate reserves therefor or there shall be any period of
120 days during which a stay of enforcement shall not be in effect. (Leases,
Article 14.) The related Lessor has the right to cure any such default. (Leases,
Article 17.)
If an "Event of Default" under any Lease has occurred and is continuing, and
the Lessor thereunder has declared such Lease to be in default, the Lessor may
exercise one or more of the remedies provided in the Lease with respect to its
undivided ownership interest in Scherer Unit No. 2. These remedies include the
right to rescind or terminate the Lease, to demand that Oglethorpe redeliver
such interest, to sell or relet such interest free and clear of the rights of
Oglethorpe, and to retain the proceeds of such sale or lease and to require
Oglethorpe to pay as liquidated damages any unpaid basic rent due under the
Lease through the rent payment date specified in a written notice to Oglethorpe
given not earlier than 30 days before such date, together with premium, if any,
due on the Lessor Notes, plus, in the sole discretion of the Lessor any of the
following amounts, with interest thereon at the Stipulated Interest Rate to the
date of payment:
(a) (i) an amount equal to the excess, if any, of (A) the applicable
Stipulated Loss Value as of such payment date, over (B) the aggregate fair
market rental value of the Lessor's undivided ownership interest in Scherer
Unit No. 2 until the end of the basic term or the then current renewal term
of the Lease, after discounting such rental value to present worth at the
Stipulated Interest Rate;
(ii) an amount equal to the excess, if any, of such Stipulated Loss
Value over the fair market sales value of the Lessor's undivided
ownership interest in Scherer Unit No. 2 as of such payment date; or
(iii) an amount equal to such Stipulated Loss Value and, if such
amount is demanded, upon full payment by Oglethorpe of all sums due under
the Lease, the Lessor is required, at the option of Oglethorpe, either to
(x) exercise commercially reasonable efforts to sell its undivided
ownership interest in Scherer Unit No. 2 and pay over to Oglethorpe the
net proceeds of such sale or (y) transfer its undivided ownership
interest in Scherer Unit No. 2 and the Support Agreement to Oglethorpe,
whereupon the Lease shall terminate; or
(b) the amount of any deficiency between Stipulated Loss Value as of
such payment date and the net proceeds of such sale, together with interest
on such rent and such deficiency, calculated as provided in the Lease, from
the date of such sale until the date of actual payment.
For a period of 30 days before the exercise of any of the remedies described
above, each Lessor is required to attempt to lease its interest in Scherer Unit
No. 2 and assign Oglethorpe's related rights and obligations, on the same terms
and conditions, to any other Co-Owner or a rural electric cooperative with a net
worth of at least $25,000,000 or a public utility having a net worth of at least
$200,000,000. (Leases, Section 15.1.) Any new lessee must cure all defaults of
Oglethorpe and obtain all necessary governmental consents. (See "DESCRIPTION OF
THE LEASE INDENTURES--Rights of the Lessors to Cure and Purchase Lessor Notes.")
MERGER, CONSOLIDATION; MAINTENANCE OF CORPORATE EXISTENCE
Pursuant to the Participation Agreements, Oglethorpe shall at all times
maintain its existence as an electric membership corporation under Georgia law,
provided that Oglethorpe may consolidate or merge with or into any other
corporation or convey, transfer or lease all or substantially all of its assets
to
117
any person if, among other things: (i) the resulting entity formed by such
consolidation or merger or the resulting entity that acquires by conveyance,
transfer or lease shall be a corporation organized under the laws of the
District of Columbia or any State of the United States; (ii) in the case of a
conveyance, transfer or lease, such entity agrees to assume the due and punctual
performance of each covenant and condition to be performed or complied with by
Oglethorpe in connection with each Lease; (iii) Oglethorpe shall have delivered
to the Lessors, the Equity Investors and the Lease Indenture Trustees an opinion
of independent counsel, to the effect that clause (i) has been complied with,
and the assumption agreement, if required by clause (ii), is a legal, valid and
binding agreement of, and enforceable against, the resulting entity; (iv)
immediately after giving effect to such transaction, no default or "Event of
Default" shall have occurred and be continuing under the Lease; (v) the debt of
the resulting entity is rated at levels specified in the related Participation
Agreement which are based on the credit ratings of Oglethorpe at such time or,
in the alternative, the resulting entity shall have a consolidated net worth at
least equal to that of Oglethorpe prior to the transaction; and (vi) the
resulting entity has acquired all necessary consents, approvals and permits of
governmental authorities, Oglethorpe's Members and the RUS. Oglethorpe also may
not acquire all or substantially all the assets of any other person or permit
any corporation to be merged into Oglethorpe unless the last two conditions are
fulfilled. No such conveyance, transfer or lease of all or substantially all of
the assets of Oglethorpe shall have the effect of releasing Oglethorpe or any
resulting entity from its liability with respect to the undivided ownership
interest in Scherer Unit No. 2 without the prior written consent of the Lessors,
the Equity Investors and the Lease Indenture Trustees. (Participation
Agreements, Section 5.5(t).)
118
CERTAIN UNITED STATES FEDERAL INCOME TAX CONSEQUENCES
The following is a summary of the principal U.S. federal income tax
consequences of the exchange of Private Facility Bonds for Exchange Facility
Bonds and the ownership and disposition of Exchange Facility Bonds. This summary
deals only with Exchange Facility Bonds held as capital assets by initial
holders. This summary does not address all aspects of U.S. federal income
taxation that may be relevant to a U.S. Holder (as defined below) based on such
U.S. Holder's specific circumstances. In particular, the following summary does
not address the tax treatment of persons who are not U.S. Holders or of U.S.
Holders who are dealers in securities or currencies, banks, certain U.S.
expatriates, tax-exempt organizations, life insurance companies, persons subject
to the alternative minimum tax, persons that hold Exchange Facility Bonds that
are a hedge or that are hedged against currency risks or that are part of a
straddle or conversion transaction or persons whose functional currency is not
the U.S. dollar. The summary is based on the Internal Revenue Code of 1986, as
amended (the "Code"), its legislative history, existing and proposed Treasury
Regulations promulgated thereunder, published rulings and court decisions, all
as currently in effect and all subject to change at any time, perhaps with
retroactive effect.
For purposes of this discussion, "U.S. Holder" means a beneficial owner of
Exchange Facility Bonds who or that is a citizen or resident of the United
States, a corporation, partnership or other entity created or organized in or
under the laws of the United States or of any political subdivision thereof, an
estate the income of which is includable in gross income for U.S. federal income
tax purposes regardless of its source or a trust if (i) a court within the
United States is able to exercise primary supervision over the administration of
the trust and (ii) one or more U.S. trustees have the authority to control all
substantial decisions of the trust.
This summary is of a general nature only and is not intended to be, and
should not be construed to be, legal or tax advice to any prospective investor
and no representation is made with respect to the tax consequences to any
particular investor. This summary does not address any aspect of any state or
local tax law or any estate or gift tax considerations, or the tax laws of
jurisdictions outside the United States that may be applicable to the Exchange
Facility Bonds or holders thereof, or the tax considerations applicable to
non-U.S. Holders. There can be no assurance that the Internal Revenue Service
(the "IRS") will take a similar view of the ownership or disposition of the
Exchange Facility Bonds. Persons considering exchanging Private Facility Bonds
for Exchange Facility Bonds should consult their own tax advisors concerning the
consequences, in their particular circumstances, under the Code and the laws of
any other state, local or non-U.S. taxing jurisdiction, of such exchange and the
ownership and disposition of Exchange Facility Bonds.
EXCHANGE OF PRIVATE FACILITY BONDS
The exchange of the Private Facility Bonds for the Exchange Facility Bonds
in the Exchange Offer should not constitute a taxable event to U.S. Holders.
Consequently, no gain or loss should be recognized by a U.S. Holder upon receipt
of an Exchange Facility Bond, the holding period of the Exchange Facility Bond
should include the holding period of the Private Facility Bond, and the basis of
the Exchange Facility Bond should be the same as the basis of the Private
Facility Bond immediately before the exchange. (See "THE EXCHANGE OFFER.")
REDEMPTION, SALE OR EXCHANGE OF EXCHANGE FACILITY BONDS
A U.S. Holder generally will have an adjusted tax basis for an Exchange
Facility Bond equal to the cost of the Private Facility Bond exchanged therefor
(but excluding accrued interest at the time of purchase of the Private Facility
Bond), reduced by prior payments of principal on the Private Facility Bond and
payments of principal on the Exchange Facility Bond. Upon the redemption, sale,
exchange or retirement of an Exchange Facility Bond, a U.S. Holder generally
will recognize gain or loss equal to the
119
difference between the amount realized upon the redemption, sale, exchange or
retirement and the adjusted tax basis of the Exchange Facility Bond. Gain or
loss recognized by a U.S. Holder on the redemption, sale, exchange or retirement
of the Exchange Facility Bond generally will be capital gain or loss. Any such
capital gain or loss will be either long-term or short-term capital gain or loss
depending on the U.S. Holder's holding period for the Exchange Facility Bond at
the time of its redemption, sale, exchange or retirement. Capital losses are
subject to limitations on deductibility for U.S. federal income tax purposes.
INFORMATION REPORTING AND BACKUP WITHHOLDING
In general, information reporting requirements will apply to payments of
principal and interest on an Exchange Facility Bond, and the proceeds of the
sale of an Exchange Facility Bond before maturity within the United States, to
noncorporate U.S. Holders. If a non-corporation U.S. Holder fails to furnish a
correct taxpayer identification number or a certification of exempt status,
fails to report dividend and interest income in full, or fails to certify that
such U.S. Holder has provided a correct taxpayer identification number and is
not subject to backup withholding, a 31% federal backup withholding tax may be
withheld on amounts paid to the U.S. Holder. The backup withholding tax is not
an additional tax and may be credited against a U.S. Holder's regular U.S.
federal income tax liability or refunded by the IRS where applicable.
PLAN OF DISTRIBUTION
This Prospectus, as it may be amended or supplemented from time to time, may
be used by a broker-dealer in connection with resales of any Exchange Facility
Bonds received in exchange for Private Facility Bonds acquired by such
broker-dealer as a result of market making or other trading activities. Each
such broker-dealer that receives Exchange Facility Bonds for its own account in
exchange for such Private Facility Bonds pursuant to the Exchange Offer must
acknowledge that it will deliver a prospectus in connection with any resale of
such Exchange Facility Bonds. Oglethorpe has agreed that for a period of up to
90 days after the Expiration Date, it will make this Prospectus, as amended or
supplemented, available to any such broker-dealer that requests copies of this
Prospectus in the Letter of Transmittal for use in connection with any such
resale.
Exchange Facility Bonds received by a broker-dealer for its own account
pursuant to the Exchange Offer may be sold from time to time in one or more
transactions in the over-the-counter market, in negotiated transactions or
through the writing of options on the Exchange Facility Bonds, or a combination
of such methods of resale, at market prices prevailing at the time of resale or
negotiated prices. Any such resale may be made directly to purchasers or to or
through brokers or dealers who may receive compensation in the form of
commissions or concessions from any such broker-dealer and/or the purchasers of
any such Exchange Facility Bonds. Any broker-dealer that resells Exchange
Facility Bonds that were received by it for its own account pursuant to the
Exchange Offer in exchange for Private Facility Bonds acquired by such
broker-dealer as a result of market making or other trading activities and any
broker-dealer that participates in a distribution of such Exchange Facility
Bonds may be deemed to be an "underwriter" within the meaning of the Securities
Act and any profit on any such resale of Exchange Facility Bonds and any
commissions or concessions received by any such persons may be deemed to be
underwriting compensation under the Securities Act. The Letter of Transmittal
states that by acknowledging that it will deliver and by delivering a
prospectus, a broker-dealer will not be deemed to admit that it is an
"underwriter" within the meaning of the Securities Act.
Neither Oglethorpe nor OPC Scherer 1997 Funding Corporation will receive any
proceeds from any sale of Exchange Facility Bonds by broker-dealers or any other
persons. The Lessors have agreed to pay all expenses incident to Oglethorpe's
performance of, or compliance with, the Registration Rights Agreement.
120
By acceptance of this Exchange Offer, each broker-dealer that receives
Exchange Facility Bonds for its own account pursuant to the Exchange Offer
agrees that, upon receipt of notice from Oglethorpe of the happening of any
event which makes any statement in the Prospectus untrue in any material respect
or which requires the making of any changes in the Prospectus in order to make
the statements therein not misleading (which notice Oglethorpe has agreed to
deliver promptly to such broker-dealer), such broker-dealer will suspend use of
the Prospectus until Oglethorpe has amended or supplemented the Prospectus to
correct such misstatement or omission and has furnished copies of the amended or
supplemental Prospectus to such broker-dealer.
LEGAL OPINIONS
The validity of the Exchange Facility Bonds offered hereby will be passed
upon for OPC Scherer 1997 Funding Corporation and Oglethorpe by Sutherland,
Asbill & Brennan LLP, Atlanta, Georgia.
EXPERTS
The financial statements of Oglethorpe as of December 31, 1996 and 1995 and
for each of the years in the two-year period ended December 31, 1996, have been
included herein in reliance upon the report of Coopers & Lybrand L.L.P.,
independent public accountants, appearing elsewhere herein, and upon the
authority of such firm as experts in accounting and auditing. The financial
statements of Oglethorpe for the year ended December 31, 1994, have been
included herein in reliance upon the report of Arthur Andersen LLP, independent
public accountants, appearing elsewhere herein, and upon the authority of such
firm as experts in accounting and auditing.
With respect to the unaudited interim financial statements as of and for the
twelve months ended September 30, 1997, included herein, Coopers & Lybrand
L.L.P. has reported that they applied limited procedures in accordance with
professional standards for a review of such information. However, their separate
report included herein states that they did not audit and they did not express
an opinion on that interim financial information. Accordingly, the degree of
reliance on their report on such information should be restricted in light of
the limited nature of the review procedures applied.
121
OGLETHORPE POWER CORPORATION
INDEX TO FINANCIAL STATEMENTS
PAGE
-----
AUDITED ANNUAL FINANCIAL STATEMENTS:
Reports of Independent Public Accountants............................................ F-2
Statements of Revenues and Expenses, For the Years Ended December 31, 1996, 1995 and
1994............................................................................... F-4
Statements of Patronage Capital, For the Years Ended December 31, 1996, 1995 and
1994............................................................................... F-4
Balance Sheets, As of December 31, 1996 and 1995..................................... F-5
Statements of Capitalization, As of December 31, 1996 and 1995....................... F-6
Statements of Cash Flows, For the Years Ended December 31, 1996, 1995 and 1994....... F-7
Notes to Financial Statements........................................................ F-8
UNAUDITED INTERIM FINANCIAL STATEMENTS:
Accountants' Review Report........................................................... F-28
Condensed Statements of Revenues and Expenses, For the Twelve Months Ended September
30, 1997 and the Year Ended December 31, 1996...................................... F-29
Condensed Balance Sheets, As of September 30, 1997 and December 31, 1996............. F-30
Condensed Statements of Cash Flows, For the Twelve Months Ended September 30, 1997
and the Year Ended December 31, 1996............................................... F-31
Notes to Condensed Interim Financial Statements...................................... F-32
F-1
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors of Oglethorpe Power Corporation:
We have audited the accompanying balance sheets and statements of
capitalization of Oglethorpe Power Corporation (a Georgia corporation) as of
December 31, 1996 and 1995 and the related statements of revenues and expenses,
patronage capital, and cash flows for the years then ended. These financial
statements are the responsibility of Oglethorpe'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 Oglethorpe Power Corporation
as of December 31, 1996 and 1995 and the results of its operations and its cash
flows for the years then ended in conformity with generally accepted accounting
principles.
Coopers & Lybrand L.L.P.
Atlanta, Georgia,
February 21, 1997, except for Note 11, as to which
the date is March 11, 1997.
F-2
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors of Oglethorpe Power Corporation:
We have audited the statements of revenues and expenses, patronage capital,
and cash flows of Oglethorpe Power Corporation (a Georgia corporation) for the
year ended December 31, 1994. These financial statements are the responsibility
of Oglethorpe's management. Our responsibility is to express an opinion on these
financial statements based on our audit.
We conducted our audit 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 audit provides a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the results of operations, changes in patronage
capital, and cash flows of Oglethorpe Power Corporation for the year ended
December 31, 1994 in conformity with generally accepted accounting principles.
As explained in Note 2 of notes to financial statements, effective January
1, 1994, Oglethorpe Power Corporation changed its method of accounting for
certain investments in debt and equity securities.
Arthur Andersen LLP
Atlanta, Georgia,
February 24, 1995.
F-3
STATEMENTS OF REVENUES AND EXPENSES
FOR THE YEARS ENDED DECEMBER 31,
----------------------------------
1996 1995 1994
---------- ---------- ----------
(DOLLARS IN THOUSANDS)
OPERATING REVENUES (NOTE 1):
Sales to Members.......................................................... $1,023,094 $1,030,797 $ 930,875
Sales to non-Members...................................................... 78,343 118,764 125,207
---------- ---------- ----------
TOTAL OPERATING REVENUES.................................................... 1,101,437 1,149,561 1,056,082
---------- ---------- ----------
OPERATING EXPENSES:
Fuel...................................................................... 206,524 219,062 203,444
Production................................................................ 129,178 133,858 132,723
Purchased power (Note 9).................................................. 229,089 264,844 227,477
Power delivery............................................................ 18,216 17,520 16,965
Sales, administrative and general......................................... 42,289 39,015 32,269
Depreciation and amortization............................................. 163,130 139,024 131,056
Taxes other than income taxes............................................. 30,262 27,561 24,741
Income taxes (Note 3)..................................................... -- -- --
---------- ---------- ----------
TOTAL OPERATING EXPENSES.................................................... 818,688 840,884 768,675
---------- ---------- ----------
OPERATING MARGIN............................................................ 282,749 308,677 287,407
---------- ---------- ----------
OTHER INCOME (EXPENSE):
Interest income........................................................... 23,485 18,031 10,518
Amortization of deferred gains (Notes 1 and 4)............................ 2,341 2,341 9,985
Amortization of net benefit of sale of income tax benefits (Note 1)....... 8,054 8,043 8,102
Amortization of deferred margins (Note 1)................................. 32,047 15,959 18,072
Deferred margins (Note 1)................................................. -- (14,282) (9,287)
Allowance for equity funds used during construction (Note 1).............. 238 1,715 2,907
Other..................................................................... (831) 1,903 498
---------- ---------- ----------
TOTAL OTHER INCOME.......................................................... 65,334 33,710 40,795
---------- ---------- ----------
INTEREST CHARGES:
Interest on long-term debt and capital leases............................. 308,013 317,968 329,738
Other interest............................................................ 10,006 12,979 3,856
Allowance for debt funds used during construction (Note 1)................ (2,576) (21,114) (36,113)
Amortization of debt discount and expense................................. 10,888 10,296 7,639
---------- ---------- ----------
NET INTEREST CHARGES........................................................ 326,331 320,129 305,120
---------- ---------- ----------
NET MARGIN.................................................................. $ 21,752 $ 22,258 $ 23,082
---------- ---------- ----------
---------- ---------- ----------
STATEMENTS OF PATRONAGE CAPITAL
FOR THE YEARS ENDED DECEMBER 31,
----------------------------------
1996 1995 1994
---------- ---------- ----------
(DOLLARS IN THOUSANDS)
Patronage capital and membership fees--beginning of year (Note 1)......... $ 338,891 $ 309,496 $ 289,982
Net margin................................................................ 21,752 22,258 23,082
Change in unrealized gain (loss) on available-for-sale securities, net of
income taxes (Note 2)................................................... (4,414) 7,137 (3,568)
---------- ---------- ----------
Patronage capital and membership fees--end of year........................ $ 356,229 $ 338,891 $ 309,496
---------- ---------- ----------
---------- ---------- ----------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE FINANCIAL STATEMENTS.
F-4
BALANCE SHEETS
DECEMBER 31,
------------------------
1996 1995
----------- -----------
(DOLLARS IN THOUSANDS)
ASSETS
ELECTRIC PLANT (NOTES 1, 4 AND 6):
In service........................................................................................ $ 5,742,597 $ 5,699,213
Less: Accumulated provision for depreciation...................................................... (1,488,272) (1,362,431)
----------- -----------
4,254,325 4,336,782
Nuclear fuel, at amortized cost................................................................... 86,722 94,013
Plant acquisition adjustments, at amortized cost.................................................. 4,153 5,214
Construction work in progress..................................................................... 31,181 35,753
----------- -----------
4,376,381 4,471,762
----------- -----------
INVESTMENTS AND FUNDS (NOTES 1 AND 2):
Bond, reserve and construction funds, at market................................................... 53,955 56,511
Decommissioning fund, at market................................................................... 86,269 74,492
Investment in associated organizations, at cost................................................... 15,379 15,853
Deposit on Rocky Mountain transactions, at cost................................................... 41,685 --
----------- -----------
197,288 146,856
----------- -----------
CURRENT ASSETS:
Cash and temporary cash investments, at cost (Note 1)............................................. 132,783 201,151
Other short-term investments, at market........................................................... 91,499 79,165
Receivables....................................................................................... 113,289 99,559
Inventories, at average cost (Note 1)............................................................. 89,825 82,949
Prepayments and other current assets.............................................................. 14,625 14,325
----------- -----------
442,021 477,149
----------- -----------
DEFERRED CHARGES:
Premium and loss on reacquired debt, being amortized (Note 5)..................................... 201,007 200,794
Deferred amortization of Scherer leasehold (Note 4)............................................... 90,717 87,134
Deferred debt expense, being amortized............................................................ 21,703 21,135
Other (Note 1).................................................................................... 33,058 33,666
----------- -----------
346,485 342,729
----------- -----------
$ 5,362,175 $ 5,438,496
----------- -----------
----------- -----------
EQUITY AND LIABILITIES
CAPITALIZATION (SEE ACCOMPANYING STATEMENTS):
Patronage capital and membership fees (Note 1).................................................... $ 356,229 $ 338,891
Long-term debt.................................................................................... 4,052,470 4,207,320
Obligation under capital leases (Note 4).......................................................... 293,682 296,478
Obligation under Rocky Mountain transactions (Note 1)............................................. 41,685 --
----------- -----------
4,744,066 4,842,689
----------- -----------
CURRENT LIABILITIES:
Long-term debt and capital leases due within one year............................................. 159,622 89,675
Deferred margins to be refunded within one year (Note 1).......................................... -- 32,047
Accounts payable.................................................................................. 42,891 48,855
Accrued interest.................................................................................. 15,931 91,096
Accrued and withheld taxes........................................................................ 4,940 1,785
Other current liabilities......................................................................... 9,540 18,007
----------- -----------
232,924 281,465
----------- -----------
DEFERRED CREDITS AND OTHER LIABILITIES:
Gain on sale of plant, being amortized (Note 4)................................................... 58,527 60,868
Net benefit of sale of income tax benefits, being amortized (Note 1).............................. 42,049 50,194
Net benefit of Rocky Mountain transactions, being amortized (Note 1).............................. 70,701 --
Accumulated deferred income taxes (Note 3)........................................................ 61,985 65,510
Decommissioning reserve (Note 1).................................................................. 124,468 114,049
Other............................................................................................. 27,455 23,721
----------- -----------
385,185 314,342
----------- -----------
COMMITMENTS AND CONTINGENCIES (NOTES 4, 9 AND 11)
$ 5,362,175 $ 5,438,496
----------- -----------
----------- -----------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE BALANCE SHEETS.
F-5
STATEMENTS OF CAPITALIZATION
DECEMBER 31,
----------------------
1996 1995
---------- ----------
(DOLLARS IN THOUSANDS)
LONG-TERM DEBT (NOTE 5):
Mortgage notes payable to the Federal Financing Bank (FFB) at interest rates varying
from 5.27% to 9.51% (average rate of 6.95% at December 31, 1996) due in quarterly
installments through 2023............................................................ $3,172,851 $3,253,636
Mortgage notes payable to the Rural Utilities Service (RUS) at an interest rate of 5%
due in monthly installments through 2021............................................. 22,475 22,983
Mortgage notes issued in conjunction with the sale by public authorities of pollution
control revenue bonds (PCBs):
- Series 1982
Serial bonds, 10.60%, due serially through 1997.................................. 6,675 6,675
- Series 1992
Term bonds, 7.50% to 8.00%, due 2003 to 2022..................................... 92,130 92,130
- Series 1992A
Adjustable tender bonds, 3.40% to 3.70%, due 2025................................ 216,925 216,925
Serial bonds, 5.35% to 6.80%, due serially from 1998 to 2012..................... 124,690 129,760
- Series 1993
Serial bonds, 3.55% to 5.25%, due serially from 1997 through 2013................ 37,255 38,110
- Series 1993A
Adjustable tender bonds, 4.00%, due 2016......................................... 199,690 199,690
- Series 1993B
Serial bonds, 3.75% to 5.05%, due serially from 1998 through 2008................ 126,935 136,745
- Series 1994
Serial bonds, 4.20% to 7.125%, due serially from 1997 through 2015............... 10,365 10,690
Term bonds, 7.15% due 2021....................................................... 11,550 11,550
- Series 1994A
Adjustable tender bonds, 4.00%, due 2019......................................... 122,740 122,740
- Series 1994B
Serial bonds, 5.45% to 6.45%, due serially from 1998 through 2005................ 11,140 12,475
Unsecured notes issued in conjunction with the sale by public authorities of
pollution control revenue bonds:
- Series 1995
Adjustable rate bonds, 3.70% to June 1996, due in 2015........................... -- 21,670
- Series 1996
Adjustable rate bonds, 3.88% to April 1997, due in 2017.......................... 37,885 --
CoBank, ACB notes payable:
- Headquarters note payable: fixed at 6.60% through April 1997, due in quarterly
installments through January 1, 2009............................................. 4,672 5,159
- Mortgage note payable: fixed at 6.50% through September 1997, due in bimonthly
installments through November 1, 2018............................................ 2,237 2,261
- Mortgage note payable: fixed at 6.50% through October 1997, due in bimonthly
installments through September 1, 2019........................................... 8,556 8,637
---------- ----------
4,208,771 4,291,836
Less: Unamortized debt discount...................................................... (766) (832)
---------- ----------
Total long-term debt, net............................................................ 4,208,005 4,291,004
Less: Long-term debt due within one year............................................. (155,535) (83,684)
---------- ----------
TOTAL LONG-TERM DEBT, EXCLUDING AMOUNT DUE WITHIN ONE YEAR......................... 4,052,470 4,207,320
OTHER LONG-TERM LIABILITIES
Obligation under capital leases, long-term (Note 4).................................... 293,682 296,478
Obligation under Rocky Mountain transactions, long-term (Note 1)....................... 41,685 --
EQUITIES
Patronage capital and membership fees (Note 1)......................................... 356,229 338,891
---------- ----------
TOTAL CAPITALIZATION............................................................... $4,744,066 $4,842,689
---------- ----------
---------- ----------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE FINANCIAL STATEMENTS.
F-6
STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER
31,
-------------------------------
1996 1995 1994
--------- --------- ---------
(DOLLARS IN THOUSANDS)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net margin.............................................................................. $ 21,752 $ 22,258 $ 23,082
--------- --------- ---------
Adjustments to reconcile net margin to net cash provided by operating activities:
Depreciation and amortization....................................................... 196,593 196,920 193,351
Net benefit of Rocky Mountain transactions.......................................... 70,701 -- --
Interest on decommissioning reserve................................................. 7,167 9,951 1,291
Amortization of deferred gains...................................................... (2,341) (2,341) (9,985)
Deferred margins and amortization of deferred margins............................... (32,047) (1,677) (8,785)
Amortization of net benefit of sale of income tax benefits.......................... (8,145) (8,043) (8,102)
Allowance for equity funds used during construction................................. (238) (1,715) (2,907)
Deferred income taxes............................................................... (3,525) -- --
Option payment on power swap agreement.............................................. (3,750) -- --
Other............................................................................... (13) (13) (13)
Change in net current assets, excluding long-term debt due within one year and deferred
margins and Vogtle surcharge to be refunded within one year:
Receivables......................................................................... (13,731) (10,686) (18,055)
Inventories......................................................................... (6,875) 12,127 (8,608)
Prepayments and other current assets................................................ (299) 532 (94)
Accounts payable.................................................................... (5,964) (4,066) (10,569)
Accrued interest.................................................................... (75,165) (8,914) (8,692)
Accrued and withheld taxes.......................................................... 3,155 219 (7,835)
Other current liabilities........................................................... (3,985) (169) (24,124)
--------- --------- ---------
Total adjustments....................................................................... 121,538 182,125 86,873
--------- --------- ---------
NET CASH PROVIDED BY OPERATING ACTIVITIES................................................. 143,290 204,383 109,955
--------- --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Property additions...................................................................... (93,704) (138,921) (206,345)
Activity in decommissioning fund -- Purchases........................................... (327,233) (410,597) (297,492)
-- Proceeds............................................ 316,542 399,077 293,990
Activity in bond, reserve and construction
funds -- Purchases.................................................................... (107,890) (27,762) (498,052)
-- Proceeds..................................................................... 109,230 39,566 540,712
Activity in other short-term investments -- Purchases................................... (15,532) (76,180) --
Decrease in investment in associated organizations...................................... 474 1,518 1,752
--------- --------- ---------
NET CASH USED IN INVESTING ACTIVITIES..................................................... (118,113) (213,299) (165,435)
--------- --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Debt proceeds, net...................................................................... 2,243 132,874 523,518
Debt payments........................................................................... (95,367) (108,481) (517,530)
Return of Vogtle surcharge.............................................................. -- (3,320) (2,031)
Other................................................................................... (421) (1,648) (2,008)
--------- --------- ---------
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES....................................... (93,545) 19,425 1,949
--------- --------- ---------
NET INCREASE (DECREASE) IN CASH AND TEMPORARY CASH INVESTMENTS............................ (68,368) 10,509 (53,531)
CASH AND TEMPORARY CASH INVESTMENTS AT BEGINNING OF YEAR.................................. 201,151 190,642 244,173
--------- --------- ---------
CASH AND TEMPORARY CASH INVESTMENTS AT END OF YEAR........................................ $ 132,783 $ 201,151 $ 190,642
--------- --------- ---------
--------- --------- ---------
CASH PAID FOR:
Interest (net of amounts capitalized)................................................... $ 383,440 $ 308,797 $ 304,882
Income taxes............................................................................ -- -- --
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE FINANCIAL STATEMENTS.
F-7
NOTES TO FINANCIAL STATEMENTS
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:
A. BUSINESS DESCRIPTION
Oglethorpe Power Corporation ("Oglethorpe") is an electric generation and
transmission ("G&T") cooperative incorporated in 1974 and headquartered in
suburban Atlanta. Oglethorpe provides wholesale electric service, on a
not-for-profit basis, to 39 of Georgia's 42 Electric Membership Corporations
("EMCs"). These 39 electric distribution cooperatives ("Members") in turn
distribute energy on a retail basis to more than 2.6 million people across
two-thirds of the State. Oglethorpe is the nation's largest G&T in terms of
operating revenues, assets, kilowatt-hour ("kWh") sales and, through its
Members, consumers served.
Oglethorpe supplies energy to the Members from 3,335 megawatts ("MW") of
owned or leased generating capacity and purchases the remainder from other power
suppliers. Oglethorpe also has access to over 16,000 miles of transmission line
through its ownership in the statewide Integrated Transmission System ("ITS").
Oglethorpe and the Members completed on March 11, 1997, a corporate
restructuring ("Corporate Restructuring"). For a discussion of the Corporate
Restructuring, see Note 11.
B. BASIS OF ACCOUNTING
Oglethorpe follows generally accepted accounting principles and the
practices prescribed in the Uniform System of Accounts of the Federal Energy
Regulatory Commission ("FERC") as modified and adopted by the Rural Utilities
Service ("RUS").
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities as of December 31, 1996 and 1995
and the reported amounts of revenues and expenses for each of the three years
ending December 31, 1996. Actual results could differ from those estimates.
C. PATRONAGE CAPITAL AND MEMBERSHIP FEES
Oglethorpe is organized and operates as a cooperative. The Members paid a
total of $195 in membership fees. Patronage capital is the retained net margin
of Oglethorpe. As provided in the bylaws, any excess of revenue over
expenditures from operations is treated as advances of capital by the Members
and is allocated to each of them on the basis of their electricity purchases
from Oglethorpe.
Under Oglethorpe's patronage capital retirements policy, margins are to be
returned to the Members 30 years after the year in which the margins are earned.
Pursuant to such policy, no patronage capital would be returned to the Members
until 2010, at which time the 1979 patronage capital would be returned.
Since Oglethorpe replaced its Consolidated Mortgage and Security Agreement,
dated as of September 1, 1994 (the "RUS Mortgage") with an Indenture, dated
March 1, 1997, from Oglethorpe to SunTrust Bank, Atlanta, as trustee (the
"Mortgage Indenture") in connection with Oglethorpe's Corporate Restructuring,
patronage distributions also will be restricted by the terms of the Mortgage
Indenture.
D. MARGIN POLICY
Under Oglethorpe's prior RUS Mortgage, Oglethorpe's margin policy was based
on the provision of a Times Interest Earned Ratio ("TIER") established annually
by the Oglethorpe Board of Directors.
F-8
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
Pursuant to this policy, the annual net margin goal for 1996, 1995 and 1994 was
the amount required to produce a TIER of 1.07. The RUS Mortgage was replaced
with the Mortgage Indenture in connection with Oglethorpe's Corporate
Restructuring. Under the Mortgage Indenture, Oglethorpe is required to produce a
Margins for Interest ("MFI") Ratio of 1.10.
The Oglethorpe Board of Directors adopted resolutions annually requiring
that Oglethorpe's net margins for the years 1985 through 1995 in excess of its
annual margin goals be deferred and used to mitigate rate increases associated
with the Alvin W. Vogtle Plant ("Plant Vogtle") and the Rocky Mountain Pumped
Storage Hydroelectric Facility ("Rocky Mountain"). In addition, during 1986 and
1987, Oglethorpe's wholesale electric rate to its Members provided for a one
mill per kWh charge ("Vogtle Surcharge"), also to be used to mitigate the effect
of Plant Vogtle on rates.
Pursuant to rate actions by Oglethorpe's Board of Directors, specified
amounts of deferred margins and Vogtle Surcharge were returned in 1989 through
1995 and all remaining amounts were returned in 1996. A summary of deferred
margins and Vogtle Surcharge as of December 31, 1996 and 1995 is as follows:
1996 1995
--------- ---------
(DOLLARS IN
THOUSANDS)
DEFERRED MARGINS
1985-92............................................................ $ 165,552 $ 165,552
1993............................................................... 5,083 5,083
1994............................................................... 9,287 9,287
1995............................................................... 14,282 14,282
--------- ---------
194,204 194,204
VOGTLE SURCHARGE
1986-87............................................................ 36,613 36,613
--------- ---------
Subtotal........................................................... 230,817 230,817
LESS: AMOUNTS RETURNED IN:
1989-93............................................................ (159,388) (159,388)
1994............................................................... (20,103) (20,103)
1995............................................................... (19,279) (19,279)
1996............................................................... (32,047) --
--------- ---------
-- 32,047
LESS: CURRENT PORTION................................................ -- (32,047)
--------- ---------
LONG-TERM BALANCE.................................................... $ -- $ --
--------- ---------
--------- ---------
E. OPERATING REVENUES
Operating revenues consist primarily of electricity sales pursuant to
long-term wholesale power contracts which Oglethorpe maintains with each of its
Members. These wholesale power contracts obligate each Member to pay Oglethorpe
for capacity and energy furnished in accordance with rates established by
Oglethorpe. Energy furnished is determined based on meter readings which are
conducted at the end of each month. Actual energy costs are compared, on a
monthly basis, to the billed energy costs, and an adjustment to revenues is made
such that energy revenues are equal to actual energy costs.
F-9
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
Revenues from Cobb EMC and Jackson EMC, two of Oglethorpe's Members,
accounted for 12.5% and 11.2% in 1996, 11.3% and 10.4% in 1995, and 11.0% and
10.5% in 1994, respectively, of Oglethorpe's total operating revenues.
F. NUCLEAR FUEL COST
The cost of nuclear fuel, including a provision for the disposal of spent
fuel, is being amortized to fuel expense based on usage. The total nuclear fuel
expense for 1996, 1995 and 1994 amounted to $49,298,000, $54,588,000 and
$55,229,000, respectively.
Contracts with the U.S. Department of Energy ("DOE") have been executed to
provide for the permanent disposal of spent nuclear fuel for the life of the
Edwin I. Hatch Plant ("Plant Hatch") and Plant Vogtle. The services to be
provided by DOE were scheduled to begin in 1998. However, the actual year that
these services will begin is uncertain. The Plant Hatch spent fuel storage is
expected to be sufficient into 2003. The Plant Vogtle spent fuel storage is
expected to be sufficient into 2008. Activities for adding dry cast storage
capacity at Plant Hatch by as early as 1999 are in progress.
The Energy Policy Act of 1992 (the "Energy Policy Act") required that
utilities with nuclear plants be assessed over a 15-year period an amount which
will be used by DOE for the decontamination and decommissioning of its nuclear
fuel enrichment facilities. The amount of each utility's assessment was based on
its past purchases of nuclear fuel enrichment services from DOE. Based on its
ownership in Plants Hatch and Vogtle, Oglethorpe has a remaining nuclear fuel
asset of approximately $14,900,000, which is being amortized to nuclear fuel
expenses over the next 11 years. Oglethorpe has also recorded an obligation to
DOE which approximated $11,800,000 at December 31, 1996.
G. NUCLEAR DECOMMISSIONING
Oglethorpe's portion of the costs of decommissioning co-owned nuclear
facilities is estimated as follows:
HATCH HATCH VOGTLE VOGTLE
UNIT NO. 1 UNIT NO. 2 UNIT NO. 1 UNIT NO. 2
----------- ----------- ----------- -----------
(DOLLARS IN THOUSANDS)
Years of site study......................... 1994 1994 1994 1994
Expected start date of decommissioning...... 2014 2018 2027 2029
Decommissioning cost:
Discounted................................ $ 92,000 $ 109,000 $ 82,000 $ 106,000
Undiscounted.............................. 157,000 207,000 198,000 271,000
The decommissioning cost estimates are based on prompt dismantlement and
removal of the plant from service. The actual decommissioning costs may vary
from the above estimates because of changes in the assumed date of
decommissioning, changes in regulatory requirements, changes in technology, and
changes in costs of labor, materials and equipment.
The annual provision for decommissioning for 1996, 1995 and 1994 was
$2,597,000, $4,156,000 and $5,948,000, respectively. In developing the amount of
the annual provision for 1996 and 1997, the escalation rate was assumed to be
2.72% and return on trust assets was assumed to be 8%. Oglethorpe accounts for
this provision for decommissioning as depreciation expense with an offsetting
credit to a decommissioning reserve. Oglethorpe's management is of the opinion
that any changes in cost estimates of decommissioning will be fully recovered in
future rates.
F-10
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
In compliance with a Nuclear Regulatory Commission ("NRC") regulation,
Oglethorpe maintains an external trust fund to provide for a portion of the cost
of decommissioning its nuclear facilities. The NRC regulation requires funding
levels based on average expected cost to decommission only the radioactive
portions of a typical nuclear facility. Oglethorpe's decommissioning reserve
reflects its obligation to decommission both the radioactive and most of the
non-radioactive portions of its nuclear facilities.
Realized investment earnings from the external trust fund, while increasing
the fund and interest income, also are applied to the decommissioning reserve
and charged to interest expense. Interest income earned from the external trust
fund is offset by the recognition of interest expense such that there is no
effect on Oglethorpe's net margin.
H. DEPRECIATION
Depreciation is computed on additions when they are placed in service using
the composite straight-line method. Annual depreciation rates in effect for
1996, 1995 and 1994 were as follows:
1996 1995 1994
------------ ------------ ------------
Steam production................................... 2.13% 2.13% 2.47%
Nuclear production................................. 2.73% 2.78% 2.84%
Hydro production................................... 2.00% 2.00% 2.00%
Other production................................... 3.75% 3.75% 2.42%
Transmission....................................... 2.75% 2.75% 2.75%
Distribution....................................... 2.88% 2.88% 2.88%
General............................................ 2.00-20.00% 2.00-20.00% 2.00-20.00%
I. ELECTRIC PLANT
Electric plant is stated at original cost, which is the cost of the plant
when first dedicated to public service, plus the cost of any subsequent
additions. Cost includes an allowance for the cost of equity and debt funds used
during construction. The cost of equity and debt funds is calculated at the
embedded cost of all such funds. The plant acquisition adjustments represent the
excess of the cost of the plant to Oglethorpe over the original cost, less
accumulated depreciation at the time of acquisition, and are being amortized
over a ten-year period.
Maintenance and repairs of property and replacements and renewals of items
determined to be less than units of property are charged to expense.
Replacements and renewals of items considered to be units of property are
charged to the plant accounts. At the time properties are disposed of, the
original cost, plus cost of removal, less salvage of such property, is charged
to the accumulated provision for depreciation.
J. BOND, RESERVE AND CONSTRUCTION FUNDS:
Bond, reserve and construction funds for pollution control bonds are
maintained as required by Oglethorpe's bond agreements. Bond funds serve as
payment clearing accounts, reserve funds maintain amounts equal to the maximum
annual debt service of each bond issued and construction funds hold bond
proceeds for which construction expenditures have not yet been made. As of
December 31, 1996 and 1995, substantially all of the funds were invested in U.S.
Government securities.
F-11
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
K. CASH AND TEMPORARY CASH INVESTMENTS
Oglethorpe considers all temporary cash investments purchased with a
maturity of three months or less to be cash equivalents. Temporary cash
investments with maturities of more than three months are classified as other
short-term investments.
Of the amount reported as cash and temporary cash investments at December
31, 1996, approximately $65,600,000 is restricted by RUS for the purpose of
prepaying certain Federal Financing Bank ("FFB") long-term debt on or before
March 31, 1997.
L. INVENTORIES
Oglethorpe maintains inventories of fossil fuels for its generation plant
and spare parts for certain of its generation and transmission plant. These
inventories are stated at weighted average cost on the accompanying balance
sheets.
At December 31, 1996 and 1995, fossil fuels inventories were $23,062,000 and
$12,296,000, respectively. Inventories for spare parts at December 31, 1996 and
1995 were $66,763,000 and $70,653,000, respectively.
M. DEFERRED CHARGES
Prior to 1996, Oglethorpe expensed nuclear refueling outage costs as
incurred. In 1996, Oglethorpe began accounting for these costs on a normalized
basis. Under this method of accounting, refueling outage costs are deferred and
subsequently amortized to expense over the 18-month operating cycle of each
unit. Deferred nuclear outage costs at December 31, 1996 were $12,961,000.
As a result of the availability of long-term capacity purchases at similar
costs but with reduced risks to Oglethorpe and its Members, Oglethorpe
determined that the Smarr Combustion Turbine Project was not needed within the
present planning horizon. Therefore, Oglethorpe is amortizing the accumulated
project costs in excess of the current value of the land purchased. The
remaining project costs of $6,445,000 are reflected as deferred charges on the
accompanying balance sheets. In 1995, Oglethorpe's Board of Directors authorized
that these project costs be amortized and fully recovered through future rates
over a period of 15 years beginning in that year.
N. DEFERRED CREDITS
In October 1989, Oglethorpe sold to Georgia Power Company ("GPC") a 24.45%
ownership interest in the Robert W. Scherer Plant ("Plant Scherer") common
facilities as required under the Plant Scherer Purchase and Ownership Agreement
to adjust its ownership in the Scherer units. Oglethorpe realized a gain on the
sale of $50,600,000. RUS and Oglethorpe's Board of Directors approved a plan
whereby this gain was deferred and was amortized over 60 months ending in
September 1994.
In April 1982, Oglethorpe sold to three purchasers certain of the income tax
benefits associated with the Plant Robert W. Scherer Unit No. 1 ("Scherer Unit
No. 1") and related common facilities pursuant to the safe harbor lease
provisions of the Economic Recovery Tax Act of 1981. Oglethorpe received a total
of approximately $110,000,000 from the safe harbor lease transactions.
Oglethorpe accounts for the net benefits as a deferred credit and is amortizing
the amount over the 20-year term of the leases.
In December 1996, Oglethorpe entered into long-term lease transactions for a
portion of its 74.61% undivided ownership interest in Rocky Mountain. The lease
transactions are characterized as a sale and lease-back for income tax purposes,
but not for financial reporting purposes. As a result of these leases,
Oglethorpe recorded a net benefit of $70,701,000 which was deferred and will be
amortized to income
F-12
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
over the 30-year lease-back period. The lease transactions increased
Oglethorpe's Capitalization and Investments and funds by $41,685,000,
respectively (see Note 2 where discussed further).
In January 1997, Oglethorpe completed long-term lease transactions for the
remainder of its interest in Rocky Mountain resulting in a net benefit of
$24,859,000. The net benefit will be deferred and amortized to income over the
30-year term of the leases. Oglethorpe will increase Capitalization and
Investments and funds by $15,810,000, respectively.
O. REGULATORY ASSETS AND LIABILITIES
Oglethorpe is subject to the provisions of Statement of Financial Accounting
Standards ("SFAS") No. 71, "Accounting for the Effects of Certain Types of
Regulation." Regulatory assets represent probable future revenues to Oglethorpe
associated with certain costs which will be recovered from Members through the
rate-making process. Regulatory liabilities represent probable future reduction
in revenues associated with amounts that are to be credited to Members through
the rate-making process. The following regulatory assets and liabilities were
reflected on the accompanying balance sheets as of December 31, 1996 and 1995:
1996 1995
--------- ---------
(DOLLARS IN
THOUSANDS)
Premium and loss on reacquired debt................................... $ 201,007 $ 200,794
Deferred amortization of Scherer leasehold............................ 90,717 87,134
Other regulatory assets............................................... 29,308 33,666
Net benefit of sale of income tax benefits............................ (42,049) (50,194)
Net benefit of Rocky Mountain transactions............................ (70,701) --
Deferred margins...................................................... -- (32,047)
Energy costs.......................................................... -- 4,237
--------- ---------
$ 208,282 $ 243,590
--------- ---------
--------- ---------
In the event that Oglethorpe is no longer subject to the provisions of SFAS
No. 71, Oglethorpe would be required to write off related regulatory assets and
liabilities. In addition, Oglethorpe would be required to determine any
impairment to other assets, including plant, and write down the assets, if
impaired, to their fair value.
P. PRESENTATION
Certain prior year amounts have been reclassified to conform with current
year presentation.
F-13
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
2. FAIR VALUE OF FINANCIAL INSTRUMENTS:
A detail of the estimated fair values of Oglethorpe's financial instruments
as of December 31, 1996 and 1995 is as follows:
DECEMBER 31, 1996 DECEMBER 31, 1995
---------------------- ----------------------
FAIR FAIR
COST VALUE COST VALUE
---------- ---------- ---------- ----------
(DOLLARS IN THOUSANDS)
CASH AND TEMPORARY CASH INVESTMENTS:
Commercial paper.............................................................. $ 52,700 $ 52,700 $ 179,055 $ 179,055
Certificates of deposit....................................................... 10,000 10,000 20,000 20,000
Cash and money market securities.............................................. 70,083 70,083 2,096 2,096
---------- ---------- ---------- ----------
TOTAL........................................................................... $ 132,783 $ 132,783 $ 201,151 $ 201,151
---------- ---------- ---------- ----------
---------- ---------- ---------- ----------
OTHER SHORT TERM INVESTMENTS:
Commingled investment fund.................................................... $ 91,712 $ 91,499 $ 76,180 $ 79,165
---------- ---------- ---------- ----------
TOTAL........................................................................... $ 91,712 $ 91,499 $ 76,180 $ 79,165
---------- ---------- ---------- ----------
---------- ---------- ---------- ----------
BOND, RESERVE AND CONSTRUCTION FUNDS:
U.S. Government securities.................................................... $ 36,505 $ 35,873 $ 49,348 $ 49,932
Repurchase agreements......................................................... 18,082 18,082 6,579 6,579
---------- ---------- ---------- ----------
TOTAL........................................................................... $ 54,587 $ 53,955 $ 55,927 $ 56,511
---------- ---------- ---------- ----------
---------- ---------- ---------- ----------
DECOMMISSIONING FUND:
U.S. Government securities.................................................... $ 24,034 $ 23,950 $ 23,087 $ 23,568
Foreign government securities................................................. 1,228 1,278 -- --
Commercial paper.............................................................. -- -- 4,036 4,036
Corporate bonds............................................................... 11,953 11,868 5,875 6,073
Equity securities............................................................. 30,339 34,073 19,514 21,271
Asset-backed securities....................................................... 3,103 3,125 12,484 12,614
Other bonds................................................................... 5,445 5,453 -- --
Cash and money market securities.............................................. 6,522 6,522 6,937 6,930
---------- ---------- ---------- ----------
TOTAL........................................................................... $ 82,624 $ 86,269 $ 71,933 $ 74,492
---------- ---------- ---------- ----------
---------- ---------- ---------- ----------
LONG-TERM DEBT.................................................................. $4,118,117 $4,228,317 $4,207,320 $4,506,925
---------- ---------- ---------- ----------
---------- ---------- ---------- ----------
INTEREST RATE SWAP.............................................................. $ -- $ 33,938 $ -- $ 52,089
---------- ---------- ---------- ----------
---------- ---------- ---------- ----------
F-14
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
The contractual maturities of debt securities available for sale at December
31, 1996 and 1995, regardless of their balance sheet classification, are as
follows:
DECEMBER 31, DECEMBER 31,
1996 1995
---------------- ----------------
FAIR FAIR
COST VALUE COST VALUE
------- ------- ------- -------
(DOLLARS IN THOUSANDS)
Due within one year....................................................................... $33,944 $33,819 $21,050 $21,300
Due after one year through five years..................................................... 17,439 17,266 37,172 37,452
Due after five years through ten years.................................................... 27,912 27,302 27,628 27,966
Due after ten years....................................................................... 15,610 15,789 11,523 12,049
------- ------- ------- -------
$94,905 $94,176 $97,373 $98,767
------- ------- ------- -------
------- ------- ------- -------
Oglethorpe used the methods and assumptions described below to estimate the
fair value of each class of financial instruments. For cash and temporary cash
investments, the carrying amount approximates fair value because of the
short-term maturity of those instruments. The fair value of Oglethorpe's
long-term debt and the swap arrangements is estimated based on the quoted market
prices for the same or similar issues or on the current rates offered to
Oglethorpe for debt of similar maturities.
Under the interest rate swap arrangements, Oglethorpe makes payments to the
counterparty based on the notional principal at a contractually fixed rate and
the counterparty makes payments to Oglethorpe based on the notional principal at
the existing variable rate of the refunding bonds. The differential to be paid
or received is accrued as interest rates change and is recognized as an
adjustment to interest expense. Oglethorpe entered into the swap arrangements
for the purpose of securing a fixed rate lower than otherwise would have been
available to Oglethorpe had it issued fixed rate bonds. For the Series 1993A
notes, the notional principal was $199,690,000 and the fixed swap rate is 5.67%
(the variable rate at December 31, 1996 and 1995 was 4.00% and 5.15%,
respectively). With respect to the Series 1994A notes, the notional principal
was $122,740,000 and the fixed swap rate is 6.01% (the variable rate at December
31, 1996 and 1995 was 4.00% and 5.05%, respectively). The notional principal
amount is used to measure the amount of the swap payments and does not represent
additional principal due to the counterparty. The swap arrangements extend for
the life of the refunding bonds, with reductions in the outstanding principal
amounts of the refunding bonds causing corresponding reductions in the notional
amounts of the swap payments. The estimated fair value of Oglethorpe's liability
under the swap arrangements at December 31, 1996 and 1995 was $33,938,000 and
$52,089,000, respectively. This amount represents payment Oglethorpe would pay
if the swap arrangements were terminated. Oglethorpe may be exposed to losses in
the event of nonperformance of the counterparty, but does not anticipate such
nonperformance.
Oglethorpe adopted SFAS No. 115, "Accounting for Certain Investments in Debt
and Equity Securities," as of January 1, 1994. Under this SFAS, investment
securities held by Oglethorpe are classified as either available-for-sale or
held-to-maturity. Available-for-sale securities are carried at market value with
unrealized gains and losses, net of any tax effect, added to or deducted from
patronage capital. Unrealized gains and losses from investment securities held
in the decommissioning fund, which are also classified as available-for-sale,
are directly added to or deducted from the decommissioning reserve.
Held-to-maturity securities are carried at cost. All realized and unrealized
gains and losses are determined using the specific identification method. Gross
unrealized gains and losses at December 31, 1996 were $7,785,000 and $4,985,000,
respectively. Gross unrealized gains and losses at December 31,
F-15
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
1995 were $6,497,000 and $368,000, respectively. For 1996 and 1995, proceeds
from sales of available-for-sale securities totaled $425,772,000 and
$438,643,000, respectively. Gross realized gains and losses from the 1996 sales
were $6,410,000 and $3,671,000 respectively. Gross realized gains and losses
from the 1995 sales were $5,098,000 and $1,308,000, respectively.
Investments in associated organizations were as follows at December 31, 1996
and 1995:
DECEMBER 31, DECEMBER 31,
1996 1995
------------ ------------
(DOLLARS IN THOUSANDS)
National Rural Utilities Cooperative Finance Corp. ("CFC").......................................... $13,476 $13,476
CoBank, ACB......................................................................................... 1,664 2,132
Other............................................................................................... 239 245
------------ ------------
Total............................................................................................. $15,379 $15,853
------------ ------------
------------ ------------
The investments in these associated organizations are similar to
compensating bank balances in that they are required in order to maintain
current financing arrangements. Accordingly, there is no market for these
investments.
The $41,685,000 deposit on the Rocky Mountain transactions (see Note 1 where
discussed) as of December 31, 1996 is invested in a guaranteed investment
contract which will be held to maturity (the end of the 30-year lease-back
period). At maturity, Oglethorpe fully intends to use the deposit to repurchase
tax ownership and to retain all other rights of ownership with respect to the
plant. The deposit is carried at cost.
In addition, from the proceeds of the Rocky Mountain transactions,
Oglethorpe paid $460,769,000 to a financial institution. In return, this
financial institution undertook to pay a portion of Oglethorpe's lease
obligations. Both Oglethorpe's interest in this payment undertaking agreement
and the corresponding lease obligations have been extinguished for financial
reporting purposes.
3. INCOME TAXES
Oglethorpe is a not-for-profit membership corporation subject to Federal and
state income taxes. As a taxable electric cooperative, Oglethorpe has annually
allocated its income and deductions between Member and non-Member activities.
Any Member taxable income has been offset with a patronage exclusion and member
loss carryforwards.
Oglethorpe accounts for its income taxes pursuant to SFAS No. 109. SFAS No.
109 requires the recognition of deferred tax assets and liabilities for the
expected future tax consequences of events that have been included in the
financial statements or tax returns.
F-16
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
A detail of the provision for income taxes in 1996, 1995 and 1994 is shown
as follows:
1996 1995 1994
------- ----- -----
(DOLLARS IN
THOUSANDS)
Current
Federal........................................................................................... $ 3,525 $-- $--
State............................................................................................. -- -- --
------- ----- -----
3,525 -- --
------- ----- -----
Deferred
Federal........................................................................................... (3,525) $-- $--
State............................................................................................. -- -- --
------- ----- -----
(3,525) -- --
------- ----- -----
Income taxes charged to operations.................................................................. $ -- $-- $--
------- ----- -----
------- ----- -----
The difference between the statutory federal income tax rate on income
before income taxes and Oglethorpe's effective income tax rate is summarized as
follows:
1996 1995 1994
------ ------ ------
Statutory federal income tax rate................................................................... 35.0% 35.0% 35.0%
Patronage exclusion................................................................................. (35.7)% (35.6)% (35.4)%
Other............................................................................................... 0.7% 0.6% 0.4%
------ ------ ------
Effective income tax rate........................................................................... 0.0% 0.0% 0.0%
------ ------ ------
------ ------ ------
F-17
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
The components of the net deferred tax liabilities as of December 31, 1996
and 1995 were as follows:
1996 1995
----------- -----------
(DOLLARS IN THOUSANDS)
DEFERRED TAX ASSETS
Net operating losses.............................................................................. $ 473,114 $ 538,067
Member loss carryforwards......................................................................... 328,912 342,370
Tax credits (alternative minimum tax and other)................................................... 256,205 252,680
Accounting for Rocky Mountain transactions........................................................ 233,045 --
Accounting for sale of income tax benefits........................................................ 77,429 86,599
Accrued nuclear decommissioning expense........................................................... 49,127 45,042
Accounting for asset dispositions................................................................. 32,545 33,496
Other............................................................................................. 3,318 18,277
----------- -----------
1,453,695 1,316,531
Less: Valuation allowance......................................................................... (252,680) (252,680)
----------- -----------
1,201,015 1,063,851
----------- -----------
DEFERRED TAX LIABILITIES
Depreciation...................................................................................... (1,008,714) (1,034,153)
Accounting for Rocky Mountain transactions........................................................ (156,557) --
Accounting for debt extinguishment................................................................ (64,841) (64,006)
Other............................................................................................. (32,888) (31,202)
----------- -----------
(1,263,000) (1,129,361)
----------- -----------
NET DEFERRED TAX LIABILITIES........................................................................ $ (61,985) $ (65,510)
----------- -----------
----------- -----------
F-18
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
As of December 31, 1996, Oglethorpe has federal tax net operating loss
carryforwards ("NOLs"), alternative minimum tax credits ("AMT") and unused
general business credits (consisting primarily of investment tax credits) as
follows:
ALTERNATIVE
MINIMUM
EXPIRATION DATE TAX CREDITS TAX CREDITS NOLS
- ------------------------------------------------------------------------------------------ ----------- ----------- ----------
(DOLLARS IN THOUSANDS)
1997...................................................................................... $-- $ 11,197 $ --
1998...................................................................................... -- 6,934 --
1999...................................................................................... -- 37,206 --
2000...................................................................................... -- 3,198 --
2001...................................................................................... -- 7,264 --
2002...................................................................................... -- 130,377 --
2003...................................................................................... -- 652 242,187
2004...................................................................................... -- 55,663 114,285
2005...................................................................................... -- 189 213,080
2006...................................................................................... -- -- 209,009
2007...................................................................................... -- -- 86,779
2008...................................................................................... -- -- 94,927
2009...................................................................................... -- -- 96,394
2010...................................................................................... -- -- 77,970
None...................................................................................... 3,525 -- --
----------- ----------- ----------
$3,525 $252,680 $1,134,631
----------- ----------- ----------
----------- ----------- ----------
Based on Oglethorpe's historical taxable transactions, the timing of the
reversal of existing temporary differences, future income, and tax planning
strategies, it is more likely than not that Oglethorpe's future taxable income
will be sufficient to realize the benefit of NOLs before their respective
expiration dates. The NOLs expiration dates start in the year 2003 and end in
the year 2010. However, as reflected in the above valuation allowance, it is
more likely than not that the tax credits will not be utilized before
expiration. It is more likely than not that the AMT credit will be utilized.
F-19
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
4. CAPITAL LEASES:
In December 1985, Oglethorpe sold and subsequently leased back from four
purchasers its 60% undivided ownership interest in the Plant Robert W. Scherer
Unit No. 2 ("Scherer Unit No. 2"). The gain from the sale is being amortized
over the 36-year term of the leases. The minimum lease payments under the
capital leases together with the present value of net minimum lease payments as
of December 31, 1996 are as follows:
YEAR ENDING DECEMBER 31, (DOLLARS IN THOUSANDS)
- --------------------------------------------------------------------
1997.............................................................. $ 36,531
1998.............................................................. 37,302
1999.............................................................. 37,890
2000.............................................................. 37,755
2001.............................................................. 37,629
2002-2021......................................................... 569,179
----------
Total minimum lease payments...................................... 756,286
Less: Amount representing interest................................ (458,517)
----------
Present value of net minimum lease payments....................... 297,769
Less: Current portion............................................. (4,087)
----------
Long-term balance................................................. $ 293,682
----------
----------
The capital leases provide that Oglethorpe's rental payments vary to the
extent of interest rate changes associated with the debt used by the lessors to
finance their purchase of undivided ownership shares in Scherer Unit No. 2. The
debt of three of the lessors is financed at fixed interest rates averaging
9.70%. As of December 31, 1996, the variable interest rates of the debt of the
remaining lessor ranged from 6.40% to 8.05% for an average rate of 6.83%.
Oglethorpe's future rental payments under its leases will vary from amounts
shown in the table above to the extent that the actual interest rates associated
with the fixed and variable rate debt of the lessors varies from the 11.05% debt
rate assumed in the table.
The Scherer Unit No. 2 lease meets the definitional criteria to be reported
on Oglethorpe's balance sheets as a capital lease. For rate-making purposes,
however, Oglethorpe treats this lease as an operating lease; that is, Oglethorpe
considers the actual rental payment on the leased asset in its cost of service.
Oglethorpe's accounting treatment for this capital lease has been modified,
therefore, to reflect its rate-making treatment. Interest expense is applied to
the obligation under the capital lease; then, amortization of the leasehold is
recognized, such that interest and amortization equal the actual rental payment.
Through 1994, the level of actual rental payments was such that amortization of
the Scherer Unit No. 2 leasehold calculated in this manner was less than zero.
Thereafter, the scheduled cash rental payments increase such that positive
amortization of the leasehold occurs and the entire cost of the leased asset is
recovered through the rate-making process. The difference in the amortization
recognized in this manner on the statements of revenues and expenses and the
straight-line amortization of the leasehold is reflected on Oglethorpe's balance
sheets as a deferred charge.
In 1991 and 1992, all four of the lessors received Notices of Proposed
Adjustments from the Internal Revenue Service ("IRS") proposing adjustments to
the tax benefits claimed by these lessors in connection with their purchase and
ownership of an undivided interest in Scherer Unit No. 2. In 1994, the IRS
issued a revised Notice of Proposed Adjustments to one of the lessors which
reduced the proposed adjustments. During 1995, this lessor advised Oglethorpe
that it had settled this issue on the basis of the
F-20
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
revised Notice of Proposed Adjustments. Oglethorpe subsequently made a lump sum
indemnity payment of $362,000 to the lessor in order to compensate for the
reduction in the lessor's tax benefits resulting from the sale and leaseback
transaction. The IRS has indicated that it will take consistent positions with
the other three lessors. If the IRS's current positions regarding the sale and
leaseback transactions were ultimately upheld, Oglethorpe would be required to
indemnify the other three lessors. Oglethorpe's indemnification liability to the
three lessors is estimated to be approximately $1,290,000 as of December 31,
1996. This liability has been reflected on the accompanying balance sheet.
5. LONG-TERM DEBT:
Long-term debt consists of mortgage notes payable to the United States of
America acting through the FFB and the RUS, mortgage notes issued in conjunction
with the sale by public authorities of pollution control revenue bonds, and
notes payable to CoBank, ACB ("CoBank"). Oglethorpe's headquarters facility is
pledged as collateral for the CoBank headquarters note; substantially all of the
owned tangible and certain of the intangible assets of Oglethorpe are pledged as
collateral for the FFB and RUS notes, the remaining CoBank notes and the notes
issued in conjunction with the sale of pollution control revenue bonds. The
detail of the notes is included in the statements of capitalization.
Oglethorpe currently has ten RUS-guaranteed FFB notes of which
$3,172,851,000 and $3,253,636,000 were outstanding at December 31, 1996 and
1995, respectively, with rates ranging from 5.27% to 9.51%.
In January 1996, Oglethorpe completed note modifications pursuant to which
it repriced $89,447,000 of FFB advances. In connection with such modification,
Oglethorpe paid a premium of $9,332,000. These amounts are reported as deferred
charges on the balance sheet, and will be amortized over 22 years, the longest
remaining life of the subject advances.
In October 1996, Oglethorpe completed a current refunding transaction
whereby $37,885,000 of fixed rate pollution control revenue bonds were issued.
The proceeds of this transaction were used to retire $37,885,000 of existing
bonds. The unamortized transaction costs related to this transaction have been
reported as a deferred charge on the balance sheet and are being amortized over
the life of the related bonds.
The annual interest requirement for 1997 is estimated to be $294,000,000.
Maturities for the long-term debt through 2001 are as follows:
1997 1998 1999 2000 2001
--------- --------- --------- --------- ---------
(DOLLARS IN THOUSANDS)
FFB and RUS............................ $ 147,279 $ 86,894 $ 91,123 $ 98,867 $ 105,941
CoBank................................. 376 502 516 532 550
PCB Bonds.............................. 7,880 17,970 19,730 23,995 26,260
Capital Leases......................... 4,087 5,143 6,240 7,075 7,775
--------- --------- --------- --------- ---------
Total.................................. $ 159,622 $ 110,509 $ 117,609 $ 130,469 $ 140,526
--------- --------- --------- --------- ---------
--------- --------- --------- --------- ---------
The estimated annual interest expense and the long-term debt maturities
described above do not take into account Oglethorpe's proposed Corporate
Restructuring, discussed in Note 11.
Oglethorpe has a commercial paper program under which it may issue
commercial paper not to exceed a $250,000,000 balance outstanding at any time.
The commercial paper may be used for
F-21
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
working capital requirements and for general corporate purposes. Oglethorpe's
commercial paper is backed 100% by committed lines of credit provided by a group
of banks.
As of December 31, 1996 and 1995, no commercial paper was outstanding.
Oglethorpe has a $50,000,000 uncommitted short-term line of credit with CFC
and a $30,000,000 committed line of credit with SunTrust Bank, Atlanta
("SunTrust"). The maximum combined amount that can be outstanding under these
lines of credit and the commercial paper program at any one time totals
$250,000,000 due to certain restrictions contained in the CFC and SunTrust line
of credit agreements. No balance was outstanding on either of these two lines of
credit at either December 31, 1996 or 1995.
6. ELECTRIC PLANT AND RELATED AGREEMENTS:
Oglethorpe and GPC have entered into agreements providing for the purchase
and subsequent joint operation of certain of GPC's electric generating plants
and transmission facilities. A summary of Oglethorpe's plant investments and
related accumulated depreciation as of December 31, 1996 is as follows:
ACCUMULATED
PLANT INVESTMENT DEPRECIATION
- ---------------------------------------------------------------- ----------- -------------
(DOLLARS IN THOUSANDS)
In-service
Owned property
Vogtle Units No. 1 & No. 2
(NUCLEAR--30% OWNERSHIP).................................. $2,781,446 $ 665,953
Hatch Units No. 1 & No. 2
(NUCLEAR--30% OWNERSHIP).................................. 523,163 208,687
Wansley Units No. 1 & No. 2
(FOSSIL--30% OWNERSHIP)................................... 173,192 84,388
Scherer Unit No. 1
(FOSSIL--60% OWNERSHIP)................................... 429,299 193,129
Rocky Mountain Units No. 1, No. 2 & No. 3
(HYDRO--74.6% OWNERSHIP).................................. 556,470 17,401
Tallassee (Harrison Dam)
(HYDRO--100% OWNERSHIP)................................... 9,270 1,797
Wansley (COMBUSTION TURBINE--30% OWNERSHIP)................. 3,718 1,319
Generation step-up substations.............................. 55,877 19,173
Transmission and distribution plant......................... 815,929 179,960
Other....................................................... 94,002 25,060
Property under capital lease
Scherer Unit No. 2
(FOSSIL--60% LEASEHOLD)................................... 300,231 91,405
----------- -------------
Total in-service................................................ $5,742,597 $ 1,488,272
----------- -------------
----------- -------------
Construction work in progress
Generation improvements....................................... $ 11,963
Transmission and distribution plant........................... 18,715
Other......................................................... 503
-----------
Total construction work in progress............................. $ 31,181
-----------
-----------
F-22
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
In 1988, Oglethorpe acquired from GPC an undivided ownership interest in
Rocky Mountain. Under the Rocky Mountain agreements, Oglethorpe assumed
responsibility for construction of the facility, which was commenced by GPC.
Under the agreements, GPC retained its current investment in Rocky Mountain with
the ultimate ownership interests of Oglethorpe and GPC in the facility based on
the ratio of each party's direct construction costs to total project direct
construction costs with certain adjustments.
On June 1, 1995, Unit 3 and the completed Unit Common facilities were
declared to be in commercial operation by Oglethorpe. Unit 2 and Unit 1 were
declared to be in commercial operation on June 19, 1995 and July 24, 1995,
respectively. In accordance with the Rocky Mountain agreements, the final
ownership interests of Oglethorpe and GPC in Rocky Mountain is 74.6% and 25.4%,
respectively. The final ownership interests in the project will be applied to
all future capital costs.
Oglethorpe is engaged in a continuous construction program and, as of
December 31, 1996, estimates property additions (including capitalized interest)
to be approximately $108,000,000 in 1997, $98,000,000 in 1998 and $100,000,000
in 1999, primarily for replacements and additions to generation and transmission
facilities.
Oglethorpe's proportionate share of direct expenses of joint operation of
the above plants is included in the corresponding operating expense captions
(e.g., fuel, production or depreciation) on the accompanying statements of
revenues and expenses.
7. EMPLOYEE BENEFIT PLANS:
Oglethorpe has a noncontributory defined benefit pension plan covering
substantially all employees. Oglethorpe's pension cost was approximately
$1,388,000 in 1996, $1,954,000 in 1995 and $1,262,000 in 1994. For 1995, pension
cost increased by $912,000 related to termination benefits. The termination
benefits resulted from an early retirement program undertaken in the fourth
quarter of 1995. Plan benefits are based on years of service and the employee's
compensation during the last ten years of employment. Oglethorpe's funding
policy is to contribute annually an amount not less than the minimum required by
the Internal Revenue Code and not more than the maximum tax deductible amount.
The plan's pension cost recognized in 1996, 1995 and 1994 was shown as
follows:
1996 1995 1994
--------- --------- ---------
(DOLLARS IN THOUSANDS)
Pension cost was comprised of the following
Service cost -- benefits earned during the year................. $ 1,149 $ 913 $ 1,084
Interest cost on projected benefit obligation................... 872 742 714
Actual return on plan assets.................................... (984) (1,889) 387
Net amortization and deferral................................... 351 1,288 (911)
Net gain from a plan curtailment................................ -- (12) (12)
--------- --------- ---------
Net pension cost.................................................. $ 1,388 $ 1,042 $ 1,262
--------- --------- ---------
--------- --------- ---------
F-23
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
The plan's funded status in Oglethorpe's financial statements as of December
31, 1996 and 1995 were as follows:
1996 1995
--------- ---------
(DOLLARS IN
THOUSANDS)
Actuarial present value of accumulated plan benefits:
Vested............................................................... $ 7,554 $ 6,868
Nonvested............................................................ 540 591
--------- ---------
$ 8,094 $ 7,459
--------- ---------
--------- ---------
Projected benefit obligation........................................... $ (13,211) $ (12,326)
Plan assets at fair value............................................ 9,218 7,760
--------- ---------
Projected benefit obligation in excess of plan assets.................. (3,993) (4,566)
Unrecognized net loss (gain) from past experience different from that
assumed and effects of changes in assumptions........................ (880) 223
Prior service cost not yet recognized in net periodic pension cost..... 498 548
Unrecognized net asset at transition date being recognized over 19
years................................................................ (109) (121)
--------- ---------
Pension accrual........................................................ $ (4,484) $ (3,916)
--------- ---------
--------- ---------
The discount rate and rate of increase in future compensation levels used in
determining the actuarial present value of the projected benefit obligations
shown above were 7.50% and 5.0% in 1996, and 7.25% and 5.0% in 1995,
respectively. The expected long-term rate of return on plan assets was 8.5% in
1996 and 1995, and 8% in 1994, and the discount rate used in determining the
pension expense was 7.25% in 1996, 8.5% in 1995 and 7.5% in 1994.
Oglethorpe has a contributory employee retirement savings plan covering
substantially all employees. Employee contributions to the plan may be invested
in one or more of nine funds. The employee may contribute, subject to IRS
limitations, up to 16% of his annual compensation. Oglethorpe will match the
employee's contribution up to one-half of the first 6% of the employee's annual
compensation, as long as there is sufficient net margin to do so. Oglethorpe's
contributions to the plan were approximately $561,000 in 1996, $589,000 in 1995
and $565,000 in 1994.
8. NUCLEAR INSURANCE:
GPC, on behalf of all the co-owners of Plants Hatch and Vogtle, is a member
of Nuclear Mutual Limited ("NML"), a mutual insurer established to provide
property damage insurance coverage in an amount up to $500,000,000 for members'
nuclear generating facilities. In the event that losses exceed accumulated
reserve funds, the members are subject to retroactive assessments (in proportion
to their participation in the mutual insurer). The portion of the current
maximum annual assessment for GPC that would be payable by Oglethorpe, based on
ownership share, is limited to approximately $6,351,000 for each nuclear
incident.
GPC, on behalf of all the co-owners of Plants Hatch and Vogtle, is also a
member of Nuclear Electric Insurance Limited ("NEIL"), a mutual insurer, and
Oglethorpe has coverage under NEIL II, which provides insurance to cover
decontamination, debris removal and premature decommissioning as well as excess
property damage to nuclear generating facilities for an additional
$2,250,000,000 for losses in excess of the $500,000,000 NML coverage described
above. Under the NEIL policies, members are
F-24
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
subject to retroactive assessments in proportion to their participation if
losses exceed the accumulated funds available to the insurer under the policy.
The portion of the current maximum annual assessment for GPC that would be
payable by Oglethorpe, based on ownership share, is limited to approximately
$12,960,000.
For all on-site property damage insurance policies for commercial nuclear
power plants, the NRC requires that the proceeds of such policies issued or
annually renewed on or after April 2, 1991 shall be dedicated first for the sole
purpose of placing the reactor in a safe and stable condition after an accident.
Any remaining proceeds are next to be applied toward the costs of
decontamination and debris removal operations ordered by the NRC, and any
further remaining proceeds are to be paid either to the company or to its bond
trustees as may be appropriate under the policies and applicable trust
indentures.
The Price-Anderson Act, as amended in 1988, limits public liability claims
that could arise from a single nuclear incident to $8,900,000,000, which amount
is to be covered by private insurance and agreements of indemnity with the NRC.
Such private insurance (in the amount of $200,000,000 for each plant, the
maximum amount currently available) is carried by GPC for the benefit of all the
co-owners of Plants Hatch and Vogtle. Agreements of indemnity have been entered
into by and between each of the co-owners and the NRC. In the event of a nuclear
incident involving any commercial nuclear facility in the country involving
total public liability in excess of $200,000,000, a licensee of a nuclear power
plant could be assessed a deferred premium of up to $79,275,000 per incident for
each licensed reactor operated by it, but not more than $10,000,000 per reactor
per incident to be paid in a calendar year. On the basis of its sell-back
adjusted ownership interest in four nuclear reactors, Oglethorpe could be
assessed a maximum of $95,130,000 per incident, but not more than $12,000,000 in
any one year.
Oglethorpe participates in an insurance program for nuclear workers that
provides coverage for worker tort claims filed for bodily injury caused at
commercial nuclear power plants. In the event that claims for this insurance
exceed the accumulated reserve funds, Oglethorpe could be subject to a total
maximum assessment of $3,365,000.
All retrospective assessments, whether generated for liability or property,
may be subject to applicable state premium taxes.
9. POWER PURCHASE AND SALE AGREEMENTS:
Oglethorpe has entered into long-term power purchase agreements with GPC,
Big Rivers Electric Corporation ("Big Rivers"), and Entergy Power, Inc. ("EPI").
Under the agreement with GPC, Oglethorpe purchased on a take-or-pay basis 1,250
MW of capacity through the period ending August 31, 1996. Effective September 1,
1996, Oglethorpe will purchase 1,000 MW of capacity through the period ending
August 31, 1997. Effective September 1, 1997, Oglethorpe will purchase 750 MW of
capacity through the period ending August 31, 1998. Effective September 1, 1998,
Oglethorpe will purchase 500 MW of capacity through the period ending December
31, 2004, subject to reductions or extension with proper notice. The Big Rivers
agreement commenced in August 1992 and is effective through July 2002.
Oglethorpe is obligated under this agreement to purchase on a take-or-pay basis
100 MW of firm capacity and certain minimum energy amounts associated with that
capacity. The EPI agreement commenced in July 1992, has a term of ten years and
represents a take-or-pay commitment by Oglethorpe to purchase 100 MW of
capacity.
Oglethorpe has a contract with Hartwell Energy Limited Partnership for the
purchase of approximately 300 MW of capacity for a 25-year period commencing in
April 1994.
F-25
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
Oglethorpe has entered into a short-term seasonal power purchase agreement
with Florida Power Corporation. Under the agreement, Oglethorpe will purchase 50
MW of capacity on a take-or-pay basis for the period June 1, 1997 through
September 30, 1997 and 275 MW for the period June 1, 1998 through September 30,
1998.
As of December 31, 1996, Oglethorpe's minimum purchase commitments under the
above agreements, without regard to capacity reductions or adjustments for
changes in costs, for the next five years are as follows:
YEAR ENDING DECEMBER 31, (DOLLARS IN THOUSANDS)
- ---------------------------------------------------- ----------------------
1997........................................ $ 130,457
1998........................................ 111,539
1999........................................ 92,873
2000........................................ 94,917
2001........................................ 97,116
Oglethorpe's power purchases from these agreements amounted to approximately
$190,760,000 in 1996, $206,641,000 in 1995 and $182,965,000 in 1994.
Oglethorpe has entered into an agreement with Alabama Electric Cooperative
to sell 100 MW of capacity for the period June 1998 through December 2005.
As a means of reducing the cost of power provided to the Members, in 1996,
Oglethorpe utilized short-term power supply agreements. The initial agreement
was with Enron Power Marketing, Inc. and was in place from January 4, 1996
through August 31, 1996. From September 1, 1996 through December 31, 1996,
Oglethorpe utilized a short-term power supply transaction with Duke/Louis
Dreyfus L.L.C. Under both of the agreements, the power marketer was required to
provide to Oglethorpe at a favorable fixed rate all the energy necessary to meet
the Members' requirements and Oglethorpe was required to provide to the power
marketer at cost, subject to certain limitations, upon request all energy
available from Oglethorpe's total power resources. Under both agreements,
Oglethorpe continued to operate the power supply system and continued to
dispatch the generating resources to ensure system reliability.
10. QUARTERLY FINANCIAL DATA (UNAUDITED):
Summarized quarterly financial information for 1996 and 1995 is as follows:
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
-------- -------- -------- --------
(DOLLARS IN THOUSANDS)
1996
Operating revenues...................................................................... $270,689 $275,228 $286,648 $268,872
Operating margin........................................................................ 73,568 72,514 75,009 61,658
Net margin.............................................................................. 8,988 4,732 12,508 (4,476)
1995
Operating revenues...................................................................... $257,547 $281,228 $317,536 $293,250
Operating margin........................................................................ 68,682 82,048 82,949 74,998
Net margin.............................................................................. 8,462 20,292 10,656 (17,152)
F-26
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(AMOUNTS AND DISCLOSURES FOR THE YEARS ENDED TO DECEMBER 31, 1996, 1995 AND
1994)
Oglethorpe's business is influenced by seasonal weather conditions. Second
quarter 1996 net margin was lower than the same period of 1995 primarily as a
result of unbudgeted savings in 1995 from the continued capitalization of costs
of Rocky Mountain due to delay in commercial operation of the initial unit from
April 1995 to June 1995.
The negative net margin for the fourth quarter of 1996 is consistent with
expectations and reflects incurrence of certain nonrecurring expenses.
The negative net margin for the fourth quarter of 1995 was primarily
attributable to the deferral of excess margin. For a discussion of the amount of
excess margin deferred, see Note 1.
11. SUBSEQUENT EVENTS:
A. POWER SUPPLY ARRANGEMENTS
Oglethorpe has entered into power supply agreements for approximately 50% of
its Members' load requirements with LG&E Power Marketing Inc. These agreements
commenced on January 1, 1997, initially on a short-term basis. These agreements
converted to a long-term arrangement upon the closing of the corporate
Restructuring discussed below. Oglethorpe is now working to complete a long-term
contract for the remaining approximately 50% of its load.
B. CORPORATE RESTRUCTURING
Oglethorpe and the Members completed on March 11, 1997, the Corporate
Restructuring, in which Oglethorpe was divided into three specialized operating
companies to respond to increasing competition and regulatory changes in the
electric industry. As part of the Corporate Restructuring, Oglethorpe's
transmission business was sold to and is now owned and operated by Georgia
Transmission Corporation (An Electric Membership Corporation) ("GTC"), a
recently formed Georgia electric membership corporation. Oglethorpe's system
operations business was sold to and is now owned and operated by Georgia System
Operations Corporation ("GSOC"), a recently formed Georgia nonprofit
corporation. Oglethorpe continues to own and operate its power supply business.
F-27
INDEPENDENT ACCOUNTANTS' REVIEW REPORT
To the Board of Directors of
Oglethorpe Power Corporation:
We have reviewed the accompanying condensed balance sheet of Oglethorpe
Power Corporation (a Georgia Corporation) as of September 30, 1997, and the
related unaudited condensed statements of revenues and expenses and cash flows
for the twelve-month period then ended. These financial statements are the
responsibility of the company's management.
We conducted our review in accordance with standards established by the
American Institute of Certified Public Accountants. A review of interim
financial information consists principally of applying analytical procedures to
financial data and making inquiries of persons responsible for financial and
accounting matters. It is substantially less in scope than an audit conducted in
accordance with generally accepted auditing standards, the objective of which is
the expression of an opinion regarding the financial statements taken as a
whole. Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material modifications that
should be made to the condensed financial statements referred to above for them
to be in conformity with generally accepted accounting principles.
Coopers & Lybrand L.L.P.
Atlanta, Georgia
November 14, 1997.
F-28
CONDENSED STATEMENTS OF REVENUES AND EXPENSES
TWELVE MONTHS ENDED FOR THE YEAR ENDED
SEPTEMBER 30, DECEMBER 31,
1997 1996
--------------------- -------------------
(UNAUDITED)
(DOLLARS IN THOUSANDS)
OPERATING REVENUES:
Sales to Members............................. $ 1,019,430 $ 1,023,094
Sales to non-Members......................... 50,383 78,343
----------- -------------------
TOTAL OPERATING REVENUES................. 1,069,813 1,101,437
----------- -------------------
OPERATING EXPENSES:
Fuel......................................... 200,858 206,524
Production................................... 139,645 129,178
Purchased power (Note 6)..................... 254,996 229,089
Power delivery............................... 10,210 18,216
Depreciation and amortization................ 149,891 163,130
Taxes other than income taxes................ 27,309 30,262
Other operating expenses..................... 29,253 42,289
----------- -------------------
TOTAL OPERATING EXPENSES................. 812,162 818,688
----------- -------------------
OPERATING MARGIN............................... 257,651 282,749
----------- -------------------
OTHER INCOME (EXPENSE):
Interest income.............................. 27,049 23,485
Amortization of net benefit of sale of income
tax benefits............................... 10,427 8,054
Amortization of deferred margins............. 7,927 32,047
Allowance for equity funds used during
construction............................... 182 238
Other........................................ 3,753 1,510
----------- -------------------
TOTAL OTHER INCOME............................. 49,338 65,334
----------- -------------------
INTEREST CHARGES:
Interest on long-term debt and other
obligations................................ 299,353 328,907
Allowance for debt funds used during
construction............................... (1,964) (2,576)
----------- -------------------
NET INTEREST CHARGES........................... 297,389 326,331
----------- -------------------
NET MARGIN..................................... $ 9,600 $ 21,752
----------- -------------------
----------- -------------------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE CONDENSED FINANCIAL
STATEMENTS.
F-29
CONDENSED BALANCE SHEETS
SEPTEMBER 30, DECEMBER 31,
1997 1996
-------------- --------------
(UNAUDITED)
(DOLLARS IN THOUSANDS)
ASSETS
ELECTRIC PLANT:
In service..................................................................... $4,906,315 $ 5,742,597
Less: Accumulated provision for depreciation................................... (1,382,063) (1,488,272)
-------------- --------------
3,524,252 4,254,325
Nuclear fuel, at amortized cost................................................ 86,980 86,722
Plant acquisition adjustments, at amortized cost............................... -- 4,153
Construction work in progress.................................................. 13,059 31,181
-------------- --------------
3,624,291 4,376,381
-------------- --------------
INVESTMENTS AND FUNDS:
Bond, reserve and construction funds, at market................................ 32,328 53,955
Decommissioning fund, at market................................................ 101,821 86,269
Investment in associated organizations, at cost................................ 15,407 15,379
Deposit on Rocky Mountain transactions, at cost (Note 5)....................... 51,325 41,685
-------------- --------------
200,881 197,288
-------------- --------------
CURRENT ASSETS:
Cash and temporary cash investments, at cost................................... 59,981 132,783
Other short-term investments, at market........................................ 96,145 91,499
Receivables.................................................................... 117,580 113,289
Inventories, at average cost................................................... 70,872 89,825
Prepayments and other current assets........................................... 22,371 14,625
-------------- --------------
366,949 442,021
-------------- --------------
DEFERRED CHARGES:
Premium and loss on reacquired debt, being amortized........................... 189,692 201,007
Deferred amortization of Scherer leasehold..................................... 94,832 90,717
Deferred debt expense, being amortized......................................... 13,641 21,703
Other.......................................................................... 36,994 33,058
-------------- --------------
335,159 346,485
-------------- --------------
$4,527,280 $ 5,362,175
-------------- --------------
-------------- --------------
EQUITY AND LIABILITIES
CAPITALIZATION:
Patronage capital and membership fees (including unrealized loss of ($515) at
September 30, 1997 and ($844) at December 31, 1996 on available-for-sale
securities).................................................................. $ 321,771 $ 356,229
Long-term debt (Note 3)........................................................ 3,171,511 4,052,470
Obligation under capital leases (Note 3)....................................... 289,825 293,682
Obligation under Rocky Mountain transactions (Note 5).......................... 51,325 41,685
-------------- --------------
3,834,432 4,744,066
-------------- --------------
CURRENT LIABILITIES:
Long-term debt and capital leases due within one year (Note 3)................. 87,847 159,622
Notes payable (Note 4)......................................................... 92,220 --
Accounts payable............................................................... 53,641 42,891
Accrued interest............................................................... 13,560 15,931
Accrued and withheld taxes..................................................... 19,800 4,940
Other current liabilities...................................................... 4,891 9,540
-------------- --------------
271,959 232,924
-------------- --------------
DEFERRED CREDITS AND OTHER LIABILITIES:
Gain on sale of plant, being amortized......................................... 61,375 58,527
Net benefit of sale of income tax benefits, being amortized.................... 36,042 42,049
Net benefit of Rocky Mountain transactions, being amortized (Note 5)........... 93,171 70,701
Accumulated deferred income taxes.............................................. 60,325 61,985
Decommissioning reserve........................................................ 141,399 124,468
Other.......................................................................... 28,577 27,455
-------------- --------------
420,889 385,185
-------------- --------------
COMMITMENTS AND CONTINGENCIES
$4,527,280 $ 5,362,175
-------------- --------------
-------------- --------------
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE CONDENSED BALANCE SHEETS.
F-30
CONDENSED STATEMENTS OF CASH FLOWS
TWELVE MONTHS ENDED FOR THE YEAR ENDED
SEPTEMBER 30, DECEMBER 31,
1997 1996
--------------------- -------------------
(UNAUDITED)
(DOLLARS IN THOUSANDS)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net margin......................................................... $ 9,600 $ 21,752
---------- ----------
ADJUSTMENTS TO RECONCILE NET MARGIN TO NET CASH PROVIDED BY
OPERATING ACTIVITIES:
Depreciation and amortization.................................. 203,218 196,593
Net benefit of Rocky Mountain transactions..................... 93,171 70,701
Deferred gain from Corporate Restructuring..................... 4,670 --
Allowance for equity funds used during construction............ (182) (238)
Amortization of deferred margins............................... (7,927) (32,047)
Amortization of net benefit of sale of income tax benefits..... (10,518) (8,145)
Deferred income taxes.......................................... (5,185) (3,525)
Option payment on power swap agreement......................... (6,004) (3,750)
Other.......................................................... 7,147 4,813
CHANGE IN NET CURRENT ASSETS, EXCLUDING LONG-TERM DEBT DUE WITHIN
ONE YEAR AND DEFERRED MARGINS TO BE REFUNDED WITHIN ONE YEAR:
Receivables.................................................... (10,008) (13,731)
Inventories.................................................... 12,954 (6,875)
Prepayments and other current assets........................... (8,154) (299)
Accounts payable............................................... 10,268 (5,964)
Accrued interest............................................... (7,125) (75,165)
Accrued and withheld taxes..................................... (2,686) 3,155
Other current liabilities...................................... 2,730 (3,985)
---------- ----------
TOTAL ADJUSTMENTS.................................................. 276,369 121,538
---------- ----------
NET CASH PROVIDED BY OPERATING ACTIVITIES............................ 285,969 143,290
---------- ----------
CASH FLOWS FROM INVESTING ACTIVITIES:
Property additions................................................. (74,367) (93,704)
Net proceeds from bond, reserve and construction funds............. 19,896 1,340
Decrease in investment in associated organizations................. 16 474
Increase in other short-term investments........................... (5,208) (15,532)
Increase in decommissioning fund................................... (13,431) (10,691)
Net cash received in Corporate Restructuring....................... 24,539 --
---------- ----------
NET CASH USED IN INVESTING ACTIVITIES.......................... (48,555) (118,113)
---------- ----------
CASH FLOWS FROM FINANCING ACTIVITIES:
Debt proceeds, net................................................. 191,640 2,243
Debt payments...................................................... (414,395) (95,367)
Retirement of patronage capital.................................... (48,863) --
Other.............................................................. (1,679) (421)
---------- ----------
NET CASH USED IN FINANCING ACTIVITIES.......................... (273,297) (93,545)
---------- ----------
NET DECREASE IN CASH AND TEMPORARY CASH INVESTMENTS.................. (35,883) (68,368)
CASH AND TEMPORARY CASH INVESTMENTS AT BEGINNING OF PERIOD........... 95,864 201,151
---------- ----------
CASH AND TEMPORARY CASH INVESTMENTS AT END OF PERIOD................. $ 59,981 $ 132,783
---------- ----------
---------- ----------
CASH PAID FOR:
Interest (net of amounts capitalized).............................. $ 284,165 $ 383,440
Income taxes....................................................... $ 830 $ --
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE CONDENSED FINANCIAL
STATEMENTS.
F-31
NOTES TO INTERIM CONDENSED FINANCIAL STATEMENTS
(UNAUDITED)
1. PRINCIPLES OF PREPARATION:
The interim condensed financial statements included herein have been
prepared by Oglethorpe Power Corporation (An Electric Membership Corporation)
("Oglethorpe"), without audit, pursuant to the rules and regulations of the
Securities and Exchange Commission (the "Commission"). In the opinion of
management, the accompanying interim condensed financial statements reflect all
adjustments (which include only normal recurring adjustments) necessary to
present fairly, in all material respects, the results for the twelve months
ended September 30, 1997. Certain information and footnote disclosures normally
included in financial statements prepared in accordance with generally accepted
accounting principles have been condensed or omitted pursuant to such Commission
rules and regulations, although Oglethorpe believes that the disclosures are
adequate to make the information presented not misleading. These interim
condensed financial statements should be read in conjunction with Oglethorpe's
audited financial statements included in this Prospectus. Certain amounts for
1996 have been reclassified to conform with the current period presentation.
2. CORPORATE RESTRUCTURING:
Oglethorpe and the Members completed on March 11, 1997 a corporate
restructuring (the "Corporate Restructuring"), in which Oglethorpe was divided
into three specialized operating companies to respond to increasing competition
and regulatory changes in the electric industry. Oglethorpe's transmission
business was sold to, and is now owned and operated by, Georgia Transmission
Corporation (An Electric Membership Corporation) ("GTC"), a recently formed
Georgia electric membership corporation. Oglethorpe's system operations business
was sold to, and is now owned and operated by, Georgia System Operations
Corporation ("GSOC"), a recently formed Georgia nonprofit corporation.
Oglethorpe continues to own and operate its power supply business. (See
"BUSINESS OF OGLETHORPE--Corporate Restructuring," "--Relationship with GTC" and
"--Relationship with GSOC.")
The total purchase price GTC and GSOC paid Oglethorpe for the transmission
and system operations businesses was approximately $717 million. The following
summarizes the assets and liabilities sold by Oglethorpe to GTC and GSOC as a
result of the restructuring:
ASSETS EQUITY & LIABILITIES
(DOLLARS IN THOUSANDS)
Plant in service........................ $ 847,172 Long-term debt.......................... $ 686,054
Accumulated depreciation................ (195,944) Accounts payable........................ 585
Construction work in progress........... 13,313 Accrued interest........................ 121
Plant acquisition adjustments........... 3,887 Accrued pension cost.................... 1,047
Inventories............................. 8,980 Deferred revenues....................... 310
----------
Prepayments............................. 71 TOTAL LIABILITIES EXTINGUISHED.... 688,117
Premium on reacquired debt.............. 33,410 Notes received from GSOC................ 4,823
Deferred debt expense................... 1,920 Net cash received....................... 24,539
----------- ----------
TOTAL ASSETS SOLD..................... 712,809 TOTAL PURCHASE PRICE.................... $ 717,479
----------
----------
Deferred gain on sale................... 4,670
-----------
TOTAL PURCHASE PRICE.................. $ 717,479
-----------
-----------
F-32
NOTES TO INTERIM CONDENSED FINANCIAL STATEMENTS (CONTINUED)
(UNAUDITED)
On October 1, 1996, Oglethorpe transferred to GSOC its system operations
assets, consisting of its system control center and related energy control and
revenue metering systems equipment. The purchase price totaled approximately
$9.4 million and was paid by (i) GSOC's assumption of Oglethorpe's obligations
under an existing note held by RUS, (ii) delivery of a purchase money note
payable to Oglethorpe, and (iii) the assumption of certain other liabilities of
Oglethorpe. From October 1, 1996 to March 11, 1997, Oglethorpe was the sole
member of GSOC; therefore, the assets transferred to GSOC remained in the
balance sheet of Oglethorpe. The Members became members of GSOC on March 11,
1997; and thereafter the assets, liabilities and equity of GSOC were no longer
part of Oglethorpe.
Decreases in operating revenues, power delivery expenses, depreciation and
amortization, taxes other than income taxes, operating margin, other operating
income, and net interest charges from 1996 to 1997 are primarily attributable to
the Corporate Restructuring. (See "MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS.")
3. DEBT OBLIGATIONS:
As discussed in Note 2, GTC assumed approximately $686 million of
Oglethorpe's long-term debt obligations. The following schedule reflects as of
September 30, 1997 the annual maturities of Oglethorpe's debt remaining after
the Corporate Restructuring:
1997 1998 1999 2000 2001
--------- --------- --------- --------- ---------
(DOLLARS IN THOUSANDS)
FFB & RUS................................ $ 133,404 $ 69,414 $ 72,740 $ 78,471 $ 84,471
CoBank................................... 365 483 495 508 523
PCB Bonds................................ 14,482 13,206 14,540 17,949 19,678
Capital Leases........................... 4,087 5,143 6,240 7,075 7,775
--------- --------- --------- --------- ---------
Total.................................... $ 152,338 $ 88,246 $ 94,015 $ 104,003 $ 112,447
--------- --------- --------- --------- ---------
--------- --------- --------- --------- ---------
4. NOTES PAYABLE:
The $92 million classified as Notes Payable on the Balance Sheet relates to
commercial paper outstanding which was issued to defease approximately $92
million in principal amount of Series 1992 pollution control revenue bonds
("PCBs"). It is Oglethorpe's intent to refinance this commercial paper on a
long-term basis by issuing medium-term notes or PCBs. However, as no formal
financing agreement is in place for this longer term refinancing, the $92
million has been classified as a current liability.
5. SALE AND LEASEBACK AGREEMENTS:
In December 1996, Oglethorpe entered into long-term lease transactions for a
portion of its 74.61% undivided ownership interest in the Rocky Mountain Pumped
Storage Hydroelectric Facility ("Rocky Mountain"). The lease transactions are
characterized as a sale and leaseback for income tax purposes, but not for
financial reporting purposes. As a result of these leases, Oglethorpe recorded a
net benefit of approximately $71 million, which was deferred and will be
amortized to income over the 30-year leaseback period. The lease transactions
increased Oglethorpe's Capitalization and Investments and funds in the December
31, 1996 balance sheet by approximately $41 million.
In January 1997, Oglethorpe completed the long-term lease transactions for
the remainder of its interest in Rocky Mountain resulting in a net benefit of
approximately $25 million, which will also be
F-33
NOTES TO INTERIM CONDENSED FINANCIAL STATEMENTS (CONTINUED)
(UNAUDITED)
deferred over the 30-year leaseback period. These additional lease transactions
increased Oglethorpe's Capitalization and Investments and funds by approximately
$16 million.
6. POWER MARKETER AGREEMENTS:
Effective January 1, 1997, Oglethorpe entered into power marketer agreements
with LG&E Energy Marketing, Inc. ("LEM") for 50% of the load requirements of the
Members. Under the agreement, LEM is obligated to deliver, and Oglethorpe is
obligated to take, approximately 50% of load requirements of the participating
Members less the load requirements for certain customers who have the right to
choose electric suppliers, plus 50% of the delivery obligations under
Oglethorpe's existing firm power off-system sale contracts. The LEM agreement
relating to 37 of the 39 Members has a term extending through 2011.
Effective May 1, 1997, Oglethorpe entered into a power marketer agreement
with Morgan Stanley Capital Group Inc. ("Morgan Stanley") with respect to 50% of
the Members' forecasted load requirements. The agreement obligates Oglethorpe to
purchase fixed quantities of energy at fixed prices. Each Member selected a term
for its obligation, as well as the portion of its forecasted requirements to be
purchased as a fixed quantity. Oglethorpe is obligated to sell and Morgan
Stanley is obligated to buy 50% of the output, in contractually fixed amounts,
of each Member's percentage capacity responsibility ("PCR") share (for the term
and portion selected) of the "must run" units (primarily nuclear units).
Oglethorpe is also obligated to make available the same share of all other
resources, in contractually fixed amounts, which Morgan Stanley may schedule for
each 24-hour day. This schedule is set the day prior based on availability
limitations in the contract. Morgan Stanley pays a contractually fixed amount
each month and an amount for the scheduled energy based on contractually fixed
prices. The agreement has an initial term extending to March 31, 2000. The
agreement has a term extending to March 31, 2005, but the purchases for certain
Members decline to zero prior to that date. Oglethorpe plans to manage the
system resources covered by the Morgan Stanley agreement through scheduling and
dispatching such resources. Oglethorpe will also make purchases and sales to
balance the fixed purchase obligation against the actual requirements and to
optimize the use of the resources after receiving the daily schedule from Morgan
Stanley.
(See "MEMBER REQUIREMENTS AND POWER SUPPLY RESOURCES--Power Marketer
Arrangements.")
F-34
APPENDIX A
MEMBER FINANCIAL AND STATISTICAL INFORMATION
Oglethorpe's Members operate their systems on a not-for-profit basis.
Accumulated margins derived after payment of operating expenses and provision
for depreciation constitute patronage capital of the consumers of the Members.
Refunds of accumulated patronage capital to the individual consumers may be made
from time to time subject to limitations contained in mortgages between the
Members and RUS or loan documents with other lenders. The RUS mortgages
generally prohibit such distributions unless, after any such distribution the
Member's total equity will equal at least 40% (30% in the case of Members, if
any, that have the new form of RUS loan documents) of its total assets, except
that distributions may be made of up to 25% of the margins and patronage capital
received by the Member in the preceding year (provided that equity is at least
20% in the case of Members, if any, that have the new form of RUS loan
documents). (See "THE MEMBERS OF OGLETHORPE--Members' Relationship with RUS.")
Oglethorpe is a membership corporation, and the Members are not subsidiaries
of Oglethorpe. Except with respect to the obligations of the Members under each
Member's Wholesale Power Contract with Oglethorpe and Oglethorpe's rights under
such contracts to receive payment for power and energy supplied, Oglethorpe has
no legal interest in, or obligations in respect of, any of the assets,
liabilities, equity, revenues or margins of the Members. The following selected
information on the individual Members is intended to show, in the aggregate, the
assets, liabilities, equity, revenues and margins of the Members; Member assets,
liabilities, equity, revenues and margins should not, however, be attributed to
Oglethorpe itself. In addition, the revenues of the Members are not pledged to
Oglethorpe, but such revenues are received by the respective Members and are the
source from which moneys are derived by the Members to pay for power and energy
received from Oglethorpe. Revenues of the Members are, however, pledged under
their respective RUS mortgages or loan documents with other lenders.
The information contained in these Tables was taken from RUS Financial and
Statistical Reports (RUS Form 7) or similar reports prepared for other lenders
or provided directly by a Member. This information has not been independently
verified by RUS, any lender or Oglethorpe. The "Total" columns for all these
years were not supplied or compiled by RUS, any lender or the Members. The
"Total" column in each table is for informational purposes only, inasmuch as
each Member operates independently and is not responsible for the obligations of
other Members. For the calendar years 1994, 1995 and 1996, the information on
the individual Members is presented in the succeeding tables as follows: Table
1, selected statistics; Table 2, average number of consumers served; Table 3,
annual MWh sales by consumer class; Table 4, annual revenues by consumer class;
Table 5, summary of operating results; and Table 6, condensed balance sheet
information.
A-1
OGLETHORPE POWER CORPORATION
MEMBER FINANCIAL AND STATISTICAL INFORMATION
TABLE 1
SELECTED STATISTICS OF EACH MEMBER
(AS OF DECEMBER 31)
CENTRAL
ALTAMAHA AMICALOLA CANOOCHEE CARROLL GEORGIA COASTAL
----------- ------------- ------------- ----------- ----------- -----------
1996
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 89.96 82.24 94.26 82.03 86.71 97.70
Avg. Monthly Residential kWh.............. 1,034 938 1,099 956 1,073 1,116
Avg. Residential Rev.(cents per kWh)...... 8.70 8.76 8.57 8.58 8.08 8.75
Times Interest Earned Ratio............... 2.81 1.72 2.85 2.66 2.75 1.57
Equity/Assets............................. 56.5% 30.6% 46.4% 41.6% 46.6% 29.5%
Equity/Total Capitalization............... 61.7% 35.0% 50.4% 47.5% 50.2% 32.2%
1995
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 89.74 83.27 92.84 80.38 89.47 98.10
Avg. Monthly Residential kWh.............. 992 898 1,056 909 1,018 1,058
Avg. Residential Rev.(cents per kWh)...... 9.04 9.28 8.79 8.84 8.79 9.27
Times Interest Earned Ratio............... 3.88 1.83 2.36 2.02 2.06 1.87
Equity/Assets............................. 58.2% 30.2% 46.0% 41.8% 43.6% 31.7%
Equity/Total Capitalization............... 63.1% 34.4% 50.0% 46.8% 47.4% 35.2%
1994
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 84.18 76.87 88.28 75.77 81.80 88.96
Avg. Monthly Residential kWh.............. 929 856 991 862 962 974
Avg. Residential Rev.(cents per kWh)...... 9.06 8.98 8.91 8.79 8.50 9.14
Times Interest Earned Ratio............... 3.42 1.54 2.97 2.97 2.06 1.54
Equity/Assets............................. 59.4% 29.8% 46.8% 42.0% 45.3% 31.7%
Equity/Total Capitalization............... 63.7% 33.4% 50.8% 45.9% 51.0% 35.0%
COWETA-
COBB COLQUITT FAYETTE
----------- ----------- -----------
1996
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 89.71 88.88 92.06
Avg. Monthly Residential kWh.............. 1,030 1,182 1,111
Avg. Residential Rev.(cents per kWh)...... 8.71 7.52 8.29
Times Interest Earned Ratio............... 1.57 3.36 1.92
Equity/Assets............................. 33.6% 52.5% 31.8%
Equity/Total Capitalization............... 40.2% 56.8% 36.4%
1995
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 91.13 89.57 95.77
Avg. Monthly Residential kWh.............. 1,038 1,140 1,081
Avg. Residential Rev.(cents per kWh)...... 8.78 7.86 8.86
Times Interest Earned Ratio............... 1.82 2.86 1.78
Equity/Assets............................. 33.3% 50.0% 32.2%
Equity/Total Capitalization............... 39.0% 54.0% 36.5%
1994
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 87.09 83.47 86.78
Avg. Monthly Residential kWh.............. 922 1,063 1,009
Avg. Residential Rev.(cents per kWh)...... 9.44 7.85 8.60
Times Interest Earned Ratio............... 2.28 2.36 1.66
Equity/Assets............................. 33.1% 51.1% 33.8%
Equity/Total Capitalization............... 38.2% 55.2% 38.1%
MIDDLE OKEFE-
GEORGIA MITCHELL OCMULGEE OCONEE NOKE(1) PATAULA
----------- ------------- ------------- ----------- ----------- -----------
1996
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 93.56 98.47 79.03 90.26 94.92 66.45
Avg. Monthly Residential kWh.............. 1,169 1,220 902 1,000 1,172 775
Avg. Residential Rev.(cents per kWh)...... 8.00 8.07 8.76 9.02 8.10 8.58
Times Interest Earned Ratio............... 2.09 2.24 3.00 2.66 1.75 4.18
Equity/Assets............................. 42.2% 51.5% 46.6% 46.4% 33.7% 57.7%
Equity/Total Capitalization............... 44.0% 59.1% 51.2% 51.9% 42.3% 60.8%
1995
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 99.58 98.29 82.25 90.72 98.29 67.12
Avg. Monthly Residential kWh.............. 1,096 1,164 861 977 1,134 737
Avg. Residential Rev.(cents per kWh)...... 9.08 8.44 9.56 9.29 8.66 9.10
Times Interest Earned Ratio............... 2.13 2.38 2.02 2.16 1.57 3.36
Equity/Assets............................. 40.7% 50.9% 46.8% 47.6% 33.4% 54.2%
Equity/Total Capitalization............... 44.0% 62.0% 49.1% 53.2% 40.5% 57.3%
1994
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 91.65 89.97 76.00 82.98 89.03 62.85
Avg. Monthly Residential kWh.............. 1,018 1,088 804 905 1,059 692
Avg. Residential Rev.(cents per kWh)...... 9.01 8.27 9.45 9.17 8.41 9.08
Times Interest Earned Ratio............... 1.76 2.77 2.57 1.76 1.54 2.61
Equity/Assets............................. 40.0% 50.7% 48.7% 47.6% 34.6% 51.2%
Equity/Total Capitalization............... 44.0% 60.8% 51.3% 52.3% 39.8% 54.2%
PLANTERS RAYLE SATILLA
----------- ----------- -----------
1996
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 84.45 80.01 83.09
Avg. Monthly Residential kWh.............. 1,104 914 1,145
Avg. Residential Rev.(cents per kWh)...... 7.65 8.76 7.26
Times Interest Earned Ratio............... 2.63 1.92 2.29
Equity/Assets............................. 48.1% 40.6% 55.8%
Equity/Total Capitalization............... 53.8% 44.0% 60.3%
1995
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 85.19 82.64 87.69
Avg. Monthly Residential kWh.............. 1,061 876 1,093
Avg. Residential Rev.(cents per kWh)...... 8.03 9.43 8.03
Times Interest Earned Ratio............... 2.91 1.58 2.62
Equity/Assets............................. 48.6% 40.0% 55.0%
Equity/Total Capitalization............... 54.4% 42.7% 59.9%
1994
- ------------------------------------------
Avg. Monthly Residential Rev.($).......... 82.70 75.97 79.78
Avg. Monthly Residential kWh.............. 993 827 1,038
Avg. Residential Rev.(cents per kWh)...... 8.33 9.18 7.69
Times Interest Earned Ratio............... 3.11 1.76 3.16
Equity/Assets............................. 49.2% 41.0% 56.7%
Equity/Total Capitalization............... 54.8% 43.2% 61.1%
- ------------------------
(1) Includes information relating to Okefenoke Rural EMC's operations in both
Georgia and Florida. Okefenoke Rural EMC purchases a portion of its power
and energy from an electric supplier in Florida. In 1996, such energy
amounted to approximately 26% of its total energy requirements.
(2) Weighted Average.
A-2
TABLE 1 (CONTINUED)
EXCELSIOR FLINT GRADY GREYSTONE HABERSHAM HART IRWIN JACKSON JEFFERSON
- ----------- ----------- ------------- ------------- ------------- ----------- ----------- ----------- -------------
81.86 89.06 88.98 86.19 73.72 81.69 85.77 82.67 89.77
1,140 1,238 1,067 1,122 943 984 1,067 1,112 1,069
7.18 7.20 8.34 7.68 7.82 8.31 8.04 7.43 8.40
1.97 2.55 1.97 3.66 1.93 3.52 1.77 2.04 2.07
42.3% 42.7% 48.7% 45.4% 44.8% 44.0% 39.2% 35.9% 40.2%
47.5% 51.3% 55.4% 49.4% 52.3% 50.8% 41.0% 41.2% 48.0%
82.28 91.35 88.92 90.22 73.14 76.84 83.89 86.69 92.95
1,077 1,209 1,026 1,087 895 951 1,027 1,072 1,042
7.64 7.55 8.67 8.30 8.18 8.08 8.16 8.08 8.92
1.88 2.27 1.55 3.00 1.88 2.00 1.67 1.97 1.82
46.5% 44.4% 48.2% 42.0% 44.9% 42.5% 40.3% 36.6% 39.7%
51.8% 51.5% 53.8% 44.9% 52.1% 49.8% 42.4% 42.3% 45.3%
78.01 85.79 82.71 81.24 69.47 71.31 81.34 83.38 86.10
1,005 1,140 915 1,030 871 908 947 1,021 989
7.76 7.53 9.04 7.89 7.97 7.85 8.59 8.17 8.70
1.89 3.25 2.42 2.20 -1.01 1.55 1.86 1.87 2.32
48.1% 45.9% 53.5% 41.0% 45.6% 44.5% 40.4% 37.6% 40.4%
53.6% 51.9% 58.0% 44.0% 52.8% 52.3% 42.4% 42.3% 46.6%
LITTLE
EXCELSIOR LAMAR OCMULGEE
- ----------- --------------- -------------
81.86 86.41 80.92
1,140 1,086 941
7.18 7.96 8.60
1.97 3.67 1.70
42.3% 50.1% 38.4%
47.5% 59.1% 40.7%
82.28 86.56 85.82
1,077 1,053 993
7.64 8.22 8.64
1.88 2.47 1.69
46.5% 50.1% 37.1%
51.8% 57.2% 38.9%
78.01 78.04 74.43
1,005 988 844
7.76 7.90 8.82
1.89 3.61 1.94
48.1% 50.3% 38.7%
53.6% 57.0% 40.7%
SLASH SNAPPING THREE TRI- UPSON
SAWNEE PINE SHOALS SUMTER NOTCH COUNTY TROUP COUNTY WALTON
- ----------- ----------- ------------- ------------- ------------- ----------- ----------- ----------- -------------
93.08 90.29 91.51 101.33 79.21 87.50 93.42 73.92 92.04
1,089 1,119 1,185 1,319 1,047 1,026 1,222 900 1,202
8.55 8.07 7.72 7.69 7.57 8.52 7.64 8.21 7.66
2.07 2.53 1.76 1.95 2.46 2.55 2.97 4.70 3.34
32.0% 46.8% 40.6% 42.7% 54.4% 40.5% 49.8% 57.5% 49.1%
35.1% 51.8% 51.9% 47.3% 57.6% 44.1% 58.0% 63.9% 59.1%
95.59 91.85 94.02 99.84 89.45 85.05 97.93 71.01 96.26
1,060 1,078 1,143 1,258 1,056 971 1,148 868 1,166
9.02 8.52 8.23 7.94 8.47 8.76 8.53 8.18 8.26
1.59 2.25 2.13 2.03 2.57 1.71 3.52 2.49 3.12
33.0% 48.7% 41.8% 46.3% 53.1% 38.1% 49.3% 55.3% 48.0%
37.8% 55.1% 50.7% 50.4% 55.6% 40.5% 55.1% 61.3% 55.9%
84.27 83.52 87.46 93.72 79.84 77.45 91.63 67.16 88.35
979 1,004 1,069 1,193 951 915 1,091 815 1,080
8.61 8.32 8.18 7.86 8.39 8.46 8.40 8.24 8.18
1.53 2.50 2.88 2.26 2.06 1.58 2.02 3.19 2.20
34.9% 52.8% 42.0% 51.3% 54.4% 39.0% 42.8% 54.8% 46.0%
40.0% 59.3% 76.5% 55.1% 58.9% 42.4% 46.8% 60.1% 51.9%
SAWNEE WASHINGTON TOTAL
- ----------- --------------- -------------
93.08 84.17 87.75
1,089 979 1,096
8.55 8.60 8.00
2.07 2.01 2.30(2)
32.0% 41.7% 41.3%(2)
35.1% 45.8% 47.1%(2)
95.59 82.39 89.80
1,060 932 1,062
9.02 8.84 8.45
1.59 2.28 2.13(2)
33.0% 41.3% 41.1%(2)
37.8% 44.6% 46.6%(2)
84.27 74.77 83.28
979 864 991
8.61 8.65 8.40
1.53 1.79 2.10(2)
34.9% 42.5% 41.7%(2)
40.0% 45.3% 47.2%(2)
A-3
OGLETHORPE POWER CORPORATION
MEMBER FINANCIAL AND STATISTICAL INFORMATION
TABLE 2
AVERAGE NUMBER OF CONSUMERS SERVED BY EACH MEMBER
CENTRAL
ALTAMAHA AMICALOLA CANOOCHEE CARROLL GEORGIA COASTAL COBB
----------- ----------- ------------- ----------- ----------- ----------- -----------
1996
Residential Service............ 14,264 25,770 14,773 31,088 26,795 9,387 120,037
Commercial & Industrial........ 1,246 1,053 251 1,695 1,476 1,036 7,555
Other.......................... 70 7 100 352 34 89 1,106
----------- ----------- ------------- ----------- ----------- ----------- -----------
Total Consumers Served..... 15,580 26,831 15,123 33,135 28,305 10,513 128,698
----------- ----------- ------------- ----------- ----------- ----------- -----------
----------- ----------- ------------- ----------- ----------- ----------- -----------
1995
Residential Service............ 13,892 24,439 14,320 30,155 26,088 8,913 113,807
Commercial & Industrial........ 1,212 1,008 215 1,646 1,179 979 7,161
Other.......................... 65 7 103 349 34 89 1,411
----------- ----------- ------------- ----------- ----------- ----------- -----------
Total Consumers Served..... 15,169 25,454 14,638 32,150 27,301 9,981 122,379
----------- ----------- ------------- ----------- ----------- ----------- -----------
----------- ----------- ------------- ----------- ----------- ----------- -----------
1994
Residential Service............ 13,493 23,165 13,835 29,169 25,177 8,495 109,251
Commercial & Industrial........ 1,159 978 209 1,605 1,108 884 6,655
Other.......................... 65 7 84 349 35 87 1,178
----------- ----------- ------------- ----------- ----------- ----------- -----------
Total Consumers Served..... 14,717 24,150 14,128 31,123 26,320 9,466 117,084
----------- ----------- ------------- ----------- ----------- ----------- -----------
----------- ----------- ------------- ----------- ----------- ----------- -----------
COWETA-
COLQUITT FAYETTE
----------- -----------
1996
Residential Service............ 40,934 43,056
Commercial & Industrial........ 1,864 2,307
Other.......................... 1,151 181
----------- -----------
Total Consumers Served..... 43,949 45,545
----------- -----------
----------- -----------
1995
Residential Service............ 39,273 40,714
Commercial & Industrial........ 1,728 2,104
Other.......................... 1,095 160
----------- -----------
Total Consumers Served..... 42,095 42,978
----------- -----------
----------- -----------
1994
Residential Service............ 38,042 38,195
Commercial & Industrial........ 1,643 1,941
Other.......................... 1,047 316
----------- -----------
Total Consumers Served..... 40,732 40,452
----------- -----------
----------- -----------
MIDDLE OKEFE-
GEORGIA MITCHELL OCMULGEE OCONEE NOKE(1) PATAULA PLANTERS
----------- ----------- ------------- ----------- ----------- ----------- -----------
1996
Residential Service............ 4,173 18,167 9,040 9,738 22,144 4,031 12,750
Commercial & Industrial........ 1,487 819 435 362 1,321 238 529
Other.......................... 385 822 293 355 255 90 425
----------- ----------- ------------- ----------- ----------- ----------- -----------
Total Consumers Served..... 6,045 19,808 9,768 10,454 23,719 4,360 13,704
----------- ----------- ------------- ----------- ----------- ----------- -----------
----------- ----------- ------------- ----------- ----------- ----------- -----------
1995
Residential Service............ 4,120 17,807 8,838 9,482 21,513 3,951 12,308
Commercial & Industrial........ 1,480 763 422 327 1,121 228 516
Other.......................... 342 761 286 359 239 92 415
----------- ----------- ------------- ----------- ----------- ----------- -----------
Total Consumers Served..... 5,942 19,331 9,546 10,168 22,873 4,271 13,239
----------- ----------- ------------- ----------- ----------- ----------- -----------
----------- ----------- ------------- ----------- ----------- ----------- -----------
1994
Residential Service............ 4,032 17,341 8,703 9,275 21,391 3,845 11,972
Commercial & Industrial........ 1,423 786 327 300 1,079 220 516
Other.......................... 312 700 251 352 14 92 401
----------- ----------- ------------- ----------- ----------- ----------- -----------
Total Consumers Served..... 5,767 18,827 9,281 9,927 22,484 4,157 12,889
----------- ----------- ------------- ----------- ----------- ----------- -----------
----------- ----------- ------------- ----------- ----------- ----------- -----------
RAYLE SATILLA
----------- -----------
1996
Residential Service............ 13,897 38,686
Commercial & Industrial........ 1,052 1,415
Other.......................... 0 888
----------- -----------
Total Consumers Served..... 14,949 40,988
----------- -----------
----------- -----------
1995
Residential Service............ 13,596 37,338
Commercial & Industrial........ 1,034 1,346
Other.......................... 0 855
----------- -----------
Total Consumers Served..... 14,631 39,539
----------- -----------
----------- -----------
1994
Residential Service............ 13,310 35,850
Commercial & Industrial........ 1,039 1,305
Other.......................... 0 843
----------- -----------
Total Consumers Served..... 14,349 37,998
----------- -----------
----------- -----------
- ------------------------
(1) Includes information relating to Okefenoke Rural EMC's operations in both
Georgia and Florida. Okefenoke Rural EMC purchases a portion of its power
and energy from an electric supplier in Florida. In 1996, such energy
amounted to approximately 26% of its total energy requirements.
A-4
TABLE 2 (CONTINUED)
EXCELSIOR FLINT GRADY GREYSTONE HABERSHAM HART IRWIN JACKSON JEFFERSON LAMAR
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
15,173 48,402 13,997 58,221 21,553 23,729 9,182 109,740 26,951 12,516
834 5,134 398 4,613 1,690 4,309 160 7,877 377 747
166 549 456 366 13 0 322 805 61 9
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
16,174 54,085 14,851 63,200 23,256 28,038 9,663 118,421 27,389 13,272
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
14,371 46,588 13,549 55,889 20,648 23,154 8,933 103,418 26,331 12,031
772 4,936 373 4,319 1,610 4,179 169 7,610 360 728
112 532 433 337 12 0 287 516 58 7
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
15,255 52,056 14,355 60,545 22,270 27,333 9,388 111,544 26,750 12,766
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
13,849 45,368 13,105 53,753 19,826 22,524 8,703 98,388 25,616 11,686
751 4,715 358 4,115 1,513 4,020 159 7,603 344 714
104 522 425 308 12 0 271 286 55 6
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
14,704 50,605 13,888 58,176 21,351 26,544 9,133 106,277 26,015 12,406
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
LITTLE
EXCELSIOR OCMULGEE
- ----------- -----------
15,173 8,472
834 56
166 239
- ----------- -----------
16,174 8,767
- ----------- -----------
- ----------- -----------
14,371 7,577
772 56
112 227
- ----------- -----------
15,255 7,861
- ----------- -----------
- ----------- -----------
13,849 8,093
751 60
104 225
- ----------- -----------
14,704 8,378
- ----------- -----------
- ----------- -----------
SLASH SNAPPING THREE TRI- UPSON
SAWNEE PINE SHOALS SUMTER NOTCH COUNTY TROUP COUNTY WALTON WASHINGTON
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
70,076 5,283 47,415 11,905 11,737 13,687 19,155 7,365 70,234 12,018
4,909 255 2,359 3,546 559 973 2,129 508 4,559 488
2,023 124 0 121 202 0 178 105 1,084 20
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
77,008 5,661 49,774 15,572 12,498 14,660 21,462 7,977 75,877 12,526
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
64,402 5,071 45,177 11,584 11,891 13,283 18,657 7,240 67,484 11,849
4,366 247 2,219 3,462 247 952 2,090 450 4,305 388
1,429 116 0 120 20 0 187 102 1,035 18
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
70,197 5,434 47,396 15,167 12,158 14,235 20,934 7,792 72,824 12,255
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
59,611 4,874 43,282 11,189 11,651 12,880 17,958 7,092 65,036 11,556
4,013 238 2,118 3,376 259 930 2,097 445 4,132 349
1,289 114 0 119 20 0 185 104 994 19
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
64,913 5,226 45,400 14,684 11,931 13,810 20,240 7,641 70,162 11,924
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
- ----------- --------- ----------- ------------- ------------- ----------- --------- ----------- ----------- -------------
SAWNEE TOTAL
- ----------- -----------
70,076 1,075,539
4,909 72,618
2,023 13,446
- ----------- -----------
77,008 1,161,603
- ----------- -----------
- ----------- -----------
64,402 1,029,681
4,366 68,307
1,429 12,210
- ----------- -----------
70,197 1,110,197
- ----------- -----------
- ----------- -----------
59,611 990,581
4,013 65,487
1,289 11,191
- ----------- -----------
64,913 1,067,258
- ----------- -----------
- ----------- -----------
A-5
OGLETHORPE POWER CORPORATION
MEMBER FINANCIAL AND STATISTICAL INFORMATION
TABLE 3
ANNUAL MWH SALES BY CONSUMER CLASS OF EACH MEMBER (1)
CENTRAL
ALTAMAHA AMICALOLA CANOOCHEE CARROLL GEORGIA COASTAL COBB COLQUITT
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
1996
- --------------------------
Residential Service....... 176,920 290,172 194,871 356,763 345,134 125,738 1,483,575 580,488
Commercial & Industrial... 162,148 40,898 70,042 234,058 109,657 53,053 689,253 129,086
Other..................... 1,821 104 2,220 3,920 437 970 89,332 84,060
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
Total MWh Sales....... 340,889 331,175 267,133 594,740 455,228 179,761 2,262,159 793,634
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
1995
- --------------------------
Residential Service....... 165,438 263,230 181,483 328,968 318,566 113,174 1,417,804 537,199
Commercial & Industrial... 85,985 36,571 66,445 217,124 95,655 50,203 592,854 123,338
Other..................... 1,832 13,460 1,592 3,648 426 898 84,075 79,870
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
Total MWh Sales....... 253,255 313,261 249,520 549,740 414,647 164,276 2,094,733 740,407
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
1994
- --------------------------
Residential Service....... 150,406 238,069 164,559 301,792 290,700 99,264 1,209,248 485,238
Commercial & Industrial... 89,863 36,265 60,195 210,236 85,210 39,328 551,355 107,423
Other..................... 1,425 103 912 3,294 501 791 71,446 69,338
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
Total MWh Sales....... 241,695 274,437 225,666 515,322 376,411 139,383 1,832,050 661,999
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
COWETA-
FAYETTE
-----------
1996
- --------------------------
Residential Service....... 573,983
Commercial & Industrial... 175,672
Other..................... 4,138
-----------
Total MWh Sales....... 753,794
-----------
-----------
1995
- --------------------------
Residential Service....... 528,120
Commercial & Industrial... 149,452
Other..................... 5,352
-----------
Total MWh Sales....... 682,924
-----------
-----------
1994
- --------------------------
Residential Service....... 462,622
Commercial & Industrial... 124,478
Other..................... 5,537
-----------
Total MWh Sales....... 592,637
-----------
-----------
MIDDLE OKEFE-
GEORGIA MITCHELL OCMULGEE OCONEE NOKE(2) PATAULA PLANTERS RAYLE
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
1996
- --------------------------
Residential Service....... 58,553 266,122 97,850 116,898 311,556 37,485 168,855 152,365
Commercial & Industrial... 27,633 53,697 28,051 103,525 40,077 23,420 15,243 25,775
Other..................... 3,906 19,124 3,606 2,644 7,745 3,117 4,847 0
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
Total MWh Sales....... 90,092 338,943 129,507 223,067 359,379 64,021 188,946 178,140
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
1995
- --------------------------
Residential Service....... 54,199 248,823 91,286 111,168 292,848 34,960 156,675 142,922
Commercial & Industrial... 27,105 50,918 25,465 95,436 36,158 18,947 15,777 25,811
Other..................... 4,208 18,983 3,381 2,373 5,342 3,453 4,432 0
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
Total MWh Sales....... 85,512 318,724 120,132 208,977 334,348 57,360 176,884 168,733
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
1994
- --------------------------
Residential Service....... 49,237 226,507 83,997 100,725 271,766 31,942 142,640 132,144
Commercial & Industrial... 22,338 48,575 21,723 104,691 31,879 17,114 13,397 27,285
Other..................... 1,306 8,520 1,206 1,880 227 1,207 3,865 0
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
Total MWh Sales....... 72,881 283,602 106,926 207,296 303,872 50,263 159,902 159,429
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
----------- ----------- ----------- ----------- ----------- ----------- --------- -----------
SATILLA
-----------
1996
- --------------------------
Residential Service....... 531,633
Commercial & Industrial... 69,121
Other..................... 15,189
-----------
Total MWh Sales....... 615,943
-----------
-----------
1995
- --------------------------
Residential Service....... 489,533
Commercial & Industrial... 59,406
Other..................... 13,457
-----------
Total MWh Sales....... 562,396
-----------
-----------
1994
- --------------------------
Residential Service....... 446,328
Commercial & Industrial... 54,740
Other..................... 11,131
-----------
Total MWh Sales....... 512,199
-----------
-----------
- ------------------------
(1) Includes sales of energy purchased by the Members from both Oglethorpe and
SEPA. In 1996, energy purchased by the Members from SEPA represented
approximately 5.0% of the total energy purchased by the Members.
(2) Includes information relating to Okefenoke Rural EMC's operations in both
Georgia and Florida. Okefenoke Rural EMC purchases a portion of its power
and energy from an electric supplier in Florida. In 1996, such energy
amounted to approximately 26% of its total energy requirements.
A-6
TABLE 3 (CONTINUED)
LITTLE
EXCELSIOR FLINT GRADY GREYSTONE HABERSHAM HART IRWIN JACKSON JEFFERSON LAMAR OCMULGEE
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
207,525 718,814 179,242 784,105 243,935 280,069 117,556 1,464,762 345,569 163,100 95,701
42,567 319,770 17,884 344,505 60,156 101,377 20,330 896,564 45,175 35,898 18,317
2,165 19,133 9,958 3,444 99 5,447 94,769 4,224 3,295 3,770
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
252,257 1,057,717 207,085 1,132,054 304,190 381,446 143,332 2,456,094 394,968 202,294 117,788
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
185,727 676,027 166,736 729,033 221,655 264,332 110,135 1,330,839 329,364 152,072 90,285
39,563 310,118 16,251 304,269 55,827 99,248 22,576 802,756 42,619 30,684 18,231
1,500 19,157 9,867 3,163 94 0 4,788 80,453 4,177 2,397 2,907
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
226,790 1,005,302 192,854 1,036,466 277,576 363,580 137,500 2,214,048 376,160 185,153 111,424
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
167,028 620,475 143,819 664,358 207,302 245,378 98,893 1,205,178 304,098 138,575 81,932
32,048 284,780 13,469 274,003 50,142 88,825 16,455 748,375 39,218 26,261 17,396
1,311 16,634 8,548 2,928 92 0 2,797 36,043 3,485 1,332 1,711
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
200,387 921,889 165,836 941,289 257,536 334,203 118,145 1,989,596 346,801 166,168 101,039
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
SLASH SNAPPING THREE TRI- UPSON
SAWNEE PINE SHOALS SUMTER NOTCH COUNTY TROUP COUNTY WALTON WASHINGTON TOTAL
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
915,477 70,941 674,154 188,369 147,461 168,588 280,969 79,573 1,013,243 141,116 14,149,230
328,858 30,647 153,020 57,290 24,354 37,413 73,554 13,509 375,159 175,979 5,222,736
13,674 4,956 37 4,865 8,388 0 5,722 1,247 35,814 459 468,646
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
1,258,009 106,544 827,211 250,525 180,202 206,001 360,244 94,330 1,424,217 317,555 19,840,612
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
818,945 65,572 619,675 174,836 150,631 154,839 256,948 75,420 943,849 132,551 13,125,868
291,993 28,083 141,484 51,411 10,953 36,256 67,590 12,850 354,854 181,047 4,691,315
13,627 4,553 314 6,673 774 0 5,672 1,181 34,367 529 442,974
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
1,124,565 98,208 761,473 232,920 162,358 191,094 330,211 89,451 1,333,069 314,128 18,260,157
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
700,328 58,728 555,323 160,126 132,989 141,487 235,142 69,367 842,668 119,879 11,780,256
257,702 24,922 126,927 45,775 12,930 34,474 66,636 10,412 327,294 179,925 4,324,064
10,057 4,243 0 2,611 412 0 5,578 1,465 29,712 381 312,030
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
968,087 87,893 682,250 208,511 146,331 175,961 307,356 81,244 1,199,674 300,185 16,416,349
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
- --------- --------- ----------- ----------- ----------- --------- --------- --------- ----------- ------------- ----------
A-7
OGLETHORPE POWER CORPORATION
MEMBER FINANCIAL AND STATISTICAL INFORMATION
TABLE 4
ANNUAL REVENUES BY CONSUMER CLASS OF EACH MEMBER (1)
CENTRAL
ALTAMAHA AMICALOLA CANOOCHEE CARROLL GEORGIA COASTAL COBB
----------- ----------- ----------- ----------- ----------- ----------- -------------
1996
- -----------------------------------
Residential Service................ $15,397,747 $25,431,363 $16,710,104 $30,602,655 $27,881,595 $11,005,687 $ 129,223,081
Commercial & Industrial............ 7,336,008 3,678,005 4,454,093 12,040,453 6,735,877 3,133,582 49,061,268
Other.............................. 129,822 12,029 188,310 385,925 44,193 104,082 9,977,181
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Electric Sales............. $22,863,577 $29,121,397 $21,352,507 $43,029,033 $34,661,665 $14,243,351 $ 188,261,530
Other Operating Revenue............ 314,778 1,134,841 149,790 458,124 1,396,259 301,933 4,756,324
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Operating Revenue.......... $23,178,355 $30,256,238 $21,502,297 $43,487,157 $36,057,924 $14,545,284 $ 193,017,854
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1995
- -----------------------------------
Residential Service................ $14,960,330 $24,420,513 $15,954,042 $29,087,323 $28,008,567 $10,491,674 $ 124,448,118
Commercial & Industrial............ 6,426,889 3,325,420 4,303,301 11,880,051 6,049,246 3,250,333 45,107,329
Other.............................. 133,224 383,195 146,300 368,120 47,050 100,289 9,770,596
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Electric Sales............. $21,520,443 $28,129,128 $20,403,643 $41,335,494 $34,104,863 $13,842,296 $ 179,326,043
Other Operating Revenue............ 306,744 977,329 134,478 465,360 781,238 301,003 4,453,285
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Operating Revenue.......... $21,827,187 $29,106,457 $20,538,121 $41,800,854 $34,886,101 $14,143,299 $ 183,779,328
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1994
- -----------------------------------
Residential Service................ $13,629,657 $21,368,018 $14,655,563 $26,520,188 $24,715,118 $ 9,068,768 $ 114,176,385
Commercial & Industrial............ 5,821,048 3,084,049 4,129,309 11,161,446 5,347,654 2,727,683 43,907,247
Other.............................. 106,505 9,695 91,048 335,622 42,916 88,758 9,157,976
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Electric Sales............. $19,557,210 $24,461,762 $18,875,920 $38,017,256 $30,105,686 $11,885,209 $ 167,241,608
Other Operating Revenue............ 187,732 927,860 129,134 2,321,961 639,206 260,888 3,975,350
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Operating Revenue.......... $19,744,942 $25,389,622 $19,005,054 $40,339,217 $30,744,892 $12,146,097 $ 171,216,958
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
COWETA-
COLQUITT FAYETTE
----------- -----------
1996
- -----------------------------------
Residential Service................ $43,657,833 $47,564,622
Commercial & Industrial............ 8,259,766 12,783,191
Other.............................. 5,051,834 430,652
----------- -----------
Total Electric Sales............. $56,969,433 $60,778,465
Other Operating Revenue............ 1,211,893 324,105
----------- -----------
Total Operating Revenue.......... $58,181,326 $61,102,570
----------- -----------
----------- -----------
1995
- -----------------------------------
Residential Service................ $42,213,494 $46,789,991
Commercial & Industrial............ 7,934,026 11,483,856
Other.............................. 4,788,308 435,297
----------- -----------
Total Electric Sales............. $54,935,828 $58,709,144
Other Operating Revenue............ 1,092,680 947,967
----------- -----------
Total Operating Revenue.......... $56,028,508 $59,657,111
----------- -----------
----------- -----------
1994
- -----------------------------------
Residential Service................ $38,103,102 $39,772,144
Commercial & Industrial............ 7,145,892 9,964,317
Other.............................. 4,188,939 538,516
----------- -----------
Total Electric Sales............. $49,437,933 $50,274,977
Other Operating Revenue............ 990,088 931,813
----------- -----------
Total Operating Revenue.......... $50,428,021 $51,206,790
----------- -----------
----------- -----------
MIDDLE OKEFE-
GEORGIA MITCHELL OCMULGEE OCONEE NOKE(2) PATAULA PLANTERS
----------- ----------- ----------- ----------- ----------- ----------- -------------
1996
- -----------------------------------
Residential Service................ $ 4,685,286 NA $ 8,572,691 $10,546,690 $25,223,021 $ 3,214,404 $ 12,921,032
Commercial & Industrial............ 2,263,551 NA 1,822,642 5,254,167 2,958,376 1,154,810 1,026,554
Other.............................. 446,710 NA 354,769 234,466 591,847 233,056 440,864
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Electric Sales............. $ 7,395,547 NA $10,750,102 $16,035,323 $28,773,244 $ 4,602,270 $ 14,388,450
Other Operating Revenue............ 121,779 NA 255,093 78,810 642,299 86,791 380,977
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Operating Revenue.......... $ 7,517,326 NA $11,005,195 $16,114,133 $29,415,543 $ 4,689,061 $ 14,769,427
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1995
- -----------------------------------
Residential Service................ $ 4,923,224 $21,003,355 $ 8,722,860 $10,322,787 $25,373,143 $ 3,182,397 $ 12,582,079
Commercial & Industrial............ 2,452,478 3,959,059 1,725,239 5,219,557 2,823,508 968,612 1,090,770
Other.............................. 477,322 1,634,981 350,680 222,134 454,583 267,994 420,313
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Electric Sales............. $ 7,853,024 $26,597,395 $10,798,779 $15,764,478 $28,651,234 $ 4,419,003 $ 14,093,162
Other Operating Revenue............ 123,785 876,119 245,437 66,531 665,738 83,204 255,814
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Operating Revenue.......... $ 7,976,809 $27,473,514 $11,044,216 $15,831,009 $29,316,972 $ 4,502,207 $ 14,348,976
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1994
- -----------------------------------
Residential Service................ $ 4,434,279 $18,722,405 $ 7,936,975 $ 9,236,251 $22,853,508 $ 2,899,970 $ 11,880,724
Commercial & Industrial............ 2,046,137 3,614,615 1,474,142 5,402,277 2,473,957 816,103 999,634
Other.............................. 171,215 799,478 166,238 182,571 43,800 130,313 385,247
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Electric Sales............. $ 6,651,631 $23,136,498 $ 9,577,355 $14,821,099 $25,371,265 $ 3,846,386 $ 13,265,605
Other Operating Revenue............ 113,030 715,755 218,116 24,341 596,084 77,221 172,095
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Operating Revenue.......... $ 6,764,661 $23,852,253 $ 9,795,471 $14,845,440 $25,967,349 $ 3,923,607 $ 13,437,700
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
RAYLE SATILLA
----------- -----------
1996
- -----------------------------------
Residential Service................ $13,343,438 $38,574,185
Commercial & Industrial............ 2,011,881 4,589,701
Other.............................. 0 1,098,887
----------- -----------
Total Electric Sales............. $15,355,319 $44,262,773
Other Operating Revenue............ -399,434 1,474,354
----------- -----------
Total Operating Revenue.......... $14,955,885 $45,737,127
----------- -----------
----------- -----------
1995
- -----------------------------------
Residential Service................ $13,483,920 $39,289,316
Commercial & Industrial............ 2,211,522 4,426,593
Other.............................. 0 1,078,912
----------- -----------
Total Electric Sales............. $15,695,442 $44,794,821
Other Operating Revenue............ 81,784 1,442,918
----------- -----------
Total Operating Revenue.......... $15,777,226 $46,237,739
----------- -----------
----------- -----------
1994
- -----------------------------------
Residential Service................ $12,133,726 $34,319,251
Commercial & Industrial............ 2,131,273 3,918,707
Other.............................. 0 883,067
----------- -----------
Total Electric Sales............. $14,264,999 $39,121,025
Other Operating Revenue............ 115,412 1,323,395
----------- -----------
Total Operating Revenue.......... $14,380,411 $40,444,420
----------- -----------
----------- -----------
- ------------------------
(1) NA = Not Available
(2) Includes information relating to Okefenoke Rural EMC's operations in both
Georgia and Florida. Okefenoke Rural EMC purchases a portion of its power
and energy from an electric supplier in Florida. In 1996, such energy
amounted to approximately 26% of its total energy requirements.
A-8
TABLE 4 (CONTINUED)
EXCELSIOR FLINT GRADY GREYSTONE HABERSHAM HART IRWIN JACKSON JEFFERSON
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 14,905,466 $51,726,415 $14,945,512 $60,214,615 $19,066,690 $23,261,436 $ 9,449,941 $ 108,864,367 $ 29,033,356
2,889,136 21,587,914 1,258,316 22,289,990 4,245,885 7,926,007 1,436,481 53,777,842 2,932,475
187,413 1,621,204 814,237 616,719 7,903 0 474,849 6,410,907 370,990
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 17,982,015 $74,935,533 $17,018,065 $83,121,324 $23,320,478 $31,187,443 $11,361,271 $ 169,053,116 $ 32,336,821
281,708 1,705,721 611,478 2,006,141 440,380 975,657 198,335 5,211,161 1,006,931
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 18,263,723 $76,641,254 $17,629,543 $85,127,465 $23,760,858 $32,163,100 $11,559,606 $ 174,264,277 $ 33,343,752
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 14,189,915 $51,067,799 $14,456,906 $60,505,609 $18,121,940 $21,348,639 $ 8,992,473 $ 107,585,286 $ 29,368,534
2,596,239 22,072,374 1,176,342 21,318,543 4,141,890 7,284,568 1,598,910 51,878,517 2,927,924
141,698 1,652,835 828,460 565,154 8,170 0 427,259 5,621,245 365,715
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 16,927,852 $74,793,008 $16,461,708 $82,389,306 $22,272,000 $28,633,207 $11,018,642 $ 165,085,048 $ 32,662,173
371,380 723,445 261,778 1,877,678 403,820 920,191 196,846 1,493,543 893,210
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 17,299,232 $75,516,453 $16,723,486 $84,266,984 $22,675,820 $29,553,398 $11,215,488 $ 166,578,591 $ 33,555,383
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 12,964,157 $46,704,011 $13,006,745 $52,401,607 $16,528,905 $19,273,810 $ 8,494,593 $ 98,437,728 $ 26,466,689
2,322,274 20,837,092 1,045,835 19,114,116 3,629,437 6,488,462 1,321,485 49,130,967 2,599,192
122,836 1,494,841 735,777 529,254 7,849 0 294,015 2,878,212 313,562
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 15,409,267 $69,035,944 $14,788,357 $72,044,977 $20,166,191 $25,762,272 $10,110,093 $ 150,446,907 $ 29,379,443
-444,248 2,176,541 545,497 1,423,371 375,071 829,076 186,623 -333,627 899,155
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 14,965,019 $71,212,485 $15,333,854 $73,468,348 $20,541,262 $26,591,348 $10,296,716 $ 150,113,280 $ 30,278,598
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
LITTLE
EXCELSIOR LAMAR OCMULGEE
- ------------- ------------ --------------
$ 14,905,466 $12,978,930 $ 8,226,645
2,889,136 2,213,667 1,241,715
187,413 203,302 316,048
- ------------- ------------ --------------
$ 17,982,015 $15,395,899 $ 9,784,408
281,708 466,364 128,045
- ------------- ------------ --------------
$ 18,263,723 $15,862,263 $ 9,912,453
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 14,189,915 $12,496,940 $ 7,803,216
2,596,239 2,047,781 1,234,220
141,698 130,786 253,191
- ------------- ------------ --------------
$ 16,927,852 $14,675,507 $ 9,290,627
371,380 416,852 130,674
- ------------- ------------ --------------
$ 17,299,232 $15,092,359 $ 9,421,301
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 12,964,157 $10,944,224 $ 7,228,977
2,322,274 1,796,518 1,192,873
122,836 77,671 194,999
- ------------- ------------ --------------
$ 15,409,267 $12,818,413 $ 8,616,849
-444,248 391,015 129,397
- ------------- ------------ --------------
$ 14,965,019 $13,209,428 $ 8,746,246
- ------------- ------------ --------------
- ------------- ------------ --------------
SLASH SNAPPING THREE TRI- UPSON
SAWNEE PINE SHOALS SUMTER NOTCH COUNTY TROUP COUNTY WALTON
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 78,274,899 $ 5,724,048 $52,066,299 $14,476,505 $11,157,260 $14,371,233 $21,472,115 $ 6,532,561 $ 77,570,054
26,006,350 1,657,050 10,573,357 4,878,576 1,881,433 2,995,344 5,483,185 1,152,868 25,439,115
1,538,739 331,842 5,107 443,272 830,186 0 531,450 128,491 3,372,515
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 105,819,988 $ 7,712,940 $62,644,763 $19,798,353 $13,868,879 $17,366,577 $27,486,750 $ 7,813,920 $ 106,381,684
379,618 44,123 1,410,751 -55,656 211,741 601,772 749,352 195,046 1,834,917
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 106,199,606 $ 7,757,063 $64,055,514 $19,742,697 $14,080,620 $17,968,349 $28,236,102 $ 8,008,966 $ 108,216,601
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 73,872,717 $ 5,589,263 $50,970,969 $13,878,776 $12,763,902 $13,556,426 $21,925,663 $ 6,168,920 $ 77,948,750
24,032,487 1,629,172 10,133,343 4,617,537 942,249 2,912,686 5,413,059 1,100,288 24,741,810
1,441,223 331,399 19,894 576,472 71,932 0 579,500 119,217 3,275,711
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 99,346,427 $ 7,549,834 $61,124,206 $19,072,785 $13,778,083 $16,469,112 $27,918,222 $ 7,388,425 $ 105,966,271
391,440 44,992 1,263,673 20,930 211,673 523,094 372,950 167,938 1,718,444
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 99,737,867 $ 7,594,826 $62,387,879 $19,093,715 $13,989,756 $16,992,206 $28,291,172 $ 7,556,363 $ 107,684,715
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 60,277,551 $ 4,884,452 $45,424,799 $12,583,235 $11,163,332 $11,970,430 $19,744,397 $ 5,715,668 $ 68,947,331
20,700,491 1,357,506 9,429,852 4,180,289 1,056,507 2,658,639 5,317,891 970,141 23,067,545
1,119,710 302,258 0 336,998 44,804 0 577,540 139,831 2,894,135
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 82,097,752 $ 6,544,216 $54,854,651 $17,100,522 $12,264,643 $14,629,069 $25,639,828 $ 6,825,640 $ 94,909,011
3,454,623 45,706 1,175,484 -11,308 196,721 377,095 342,878 183,153 2,279,854
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
$ 85,552,375 $ 6,589,922 $56,030,135 $17,089,214 $12,461,364 $15,006,164 $25,982,706 $ 7,008,793 $ 97,188,865
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
- ------------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- -------------
SAWNEE WASHINGTON TOTAL
- ------------- ------------ --------------
$ 78,274,899 $12,138,346 $1,111,012,127
26,006,350 8,933,996 339,364,627
1,538,739 35,961 37,965,762
- ------------- ------------ --------------
$ 105,819,988 $21,108,303 $1,488,342,516
379,618 -141,523 30,950,778
- ------------- ------------ --------------
$ 106,199,606 $20,966,780 $1,519,293,294
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 73,872,717 $11,715,735 $1,109,585,511
24,032,487 9,303,194 327,740,922
1,441,223 38,982 37,528,141
- ------------- ------------ --------------
$ 99,346,427 $21,057,911 $1,474,854,574
391,440 221,942 25,927,907
- ------------- ------------ --------------
$ 99,737,867 $21,279,853 $1,500,782,481
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 60,277,551 $10,368,678 $ 989,957,351
20,700,491 9,151,258 303,533,860
1,119,710 32,779 29,418,975
- ------------- ------------ --------------
$ 82,097,752 $19,552,715 $1,322,910,186
3,454,623 236,757 28,178,315
- ------------- ------------ --------------
$ 85,552,375 $19,789,472 $1,351,088,501
- ------------- ------------ --------------
- ------------- ------------ --------------
A-9
OGLETHORPE POWER CORPORATION
MEMBER FINANCIAL AND STATISTICAL INFORMATION
TABLE 5
SUMMARY OF OPERATING RESULTS OF EACH MEMBER
CENTRAL
ALTAMAHA AMICALOLA CANOOCHEE CARROLL GEORGIA COASTAL
----------- ----------- ----------- ----------- ----------- -----------
1996
Operating Revenue and Patronage Capital.... $23,178,355 $30,256,238 2$1,502,297 $43,487,157 $36,057,924 $14,545,284
Depreciation and Amortization.............. 1,347,834 2,378,263 1,327,694 2,842,770 2,624,803 889,945
Other Operating Expenses................... 19,231,960 24,573,139 17,506,714 36,153,599 29,250,606 12,138,956
----------- ----------- ----------- ----------- ----------- -----------
Electric Operating Margin................ $ 2,598,561 $ 3,304,836 $2,667,889 $ 4,490,788 $ 4,182,515 $ 1,516,383
Other Income............................... 694,842 621,649 467,212 934,572 814,198 217,395
----------- ----------- ----------- ----------- ----------- -----------
Gross Operating Margin................... $ 3,293,403 $ 3,926,485 $3,135,101 $ 5,425,360 $ 4,996,713 $ 1,733,778
Interest on Long-term Debt................. 1,134,702 2,280,821 1,100,870 2,016,480 1,819,295 1,054,585
Other Deductions........................... 110,384 8,872 1,152 62,288 0 73,224
----------- ----------- ----------- ----------- ----------- -----------
Net Margins............................ $ 2,048,317 $ 1,636,792 $2,033,079 $ 3,346,592 $ 3,177,418 $ 605,969
----------- ----------- ----------- ----------- ----------- -----------
----------- ----------- ----------- ----------- ----------- -----------
1995
Operating Revenue and Patronage Capital.... $21,827,187 $29,106,457 2$0,538,121 $41,800,852 $34,886,101 $14,143,299
Depreciation and Amortization.............. 1,265,192 2,234,634 1,261,498 2,500,606 2,087,101 809,468
Other Operating Expenses................... 17,742,016 23,594,551 17,154,552 36,066,571 30,068,950 11,767,343
----------- ----------- ----------- ----------- ----------- -----------
Electric Operating Margin................ $ 2,819,979 $ 3,277,272 $2,122,071 $ 3,233,675 $ 2,730,050 $ 1,566,488
Other Income............................... 584,960 727,666 410,040 933,691 888,651 265,151
----------- ----------- ----------- ----------- ----------- -----------
Gross Operating Margin................... $ 3,404,939 $ 4,004,938 $2,532,111 $ 4,167,366 $ 3,618,701 $ 1,831,639
Interest on Long-term Debt................. 849,645 2,185,795 1,071,592 2,050,629 1,760,592 941,668
Other Deductions........................... 109,376 12,094 0 24,501 0 69,208
----------- ----------- ----------- ----------- ----------- -----------
Net Margins............................ $ 2,445,918 $ 1,807,049 $1,460,519 $ 2,092,236 $ 1,858,109 $ 820,763
----------- ----------- ----------- ----------- ----------- -----------
----------- ----------- ----------- ----------- ----------- -----------
1994
Operating Revenue and Patronage Capital.... $19,744,942 $25,389,622 1$9,005,054 $40,339,217 $30,744,892 $12,146,097
Depreciation and Amortization.............. 1,202,864 2,068,801 1,179,374 2,533,874 2,264,849 729,265
Other Operating Expenses................... 16,218,772 21,035,284 15,558,769 33,532,027 26,146,544 10,385,376
----------- ----------- ----------- ----------- ----------- -----------
Electric Operating Margin................ $ 2,323,306 $ 2,285,537 $2,266,911 $ 4,273,316 $ 2,333,499 $ 1,031,456
Other Income............................... 384,560 650,681 431,381 951,413 720,311 271,268
----------- ----------- ----------- ----------- ----------- -----------
Gross Operating Margin................... $ 2,707,866 $ 2,936,218 $2,698,292 $ 5,224,729 $ 3,053,810 $ 1,302,724
Interest on Long-term Debt................. 757,193 1,871,683 909,904 1,745,745 1,462,415 809,133
Other Deductions........................... 115,587 49,251 0 35,800 41,618 55,082
----------- ----------- ----------- ----------- ----------- -----------
Net Margins............................ $ 1,835,086 $ 1,015,284 $1,788,388 $ 3,443,184 $ 1,549,777 $ 438,509
----------- ----------- ----------- ----------- ----------- -----------
----------- ----------- ----------- ----------- ----------- -----------
COWETA-
COBB COLQUITT FAYETTE
------------- ----------- -----------
1996
Operating Revenue and Patronage Capital.... $ 193,017,854 $58,181,326 $61,102,570
Depreciation and Amortization.............. 8,742,374 2,758,976 3,483,312
Other Operating Expenses................... 171,871,205 49,014,039 52,036,510
------------- ----------- -----------
Electric Operating Margin................ $ 12,404,275 $ 6,408,311 $ 5,582,748
Other Income............................... 3,972,847 1,418,584 1,357,165
------------- ----------- -----------
Gross Operating Margin................... $ 16,377,122 $ 7,826,895 $ 6,939,913
Interest on Long-term Debt................. 9,666,964 2,329,067 3,309,895
Other Deductions........................... 1,176,098 0 570,434
------------- ----------- -----------
Net Margins............................ $ 5,534,060 $ 5,497,828 $ 3,059,584
------------- ----------- -----------
------------- ----------- -----------
1995
Operating Revenue and Patronage Capital.... $ 183,779,328 $56,028,508 $59,657,111
Depreciation and Amortization.............. 8,101,420 2,586,462 3,126,469
Other Operating Expenses................... 162,026,092 48,373,726 51,750,356
------------- ----------- -----------
Electric Operating Margin................ $ 13,651,816 $ 5,068,320 $ 4,780,286
Other Income............................... 4,148,093 1,279,399 1,193,269
------------- ----------- -----------
Gross Operating Margin................... $ 17,799,909 $ 6,347,719 $ 5,973,555
Interest on Long-term Debt................. 9,205,880 2,223,045 3,246,890
Other Deductions........................... 1,062,512 0 190,735
------------- ----------- -----------
Net Margins............................ $ 7,531,517 $ 4,124,674 $ 2,535,930
------------- ----------- -----------
------------- ----------- -----------
1994
Operating Revenue and Patronage Capital.... $ 171,216,958 $50,428,021 $51,206,790
Depreciation and Amortization.............. 7,502,423 2,439,285 2,859,899
Other Operating Expenses................... 148,164,763 44,706,743 44,970,380
------------- ----------- -----------
Electric Operating Margin................ $ 15,549,772 $ 3,281,993 $ 3,376,511
Other Income............................... 3,683,379 1,283,373 1,099,466
------------- ----------- -----------
Gross Operating Margin................... $ 19,233,151 $ 4,565,366 $ 4,475,977
Interest on Long-term Debt................. 8,110,516 1,938,473 2,528,572
Other Deductions........................... 760,032 0 275,658
------------- ----------- -----------
Net Margins............................ $ 10,362,603 $ 2,626,893 $ 1,671,747
------------- ----------- -----------
------------- ----------- -----------
MIDDLE OKEFE-
GEORGIA MITCHELL OCMULGEE OCONEE NOKE(1) PATAULA
----------- ----------- ----------- ----------- ----------- -----------
1996
Operating Revenue and Patronage Capital.... $ 7,517,326 $29,748,002 1$1,005,195 $16,114,133 $29,415,543 $ 4,689,061
Depreciation and Amortization.............. 582,465 1,726,985 629,201 808,910 2,122,450 277,524
Other Operating Expenses................... 5,926,887 24,742,724 8,802,333 13,716,304 25,334,554 3,791,843
----------- ----------- ----------- ----------- ----------- -----------
Electric Operating Margin................ $ 1,007,974 $ 3,278,293 $1,573,661 $ 1,588,919 $ 1,958,539 $ 619,694
Other Income............................... 207,602 450,051 432,063 334,635 1,543,500 120,258
----------- ----------- ----------- ----------- ----------- -----------
Gross Operating Margin................... $ 1,215,576 $ 3,728,344 $2,005,724 $ 1,923,554 $ 3,502,039 $ 739,952
Interest on Long-term Debt................. 562,952 1,485,702 664,861 717,588 1,856,403 177,141
Other Deductions........................... 37,222 402,847 14,018 14,865 248,776 0
----------- ----------- ----------- ----------- ----------- -----------
Net Margins............................ $ 615,402 $ 1,839,795 $1,326,845 $ 1,191,101 $ 1,396,860 $ 562,811
----------- ----------- ----------- ----------- ----------- -----------
----------- ----------- ----------- ----------- ----------- -----------
1995
Operating Revenue and Patronage Capital.... $ 7,976,809 $27,473,514 1$1,044,216 $15,831,009 $29,316,972 $ 4,502,207
Depreciation and Amortization.............. 559,308 1,404,032 603,215 754,565 2,001,800 251,543
Other Operating Expenses................... 6,423,046 24,443,833 9,554,730 13,802,171 24,845,555 3,750,941
----------- ----------- ----------- ----------- ----------- -----------
Electric Operating Margin................ $ 994,455 $ 1,625,649 $ 886,271 $ 1,274,273 $ 2,469,617 $ 499,723
Other Income............................... 200,533 1,011,598 348,660 354,857 1,671,083 117,299
----------- ----------- ----------- ----------- ----------- -----------
Gross Operating Margin................... $ 1,194,988 $ 2,637,247 $1,234,931 $ 1,629,130 $ 4,140,700 $ 617,022
Interest on Long-term Debt................. 534,709 1,485,458 606,560 749,090 2,129,783 183,304
Other Deductions........................... 58,323 -894,440 7,299 11,300 801,384 459
----------- ----------- ----------- ----------- ----------- -----------
Net Margins............................ $ 601,956 $ 2,046,229 $ 621,072 $ 868,740 $ 1,209,533 $ 433,259
----------- ----------- ----------- ----------- ----------- -----------
----------- ----------- ----------- ----------- ----------- -----------
1994
Operating Revenue and Patronage Capital.... $ 6,764,661 $23,851,984 $9,795,471 $14,845,440 $25,967,349 $ 3,923,607
Depreciation and Amortization.............. 524,669 1,307,917 575,314 709,922 1,802,521 239,882
Other Operating Expenses................... 5,538,469 22,876,882 8,078,819 13,300,270 23,166,991 3,328,521
----------- ----------- ----------- ----------- ----------- -----------
Electric Operating Margin................ $ 701,523 ($ 332,815) $1,141,338 $ 835,248 $ 997,837 $ 355,204
Other Income............................... 203,924 556,380 335,955 330,625 2,310,696 107,859
----------- ----------- ----------- ----------- ----------- -----------
Gross Operating Margin................... $ 905,447 $ 223,565 $1,477,293 $ 1,165,873 $ 3,308,533 $ 463,063
Interest on Long-term Debt................. 495,507 954,076 572,300 652,864 2,069,598 177,037
Other Deductions........................... 32,709 -2,423,513 5,238 15,060 116,285 400
----------- ----------- ----------- ----------- ----------- -----------
Net Margins............................ $ 377,231 $ 1,693,002 $ 899,755 $ 497,949 $ 1,122,650 $ 285,626
----------- ----------- ----------- ----------- ----------- -----------
----------- ----------- ----------- ----------- ----------- -----------
PLANTERS RAYLE SATILLA
------------- ----------- -----------
1996
Operating Revenue and Patronage Capital.... $ 14,769,428 $14,955,885 $45,737,127
Depreciation and Amortization.............. 1,049,412 1,172,314 2,284,764
Other Operating Expenses................... 12,462,804 12,184,879 40,564,468
------------- ----------- -----------
Electric Operating Margin................ $ 1,257,212 $ 1,598,692 $ 2,887,895
Other Income............................... 507,871 433,295 1,000,461
------------- ----------- -----------
Gross Operating Margin................... $ 1,765,083 $ 2,031,987 $ 3,888,356
Interest on Long-term Debt................. 667,577 1,051,195 1,591,911
Other Deductions........................... 6,944 16,935 245,181
------------- ----------- -----------
Net Margins............................ $ 1,090,562 $ 963,857 $ 2,051,264
------------- ----------- -----------
------------- ----------- -----------
1995
Operating Revenue and Patronage Capital.... $ 14,348,976 $15,777,226 $46,237,739
Depreciation and Amortization.............. 990,725 1,190,547 2,140,930
Other Operating Expenses................... 12,021,789 13,315,288 41,229,784
------------- ----------- -----------
Electric Operating Margin................ $ 1,336,462 $ 1,271,391 $ 2,867,025
Other Income............................... 447,726 456,560 1,336,043
------------- ----------- -----------
Gross Operating Margin................... $ 1,784,188 $ 1,727,951 $ 4,203,068
Interest on Long-term Debt................. 610,329 1,079,132 1,590,117
Other Deductions........................... 10,417 21,740 37,130
------------- ----------- -----------
Net Margins............................ $ 1,163,442 $ 627,079 $ 2,575,821
------------- ----------- -----------
------------- ----------- -----------
1994
Operating Revenue and Patronage Capital.... $ 13,437,700 $14,380,411 $40,444,421
Depreciation and Amortization.............. 931,195 1,203,794 2,001,050
Other Operating Expenses................... 11,228,129 11,991,995 35,342,538
------------- ----------- -----------
Electric Operating Margin................ $ 1,278,376 $ 1,184,622 $ 3,100,833
Other Income............................... 415,305 301,695 1,096,472
------------- ----------- -----------
Gross Operating Margin................... $ 1,693,681 $ 1,486,317 $ 4,197,305
Interest on Long-term Debt................. 535,518 816,664 1,315,655
Other Deductions........................... 28,110 47,831 37,130
------------- ----------- -----------
Net Margins............................ $ 1,130,053 $ 621,822 $ 2,844,520
------------- ----------- -----------
------------- ----------- -----------
- ----------------------------------------
(1) Includes information relating to Okefenoke Rural EMC's operations in both
Georgia and Florida. Okefenoke Rural EMC purchases a portion of its power
and energy from an electric supplier in Florida. In 1996, such energy
amounted to approximately 26% of its total energy requirements.
A-10
TABLE 5 (CONTINUED)
EXCELSIOR FLINT GRADY GREYSTONE HABERSHAM HART IRWIN JACKSON JEFFERSON LAMAR
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$18,263,723 $76,641,254 $17,624,644 $85,127,465 $23,760,858 $32,163,100 $11,559,605 $ 174,264,277 $33,343,751 $15,862,263
1,032,872 4,324,380 1,118,247 3,413,536 1,640,028 1,867,995 841,357 7,860,818 1,793,192 707,715
15,898,636 66,334,944 15,206,854 71,523,808 20,468,567 25,863,543 9,764,114 151,813,967 28,875,794 13,885,071
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 1,332,215 $ 5,981,930 $ 1,299,543 $10,190,121 $ 1,652,263 $ 4,431,562 $ 954,134 $ 14,589,492 $ 2,674,765 $ 1,269,477
603,438 1,669,733 354,017 1,915,361 553,525 702,082 264,136 3,868,904 609,917 473,252
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 1,935,653 $ 7,651,663 $ 1,653,560 $12,105,482 $ 2,205,788 $ 5,133,644 $ 1,218,270 $ 18,458,396 $ 3,284,682 $ 1,742,729
976,266 2,974,578 793,735 3,250,972 1,105,836 1,449,963 673,442 8,701,681 1,542,645 474,877
12,815 55,746 88,577 209,091 73,038 25,813 25,930 731,906 85,052 0
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 946,572 $ 4,621,339 $ 771,248 $ 8,645,419 $ 1,026,914 $ 3,657,868 $ 518,898 $ 9,024,809 $ 1,656,985 $ 1,267,852
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$17,299,232 $75,516,453 $16,723,486 $84,266,984 $22,675,820 $29,553,398 $11,215,488 $ 166,578,591 $33,555,383 $15,092,358
942,853 4,055,184 1,075,274 3,193,929 1,503,095 1,682,576 772,638 7,222,083 1,678,790 602,036
15,306,379 67,187,225 14,763,736 72,612,625 19,622,026 25,761,686 9,555,777 145,748,027 29,641,714 13,766,945
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 1,050,000 $ 4,274,044 $ 884,476 $ 8,460,430 $ 1,550,699 $ 2,109,136 $ 887,073 $ 13,608,481 $ 2,234,879 $ 723,377
585,825 1,648,980 313,630 1,879,789 572,846 752,445 226,149 4,138,725 636,246 450,973
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 1,635,825 $ 5,923,024 $ 1,198,106 $10,340,219 $ 2,123,545 $ 2,861,581 $ 1,113,222 $ 17,747,206 $ 2,871,125 $ 1,174,350
862,653 2,592,128 701,072 3,403,739 1,120,964 1,426,046 664,103 8,983,845 1,546,223 476,350
14,256 44,255 108,589 145,506 15,627 4,685 3,610 43,216 64,560 0
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 758,916 $ 3,286,641 $ 388,445 $ 6,790,974 $ 986,954 $ 1,430,850 $ 445,509 $ 8,720,145 $ 1,260,342 $ 698,000
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$14,965,019 $71,212,485 $15,333,854 $73,468,348 $20,541,261 $26,591,348 $10,296,716 $ 150,113,280 $30,278,598 $13,209,428
856,090 3,672,952 1,056,910 2,922,381 1,339,183 1,546,706 725,265 6,664,339 1,555,099 551,293
13,182,530 62,099,637 13,227,167 65,863,142 20,550,336 24,003,135 8,807,691 133,565,037 26,301,438 11,855,600
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 926,399 $ 5,439,896 $ 1,049,777 $ 4,682,825 ($1,348,258) $ 1,041,507 $ 763,760 $ 9,883,904 $ 2,422,061 $ 802,535
520,194 1,787,802 325,415 1,789,617 522,534 720,272 247,680 3,656,107 651,793 361,071
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 1,446,593 $ 7,227,698 $ 1,375,192 $ 6,472,442 ($ 825,724) $ 1,761,779 $ 1,011,440 $ 13,540,011 $ 3,073,854 $ 1,163,606
756,827 2,216,451 568,087 2,762,351 866,785 1,126,406 536,597 7,207,812 1,306,044 322,218
15,793 28,496 2,064 395,407 48,515 10,500 12,138 69,477 45,732 0
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
$ 673,973 $ 4,982,751 $ 805,041 $ 3,314,684 ($1,741,024) $ 624,873 $ 462,705 $ 6,262,722 $ 1,722,078 $ 841,388
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
- ----------- ----------- ----------- ----------- ----------- ----------- ----------- ------------- ----------- -----------
LITTLE
EXCELSIOR OCMULGEE
- ----------- --------------
$18,263,723 $ 9,912,451
1,032,872 678,796
15,898,636 8,256,043
- ----------- --------------
$ 1,332,215 $ 977,612
603,438 329,502
- ----------- --------------
$ 1,935,653 $ 1,307,114
976,266 748,873
12,815 31,978
- ----------- --------------
$ 946,572 $ 526,263
- ----------- --------------
- ----------- --------------
$17,299,232 $ 9,421,301
942,853 641,275
15,306,379 7,732,420
- ----------- --------------
$ 1,050,000 $ 1,047,606
585,825 279,390
- ----------- --------------
$ 1,635,825 $ 1,326,996
862,653 763,520
14,256 39,222
- ----------- --------------
$ 758,916 $ 524,254
- ----------- --------------
- ----------- --------------
$14,965,019 $ 8,746,246
856,090 623,101
13,182,530 7,082,538
- ----------- --------------
$ 926,399 $ 1,040,607
520,194 230,137
- ----------- --------------
$ 1,446,593 $ 1,270,744
756,827 622,699
15,793 63,661
- ----------- --------------
$ 673,973 $ 584,384
- ----------- --------------
- ----------- --------------
SLASH SNAPPING THREE TRI- UPSON
SAWNEE PINE SHOALS SUMTER NOTCH COUNTY TROUP COUNTY WALTON WASHINGTON
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 106,199,605 $7,757,063 $64,055,514 $19,742,697 $14,080,620 $17,968,349 $28,236,102 $8,008,966 $ 108,216,601 $20,966,780
5,461,439 347,392 3,149,513 1,364,107 724,564 1,087,677 1,689,778 345,917 4,784,938 1,120,202
90,138,664 6,645,532 58,638,522 17,044,494 12,215,197 14,375,621 23,148,170 6,841,940 95,041,808 18,147,494
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 10,599,502 $ 764,139 $ 2,267,479 $ 1,334,096 $ 1,140,859 $ 2,505,051 $ 3,398,154 $ 821,109 $ 8,389,855 $1,699,084
1,963,171 161,350 1,291,013 603,583 354,285 333,192 625,724 162,519 2,425,084 828,895
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 12,562,673 $ 925,489 $ 3,558,492 $ 1,937,679 $ 1,495,144 $ 2,838,243 $ 4,023,878 $ 983,628 $ 10,814,939 $2,527,979
5,767,038 363,039 1,687,796 990,057 599,282 1,096,312 1,317,856 209,258 3,209,510 1,246,947
631,716 6,909 583,546 8,498 18,791 46,005 112,967 1,001 98,925 19,163
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 6,163,919 $ 555,541 $ 1,287,150 $ 939,124 $ 877,071 $ 1,695,926 $ 2,593,055 $ 773,369 $ 7,506,504 $1,261,869
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 99,737,867 $7,594,826 $62,387,879 $19,093,715 $13,989,755 $16,992,206 $28,291,170 $7,556,363 $ 107,684,715 $21,279,853
4,835,543 314,311 2,912,891 1,129,572 725,790 1,035,992 1,573,631 333,446 4,427,546 1,135,431
88,339,450 6,722,621 55,760,048 16,685,944 12,291,452 14,387,170 23,911,842 6,819,168 94,907,445 18,219,068
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 6,562,874 $ 557,894 $ 3,714,940 $ 1,278,199 $ 972,513 $ 1,569,044 $ 2,805,697 $ 403,749 $ 8,349,724 $1,925,354
1,925,480 175,202 1,273,842 488,791 381,017 357,182 1,860,207 153,975 2,321,595 616,521
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 8,488,354 $ 733,096 $ 4,988,782 $ 1,766,990 $ 1,353,530 $ 1,926,226 $ 4,665,904 $ 557,724 $ 10,671,319 $2,541,875
5,084,334 313,562 2,288,847 864,786 506,044 1,074,470 1,314,612 219,276 3,379,073 1,087,822
388,338 26,743 121,553 14,094 50,640 87,689 40,352 12,699 134,758 61,974
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 3,015,682 $ 392,791 $ 2,578,382 $ 888,110 $ 796,846 $ 764,067 $ 3,310,940 $ 325,749 $ 7,157,488 $1,392,079
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 85,552,374 $6,589,923 $56,030,435 $17,089,214 $12,461,364 $15,006,164 $25,982,706 $7,008,793 $ 97,188,865 $19,789,472
4,295,517 276,763 2,658,720 1,057,058 629,248 987,137 2,121,162 314,327 4,123,354 1,061,073
74,696,589 5,896,828 50,383,831 14,865,526 11,037,210 12,815,226 21,893,313 6,240,264 88,880,042 17,421,168
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 6,560,268 $ 416,332 $ 2,987,884 $ 1,166,630 $ 794,906 $ 1,203,801 $ 1,968,231 $ 454,202 $ 4,185,469 $1,307,231
617,135 163,177 1,244,701 459,632 172,861 336,545 856,539 159,245 2,643,241 619,216
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 7,177,403 $ 579,509 $ 4,232,585 $ 1,626,262 $ 967,767 $ 1,540,346 $ 2,824,770 $ 613,447 $ 6,828,710 $1,926,447
4,549,544 226,892 1,247,393 714,263 452,243 912,598 1,354,308 186,556 3,049,546 1,043,587
219,766 12,022 639,899 13,059 34,320 101,303 92,920 18,212 108,074 62,469
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
$ 2,408,093 $ 340,595 $ 2,345,293 $ 898,940 $ 481,204 $ 526,445 $ 1,377,542 $ 408,679 $ 3,671,090 $ 820,391
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
- ------------- ---------- ----------- ----------- ----------- ----------- ----------- ---------- ------------- ------------
SAWNEE TOTAL
- ------------- --------------
$ 106,199,605 $1,549,036,393
5,461,439 82,404,459
90,138,664 1,329,432,307
- ------------- --------------
$ 10,599,502 $ 137,199,627
1,963,171 35,620,883
- ------------- --------------
$ 12,562,673 $ 172,820,510
5,767,038 72,667,972
631,716 5,856,707
- ------------- --------------
$ 6,163,919 $ 94,295,831
- ------------- --------------
- ------------- --------------
$ 99,737,867 $1,500,782,475
4,835,543 75,663,401
88,339,450 1,307,674,062
- ------------- --------------
$ 6,562,874 $ 117,445,012
1,925,480 37,414,089
- ------------- --------------
$ 8,488,354 $ 154,859,101
5,084,334 71,177,687
388,338 2,944,404
- ------------- --------------
$ 3,015,682 $ 80,737,010
- ------------- --------------
- ------------- --------------
$ 85,552,374 $1,351,088,530
4,295,517 71,114,576
74,696,589 1,186,239,520
- ------------- --------------
$ 6,560,268 $ 93,734,434
617,135 33,219,657
- ------------- --------------
$ 7,177,403 $ 126,954,091
4,549,544 59,752,060
219,766 1,186,105
- ------------- --------------
$ 2,408,093 $ 66,015,926
- ------------- --------------
- ------------- --------------
A-11
OGLETHORPE POWER CORPORATION
MEMBER FINANCIAL AND STATISTICAL INFORMATION
TABLE 6
CONDENSED BALANCE SHEET INFORMATION OF EACH MEMBER
(AS OF DECEMBER 31)
CENTRAL
ALTAMAHA AMICALOLA CANOOCHEE CARROLL GEORGIA COASTAL COBB
----------- ----------- ----------- ----------- ----------- ----------- -------------
1996
ASSETS
Total Utility Plant(1)...... $46,494,020 $81,272,483 4$3,763,526 $82,833,008 $71,250,678 $30,069,767 $ 304,134,816
Depreciation................ 9,343,487 19,397,260 6,672,946 17,812,567 16,239,124 3,571,034 35,480,700
----------- ----------- ----------- ----------- ----------- ----------- -------------
Net Plant................. 37,150,533 61,875,223 37,090,580 65,020,441 55,011,554 26,498,733 268,654,116
Other Assets................ 21,457,737 12,574,057 9,679,245 19,218,238 15,007,593 8,026,587 66,564,406
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Assets............ $58,608,270 $74,449,280 4$6,769,825 $84,238,679 $70,019,147 $34,525,320 $ 335,218,522
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
EQUITY & LIABILITIES
Equity...................... 33,090,210 22,791,617 21,712,517 35,026,516 32,606,506 10,176,157 112,747,182
Long-term Debt.............. 20,501,442 42,344,102 21,363,427 38,677,371 32,282,981 21,384,292 167,637,801
Other Liabilities........... 5,016,618 9,313,561 3,693,881 10,534,792 5,129,660 2,964,871 54,833,539
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Equity and
Liabilities............. $58,608,270 $74,449,280 4$6,769,825 $84,238,679 $70,019,147 $34,525,320 $ 335,218,522
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1995
ASSETS
Total Utility Plant(1)...... $43,786,119 $75,454,488 4$0,193,128 $77,421,541 $66,696,238 $28,230,229 $ 284,580,456
Depreciation................ 8,524,043 17,543,466 6,105,253 16,497,094 15,025,968 3,254,410 32,429,192
----------- ----------- ----------- ----------- ----------- ----------- -------------
Net Plant................. 35,262,076 57,911,022 34,087,875 60,924,447 51,670,270 24,975,819 252,151,264
Other Assets................ 18,415,270 12,792,350 9,079,764 19,277,185 16,598,343 6,014,398 69,253,378
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Assets............ $53,677,346 $70,703,372 4$3,167,639 $80,201,632 $68,268,613 $30,990,217 $ 321,404,642
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
EQUITY & LIABILITIES
Equity...................... 31,219,629 21,324,070 19,845,902 33,558,414 29,777,471 9,819,863 107,123,904
Long-term Debt.............. 18,233,962 40,691,010 19,883,729 38,148,158 33,093,348 18,062,463 167,773,144
Other Liabilities........... 4,223,755 8,688,292 3,438,008 8,495,060 5,397,794 3,107,891 46,507,594
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Equity and
Liabilities............. $53,677,346 $70,703,372 4$3,167,639 $80,201,632 $68,268,613 $30,990,217 $ 321,404,642
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1994
ASSETS
Total Utility Plant(1)...... $41,507,015 $70,023,965 3$6,518,986 $73,410,250 $62,936,313 $25,422,827 $ 266,314,487
Depreciation................ 7,655,198 15,838,578 5,675,872 15,240,339 13,985,793 3,013,285 28,805,182
Net Plant................. 33,851,817 54,185,387 30,843,114 58,169,911 48,950,520 22,409,542 237,509,305
Other Assets................ 15,570,224 11,834,238 8,756,465 16,852,601 13,777,905 6,294,637 63,558,975
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Assets.............. $49,422,041 $66,019,625 3$9,599,579 $75,022,512 $62,728,425 $28,704,179 $ 301,068,280
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
EQUITY & LIABILITIES
Equity...................... 29,339,499 19,702,374 18,518,560 31,522,750 28,445,939 9,104,239 99,540,332
Long-term Debt.............. 16,716,255 39,299,485 17,945,166 37,119,571 27,305,377 16,939,004 161,285,873
Other Liabilities........... 3,366,287 7,017,766 3,135,853 6,380,191 6,977,109 2,660,936 40,242,075
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Equity and
Liabilities............. $49,422,041 $66,019,625 3$9,599,579 $75,022,512 $62,728,425 $28,704,179 $ 301,068,280
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
MIDDLE OKEFE-
GEORGIA MITCHELL OCMULGEE OCONEE NOKE(2) PATAULA PLANTERS
----------- ----------- ----------- ----------- ----------- ----------- -------------
1996
ASSETS
Total Utility Plant(1)...... $20,295,664 $55,543,119 2$5,479,748 $29,227,736 $74,060,686 $ 9,573,988 $ 30,117,312
Depreciation................ 3,927,186 10,619,159 6,391,178 3,794,394 12,784,888 2,686,414 9,678,085
----------- ----------- ----------- ----------- ----------- ----------- -------------
Net Plant................. 16,368,478 44,923,960 19,088,570 25,433,342 61,275,798 6,887,574 20,439,227
Other Assets................ 4,038,241 18,551,785 7,514,388 8,110,441 20,611,109 2,311,431 11,284,999
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Assets............ $20,406,719 $63,475,745 2$6,602,958 $33,543,783 $81,886,907 $ 9,199,005 $ 31,724,226
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
EQUITY & LIABILITIES
Equity...................... 8,617,105 32,659,494 12,393,761 15,554,278 27,626,197 5,306,154 15,271,719
Long-term Debt.............. 10,982,858 22,592,992 11,796,526 14,425,612 37,731,213 3,415,815 13,093,374
Other Liabilities........... 806,756 8,223,259 2,412,671 3,563,893 16,529,497 477,036 3,359,133
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Equity and
Liabilities............. $20,406,719 $63,475,745 2$6,602,958 $33,543,783 $81,886,907 $ 9,199,005 $ 31,724,226
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1995
ASSETS
Total Utility Plant(1)...... $19,340,002 $52,713,498 2$3,803,300 $26,676,976 $69,397,160 $ 8,972,049 $ 28,678,584
Depreciation................ 3,528,789 10,069,745 5,993,494 3,887,355 11,493,558 2,531,224 9,094,482
----------- ----------- ----------- ----------- ----------- ----------- -------------
Net Plant................. 15,811,213 42,643,753 17,809,806 22,789,621 57,903,602 6,440,825 19,584,102
Other Assets................ 3,811,691 15,178,664 6,620,492 7,998,537 20,895,200 2,299,118 10,219,327
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Assets............ $19,622,904 $57,822,417 2$4,430,298 $30,788,158 $78,798,802 $ 8,739,943 $ 29,803,429
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
EQUITY & LIABILITIES
Equity...................... 7,989,770 29,434,088 11,428,344 14,667,424 26,332,076 4,741,224 14,492,906
Long-term Debt.............. 10,187,133 18,007,963 11,859,903 12,878,739 38,746,014 3,531,758 12,148,503
Other Liabilities........... 1,446,001 10,380,363 1,142,051 3,241,995 13,720,712 466,961 3,162,020
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Equity and
Liabilities............. $19,622,904 $57,822,414 2$4,430,298 $30,788,158 $78,798,802 $ 8,739,943 $ 29,803,429
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
1994
ASSETS
Total Utility Plant(1)...... $18,496,530 $48,698,926 2$2,969,686 $24,830,254 $64,855,465 $ 8,584,360 $ 27,138,128
Depreciation................ 3,572,944 9,103,911 5,949,200 3,544,572 10,161,224 2,424,025 8,374,484
----------- ----------- ----------- ----------- ----------- ----------- -------------
Net Plant................. 14,923,586 39,595,015 17,020,486 21,285,682 54,694,241 6,160,335 18,763,644
Other Assets................ 3,500,801 14,543,602 5,955,012 8,100,607 18,620,708 2,261,786 9,257,856
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Assets............ $18,424,387 $54,138,617 2$2,975,498 $29,386,289 $73,314,949 $ 8,422,121 $ 28,021,500
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
EQUITY & LIABILITIES
Equity...................... 7,372,540 27,466,187 11,200,142 13,985,299 25,399,752 4,310,227 13,799,630
Long-term Debt.............. 9,402,152 17,707,541 10,642,337 12,776,655 38,477,769 3,644,288 11,391,343
Other Liabilities........... 1,649,695 8,964,889 1,133,019 2,624,335 9,437,428 467,606 2,830,527
----------- ----------- ----------- ----------- ----------- ----------- -------------
Total Equity and
Liabilities............. $18,424,387 $54,138,617 2$2,975,498 $29,386,289 $73,314,949 $ 8,422,121 $ 28,021,500
----------- ----------- ----------- ----------- ----------- ----------- -------------
----------- ----------- ----------- ----------- ----------- ----------- -------------
COWETA-
COLQUITT FAYETTE
------------- -------------
1996
ASSETS
Total Utility Plant(1)...... $ 92,106,574 $ 118,289,765
Depreciation................ 16,732,337 20,809,809
------------- -------------
Net Plant................. 75,374,237 97,479,956
Other Assets................ 28,710,559 22,567,210
------------- -------------
Total Assets............ $ 104,084,796 $ 120,047,166
------------- -------------
------------- -------------
EQUITY & LIABILITIES
Equity...................... 54,692,855 38,201,706
Long-term Debt.............. 41,654,063 66,604,679
Other Liabilities........... 7,737,878 15,240,781
------------- -------------
Total Equity and
Liabilities............. $ 104,084,796 $ 120,047,166
------------- -------------
------------- -------------
1995
ASSETS
Total Utility Plant(1)...... $ 85,979,491 $ 108,478,758
Depreciation................ 15,067,269 19,846,463
------------- -------------
Net Plant................. 70,912,222 88,632,295
Other Assets................ 29,317,003 21,842,319
------------- -------------
Total Assets............ $ 100,229,225 $ 110,474,614
------------- -------------
------------- -------------
EQUITY & LIABILITIES
Equity...................... 50,134,302 35,554,520
Long-term Debt.............. 42,702,587 61,886,161
Other Liabilities........... 7,392,336 13,033,933
------------- -------------
Total Equity and
Liabilities............. $ 100,229,225 $ 110,474,614
------------- -------------
------------- -------------
1994
ASSETS
Total Utility Plant(1)...... $ 80,893,338 $ 97,989,837
Depreciation................ 13,483,922 18,089,216
Net Plant................. 67,409,416 79,900,621
Other Assets................ 23,922,755 18,969,676
------------- -------------
Total Assets.............. $ 91,332,171 $ 98,870,297
------------- -------------
------------- -------------
EQUITY & LIABILITIES
Equity...................... 46,675,638 33,423,307
Long-term Debt.............. 37,817,376 54,323,116
Other Liabilities........... 6,839,157 11,123,874
------------- -------------
Total Equity and
Liabilities............. $ 91,332,171 $ 98,870,297
------------- -------------
------------- -------------
RAYLE SATILLA
------------- -------------
1996
ASSETS
Total Utility Plant(1)...... $ 38,866,252 $ 77,878,807
Depreciation................ 9,095,995 14,750,974
------------- -------------
Net Plant................. 29,770,257 63,127,833
Other Assets................ 8,152,412 21,353,873
------------- -------------
Total Assets............ $ 37,922,669 $ 84,481,706
------------- -------------
------------- -------------
EQUITY & LIABILITIES
Equity...................... 15,391,327 47,165,663
Long-term Debt.............. 19,574,998 31,066,252
Other Liabilities........... 2,956,344 6,249,791
------------- -------------
Total Equity and
Liabilities............. $ 37,922,669 $ 84,481,706
------------- -------------
------------- -------------
1995
ASSETS
Total Utility Plant(1)...... $ 36,902,764 $ 72,213,569
Depreciation................ 8,378,872 14,233,810
------------- -------------
Net Plant................. 28,523,892 57,979,759
Other Assets................ 8,730,742 24,060,173
------------- -------------
Total Assets............ $ 37,254,634 $ 82,039,932
------------- -------------
------------- -------------
EQUITY & LIABILITIES
Equity...................... 14,891,335 45,156,620
Long-term Debt.............. 20,016,582 30,273,723
Other Liabilities........... 2,346,717 6,609,589
------------- -------------
Total Equity and
Liabilities............. $ 37,254,634 $ 82,039,932
------------- -------------
------------- -------------
1994
ASSETS
Total Utility Plant(1)...... $ 34,652,482 $ 67,833,765
Depreciation................ 7,565,129 13,919,259
------------- -------------
Net Plant................. 27,087,353 53,914,506
Other Assets................ 7,928,216 20,955,681
------------- -------------
Total Assets............ $ 35,015,569 $ 74,870,187
------------- -------------
------------- -------------
EQUITY & LIABILITIES
Equity...................... 14,367,190 42,481,081
Long-term Debt.............. 18,861,706 27,080,759
Other Liabilities........... 1,786,673 5,308,347
------------- -------------
Total Equity and
Liabilities............. $ 35,015,569 $ 74,870,187
------------- -------------
------------- -------------
- ------------------------
(1) Including construction work in progress.
(2) Includes information relating to Okefenoke Rural EMC's operations in both
Georgia and Florida. Okefenoke Rural EMC purchases a portion of its power
and energy from an electric supplier in Florida. In 1996, such energy
amounted to approximately 26% of its total energy requirements.
A-12
TABLE 6 (CONTINUED)
EXCELSIOR FLINT GRADY GREYSTONE HABERSHAM HART IRWIN JACKSON JEFFERSON
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 36,751,265 $ 134,233,972 $37,267,979 $ 119,835,120 $54,370,174 $62,991,348 $26,240,440 $ 303,067,664 $ 61,213,183
8,236,346 34,181,519 7,618,851 17,154,327 13,539,289 16,475,736 7,512,796 38,248,857 9,745,502
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
28,514,919 100,052,453 29,649,128 102,680,793 40,830,885 46,515,612 18,727,644 264,818,807 51,467,681
12,069,745 35,885,347 7,777,084 35,184,355 12,003,105 17,048,933 4,808,042 67,670,782 12,793,252
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 40,584,664 $ 135,937,800 $37,426,212 $ 137,865,148 $52,833,990 $63,564,545 $23,535,686 $ 332,489,589 $ 64,260,933
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
17,179,843 58,001,645 18,215,451 62,580,192 23,682,450 27,953,409 9,229,127 119,498,699 25,809,057
18,974,326 54,977,011 14,686,762 63,983,356 21,599,712 27,062,242 13,271,725 170,892,532 27,933,712
4,430,495 22,959,144 4,523,999 11,301,600 7,551,828 8,548,894 1,034,834 42,098,358 10,518,164
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 40,584,664 $ 135,937,800 $37,426,212 $ 137,865,148 $52,833,990 $63,564,545 $23,535,686 $ 332,489,589 $ 64,260,933
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 32,711,813 $ 120,104,072 $35,415,422 $ 111,641,343 $51,078,773 $58,883,214 $24,405,784 $ 278,374,107 $ 57,969,886
7,545,520 31,775,167 7,709,204 14,958,722 12,605,884 14,997,338 7,057,769 36,994,995 9,490,587
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
25,166,293 88,328,905 27,706,218 96,682,621 38,472,889 43,885,876 17,348,015 241,379,112 48,479,299
9,697,688 35,018,903 8,517,819 36,369,445 12,510,269 13,419,913 4,490,238 67,648,547 13,130,128
$ 34,863,981 $ 123,347,808 $36,224,037 $ 133,052,066 $50,983,158 $57,305,789 $21,838,253 $ 309,027,659 $ 61,609,427
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
16,219,525 54,757,464 17,442,545 55,901,190 22,900,174 24,351,543 8,811,175 113,186,857 24,470,203
15,093,798 51,515,923 14,997,658 68,618,413 21,095,826 24,522,191 11,955,805 154,132,967 29,551,950
3,550,658 17,074,421 3,783,834 8,532,463 6,987,158 8,432,055 1,071,273 41,707,835 7,587,274
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 34,863,981 $ 123,347,808 $36,224,037 $ 133,052,066 $50,983,158 $57,305,789 $21,838,253 $ 309,027,659 $ 61,609,427
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 29,570,560 $ 111,337,009 $32,851,839 $ 103,695,947 $47,448,725 $54,722,141 $22,989,184 $ 249,775,644 $ 54,494,054
6,922,344 29,130,243 7,695,558 12,572,125 11,526,922 13,724,019 6,541,675 33,099,602 9,287,871
22,648,216 82,206,766 25,156,281 91,123,822 35,921,803 40,998,122 16,447,509 216,676,042 45,206,183
9,495,309 32,154,975 6,780,584 33,206,426 12,447,108 11,614,095 4,559,558 66,037,706 12,105,657
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 32,143,525 $ 114,361,741 $31,936,865 $ 124,330,248 $48,368,911 $52,612,217 $21,007,067 $ 282,713,748 $ 57,311,840
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
15,452,269 52,448,924 17,096,996 51,000,389 22,070,249 23,424,151 8,483,633 106,384,851 23,167,856
13,369,595 48,614,023 12,379,604 64,951,029 19,726,545 21,362,833 11,538,226 145,266,700 26,500,713
3,321,661 13,298,794 2,460,265 8,378,830 6,572,117 7,825,233 985,208 31,062,197 7,643,271
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 32,143,525 $ 114,361,741 $31,936,865 $ 124,330,248 $48,368,911 $52,612,217 $21,007,067 $ 282,713,748 $ 57,311,840
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
SLASH SNAPPING THREE TRI- UPSON
SAWNEE PINE SHOALS SUMTER NOTCH COUNTY TROUP COUNTY WALTON
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 190,223,954 $ 15,032,197 $96,016,959 $ 41,057,632 $26,498,469 $38,324,663 $55,785,972 $ 11,445,222 $ 159,383,194
24,634,660 3,085,218 24,225,875 12,404,780 6,478,775 6,663,641 15,431,754 3,578,891 37,983,776
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
165,589,294 11,946,979 71,791,084 28,652,852 20,019,694 31,661,022 40,354,218 7,866,331 121,399,418
35,030,090 3,856,843 21,283,623 13,702,278 8,100,089 6,757,400 12,827,041 4,046,568 42,462,101
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 200,619,384 $ 15,803,822 $93,074,707 $ 42,355,130 $28,119,783 $38,418,422 $53,181,259 $ 11,912,899 $ 163,861,519
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
64,131,637 7,393,295 37,789,149 18,098,421 15,287,446 15,549,783 26,505,715 6,845,184 80,514,126
118,646,087 6,878,087 35,010,446 20,133,602 11,241,955 19,735,077 19,214,254 3,860,521 55,751,578
17,841,660 1,532,440 20,275,112 4,123,107 1,590,382 3,133,562 7,461,291 1,207,194 27,595,815
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 200,619,384 $ 15,803,822 $93,074,707 $ 42,355,130 $28,119,783 $38,418,422 $53,181,260 $ 11,912,899 $ 163,861,519
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 167,665,873 $ 13,717,804 $89,637,685 $ 38,981,283 $24,404,523 $35,893,237 $49,282,334 $ 11,061,992 $ 146,222,125
22,562,091 2,823,174 22,308,766 11,547,493 6,129,931 6,336,897 14,069,228 3,319,880 34,933,018
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
145,103,782 10,894,630 67,328,919 27,433,790 18,274,592 29,556,340 35,213,106 7,742,112 111,289,107
32,550,920 3,385,152 23,116,844 10,783,460 9,182,271 7,379,609 13,298,693 3,555,441 43,540,974
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 177,654,702 $ 14,279,782 $90,445,763 $ 38,217,250 $27,456,863 $36,935,949 $48,511,799 $ 11,297,553 $ 154,830,081
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
58,620,800 6,955,485 37,783,822 17,677,856 14,578,591 14,087,964 23,934,593 6,242,146 74,285,978
96,363,156 5,675,193 36,716,227 17,370,136 11,619,620 20,732,265 19,504,362 3,939,838 58,539,679
22,670,746 1,649,104 15,945,714 3,169,258 1,258,652 2,115,720 5,072,844 1,115,569 22,004,424
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 177,654,702 $ 14,279,782 $90,445,763 $ 38,217,250 $27,456,863 $36,935,949 $48,511,799 $ 11,297,553 $ 154,830,081
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 150,637,053 $ 12,528,671 $84,805,720 $ 36,598,084 $23,053,955 $34,056,497 $46,825,167 $ 10,658,782 $ 138,148,022
21,869,170 2,707,500 20,261,007 10,753,657 5,651,536 5,950,400 12,886,268 3,093,078 31,847,856
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
128,767,883 9,821,171 64,544,713 25,844,427 17,402,419 28,106,097 33,938,899 7,565,704 106,300,166
32,365,398 2,952,753 21,211,398 7,893,536 8,228,260 6,540,434 14,702,192 3,445,875 42,824,210
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 161,133,281 $ 12,773,924 $85,756,111 $ 33,737,963 $25,630,679 $34,646,531 $48,641,091 $ 11,011,579 $ 149,124,376
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
56,172,065 6,741,764 35,993,345 17,297,039 13,954,046 13,501,556 20,818,486 6,030,366 68,530,699
84,263,435 4,635,580 11,035,522 14,118,651 9,749,917 18,319,832 23,628,914 4,004,397 63,446,325
20,697,781 1,396,581 38,727,244 2,322,273 1,926,716 2,825,143 4,193,691 976,816 17,147,352
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
$ 161,133,281 $ 12,773,925 $85,756,111 $ 33,737,963 $25,630,679 $34,646,531 $48,641,091 $ 11,011,579 $ 149,124,376
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
- ------------- ------------- ----------- ------------- ----------- ----------- ----------- ------------- -------------
LITTLE
EXCELSIOR LAMAR OCMULGEE
- ------------- ------------ --------------
$ 36,751,265 $21,315,838 $ 24,673,510
8,236,346 6,482,106 5,350,136
- ------------- ------------ --------------
28,514,919 14,833,732 19,323,374
12,069,745 9,473,378 5,099,850
- ------------- ------------ --------------
$ 40,584,664 $24,307,110 $ 24,423,224
- ------------- ------------ --------------
- ------------- ------------ --------------
17,179,843 12,181,243 9,388,397
18,974,326 8,433,787 13,695,328
4,430,495 3,692,080 1,339,499
- ------------- ------------ --------------
$ 40,584,664 $24,307,110 $ 24,423,224
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 32,711,813 $19,997,597 $ 23,129,054
7,545,520 5,872,317 4,922,284
- ------------- ------------ --------------
25,166,293 14,125,280 18,206,770
9,697,688 8,432,910 5,885,168
$ 34,863,981 $22,558,190 $ 24,091,938
- ------------- ------------ --------------
- ------------- ------------ --------------
16,219,525 11,305,328 8,931,607
15,093,798 8,463,921 14,029,833
3,550,658 2,788,941 1,130,498
- ------------- ------------ --------------
$ 34,863,981 $22,558,190 $ 24,091,938
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 29,570,560 $18,774,807 $ 21,692,853
6,922,344 5,369,286 4,360,934
22,648,216 13,405,521 17,331,919
9,495,309 8,039,257 4,576,084
- ------------- ------------ --------------
$ 32,143,525 $21,444,778 $ 21,908,003
- ------------- ------------ --------------
- ------------- ------------ --------------
15,452,269 10,782,831 8,484,297
13,369,595 8,150,561 12,386,968
3,321,661 2,511,386 1,036,738
- ------------- ------------ --------------
$ 32,143,525 $21,444,778 $ 21,908,003
- ------------- ------------ --------------
- ------------- ------------ --------------
SAWNEE WASHINGTON TOTAL
- ------------- ------------ --------------
$ 190,223,954 $39,600,256 $2,786,586,960
24,634,660 10,862,597 529,682,969
- ------------- ------------ --------------
165,589,294 28,737,659 2,256,903,991
35,030,090 17,267,811 690,882,028
- ------------- ------------ --------------
$ 200,619,384 $46,005,470 $2,947,786,019
- ------------- ------------ --------------
- ------------- ------------ --------------
64,131,637 19,182,976 1,216,048,209
118,646,087 22,679,570 1,365,791,468
17,841,660 4,142,924 365,946,343
- ------------- ------------ --------------
$ 200,619,384 $46,005,470 $2,947,786,020
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 167,665,873 $38,124,440 $2,578,220,711
22,562,091 10,767,129 492,231,881
- ------------- ------------ --------------
145,103,782 27,357,311 2,085,988,830
32,550,920 16,873,377 681,191,723
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 177,654,702 $44,230,688 $2,767,180,553
- ------------- ------------ --------------
- ------------- ------------ --------------
58,620,800 18,248,187 1,138,184,895
96,363,156 22,634,941 1,305,198,582
22,670,746 3,347,560 323,797,073
- ------------- ------------ --------------
$ 177,654,702 $44,230,688 $2,767,180,550
- ------------- ------------ --------------
- ------------- ------------ --------------
$ 150,637,053 $35,472,864 $2,393,214,192
21,869,170 9,934,272 451,587,456
- ------------- ------------ --------------
128,767,883 25,538,592 1,941,626,736
32,365,398 14,914,320 626,756,880
- ------------- ------------ --------------
$ 161,133,281 $40,452,912 $2,568,383,616
- ------------- ------------ --------------
- ------------- ------------ --------------
56,172,065 17,203,364 1,071,693,862
84,263,435 20,772,440 1,196,957,583
20,697,781 2,477,108 299,732,172
- ------------- ------------ --------------
$ 161,133,281 $40,452,912 $2,568,383,617
- ------------- ------------ --------------
- ------------- ------------ --------------
A-13
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
NO DEALER, SALES PERSON OR ANY OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS OTHER THAN THOSE CONTAINED IN THIS
PROSPECTUS IN CONNECTION WITH THE OFFERING CONTAINED HEREIN, AND, IF GIVEN OR
MADE, SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN
AUTHORIZED BY OGLETHORPE. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER OF ANY
SECURITIES OTHER THAN THOSE TO WHICH IT RELATES OR AN OFFER TO SELL, OR A
SOLICITATION TO BUY, THOSE TO WHICH IT RELATES IN ANY JURISDICTION TO ANY PERSON
TO WHOM IT IS NOT LAWFUL TO MAKE SUCH OFFER IN SUCH JURISDICTION. THE DELIVERY
OF THIS PROSPECTUS AT ANY TIME DOES NOT IMPLY THAT THE INFORMATION HEREIN IS
CORRECT AS OF ANY TIME SUBSEQUENT TO ITS DATE.
------------------------
TABLE OF CONTENTS
PAGE
-----------
Available Information................ i
Notice to Investors.................. ii
Summary Information Relating to the
Exchange Offer..................... 1
Summary Information Relating to the
Facility Bonds..................... 4
Summary Information Relating to
Oglethorpe and the Members......... 8
Summary Financial Data............... 13
Selected Definitions................. 14
Introduction......................... 15
Absence of Cash Proceeds............. 16
Security and Source of Payment for
the Facility Bonds................. 16
OPC Scherer 1997 Funding
Corporation........................ 18
Flow of Funds for Debt Service
Payments on the Facility Bonds..... 19
Business of Oglethorpe............... 20
Unaudited Pro Forma Condensed
Financial Data..................... 29
Selected Financial Data.............. 33
Capitalization....................... 35
Management's Discussion and Analysis
of Financial Condition and Results
of Operations...................... 36
The Members of Oglethorpe............ 51
Member Requirements and Power Supply
Resources.......................... 55
Co-Owners of the Plants and the Plant
Agreements......................... 62
Certain Factors Affecting the
Electric Utility Industry.......... 68
Management........................... 72
Certain Relationships and Related
Transactions....................... 78
The Exchange Offer................... 79
Description of the Facility Bonds.... 87
Description of the Lease
Indentures......................... 103
Description of the Leases............ 111
Certain United States Federal Income
Tax Consequences................... 119
Plan of Distribution................. 120
Legal Opinions....................... 121
Experts.............................. 121
Index to Financial Statements........ F-1
Appendix A--Member Financial and
Statistical Information............ A-1
OFFER TO EXCHANGE
6.974% SERIAL FACILITY BONDS
DUE JUNE 30, 2011
FOR ALL OUTSTANDING 6.974% SERIAL FACILITY
BONDS DUE JUNE 30, 2011
------------------------
THE FACILITY BONDS WILL BE
PAYABLE FROM AND SECURED, AS DESCRIBED
HEREIN, BY RENTALS TO BE PAID UNDER SEVERAL
LEASES RELATING TO SCHERER UNIT NO. 2 BY
------------------------
[LOGO]
OGLETHORPE POWER
CORPORATION
(AN ELECTRIC MEMBERSHIP
CORPORATION)
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
ITEM 20. INDEMNIFICATION OF DIRECTORS AND OFFICERS
GEORGIA STATUTE
Section 46-3-306 of the Official Code of Georgia Annotated which governs
indemnification of officers and directors of Oglethorpe provides as follows:
46-3-306. Indemnification of officers, directors, employees, and
agents; purchase and maintenance of liability insurance; notice to
members of payment of indemnification.
(a) As used in this Code section, the term "the electric membership
corporation" shall include, in addition to the surviving or new electric
membership corporation, any merging or consolidating electric membership
corporation, including any merging or consolidating electric membership
corporation of a merging or consolidating electric membership corporation,
absorbed in a merger or consolidation so that any person who is or was a
director, officer, employee, or agent of such merging or consolidating
electric membership corporation, or is or was serving at the request of such
merging or consolidating electric membership corporation as a director,
officer, employee, or agent of another corporation, partnership, joint
venture, trust, or other enterprise, shall stand in the same position under
this Code section with respect to the resulting or surviving electric
membership corporation as he would if he had served the resulting or
surviving electric membership corporation in the same capacity, provided
that no indemnification under subsections (b) and (c) of this Code section
which are permitted by this subsection shall be mandatory under this
subsection or any bylaw of the surviving or new electric membership
corporation without the approval of such indemnification by the board of
directors or members of the surviving or new electric membership
corporation, in the manner provided in paragraphs (1) and (3) of subsection
(e) of this Code section.
(b) An electric membership corporation shall have power to indemnify any
person who was or is a party or is threatened to be made a party to any
threatened, pending, or completed action or proceeding, whether civil,
criminal, administrative, or investigative (other than an action by or in
the right of the electric membership corporation), by reason of the fact
that he is or was a director, officer, employee, or agent of the electric
membership corporation, or is or was serving at the request of the electric
membership corporation as a director, officer, employee, or agent of another
corporation, partnership, joint venture, trust, or other enterprise, against
expenses, including attorney's fees, judgments, fines, and amounts paid in
settlement actually and reasonably incurred by him in connection with such
action or proceeding if he acted in a manner he reasonably believed to be in
or not opposed to the best interests of the electric membership corporation
and, with respect to any criminal action or proceeding, had no reasonable
cause to believe his conduct was unlawful. The termination of any action or
proceeding by judgment, order, settlement, or conviction, or upon a plea of
nolo contendere or its equivalent, shall not of itself create a presumption
that the person did not act in a manner which he reasonably believed to be
in or not opposed to the best interests of the electric membership
corporation and, with respect to any criminal action or proceeding, had
reasonable cause to believe that his conduct was unlawful.
(c) An electric membership corporation shall have the power to indemnify
any person who was or is a party or who is threatened to be made a party to
any threatened, pending, or completed action or suit by, or in the right of,
the electric membership corporation to procure a judgment in its favor, by
reason of the fact he is or was a director, officer, employee, or agent of
the electric membership corporation or is or was serving at the request of
the electric membership corporation as a director, employee or agent of
another corporation, partnership, joint venture, trust, or other
II-1
enterprise, against expenses, including attorney s fees, actually and
reasonably incurred by him in connection with the defense or settlement of
such action or suit, if he acted in good faith and in a manner he reasonably
believed to be in or not opposed to the best interests of the electric
membership corporation; except that no indemnification shall be made in
respect to any claim, issue, or matter as to which such person shall have
been adjudged to be liable to the electric membership corporation, unless
and only to the extent that the court in which such action or suit was
brought shall determine upon application that, despite the adjudication of
liability but in view of all the circumstances of the case, such person is
fairly and reasonably entitled to indemnity for such expenses which the
court shall deem proper.
(d) To the extent that a director, officer, employee, or agent of an
electric membership corporation has been successful, on the merits or
otherwise, in defense of any action, suit, or proceeding referred to in
subsections (b) and (c) of this Code section or in defense of any claim,
issue, or matter therein, he shall be indemnified against expenses,
including attorney s fees, actually and reasonably incurred by him in
connection therewith.
(e) Any indemnification under subsections (b) and (c) of this Code
section, unless ordered by a court, shall be made by the electric membership
corporation only as authorized in the specific case, upon a determination
that indemnification of the director, officer, employee, or agent is proper
in the circumstances because he has met the applicable standard of conduct
set forth in subsections (b) and (c) of this Code section. Such
determination shall be made:
(1) By the board of directors by a majority vote of a quorum
consisting of directors who were not parties to such action, suit, or
proceeding;
(2) If such a quorum is not obtainable or, even if obtainable, if a
quorum of disinterested directors so directs, by independent legal
counsel in a written opinion; or
(3) By the affirmative vote of the members present and voting at the
meeting at which such determination is made.
(f) Expenses incurred in defending a civil or criminal action, suit, or
proceeding may be paid by the electric membership corporation in advance of
the final disposition of such action, suit, or proceeding upon receipt of an
undertaking by or on behalf of the director, officer, employee, or agent to
repay such amount if it shall ultimately be determined that he is not
entitled to be indemnified by the electric membership corporation as
authorized in this Code section.
(g) The indemnification and advancement of expenses provided by or
granted pursuant to this Code section shall not be deemed exclusive of any
other rights, in respect to indemnification or otherwise, to which those
seeking indemnification or advancement of expenses may be entitled under any
bylaw, resolution, or agreement, either specifically or in general terms
approved by the affirmative vote of a majority of the members entitled to
vote thereon, taken at a meeting, the notice of which specified that such
bylaw, resolution, or agreement would be placed before the members, both as
to action by a director, officer, employee, or agent in his official
capacity and as to action in another capacity while holding such office or
position, except that no such other rights, in respect to indemnification or
otherwise, may be provided or granted to a director, officer, employee, or
agent pursuant to this subsection by an electric membership corporation with
respect to the liabilities described in divisions (b)(3)(A)(i) through
(b)(3)(A)(iii) of Code Section 46-3-321.
(h) An electric membership corporation shall have the power to purchase
and maintain insurance on behalf of any person who is or was a director,
officer, employee, or agent of the electric membership corporation or who is
or was serving at the request of the electric membership corporation as a
director, officer, employee, or agent of another corporation, partnership,
joint venture, trust, or other enterprise, against any liability asserted
against him and incurred by him in
II-2
any such capacity, or arising out of his status as such, whether or not the
electric membership corporation would have the power to indemnify him
against such liability under this Code section.
(i) If any expenses or other amounts are paid by way of indemnification,
otherwise than by court order or action by the members or by an insurance
carrier pursuant to insurance maintained by the electric membership
corporation, the electric membership corporation, not later than the next
annual meeting of members, unless such meeting is held within three months
from the date of such payment, and in any event, within 15 months from the
date of such payment, shall send to its members who are entitled to vote for
the election of directors a statement specifying the persons paid, the
amounts paid, and the nature and status at the time of such payment of the
litigation or threatened litigation. Such statement shall be provided to the
members in the manner provided in subsection (a) of Code Section 46-3-263
for giving notice of members meetings.
(j) The indemnification and advancement of expenses provided by or
granted pursuant to this Code section shall, unless otherwise provided when
authorized or ratified, continue as to a person who has ceased to be a
director, officer, employee, or agent and shall inure to the benefit of the
heirs, executors, and administrators of such a person. (Code 1933, Section
34C-617, enacted by Ga. L. 1981, p. 1587, Section 1; Ga. L. 1988, p. 1451,
Section 2; Ga. L. 1989, p. 14, Section 46.)
ARTICLES OF INCORPORATION
Oglethorpe's Restated Articles of Incorporation contain the following
provision:
"Article VII. A director of the Corporation shall not be personally liable
to the Corporation or its members for monetary damages for breach of duty of
care or other duty as a director, except for liability:
(i) For any appropriation, in violation of his duties, of any business
opportunity of the Corporation;
(ii) For acts or omissions not in good faith or which involve
intentional misconduct or a knowing violation of law; or
(iii) For any transaction from which the director derives an improper
personal benefit.
The liability of directors shall be deemed further limited or eliminated to
the fullest extent permitted by changes in the law governing the Corporation.
Any repeal or modification of the provisions of this Article VII shall not
adversely affect the duty, liability, rights or protection of a director
existing at the time of such repeal or modification."
BYLAWS
Oglethorpe's Bylaws contain the following provisions relating to
indemnification and insurance:
"Article VIII
Indemnification and Insurance
Section 1. Indemnification.
The Corporation shall indemnify each person who is or was a Director,
officer, employee or agent of the Corporation (including the heirs, executors,
administrators or estate of such person) or is or was serving at the request of
the Corporation as a director, officer, employee or agent of another
corporation, partnership, joint venture, trust or other enterprise to the full
extent permitted under Sections 46-3-306(b), (c) and (d) of the Georgia Electric
Membership Corporation Act or any successor provisions of the laws of the State
of Georgia. If any such indemnification is requested pursuant to Sections
46-3-306(b) or (c) of said Act or laws, the Board of Directors shall cause a
determination to be made
II-3
(unless a court has ordered the indemnification) in one of the manners
prescribed in Section 46-3-306(e) of said Act or laws as to whether
indemnification of the party requesting indemnification is proper in the
circumstances because he has met the applicable standard of conduct set forth in
Sections 46-3-306(b) or (c) of said Act or laws. Upon any such determination
that such indemnification is proper, the Corporation shall make indemnification
payments of liability, cost, payment or expense asserted against, or paid or
incurred by, him in his capacity as such a director, officer, employee or agent
to the maximum extent permitted by said Sections of said Act or laws. The
indemnification obligation of the Corporation set forth herein shall not be
deemed exclusive of any other rights, in respect of indemnification or
otherwise, to which any party may be entitled under any other bylaw provision or
resolution approved by the Members pursuant to Section 46-3-306(g) of said Act
or laws.
Section 2. Insurance.
The Corporation may purchase and maintain insurance at its expense, to
protect itself and any Director, officer, employee or agent of the Corporation
(including the heirs, executors, administrators or estate of any such person)
against any liability, cost, payment or expense described in Section 1 of this
Article VII, whether or not the Corporation would have the power to indemnify
such person against such liability."
INSURANCE
Oglethorpe maintains director and officer insurance policies which insure
the present and former directors and officers of Oglethorpe against certain
claims and liabilities asserted against them in their capacities or arising out
of their status as directors and officers of Oglethorpe.
ITEM 21. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(A) EXHIBITS:
An index of exhibits appears at pages II-7 through II-21.
(B) FINANCIAL STATEMENT SCHEDULES:
None.
ITEM 22. UNDERTAKINGS
The undersigned Registrant hereby undertakes that:
Insofar as indemnification for liabilities arising under the Securities
Act of 1933 may be permitted to directors, officers and controlling persons
of the registrant pursuant to the foregoing provisions, or otherwise, the
registrant has been advised that in the opinion of the Securities and
Exchange Commission such indemnification is against public policy as
expressed in the Act and is, therefore, unenforceable. In the event that a
claim for indemnification against such liabilities (other than the payment
by the registrant of expenses incurred or paid by a director, officer or
controlling person of the registrant in the successful defense of any
action, suit or proceeding) is asserted by such director, officer or
controlling person in connection with the securities being registered, the
registrant will, unless in the opinion of its counsel the matter has been
settled by controlling precedent, submit to a court of appropriate
jurisdiction the question whether such indemnification by it is against
public policy as expressed in the Act and will be governed by the final
adjudication of such issue.
II-4
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, the Registrant
has duly caused this Registration Statement to be signed on its behalf by the
undersigned, thereunto duly authorized, in the County of DeKalb, State of
Georgia, on the 18th day of December, 1997.
OGLETHORPE POWER CORPORATION
(AN ELECTRIC MEMBERSHIP CORPORATION)
By: /s/ J. CALVIN EARWOOD,
-----------------------------------------
J. CALVIN EARWOOD,
Chairman of the Board
POWER OF ATTORNEY
KNOW ALL PERSONS BY THESE PRESENTS, that each person whose signature appears
below hereby constitutes and appoints J. Calvin Earwood and T. D. Kilgore and
each of them (with full power to each of them to act alone), his true and lawful
attorneys-in-fact and agents, with full power of substitution and
resubstitution, for him and on his behalf and in his name, place and stead, in
any and all capacities, to sign any and all amendments (including post-effective
amendments) to this Registration Statement, and any subsequent Registration
Statement filed pursuant to Rule 462(b) under the Securities Act of 1933, as
amended, and to file the same, with all exhibits thereto, and other documents in
connection therewith, with the Securities and Exchange Commission (or any other
governmental or regulatory authority), granting unto said attorneys-in-fact and
agents, and each of them, full power and authority to do and perform each and
every act and thing requisite and necessary to be done in and about the
premises, as fully to all intents and purposes as he might or could do in
person, hereby ratifying and confirming all that said attorneys-in-fact and
agents or their substitute or substitutes or any of them, may lawfully do or
cause to be done by virtue thereof.
Pursuant to the requirements of the Securities Act of 1933, this
Registration Statement has been signed by the following persons in the
capacities and on the dates indicated.
SIGNATURE TITLE DATE
- --------------------------------------------------- --------------------------------- -----------------------
/s/ J. CALVIN EARWOOD Chairman of the Board, Director
---------------------------------------- (Principal Executive Officer) December 18, 1997
J. CALVIN EARWOOD
/s/ T.D. KILGORE President and Chief Executive
---------------------------------------- Officer (Principal Executive December 18, 1997
T.D. KILGORE Officer)
/s/ MAC F. OGLESBY Treasurer, Director (Principal
---------------------------------------- Financial Officer) December 18, 1997
MAC F. OGLESBY
/s/ THOMAS A. SMITH Senior Financial Officer
---------------------------------------- (Principal Financial Officer) December 18, 1997
THOMAS A. SMITH
/s/ ROBERT D. STEELE Controller
---------------------------------------- December 18, 1997
ROBERT D. STEELE
/s/ ASHLEY C. BROWN Director
---------------------------------------- December 18, 1997
ASHLEY C. BROWN
II-5
SIGNATURE TITLE DATE
- --------------------------------------------------- --------------------------------- -----------------------
/s/ NEWTON A. CAMPBELL Director
---------------------------------------- December 18, 1997
NEWTON A. CAMPBELL
/s/ LARRY N. CHADWICK Director
---------------------------------------- December 18, 1997
LARRY N. CHADWICK
/s/ BENNY W. DENHAM Director
---------------------------------------- December 18, 1997
BENNY W. DENHAM
/s/ WM. RONALD DUFFEY Director
---------------------------------------- December 18, 1997
WM. RONALD DUFFEY
/s/ SAMMY M. JENKINS Director
---------------------------------------- December 18, 1997
SAMMY M. JENKINS
/s/ J. SAM L. RABUN Director
---------------------------------------- December 18, 1997
J. SAM L. RABUN
/s/ JOHN S. RANSON Director
---------------------------------------- December 18, 1997
JOHN S. RANSON
II-6
EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a) Exhibits
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
*2.1 -- Second Amended and Restated Restructuring Agreement, dated February 24, 1997, by and
among Oglethorpe, Georgia Transmission Corporation (An Electric Membership Corporation)
and Georgia System Operations Corporation. (Filed as Exhibit 2.1 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*2.2 -- Member Agreement, dated August 1, 1996, by and among Oglethorpe, Georgia Transmission
Corporation (An Electric Membership Corporation), Georgia System Operations Corporation
and the Members of Oglethorpe. (Filed as Exhibit 2.2 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1996, File No. 33-7591.)
*3.1(a) -- Restated Articles of Incorporation of Oglethorpe, dated as of July 26, 1988. (Filed as
Exhibit 3.1 to the Registrant's Form 10-K for the fiscal year ended December 31, 1988,
File No. 33-7591.)
*3.1(b) -- Amendment to Articles of Incorporation of Oglethorpe, dated as of March 11, 1997. (Filed
as Exhibit 3(i)(b) to the Registrant's Form 10-K for the fiscal year ended December 31,
1996, File No. 33-7591.)
*3.2 -- Bylaws of Oglethorpe, as amended on February 24, 1997, and effective as of March 11,
1997. (Filed as Exhibit 3(ii) to the Registrant's Form 10-K for the fiscal year ended
December 31, 1996, File No. 33-7591.)
4.1 -- Form of Serial Facility Bond (included in form of Collateral Trust Indenture filed as
Exhibit 4.2).
4.2 -- Collateral Trust Indenture, dated as of December 1, 1997, between OPC Scherer 1997
Funding Corporation A, Oglethorpe and SunTrust Bank, Atlanta, as Trustee.
++4.3 -- Refunding Lessor Note, with a Schedule identifying three other substantially identical
Refunding Lessor Notes and any material differences.
++4.4 -- Amended and Restated Indenture of Trust, Deed to Secure Debt and Security Agreement No.
2, dated December 1, 1997, between Wilmington Trust Company and NationsBank, N.A.
collectively as Owner Trustee, under Trust Agreement No. 2, dated December 30, 1985,
with DFO Partnership, as assignee of Ford Motor Credit Company, and The Bank of New York
Trust Company of Florida, N.A., with a Schedule identifying three other subtantially
identical Amended and Restated Indentures of Trust, Deeds to Secure Debt and Security
Agreements and any material differences.
*4.5(a) -- Lease Agreement No. 2 dated December 30, 1985, between Wilmington Trust Company and
William J. Wade, as Owner Trustees under Trust Agreement No. 2, dated December 30, 1985,
with Ford Motor Credit Company, Lessor, and Oglethorpe, Lessee, with a Schedule
identifying three other substantially identical Lease Agreements. (Filed as Exhibit
4.5(b) to the Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on
October 9, 1986.)
II-7
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
*4.5(b) -- First Supplement to Lease Agreement No. 2 (included as Exhibit B to the Supplemental
Participation Agreement No. 2 listed as 10.1.1(b)).
*4.5(c) -- First Supplement to Lease Agreement No. 1, dated as of June 30, 1987, between The
Citizens and Southern National Bank as Owner Trustee under Trust Agreement No. 1 with
IBM Credit Financing Corporation, as Lessor, and Oglethorpe, as Lessee. (Filed as
Exhibit 4.5(c) to the Registrant's Form 10-K for the fiscal year ended December 31,
1987, File No. 33-7591.)
++4.5(d) -- Second Supplement to Lease Agreement No. 2, dated as of December 17, 1997, between
NationsBank, N.A., as an Owner Trustee under the Trust Agreement No. 2, dated December
30, 1985, with DFO Partnership, as assignee of Ford Motor Credit Company, as Lessor, and
Oglethorpe, as Lessee, with a Schedule identifying three other substantially identical
Second Supplement to Lease Agreements and any material differences.
*4.6 -- Amended and Consolidated Loan Contract, dated as of March 1, 1997, between Oglethorpe
and the United States of America, together with four notes executed and delivered
pursuant thereto. (Filed as Exhibit 4.7 to the Registrant's Form 10-K for the fiscal
year ended December 31, 1996, File No. 33-7591.)
*4.7.1(a) -- Indenture, dated as of March 1, 1997, made by Oglethorpe to SunTrust Bank, Atlanta, as
trustee. (Filed as Exhibit 4.8.1 to the Registrant's Form 10-K for the fiscal year ended
December 31, 1996, File No. 33-7591.)
*4.7.1(b) -- First Supplemental Indenture, dated as of October 1, 1997, made by Oglethorpe to
SunTrust Bank, Atlanta, as trustee, relating to the Series 1997B (Burke) Note. (Filed as
Exhibit 4.8.1(b) to the Registrant's Form 10-Q for the quarterly period ended September
30, 1997, File No. 33-7591).
*4.7.2 -- Security Agreement, dated as of March 1, 1997, made by Oglethorpe to SunTrust Bank,
Atlanta, as trustee. (Filed as Exhibit 4.8.2 to the Registrant's Form 10-K for the
fiscal year ended December 31, 1996, File No. 33-7591.)
4.8.1(2) -- Loan Agreement, dated as of October 1, 1992, between Development Authority of Monroe
County and Oglethorpe relating to Development Authority of Monroe County Pollution
Control Revenue Bonds (Oglethorpe Power Corporation Scherer Project), Series 1992A.
4.8.2(2) -- Note, dated October 1, 1992, from Oglethorpe to Trust Company Bank, as trustee acting
pursuant to a Trust Indenture, dated as of October 1, 1992, between Development
Authority of Monroe County and Trust Company Bank.
4.8.3(2) -- Trust Indenture, dated as of October 1, 1992, between Development Authority of Monroe
County and Trust Company Bank, Trustee, relating to Development Authority of Monroe
County Pollution Control Revenue Bonds (Oglethorpe Power Corporation Scherer Project),
Series 1992A.
4.9.1(3) -- Loan Agreement, dated as of December 1, 1992, between Development Authority of Burke
County and Oglethorpe relating to Development Authority of Burke County Adjustable
Tender Pollution Control Revenue Bonds (Oglethorpe Power Corporation Vogtle Project),
Series 1993A.
II-8
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
4.9.2(3) -- Note, dated December 1, 1992, from Oglethorpe to Trust Company Bank, as trustee acting
pursuant to a Trust Indenture, dated as of December 1, 1992, between Development
Authority of Burke County and Trust Company Bank.
4.9.3(3) -- Trust Indenture, dated as of December 1, 1992, from Development Authority of Burke
County to Trust Company Bank, as trustee, relating to Development Authority of Burke
County Adjustable Tender Pollution Control Revenue Bonds (Oglethorpe Power Corporation
Vogtle Project), Series 1993A.
4.9.4(3) -- Interest Rate Swap Agreement, dated as of December 1, 1992, by and between Oglethorpe
and AIG Financial Products Corp. relating to Development Authority of Burke County
Adjustable Tender Pollution Control Revenue Bonds (Oglethorpe Power Corporation Vogtle
Project), Series 1993A.
4.9.5(3) -- Liquidity Guaranty Agreement, dated as of December 1, 1992, by and between Oglethorpe
and AIG Financial Products Corp. relating to Development Authority of Burke County
Adjustable Tender Pollution Control Revenue Bonds (Oglethorpe Power Corporation Vogtle
Project), Series 1993A.
4.9.6(1) -- Standby Bond Purchase Agreement, dated as of December 14, 1995, between Oglethorpe and
Canadian Imperial Bank of Commerce, New York Agency, relating to Development Authority
of Burke County Adjustable Tender Pollution Control Revenue Bonds (Oglethorpe Power
Corporation Vogtle Project), Series 1993A.
4.9.7(1) -- Standby Bond Purchase Agreement, dated as of November 30, 1994, between Oglethorpe and
Credit Local de France, Acting through its New York Agency, relating to the Development
Authority of Burke County Adjustable Tender Pollution Control Revenue Bonds (Oglethorpe
Power Corporation Vogtle Project), Series 1994A.
4.10.1(4) -- Loan Agreement, dated as of October 1, 1996, between Development Authority of Burke
County and Oglethorpe relating to Development Authority of Burke County Pollution
Control Revenue Bonds (Oglethorpe Power Corporation Vogtle Project), Series 1996.
4.10.2(4) -- Note, dated October 1, 1996, from Oglethorpe to SunTrust Bank, Atlanta, as trustee
pursuant to an Indenture of Trust, dated as of October 1, 1996, between Development
Authority of Burke County and SunTrust Bank, Atlanta.
4.10.3(4) -- Indenture of Trust, dated as of October 1, 1996, between Development Authority of Burke
County and SunTrust Bank, Atlanta, as trustee, relating to Development Authority of
Burke County Pollution Control Revenue Bonds (Oglethorpe Power Corporation Vogtle
Project), Series 1996.
*4.12.1 -- Indemnity Agreement, dated as of March 1, 1997, by and between Oglethorpe and Georgia
Transmission Corporation (An Electric Membership Corporation). (Filed as Exhibit 4.13.1
to the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No.
33-7591.)
*4.12.2 -- Indemnification Agreement, dated as of March 11, 1997, by Oglethorpe and Georgia
Transmission Corporation (An Electric Membership Corporation) for the benefit of the
United States of America. (Filed as Exhibit 4.13.2 to the Registrant's Form 10-K for the
fiscal year ended December 31, 1996, File No. 33-7591.)
II-9
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
4.13.1(1) -- Master Loan Agreement, dated as of March 1, 1997, between Oglethorpe and CoBank, ACB,
MLA No. 0459.
4.13.2(1) -- Consolidating Supplement, dated as of March 1, 1997, between Oglethorpe and CoBank, ACB,
relating to Loan No. ML0459T1.
4.13.3(1) -- Promissory Note, dated March 1, 1997, in the original principal amount of $7,102,740.26,
from Oglethorpe to CoBank, ACB, relating to Loan No. ML0459T1.
4.13.4(1) -- Consolidating Supplement, dated as of March 1, 1997, between Oglethorpe and CoBank, ACB,
relating to Loan No. ML0459T2.
4.13.5(1) -- Promissory Note, dated March 1, 1997, in the original principal amount of $1,856,475.12,
made by Oglethorpe to CoBank, ACB, relating to Loan No. ML0459T2.
*4.14.1 -- Loan Agreement, Loan No. T-830404, between Oglethorpe and Columbia Bank for
Cooperatives, dated as of April 29, 1983. (Filed as Exhibit 4.18.1 to the Registrant's
Form S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*4.14.2 -- Promissory Note, Loan No. T-830404-1, in the original principal amount of $9,935,000,
from Oglethorpe to Columbia Bank for Cooperatives, dated as of April 29, 1983. (Filed as
Exhibit 4.18.2 to the Registrant's Form S-1 Registration Statement, File No. 33-7591,
filed on October 9, 1986.)
*4.14.3 -- Security Deed and Security Agreement, dated April 29, 1983, between Oglethorpe and
Columbia Bank for Cooperatives. (Filed as Exhibit 4.18.3 to the Registrant's Form S-1
Registration Statement, File No. 33-7591, filed on October 9, 1986.)
4.15 -- Exchange and Registration Rights Agreement, dated December 17, 1997, by and among
Oglethorpe, OPC Scherer 1997 Funding Corporation A, and Goldman, Sachs & Co. as
representative of the purchasers identified therein.
++5 -- Opinion of Sutherland, Asbill & Brennan LLP
*10.1.1(a) -- Participation Agreement No. 2 among Oglethorpe as Lessee, Wilmington Trust Company as
Owner Trustee, The First National Bank of Atlanta as Indenture Trustee, Columbia Bank
for Cooperatives as Loan Participant and Ford Motor Credit Company as Owner Participant,
dated December 30, 1985, together with a Schedule identifying three other substantially
identical Participation Agreements. (Filed as Exhibit 10.1.1(b) to the Registrant's Form
S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.1.1(b) -- Supplemental Participation Agreement No. 2. (Filed as Exhibit 10.1.1(a) to the
Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on October 9,
1986.)
*10.1.1(c) -- Supplemental Participation Agreement No. 1, dated as of June 30, 1987, among Oglethorpe
as Lessee, IBM Credit Financing Corporation as Owner Participant, Wilmington Trust
Company and The Citizens and Southern National Bank as Owner Trustee, The First National
Bank of Atlanta, as Indenture Trustee, and Columbia Bank for Cooperatives, as Loan
Participant. (Filed as Exhibit 10.1.1(c)
II-10
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
to the Registrant's Form 10-K for the fiscal year ended December 31, 1987, File No.
33-7591.)
++10.1.1(d) -- Second Supplemental Participation Agreement No. 2, dated as of December 17, 1997, among
Oglethorpe as Lessee, DFO Partnership, as assigne of Ford Motor Credit Company, as Owner
Participant, Wilmington Trust Company and NationsBank, N.A. as Owner Trustee, The Bank
of New York Trust Company of Florida, N.A. as Indenture Trustee, CoBank, ACB as Loan
Participant, OPC Scherer Funding Corporation, as Original Funding Corporation, OPC
Scherer 1997 Funding Corporation A, a Funding Corporation, and SunTrust Bank, Atlanta,
as Original Collateral Trust Trustee and Collateral Trust Trustee, with a Schedule
identifying three substantially identical Second Supplemental Participation Agreements
and any material differences.
*10.1.2 -- General Warranty Deed and Bill of Sale No. 2 between Oglethorpe, Grantor, and Wilmington
Trust Company and William J. Wade, as Owner Trustees under Trust Agreement No. 2, dated
December 30, 1985, with Ford Motor Credit Company, Grantee, together with a Schedule
identifying three substantially identical General Warranty Deeds and Bills of Sale.
(Filed as Exhibit 10.1.2 to the Registrant's Form S-1 Registration Statement, File No.
33-7591, filed on October 9, 1986.)
*10.1.3(a) -- Supporting Assets Lease No. 2, dated December 30, 1985, between Oglethorpe, Lessor, and
Wilmington Trust Company and William J. Wade, as Owner Trustees, under Trust Agreement
No. 2, dated December 30, 1985, with Ford Motor Credit Company, Lessee, together with a
Schedule identifying three substantially identical Supporting Assets Leases. (Filed as
Exhibit 10.1.3 to the Registrant's Form S-1 Registration Statement, File No. 33-7591,
filed on October 9, 1986.)
*10.1.3(b) -- First Amendment to Supporting Assets Lease No. 2, dated as of November 19, 1987,
together with a Schedule identifying three substantially identical First Amendments to
Supporting Assets Leases. (Filed as Exhibit 10.1.3(a) to the Registrant's Form 10-K for
the fiscal year ended December 31, 1987, File No. 33-7591.)
*10.1.4(a) -- Supporting Assets Sublease No. 2, dated December 30, 1985, between Wilmington Trust
Company and William J. Wade, as Owner Trustees under Trust Agreement No. 2 dated
December 30, 1985, with Ford Motor Credit Company, Sublessor, and Oglethorpe, Sublessee,
together with a Schedule identifying three substantially identical Supporting Assets
Subleases. (Filed as Exhibit 10.1.4 to the Registrant's Form S-1 Registration Statement,
File No. 33-7591, filed on October 9, 1986.)
*10.1.4(b) -- First Amendment to Supporting Assets Sublease No. 2, dated as of November 19, 1987,
together with a Schedule identifying three substantially identical First Amendments to
Supporting Assets Subleases. (Filed as Exhibit 10.1.4(a) to the Registrant's Form 10-K
for the fiscal year ended December 31, 1987, File No. 33-7591.)
*10.1.5(a) -- Tax Indemnification Agreement No. 2, dated December 30, 1985, between Ford Motor Credit
Company, Owner Participant, and Oglethorpe, Lessee, together with a Schedule identifying
three substantially identical Tax Indemnification
II-11
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
Agreements. (Filed as Exhibit 10.1.5 to the Registrant's Form S-1 Registration
Statement, File No. 33-7591, filed on October 9, 1986.)
++10.1.5(b) -- Amendment No. 1 to the Tax Indemnification Agreement, dated December 12, 1997, between
DFO Partnership, as assignee of Ford Motor Credit Company, as Owner Participant, and
Oglethorpe, as Lessee, with a Schedule identifying three substantially identical
Amendment No. 1 to the Tax Indemnification Agreements and any material differences.
*10.1.6 -- Assignment of Interest in Ownership Agreement and Operating Agreement No. 2, dated
December 30, 1985, between Oglethorpe, Assignor, and Wilmington Trust Company and
William J. Wade, as Owner Trustees under Trust Agreement No. 2, dated December 30, 1985,
with Ford Motor Credit Company, Assignee, together with Schedule identifying three
substantially identical Assignments of Interest in Ownership Agreement and Operating
Agreement. (Filed as Exhibit 10.1.6 to the Registrant's Form S-1 Registration Statement,
File No. 33-7591, filed on October 9, 1986.)
*10.1.7 -- Consent, Amendment and Assumption No. 2 dated December 30, 1985, among Georgia Power
Company and Oglethorpe and Municipal Electric Authority of Georgia and City of Dalton,
Georgia and Gulf Power Company and Wilmington Trust Company and William J. Wade, as
Owner Trustees under Trust Agreement No. 2, dated December 30, 1985, with Ford Motor
Credit Company, together with a Schedule identifying three substantially identical
Consents, Amendments and Assumptions. (Filed as Exhibit 10.1.9 to the Registrant's Form
S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.1.7(a) -- Amendment to Consent, Amendment and Assumption No. 2, dated as of August 16, 1993, among
Oglethorpe, Georgia Power Company, Municipal Electric Authority of Georgia, City of
Dalton, Georgia, Gulf Power Company, Jacksonville Electric Authority, Florida Power &
Light Company and Wilmington Trust Company and NationsBank of Georgia, N.A., as Owner
Trustees under Trust Agreement No. 2, dated December 30, 1985, with Ford Motor Credit
Company, together with a Schedule identifying three substantially identical Amendments
to Consents, Amendments and Assumptions. (Filed as Exhibit 10.1.9(a) to the Registrant's
Form 10-Q for the quarterly period ended September 30, 1993, File No. 33-7591.)
*10.2.1 -- Section 168 Agreement and Election dated as of April 7, 1982, between Continental
Telephone Corporation and Oglethorpe. (Filed as Exhibit 10.2 to the Registrant's Form
S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.2.2 -- Section 168 Agreement and Election dated as of April 9, 1982, between National Service
Industries, Inc. and Oglethorpe. (Filed as Exhibit 10.3 to the Registrant's Form S-1
Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.2.3 -- Section 168 Agreement and Election dated as of April 9, 1982, between Rollins, Inc. and
Oglethorpe. (Filed as Exhibit 10.4 to the Registrant's Form S-1 Registration Statement,
File No. 33-7591, filed on October 9, 1986.)
*10.2.4 -- Section 168 Agreement and Election dated as of December 13, 1982, between Selig
Enterprises, Inc. and Oglethorpe. (Filed as Exhibit 10.5 to the Registrant's Form S-1
Registration Statement, File No. 33-7591, filed on October 9, 1986.)
II-12
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
*10.3.1(a) -- Plant Robert W. Scherer Units Numbers One and Two Purchase and Ownership Participation
Agreement among Georgia Power Company, Oglethorpe, Municipal Electric Authority of
Georgia and City of Dalton, Georgia, dated as of May 15, 1980. (Filed as Exhibit 10.6.1
to the Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on October
9, 1986.)
*10.3.1(b) -- Amendment to Plant Robert W. Scherer Units Numbers One and Two Purchase and Ownership
Participation Agreement among Georgia Power Company, Oglethorpe, Municipal Electric
Authority of Georgia and City of Dalton, Georgia, dated as of December 30, 1985. (Filed
as Exhibit 10.1.8 to the Registrant's Form S-1 Registration Statement, File No. 33-7591,
filed on October 9, 1986.)
*10.3.1(c) -- Amendment Number Two to the Plant Robert W. Scherer Units Numbers One and Two Purchase
and Ownership Participation Agreement among Georgia Power Company, Oglethorpe, Municipal
Electric Authority of Georgia and City of Dalton, Georgia, dated as of July 1, 1986.
(Filed as Exhibit 10.6.1(a) to the Registrant's Form 10-K for the fiscal year ended
December 31, 1987, File No. 33-7591.)
*10.3.1(d) -- Amendment Number Three to the Plant Robert W. Scherer Units Numbers One and Two Purchase
and Ownership Participation Agreement among Georgia Power Company, Oglethorpe, Municipal
Electric Authority of Georgia and City of Dalton, Georgia, dated as of August 1, 1988.
(Filed as Exhibit 10.6.1(b) to the Registrant's Form 10-Q for the quarterly period ended
September 30, 1993, File No. 33-7591.)
*10.3.1(e) -- Amendment Number Four to the Plant Robert W. Scherer Units Number One and Two Purchase
and Ownership Participation Agreement among Georgia Power Company, Oglethorpe, Municipal
Electric Authority of Georgia and City of Dalton, Georgia, dated as of December 31,
1990. (Filed as Exhibit 10.6.1(c) to the Registrant's Form 10-Q for the quarterly period
ended September 30, 1993, File No. 33-7591.)
*10.3.2(a) -- Plant Robert W. Scherer Units Numbers One and Two Operating Agreement among Georgia
Power Company, Oglethorpe, Municipal Electric Authority of Georgia and City of Dalton,
Georgia, dated as of May 15, 1980. (Filed as Exhibit 10.6.2 to the Registrant's Form S-1
Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.3.2(b) -- Amendment to Plant Robert W. Scherer Units Numbers One and Two Operating Agreement among
Georgia Power Company, Oglethorpe, Municipal Electric Authority of Georgia and City of
Dalton, Georgia, dated as of December 30, 1985. (Filed as Exhibit 10.1.7 to the
Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on October 9,
1986.)
*10.3.2(c) -- Amendment Number Two to the Plant Robert W. Scherer Units Numbers One and Two Operating
Agreement among Georgia Power Company, Oglethorpe, Municipal Electric Authority of
Georgia and City of Dalton, Georgia, dated as of December 31, 1990. (Filed as Exhibit
10.6.2(a) to the Registrant's Form 10-Q for the quarterly period ended September 30,
1993, File No. 33-7591.)
*10.3.3 -- Plant Scherer Managing Board Agreement among Georgia Power Company, Oglethorpe,
Municipal Electric Authority of Georgia, City of Dalton, Georgia, Gulf Power Company,
Florida Power & Light Company and Jacksonville Electric
II-13
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
Authority, dated as of December 31, 1990. (Filed as Exhibit 10.6.3 to the Registrant's
Form 10-Q for the quarterly period ended September 30, 1993, File No. 33-7591.)
*10.4.1(a) -- Alvin W. Vogtle Nuclear Units Numbers One and Two Purchase and Ownership Participation
Agreement among Georgia Power Company, Oglethorpe, Municipal Electric Authority of
Georgia and City of Dalton, Georgia, dated as of August 27, 1976. (Filed as Exhibit
10.7.1 to the Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on
October 9, 1986.)
*10.4.1(b) -- Amendment Number One, dated January 18, 1977, to the Alvin W. Vogtle Nuclear Units
Numbers One and Two Purchase and Ownership Participation Agreement among Georgia Power
Company, Oglethorpe, Municipal Electric Authority of Georgia and City of Dalton,
Georgia. (Filed as Exhibit 10.7.3 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1986, File No. 33-7591.)
*10.4.1(c) -- Amendment Number Two, dated February 24, 1977, to the Alvin W. Vogtle Nuclear Units
Numbers One and Two Purchase and Ownership Participation Agreement among Georgia Power
Company, Oglethorpe, Municipal Electric Authority of Georgia and City of Dalton,
Georgia. (Filed as Exhibit 10.7.4 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1986, File No. 33-7591.)
*10.4.2 -- Alvin W. Vogtle Nuclear Units Numbers One and Two Operating Agreement among Georgia
Power Company, Oglethorpe, Municipal Electric Authority of Georgia and City of Dalton,
Georgia, dated as of August 27, 1976. (Filed as Exhibit 10.7.2 to the Registrant's Form
S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.5.1 -- Plant Hal Wansley Purchase and Ownership Participation Agreement between Georgia Power
Company and Oglethorpe, dated as of March 26, 1976. (Filed as Exhibit 10.8.1 to the
Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on October 9,
1986.)
*10.5.2(a) -- Plant Hal Wansley Operating Agreement between Georgia Power Company and Oglethorpe,
dated as of March 26, 1976. (Filed as Exhibit 10.8.2 to the Registrant's Form S-1
Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.5.2(b) -- Amendment, dated as of January 15, 1995, to the Plant Hal Wansley Operating Agreements
by and among Georgia Power Company, Oglethorpe, Municipal Electric Authority of Georgia
and City of Dalton, Georgia. (Filed as Exhibit 10.5.2(a) to the Registrant's Form 10-Q
for the quarterly period ended September 30, 1996, File No. 33-7591.)
*10.5.3 -- Plant Hal Wansley Combustion Turbine Agreement between Georgia Power Company and
Oglethorpe, dated as of August 2, 1982 and Amendment No. 1, dated October 20, 1982.
(Filed as Exhibit 10.18 to the Registrant's Form S-1 Registration Statement, File No.
33-7591, filed on October 9, 1986.)
*10.6.1 -- Edwin I. Hatch Nuclear Plant Purchase and Ownership Participation Agreement between
Georgia Power Company and Oglethorpe, dated as of January 6,
II-14
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
1975. (Filed as Exhibit 10.9.1 to the Registrant's Form S-1 Registration Statement, File
No. 33-7591, filed on October 9, 1986.)
*10.6.2 -- Edwin I. Hatch Nuclear Plant Operating Agreement between Georgia Power Company and
Oglethorpe, dated as of January 6, 1975. (Filed as Exhibit 10.9.2 to the Registrant's
Form S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.7.1 -- Rocky Mountain Pumped Storage Hydroelectric Project Ownership Participation Agreement,
dated as of November 18, 1988, by and between Oglethorpe and Georgia Power Company.
(Filed as Exhibit 10.22.1 to the Registrant's Form 10-K for the fiscal year ended
December 31, 1988, File No. 33-7591.)
*10.7.2 -- Rocky Mountain Pumped Storage Hydroelectric Project Operating Agreement, dated as of
November 18, 1988, by and between Oglethorpe and Georgia Power Company. (Filed as
Exhibit 10.22.2 to the Registrant's Form 10-K for the fiscal year ended December 31,
1988, File No. 33-7591.)
*10.8.1 -- Amended and Restated Wholesale Power Contract, dated as of August 1, 1996, between
Oglethorpe and Altamaha Electric Membership Corporation and all schedules thereto,
together with a Schedule identifying 37 other substantially identical Amended and
Restated Wholesale Power Contracts, and an additional Amended and Restated Wholesale
Power Contract that is not substantially identical. (Filed as Exhibit 10.8.1 to the
Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.8.2 -- Amended and Restated Supplemental Agreement, dated as of August 1, 1996, by and between
Oglethorpe, Altamaha Electric Membership Corporation and the United States of America,
together with a Schedule identifying 38 other substantially identical Amended and
Restated Supplemental Agreements. (Filed as Exhibit 10.8.2 to the Registrant's Form 10-K
for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.8.3 -- Supplemental Agreement to the Amended and Restated Wholesale Power Contract, dated as of
January 1, 1997, by and among Georgia Power Company, Oglethorpe and Altamaha Electric
Membership Corporation, together with a Schedule identifying 38 other substantially
identical Supplemental Agreements. (Filed as Exhibit 10.8.3 to the Registrant's Form
10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.8.4 -- Supplemental Agreement to the Amended and Restated Wholesale Power Contract, dated as of
March 1, 1997, by and between Oglethorpe and Altamaha Electric Membership Corporation,
together with a Schedule identifying 36 other substantially identical Supplemental
Agreements, and an additional Supplemental Agreement that is not substantially
identical. (Filed as Exhibit 10.8.4 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1996, File No. 33-7591.)
*10.8.5 -- Supplemental Agreement to the Amended and Restated Wholesale Power Contract, dated as of
March 1, 1997, by and between Oglethorpe and Coweta-Fayette Electric Membership
Corporation, together with a Schedule identifying 1 other substantially identical
Supplemental Agreement. (Filed as Exhibit 10.8.5 to the Registrant's Form 10-K for the
fiscal year ended December 31, 1996, File No. 33-7591.)
II-15
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
*10.8.6 -- Supplemental Agreement to the Amended and Restated Wholesale Power Contract, dated as of
May 1, 1997 by and between Oglethorpe and Altamaha Electric Membership Corporation,
together with a Schedule identifying 38 other substantially identical Supplemental
Agreements. (Filed as Exhibit 10.8.6 to the Registrant's Form 10-Q for the quarterly
period ended June 30, 1997, File No. 33-7591.)
*10.9 -- Transmission Facilities Operation and Maintenance Contract between Georgia Power Company
and Oglethorpe dated as of June 9, 1986. (Filed as Exhibit 10.13 to the Registrant's
Form S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.10(a) -- Joint Committee Agreement among Georgia Power Company, Oglethorpe, Municipal Electric
Authority of Georgia and the City of Dalton, Georgia, dated as of August 27, 1976.
(Filed as Exhibit 10.14(b) to the Registrant's Form S-1 Registration Statement, File No.
33-7591, filed on October 9, 1986.)
*10.10(b) -- First Amendment to Joint Committee Agreement among Georgia Power Company, Oglethorpe,
Municipal Electric Authority of Georgia and the City of Dalton, Georgia, dated as of
June 19, 1978. (Filed as Exhibit 10.14(a) to the Registrant's Form S-1 Registration
Statement, File No. 33-7591, filed on October 9, 1986.)
*10.11 -- Interconnection Agreement between Oglethorpe and Alabama Electric Cooperative, Inc.,
dated as of November 12, 1990. (Filed as Exhibit 10.16(a) to the Registrant's Form 10-K
for the fiscal year ended December 31, 1990, File No. 33-7591.)
*10.11(a) -- Amendment No. 1 to Interconnection Agreement between Alabama Electric Cooperative, Inc.
and Oglethorpe, dated as of April 22, 1994. (Filed as Exhibit 10.11(a) to the
Registrant's Form 10-Q for the quarter ended June 30, 1994, File No. 33-7591.)
*10.11(b) -- Letter of Commitment (Firm Power Sale) Under Service Schedule J-- Negotiated Interchange
Service between Alabama Electric Cooperative, Inc. and Oglethorpe, dated March 31, 1994.
(Filed as Exhibit 10.11(b) to the Registrant's Form 10-Q for the quarter ended June 30,
1994, File No. 33-7591.)
*10.12 -- Oglethorpe Deferred Compensation Plan for Key Employees, as Amended and Restated
January, 1987. (Filed as Exhibit 10.19 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1986, File No. 33-7591.)
*10.13.1 -- Assignment of Power System Agreement and Settlement Agreement, dated January 8, 1975, by
Georgia Electric Membership Corporation to Oglethorpe. (Filed as Exhibit 10.20.1 to the
Registrant's Form S-1 Registration Statement, File No. 33-7591, filed on October 9,
1986.)
*10.13.2 -- Power System Agreement, dated April 24, 1974, by and between Georgia Electric Membership
Corporation and Georgia Power Company. (Filed as Exhibit 10.20.2 to the Registrant's
Form S-1 Registration Statement, File No. 33-7591, filed on October 9, 1986.)
*10.13.3 -- Settlement Agreement, dated April 24, 1974, by and between Georgia Power Company,
Georgia Municipal Association, Inc., City of Dalton, Georgia Electric Membership
Corporation and Crisp County Power Commission. (Filed as
II-16
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
Exhibit 10.20.3 to the Registrant's Form S-1 Registration Statement, File No. 33-7591,
filed on October 9, 1986.)
*10.14 -- Distribution Facilities Joint Use Agreement between Oglethorpe and Georgia Power
Company, dated as of May 12, 1986. (Filed as Exhibit 10.21 to the Registrant's Form 10-K
for the fiscal year ended December 31, 1986, File No. 33-7591.)
*10.15.1 -- Long-Term Firm Power Purchase Agreement, dated as of July 19, 1989, by and between
Oglethorpe and Big Rivers Electric Corporation. (Filed as Exhibit 10.24.1 to the
Registrant's Form 10-K for the fiscal year ended December 31, 1989, File No. 33-7591.)
*10.15.2 -- Coordination Services Agreement, dated as of August 21, 1989, by and between Oglethorpe
and Georgia Power Company. (Filed as Exhibit 10.24.2 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1989, File No. 33-7591.)
*10.15.3 -- Long-Term Firm Power Purchase Agreement between Big Rivers Electric Corporation and
Oglethorpe, dated as of December 17, 1990. (Filed as Exhibit 10.24.3 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1990, File No. 33-7591.)
*10.15.4 -- Interchange Agreement between Oglethorpe and Big Rivers Electric Corporation, dated as
of November 12, 1990. (Filed as Exhibit 10.24.4 to the Registrant's Form 10-K for the
fiscal year ended December 31, 1990, File No. 33-7591.)
*10.16 -- Block Power Sale Agreement between Georgia Power Company and Oglethorpe, dated as of
November 12, 1990. (Filed as Exhibit 10.25 to the Registrant's Form 8-K, filed January
4, 1991, File No. 33-7591.)
*10.17 -- Coordination Services Agreement between Georgia Power Company and Oglethorpe, dated as
of November 12, 1990. (Filed as Exhibit 10.26 to the Registrant's Form 8-K, filed
January 4, 1991, File No. 33-7591.)
*10.18 -- Revised and Restated Integrated Transmission System Agreement between Oglethorpe and
Georgia Power Company, dated as of November 12, 1990. (Filed as Exhibit 10.27 to the
Registrant's Form 8-K, filed January 4, 1991, File No. 33-7591.)
*10.19 -- ITSA, Power Sale and Coordination Umbrella Agreement between Oglethorpe and Georgia
Power Company, dated as of November 12, 1990. (Filed as Exhibit 10.28 to the
Registrant's Form 8-K, filed January 4, 1991, File No. 33-7591.)
*10.20 -- Amended and Restated Nuclear Managing Board Agreement among Georgia Power Company,
Oglethorpe Power Corporation, Municipal Electric Authority of Georgia and City of
Dalton, Georgia dated as of July 1, 1993. (Filed as Exhibit 10.36 to the Registrant's
10-Q for the quarterly period ended September 30, 1993, File No. 33-7591.)
*10.21 -- Supplemental Agreement by and among Oglethorpe, Tri-County Electric Membership
Cooperation and Georgia Power Company, dated as of November 12, 1990, together with a
Schedule identifying 38 other substantially identical
II-17
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
Supplemental Agreements. (Filed as Exhibit 10.30 to the Registrant's Form 8-K, filed
January 4, 1991, File No. 33-7591.)
*10.22 -- Unit Capacity and Energy Purchase Agreement between Oglethorpe and Entergy Power
Incorporated, dated as of October 11, 1990. (Filed as Exhibit 10.31 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1990, File No. 33-7591.)
*10.23 -- Interchange Agreement between Oglethorpe and Arkansas Power & Light Company, Louisiana
Power & Light Company, Mississippi Power & Light Company, New Orleans Public Service,
Inc., Energy Services, Inc., dated as of November 12, 1990. (Filed as Exhibit 10.32 to
the Registrant's Form 10-K for the fiscal year ended December 31, 1990, File No.
33-7591.)
*10.24 -- Interchange Agreement between Oglethorpe and Seminole Electric Cooperative, Inc., dated
as of November 12, 1990. (Filed as Exhibit 10.33 to the Registrant's Form 10-K for the
fiscal year ended December 31, 1990, File No. 33-7591.)
*10.25.1 -- Excess Energy and Short-term Power Agreement between Oglethorpe and Tennessee Valley
Authority, effective as of January 23, 1991. (Filed as Exhibit 10.34.1 to the
Registrant's Form 10-K for the fiscal year ended December 31, 1990, File No. 33-7591.)
*10.25.2 -- Transmission Service Agreement between Oglethorpe and Tennessee Valley Authority,
effective as of January 23, 1991. (Filed as Exhibit 10.34.2 to the Registrant's Form
10-K for the fiscal year ended December 31, 1990, File No. 33-7591.)
*10.26 -- Power Purchase Agreement between Oglethorpe and Hartwell Energy Limited Partnership,
dated as of June 12, 1992. (Filed as Exhibit 10.35 to the Registrant's Form 10-K for the
fiscal year ended December 31, 1992, File No. 33-7591).
*10.27(5) -- Master Power Purchase and Sale Agreement between Enron Power Marketing, Inc. and
Oglethorpe, dated as of January 3, 1996. (Filed as Exhibit 10.27 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1995, File No. 33-7591.)
*10.27(a)(5) -- Extension and Modification Agreement between Enron Power Marketing, Inc. and Oglethorpe,
dated as of April 30, 1996. (Filed as Exhibit 10.27(a) to the Registrant's Form 10-Q for
the quarterly period ended March 31, 1996, File No. 33-7591.)
*10.28 -- Employment Agreement between Oglethorpe and T. D. Kilgore, dated as of December 20,
1995. (Filed as Exhibit 10.28 to the Registrant's Form 10-K for the fiscal year ended
December 31, 1995, File No. 33-7591.)
*10.29(5) -- Master Power Purchase and Sale Agreement between Duke/Louis Dreyfus L.L.C. and
Oglethorpe, dated as of August 31, 1996. (Filed as Exhibit 10.29 to the Registrant's
Form 10-Q for the quarterly period ended September 30, 1996, File No. 33-7591.)
*10.30(5) -- Power Purchase and Sale Agreement among LG&E Power Marketing Inc., LG&E Energy Corp. and
Oglethorpe, dated as of November 19, 1996. (Filed as
II-18
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
Exhibit 10.30 to the Registrant's Form 10-K for the fiscal year ended December 31, 1996,
File No. 33-7591.)
*10.31(5) -- Power Purchase and Sale Agreement among LG&E Power Marketing Inc., LG&E Power Inc. and
Oglethorpe, dated as of January 1, 1997. (Filed as Exhibit 10.31 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.1 -- Participation Agreement (P1), dated as of December 30, 1996, among Oglethorpe, Rocky
Mountain Leasing Corporation, Fleet National Bank, as Owner Trustee, SunTrust Bank,
Atlanta, as Co-Trustee, the Owner Participant named therein and Utrecht-America Finance
Co., as Lender, together with a Schedule identifying five other substantially identical
Participation Agreements. (Filed as Exhibit 10.32.1 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.2 -- Rocky Mountain Head Lease Agreement (P1), dated as of December 30, 1996, between
Oglethorpe and SunTrust Bank, Atlanta, as Co-Trustee, together with a Schedule
identifying five other substantially identical Rocky Mountain Head Lease Agreements.
(Filed as Exhibit 10.32.2 to the Registrant's Form 10-K for the fiscal year ended
December 31, 1996, File No. 33-7591.)
*10.32.3 -- Ground Lease Agreement (P1), dated as of December 30, 1996, between Oglethorpe and
SunTrust Bank, Atlanta, as Co-Trustee, together with a Schedule identifying five other
substantially identical Ground Lease Agreements. (Filed as Exhibit 10.32.3 to the
Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.4 -- Rocky Mountain Agreements Assignment and Assumption Agreement (P1), dated as of December
30, 1996, between Oglethorpe and SunTrust Bank, Atlanta, as Co-Trustee, together with a
Schedule identifying five other substantially identical Rocky Mountain Agreements
Assignment and Assumption Agreements. (Filed as Exhibit 10.32.4 to the Registrant's Form
10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.5 -- Facility Lease Agreement (P1), dated as of December 30, 1996, between SunTrust Bank,
Atlanta, as Co-Trustee and Rocky Mountain Leasing Corporation, together with a Schedule
identifying five other substantially identical Facility Lease Agreements. (Filed as
Exhibit 10.32.5 to the Registrant's Form 10-K for the fiscal year ended December 31,
1996, File No. 33-7591.)
*10.32.6 -- Ground Sublease Agreement (P1), dated as of December 30, 1996, between SunTrust Bank,
Atlanta, as Co-Trustee and Rocky Mountain Leasing Corporation, together with a Schedule
identifying five other substantially identical Ground Sublease Agreements. (Filed as
Exhibit 10.32.6 to the Registrant's Form 10-K for the fiscal year ended December 31,
1996, File No. 33-7591.)
*10.32.7 -- Rocky Mountain Agreements Re-assignment and Assumption Agreement (P1), dated as of
December 30, 1996, between SunTrust Bank, Atlanta, as Co-Trustee and Rocky Mountain
Leasing Corporation, together with a Schedule identifying five other substantially
identical Rocky Mountain Agreements Re-assignment and Assumption Agreements. (Filed as
Exhibit 10.32.7 to the Registrant's Form 10-K for the fiscal year ended December 31,
1996, File No. 33-7591.)
II-19
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
*10.32.8 -- Facility Sublease Agreement (P1), dated as of December 30, 1996, between Oglethorpe and
Rocky Mountain Leasing Corporation, together with a Schedule identifying five other
substantially identical Facility Sublease Agreements. (Filed as Exhibit 10.32.8 to the
Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.9 -- Ground Sub-sublease Agreement (P1), dated as of December 30, 1996, between Rocky
Mountain Leasing Corporation and Oglethorpe, together with a Schedule identifying five
other substantially identical Ground Sub-sublease Agreements. (Filed as Exhibit 10.32.9
to the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No.
33-7591.)
*10.32.10 -- Rocky Mountain Agreements Second Re-assignment and Assumption Agreement (P1), dated as
of December 30, 1996, between Rocky Mountain Leasing Corporation and Oglethorpe,
together with a Schedule identifying five other substantially identical Rocky Mountain
Agreements Second Re-assignment and Assumption Agreements. (Filed as Exhibit 10.32.10 to
the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No.
33-7591.)
*10.32.11 -- Payment Undertaking Agreement (P1), dated as of December 30, 1996, between Rocky
Mountain Leasing Corporation and Cooperatieve Centrale Raiffeisen-Boerenleenbank B.A.,
New York Branch, as the Bank, together with a Schedule identifying five other
substantially identical Payment Undertaking Agreements. (Filed as Exhibit 10.32.11 to
the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No.
33-7591.)
*10.32.12 -- Payment Undertaking Pledge Agreement (P1), dated as of December 30, 1996, between Rocky
Mountain Leasing Corporation, Fleet National Bank, as Owner Trustee, and SunTrust Bank,
Atlanta, as Co-Trustee, together with a Schedule identifying five other substantially
identical Payment Undertaking Pledge Agreements. (Filed as Exhibit 10.32.12 to the
Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.13 -- Equity Funding Agreement (P1), dated as of December 30, 1996, between Rocky Mountain
Leasing Corporation, AIG Match Funding Corp., the Owner Participant named therein, Fleet
National Bank, as Owner Trustee, and SunTrust Bank, Atlanta, as Co-Trustee, together
with a Schedule identifying five other substantially identical Equity Funding
Agreements. (Filed as Exhibit 10.32.13 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1996, File No. 33-7591.)
*10.32.14 -- Equity Funding Pledge Agreement (P1), dated as of December 30, 1996, between Rocky
Mountain Leasing Corporation and SunTrust Bank, Atlanta, as Co-Trustee, together with a
Schedule identifying five other substantially identical Equity Funding Pledge
Agreements. (Filed as Exhibit 10.32.14 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1996, File No. 33-7591.)
*10.32.15 -- Deed to Secure Debt, Assignment of Surety Bond and Security Agreement (P1), dated as of
December 30, 1996, between Rocky Mountain Leasing Corporation, SunTrust Bank, Atlanta,
as Co-Trustee, together with a Schedule identifying five other substantially identical
Collateral Assignment, Assignment of Surety Bond
II-20
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
and Security Agreements. (Filed as Exhibit 10.32.15 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.32.16 -- Subordinated Deed to Secure Debt and Security Agreement (P1), dated as of December 30,
1996, among Oglethorpe, AMBAC Indemnity Corporation and SunTrust Bank, Atlanta, as
Co-Trustee, together with a Schedule identifying five other substantially identical
Subordinated Deed to Secure Debt and Security Agreements. (Filed as Exhibit 10.32.16 to
the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No.
33-7591.)
*10.32.17 -- Tax Indemnification Agreement (P1), dated as of December 30, 1996, between Oglethorpe
and the Owner Participant named therein, together with a Schedule identifying five other
substantially identical Tax Indemnification Agreements. (Filed as Exhibit 10.32.17 to
the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File No.
33-7591.)
*10.32.18 -- Consent No. 1, dated as of December 30, 1996, among Georgia Power Company, Oglethorpe,
SunTrust Bank, Atlanta, as Co-Trustee, and Fleet National Bank, as Owner Trustee,
together with a Schedule identifying five other substantially identical Consents. (Filed
as Exhibit 10.32.18 to the Registrant's Form 10-K for the fiscal year ended December 31,
1996, File No. 33-7591.)
*10.32.19(a) -- OPC Intercreditor and Security Agreement No. 1, dated as of December 30, 1996, among the
United States of America, acting through the Administrator of the Rural Utilities
Service, SunTrust Bank, Atlanta, Oglethorpe, Rocky Mountain Leasing Corporation,
SunTrust Bank, Atlanta, as Co-Trustee, Fleet National Bank, as Owner Trustee,
Utrecht-America Finance Co., as Lender and AMBAC Indemnity Corporation, together with a
Schedule identifying five other substantially identical Intercreditor and Security
Agreements. (Filed as Exhibit 10.32.19 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1996, File No. 33-7591.)
10.32.19(b) -- Supplement to OPC Intercreditor and Security Agreement No. 1, dated as of March 1, 1997,
among the United States of America, acting through the Administrator of the Rural
Utilities Service, SunTrust Bank, Atlanta, Oglethorpe, Rocky Mountain Leasing
Corporation, SunTrust Bank, Atlanta, as Co-Trustee, Fleet National Bank, as Owner
Trustee, Utrecht-America Finance Co., as Lender and AMBAC Indemnity Corporation,
together with a Schedule identifying five other substantially identical Supplements to
OPC Intercreditor and Security Agreements.
*10.33.1 -- Member Transmission Service Agreement, dated as of March 1, 1997, by and between
Oglethorpe and Georgia Transmission Corporation (An Electric Membership Corporation).
(Filed as Exhibit 10.33.1 to the Registrant's Form 10-K for the fiscal year ended
December 31, 1996, File No. 33-7591.)
*10.33.2 -- Generation Services Agreement, dated as of March 1, 1997, by and between Oglethorpe and
Georgia System Operations Corporation. (Filed as Exhibit 10.33.2 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1996, File No. 33-7591.)
*10.33.3 -- Operation Services Agreement, dated as of March 1, 1997, by and between Oglethorpe and
Georgia System Operations Corporation. (Filed as Exhibit
II-21
NUMBER DESCRIPTION
- ---------------- ----------------------------------------------------------------------------------------
10.33.3 to the Registrant's Form 10-K for the fiscal year ended December 31, 1996, File
No. 33-7591.)
*10.34 -- Power Purchase and Sale Agreement between Morgan Stanley Capital Group Inc. and
Oglethorpe, dated as of April 7, 1997. (Filed as Exhibit 10.34 to the Registrant's Form
10-Q for the quarterly period ended March 30, 1997, File No. 33-7591.)
++10.35 -- Purchase Contract, dated December 11, 1997, by and among Oglethorpe, OPC Scherer 1997
Funding Corporation A and Goldman, Sachs & Co., as representative of the purchasers
named therein.
12 -- Statement regarding computation of ratio of earnings to fixed charges.
15 -- Letter from Coopers & Lybrand L.L.P. regarding unaudited interim financial information.
21.1 -- Rocky Mountain Leasing Corporation, a Delaware corporation.
++23.1 -- Consent of Sutherland, Asbill & Brennan LLP (included in their opinion filed as Exhibit
5).
23.2 -- Consent of Coopers & Lybrand L.L.P.
23.3 -- Consent of Arthur Andersen LLP.
24 -- Power of Attorney (included in Part II of the Registration Statement).
25 -- Form T-1, Statement of Eligibility and Qualification under the Trust Indenture Act of
1939 of SunTrust Bank, Atlanta, as Indenture Trustee.
27.1 -- Financial Data Schedule (for SEC use only).
++99.1 -- Form of Letter of Transmittal.
- ------------------------
* Incorporated by reference to exhibits previously filed by the Registrant as
indicated in parentheses following the description of the exhibit.
++ To be filed by amendment.
(1) Pursuant to 17 C.F.R. 229.601(b)(4)(iii), this document is not filed
herewith; however the registrant hereby agrees that such document will be
provided to the Commission upon request.
(2) For the reason stated in footnote (1), this document and six other
substantially identical documents are not filed as exhibits to this
Registration Statement.
(3) For the reason stated in footnote (1), this document and another
substantially identical document are not filed as exhibits to this
Registration Statement.
(4) For the reason stated in footnote (1), this document and three other
substantially identical documents are not filed as exhibits to this
Registration Statement.
(5) Certain portions of this document have been omitted as confidential and
filed separately with the Commission.
II-22