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FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2000
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Commission file number 1-12579
OGE ENERGY CORP.
(Exact name of registrant as specified in its charter)
Oklahoma 73-1481638
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
321 North Harvey
P. O. Box 321
Oklahoma City, Oklahoma 73101-0321
(Address of principal executive offices)
(Zip Code)
405-553-3000
(Registrant's telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the Securities
Exchange Act of 1934 during the preceding 12 months (or for such shorter
period that the registrant was required to file such reports), and (2) has
been subject to such filing requirements for the past 90 days.
Yes X No
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There were 77,863,370 Shares of Common Stock, par value $0.01 per share,
outstanding as of July 31, 2000.
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OGE ENERGY CORP.
PART I. FINANCIAL INFORMATION
ITEM 1 FINANCIAL STATEMENTS
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
3 Months Ended 6 Months Ended
June 30 June 30
-------------------------------- ---------------------------------
2000 1999 2000 1999
-------------- -------------- -------------- --------------
(THOUSANDS EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C>
OPERATING REVENUES:
Electric utility......................................... $ 335,573 $ 314,102 $ 580,905 $ 564,246
Non-utility subsidiaries................................. 391,331 136,759 727,580 264,820
-------------- -------------- -------------- --------------
Total operating revenues............................... 726,904 450,861 1,308,485 829,066
-------------- -------------- -------------- --------------
OPERATING EXPENSES:
Fuel..................................................... 97,930 75,284 159,930 132,966
Purchased power.......................................... 62,124 62,267 122,666 121,390
Gas and electricity purchased for resale................. 315,529 110,899 565,070 212,356
Other operation and maintenance.......................... 118,855 79,390 235,130 153,734
Depreciation and amortization............................ 44,997 37,323 89,916 75,586
Taxes other than income.................................. 15,723 12,551 31,831 25,812
-------------- -------------- -------------- --------------
Total operating expenses............................... 655,158 377,714 1,204,543 721,844
-------------- -------------- -------------- --------------
OPERATING INCOME........................................... 71,746 73,147 103,942 107,222
-------------- -------------- -------------- --------------
OTHER INCOME, net.......................................... 4,855 1,020 4,654 1,336
-------------- -------------- -------------- --------------
EARNINGS BEFORE INTEREST AND TAXES......................... 76,601 74,167 108,596 108,558
INTEREST INCOME (EXPENSES):
Interest income.......................................... 596 718 2,205 1,210
Interest on long-term debt............................... (25,917) (15,416) (51,304) (30,218)
Interest on trust preferred securities................... (4,317) --- (8,634) ---
Other interest charges................................... (1,949) (3,858) (7,415) (7,354)
-------------- -------------- -------------- --------------
Net interest income (expenses)......................... (31,587) (18,556) (65,148) (36,362)
-------------- -------------- -------------- --------------
EARNINGS BEFORE INCOME TAXES............................... 45,014 55,611 43,448 72,196
PROVISION FOR INCOME TAXES................................. 13,270 17,867 10,928 23,320
-------------- -------------- -------------- --------------
NET INCOME................................................. $ 31,744 $ 37,744 $ 32,520 $ 48,876
============== ============== ============== ==============
AVERAGE COMMON SHARES OUTSTANDING.......................... 77,863 77,801 77,863 77,801
EARNINGS PER AVERAGE COMMON SHARE.......................... $ 0.41 $ 0.49 $ 0.42 $ 0.63
============== ============== ============== ==============
EARNINGS PER AVERAGE COMMON SHARE -
ASSUMING DILUTION........................................ $ 0.41 $ 0.49 $ 0.42 $ 0.63
============== ============== ============== ==============
DIVIDENDS DECLARED PER SHARE............................... $ 0.3325 $ 0.3325 $ 0.6650 $ 0.6650
<FN>
THE ACCOMPANYING NOTES TO CONSOLIDATED FINANCIAL STATEMENTS ARE AN INTEGRAL PART HEREOF.
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CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
JUNE 30 DECEMBER 31
2000 1999
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(DOLLARS IN THOUSANDS)
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ASSETS
CURRENT ASSETS:
Cash and cash equivalents..................................... $ 17,777 $ 7,271
Accounts receivable - customers, less reserve of $8,253 and
$5,270, respectively........................................ 240,373 263,708
Accrued unbilled revenues..................................... 58,300 40,200
Accounts receivable - other................................... 48,757 10,462
Fuel inventories, at LIFO cost................................ 162,860 117,185
Materials and supplies, at average cost....................... 41,738 39,194
Prepayments and other......................................... 20,122 16,911
Accumulated deferred tax assets............................... 8,116 8,729
------------- --------------
Total current assets........................................ 598,043 503,660
------------- --------------
OTHER PROPERTY AND INVESTMENTS, at cost......................... 33,668 31,012
------------- --------------
PROPERTY, PLANT AND EQUIPMENT:
In service.................................................... 5,224,736 5,209,783
Construction work in progress................................. 98,450 56,553
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Total property, plant and equipment......................... 5,323,186 5,266,336
Less accumulated depreciation............................. 2,095,996 2,024,349
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Net property, plant and equipment............................. 3,227,190 3,241,987
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DEFERRED CHARGES:
Advance payments for gas...................................... 11,800 11,800
Income taxes recoverable through future rates................. 39,173 39,692
Other......................................................... 123,455 93,183
------------- --------------
Total deferred charges...................................... 174,428 144,675
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TOTAL ASSETS.................................................... $ 4,033,329 $ 3,921,334
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LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES:
Short-term debt............................................... $ 218,300 $ 589,100
Accounts payable.............................................. 215,383 161,183
Dividends payable............................................. 25,890 25,889
Customers' deposits........................................... 22,088 22,138
Accrued taxes................................................. 29,644 41,215
Accrued interest.............................................. 36,244 28,191
Long-term debt due within one year............................ 59,000 59,000
Other......................................................... 42,386 40,145
------------- --------------
Total current liabilities................................... 648,935 966,861
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LONG-TERM DEBT.................................................. 1,649,819 1,250,532
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DEFERRED CREDITS AND OTHER LIABILITIES:
Accrued pension and benefit obligation........................ 19,805 16,686
Accumulated deferred income taxes............................. 583,187 566,137
Accumulated deferred investment tax credits................... 60,003 62,578
Other......................................................... 71,460 39,161
------------- --------------
Total deferred credits and other liabilities................ 734,455 684,562
------------- --------------
STOCKHOLDERS' EQUITY:
Common stockholders' equity................................... 441,847 441,847
Retained earnings............................................. 558,273 577,532
------------- --------------
Total stockholders' equity.................................. 1,000,120 1,019,379
------------- --------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY...................... $ 4,033,329 $ 3,921,334
============= ==============
<FN>
THE ACCOMPANYING NOTES TO CONSOLIDATED FINANCIAL STATEMENTS ARE AN INTEGRAL PART HEREOF.
</FN>
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CONSOLIDATED STATEMENTS OF
CASH FLOWS
(UNAUDITED)
6 MONTHS ENDED
JUNE 30
2000 1999
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(DOLLARS IN THOUSANDS)
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CASH FLOWS FROM OPERATING ACTIVITIES:
Net Income......................................................... $ 32,520 $ 48,876
Adjustments to Reconcile Net Income to Net
Cash Provided from Operating Activities:
Depreciation and amortization.................................... 89,916 75,586
Deferred income taxes and investment tax credits, net............ 15,177 (9,495)
Gain on sale of assets........................................... (4,624) ---
Change in Certain Current Assets and Liabilities:
Accounts receivable - customers................................ 23,335 (3,574)
Accrued unbilled revenues...................................... (18,100) (36,500)
Fuel, materials and supplies inventories....................... (48,219) (34,470)
Accumulated deferred tax assets................................ 613 (798)
Other current assets........................................... (41,506) 8,520
Accounts payable............................................... 54,200 2,520
Accrued taxes.................................................. (11,571) 14,632
Accrued interest............................................... 8,053 530
Other current liabilities...................................... 2,192 (17,857)
Other operating activities....................................... 12,274 16,081
-------------- --------------
Net cash provided from operating activities.................. 114,260 64,051
-------------- --------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures............................................... (91,481) (89,336)
Proceeds from sale of assets....................................... 11,119 ---
Other investment activities........................................ 188 (22,132)
-------------- --------------
Net cash used in investing activities........................ (80,174) (111,468)
-------------- --------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Retirement of long-term debt....................................... (1,000) (1,000)
Proceeds from long-term debt....................................... 400,000 ---
Short-term debt, net............................................... (370,800) 179,700
Redemption of common stock......................................... --- (77,962)
Cash dividends declared on common stock............................ (51,780) (51,737)
-------------- --------------
Net cash provided from (used in) financing activities........ (23,580) 49,001
-------------- --------------
NET INCREASE IN CASH AND CASH EQUIVALENTS............................ 10,506 1,584
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD..................... 7,271 378
-------------- --------------
CASH AND CASH EQUIVALENTS AT END OF PERIOD........................... $ 17,777 $ 1,962
============== ==============
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SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash Paid During the Period for:
Interest (net of amount capitalized)............................. $ 48,462 $ 29,640
Income taxes..................................................... $ 7,665 $ 17,450
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NON-CASH INVESTING AND FINANCING ACTIVITIES
Other investing and financing activities......................... $ 2,400 $ ---
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DISCLOSURE OF ACCOUNTING POLICY:
For purposes of these statements, the Company considers all highly liquid debt
instruments purchased with a maturity of three months or less to be cash
equivalents. These investments are carried at cost, which approximates market.
THE ACCOMPANYING NOTES TO CONSOLIDATED FINANCIAL STATEMENTS ARE AN INTEGRAL PART HEREOF.
</FN>
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
1. The condensed consolidated financial statements included herein have been
prepared by OGE Energy Corp. (the "Company"), without audit, pursuant to
the rules and regulations of the Securities and Exchange Commission.
Certain information and footnote disclosures normally included in financial
statements prepared in accordance with accounting principles generally
accepted in the United States have been condensed or omitted pursuant to
such rules and regulations; however, the Company believes that the
disclosures are adequate to make the information presented not misleading.
In the opinion of management, all adjustments necessary to present fairly
the financial position of the Company and its subsidiaries as of June 30,
2000, and December 31, 1999, and the results of operations and the changes
in cash flows for the periods ended June 30, 2000, and June 30, 1999, have
been included and are of a normal recurring nature. Certain amounts have
been reclassified on the financial statements to conform with the 2000
presentation.
The results of operations for such interim periods are not necessarily
indicative of the results for the full year. It is suggested that these
condensed consolidated financial statements be read in conjunction with the
consolidated financial statements and the notes thereto included in the
Company's Form 10-K for the year ended December 31, 1999.
2. The Company is a holding company, which was incorporated in August 1995 in
the State of Oklahoma. The Company is not engaged in any business
independent of that conducted through its subsidiaries, Oklahoma Gas and
Electric Company ("OG&E"), Enogex Inc. and Enogex Inc.'s subsidiaries
("Enogex"), and OGE Energy Capital Trust I, a financing trust established
in 1999.
OG&E is a regulated public utility that owns and operates an interconnected
electric production, transmission and distribution system.
Enogex is an Oklahoma intrastate natural gas pipeline company that also
conducts related operations, through its subsidiaries, in interstate and
intrastate gas transmission, natural gas gathering, natural gas processing,
natural gas and electricity marketing, and oil and gas development and
production.
3. In June 1998, the Financial Accounting Standards Board ("FASB") issued
Statement of Financial Accounting Standards ("SFAS") No. 133, "Accounting
for Derivative Instruments and for Hedging Activities", with an effective
date for periods beginning after June 15, 1999. In July 1999, the FASB
issued SFAS No. 137, "Accounting for Derivative Instruments and Hedging
Activities - Deferral of the Effective Date of FASB Statement No. 133". As
a result of SFAS No. 137, adoption of SFAS No. 133 is now required for
financial statements for periods beginning after June 15, 2000. In June
2000, the FASB issued SFAS No. 138,
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"Accounting for Certain Derivative Instruments and Certain Hedging
Activities", which amends the accounting and reporting standards of SFAS
No. 133 for certain derivative instruments and hedging activities. SFAS No.
133 sweeps in a broad population of transactions and changes the previous
accounting definition of a derivative instrument. Under SFAS No. 133, every
derivative instrument is recorded in the balance sheet as either an asset
or liability measured at its fair value. SFAS No. 133 requires that changes
in the derivative's fair value be recognized currently in earnings unless
specific hedge accounting criteria are met. The Company will prospectively
adopt this new standard effective January 1, 2001, and management believes
the adoption of this new standard will not have a material impact on its
consolidated financial position or results of operation.
4. Enogex, in the normal course of business, enters into fixed price contracts
for either the purchase or sale of natural gas and electricity at future
dates. Due to fluctuations in the natural gas and electricity markets, the
Company buys or sells natural gas and electricity futures contracts, swaps
or options to hedge the price and basis risk associated with the
specifically identified purchase or sales contracts. Additionally, the
Company may use these contracts as an enhancement or speculative trade,
subject to the Company's policies on risk management. For qualifying
hedges, the Company accounts for changes in the market value of futures
contracts as a deferred gain or loss until the production month for hedged
transactions, at which time the gain or loss on the natural gas or
electricity futures contract, swap or option is recognized in the results
of operations. As market values change, the Company recognizes the gain or
loss on enhancement or speculative contracts in the results of operations.
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ITEM 2 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
RESULTS OF OPERATIONS
OVERVIEW
The following discussion and analysis presents factors which affected the
results of operations for the three and six months ended June 30, 2000
(respectively, the "current periods"), and the financial position as of June 30,
2000, of the Company and its subsidiaries: OG&E and Enogex. Unless indicated
otherwise, all comparisons are with the corresponding periods of the prior year.
For the current periods, approximately 54 percent and 56 percent of the
Company's revenues consisted of the non-utility operations of Enogex, while the
remaining 46 percent and 44 percent was provided by the regulated sales of
electricity by OG&E, a public utility. Revenues from sales of electricity are
somewhat seasonal, with a large portion of OG&E's annual electric revenues
occurring during the summer months when the electricity needs of its customers
increase. Actions of the regulatory commissions that set OG&E's electric rates
will continue to affect the Company's financial results.
On July 1, 1999, Enogex completed its previously announced acquisition of
Transok LLC and its subsidiaries ("Transok"), a gatherer, processor, and
transporter of natural gas in Oklahoma and Texas. Enogex purchased Transok from
Tejas Energy LLC, an affiliate of Shell Oil Company, for $710.3 million, which
includes assumption of $173 million of long-term debt.
Some of the matters discussed in this Form 10-Q may contain forward-looking
statements that are subject to certain risks, uncertainties and assumptions.
Actual results may vary materially. Factors that could cause actual results to
differ materially include, but are not limited to: general economic conditions,
including their impact on capital expenditures; business conditions in the
energy industry; competitive factors; unusual weather; regulatory decisions and
other risk factors listed in the Company's Form 10-K for the year ended December
31, 1999 including Exhibit 99.01 thereto and other factors described from time
to time in the Company's reports to the Securities and Exchange Commission.
EARNINGS
Net income decreased $6.0 million or 15.9 percent in the three months ended
June 30, 2000. Of the $6.0 million decrease, approximately $4.2 million was
attributable to OG&E. OG&E's decrease in earnings for the three months ended
June 30, 2000 was primarily attributable to increased operating expenses, which
more than offset increased revenues at OG&E. This decrease in net income was
partially offset by a $1.1 million increase attributable to Enogex. Enogex's
earnings increased in the three months ended June 30, 2000 primarily due to the
positive effects from its acquisition of Transok and from increased sales
volumes and prices in natural gas gathering and transportation, gas processing
and marketing of natural gas. A decrease in net income of $2.9 million was
attributable to increased expenses at the corporate
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level. For the six months ended June 30, 2000, net income decreased $16.4
million or 33.5 percent. Of the $16.4 million decrease, approximately $17.6
million was attributable to OG&E and approximately $4.3 million was attributable
to increased expenses at the corporate level. These decreases were partially
offset by a $5.5 million increase attributable to Enogex. As explained below,
OG&E's decrease in earnings for the six months ending June 30, 2000, was
primarily attributable to higher operating expenses. The increase in Enogex
earnings for the six months ended June 30, 2000 is attributable to the positive
effects from its acquisition of Transok and from increased sales volumes and
prices in natural gas gathering and transportation, gas processing and marketing
of natural gas. Earnings per average common share decreased from $0.49 to $0.41
and $0.63 to $0.42 in the current periods.
REVENUES
Total operating revenues increased $276.0 million or 61.2 percent and
$479.4 million or 57.8 percent in the current periods. These increases were
attributable primarily to significantly increased Enogex revenues reflecting in
large part its acquisition of Transok in July 1999.
Enogex revenues increased $254.6 million or 186.1 percent and $462.8
million or 174.7 percent in the current periods largely due to the inclusion of
the revenues from Transok's operations and increased prices and sales activity
pursuant to its trading and energy services unit. The integration of Transok's
pipeline with those of Enogex has increased gas transportation revenue and
provided Enogex's gas marketing unit with a better platform from which to market
natural gas.
OG&E revenues increased $21.5 million or 6.8 percent and $16.7 million or
3.0 percent in the current periods. These increases resulted primarily from the
recovery of higher priced fuel costs. Variances in the actual cost of fuel used
in electric generation and certain purchased power costs, as compared to that
component in cost-of-service for ratemaking, are passed through to OG&E's
electric customers through automatic fuel adjustment clauses. The automatic fuel
adjustment clauses are subject to periodic review by the Oklahoma Corporation
Commission ("OCC"), the Arkansas Public Service Commission ("APSC") and the
Federal Energy Regulatory Commission ("FERC"). Enogex owns and operates a
pipeline business that delivers natural gas to the generating stations of OG&E.
The OCC, the APSC and the FERC have authority to examine the appropriateness of
any gas transportation charges or other fees OG&E pays Enogex, which OG&E seeks
to recover through the fuel adjustment clause or other tariffs. See "Regulation
and Rates." Revenue was unfavorably affected in the current periods by
approximately $3.6 million and $7.7 million, due to modifications of the
Generation Efficiency Performance Rider ("GEP Rider") and by approximately $2.8
million and $3.6 million, due to lower recoveries under the Acquisition Premium
Credit Rider ("APC Rider"). See "Regulation and Rates" - "Recent Regulatory
Matters." Increases in kilowatt-hour sales of 5.4 percent and 4.8 percent to
OG&E's electric customers ("system sales") in the current periods were primarily
attributable to more favorable weather in OG&E's service area, which partially
offset the impact of the GEP Rider modifications and the APC Rider.
Kilowatt-hour sales to other utilities and power marketers ("off-system sales")
decreased 44.7 percent in the three months ended June 30, 2000 and increased 5.2
percent in the six-month period ended June 30, 2000. Off-system sales
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generally occur at much lower prices per kilowatt-hour and have less impact on
operating revenues and earnings than system sales.
EXPENSES
Total operating expenses increased $277.4 million or 73.5 percent and
$482.7 million or 66.9 percent in the current periods. These increases were
primarily due to increases in gas and electricity purchased for resale, other
operation and maintenance and fuel expense.
Fuel expense increased $22.6 million or 30.1 percent and $27.0 million or
20.3 percent in the current periods primarily due to a significant increase in
the average cost of fuel (particularly natural gas) and slightly higher
generation levels.
Gas and electricity purchased for resale pursuant to Enogex's gas and
electricity-marketing operations increased $204.6 million or 184.5 percent and
$352.7 million or 166.1 percent in the current periods. These increases are
primarily due to its acquisition of Transok and from increased prices and sales
volumes in natural gas gathering and transportation.
Other operation and maintenance increased $39.5 million or 49.7 percent and
$81.4 million or 52.9 percent in the current periods. These increases are due to
the acquisition of Transok in July 1999, increased natural gas purchases,
increased employee benefit costs and miscellaneous corporate expenses.
Purchased power costs for OG&E remained relatively constant in the three
months ended Jue 30, 2000 and increased $1.3 million or 1.1 percent in the six
months ended June 30, 2000, primarily due to an increase in transmission charges
associated with off-system purchases.
Depreciation and amortization increased $7.7 million or 20.6 percent and
$14.3 million or 19.0 percent during the current periods due to an increase in
depreciable property and higher oil and gas production volumes (based on units
of production depreciation method) and the acquisition of Transok in July 1999.
Taxes other than income increased $3.2 million or 25.3 percent and $6.0
million or 23.3 percent in the current periods. These increases are primarily
due to the acquisition of Transok in July 1999.
Other income increased $3.8 million or 376.0 percent and $3.3 million or
248.3 percent in the current periods. These increases are due to the sale by
Enogex of certain assets in Oklahoma and Utah in the three months ended June 30,
2000.
Interest charges increased $13.0 million or 70.2 percent and $28.8 million
or 79.2 percent in the current periods. These increases are due to increased
long-term debt at Enogex and due to interest expense on the trust-preferred
securities issued in October 1999. The proceeds from those securities were used
to repay short-term debt incurred to finance the acquisition of Transok. See
"Liquidity and Capital Requirements."
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LIQUIDITY AND CAPITAL REQUIREMENTS
The Company's primary needs for capital are related to construction of new
facilities to meet anticipated demand for OG&E's utility service, to replace or
expand existing facilities in OG&E's electric utility business, to replace or
expand existing facilities in its non-utility businesses, to acquire new
non-utility facilities or businesses and to some extent, for satisfying maturing
debt. The Company's capital expenditures of $91.5 million for the six months
ended June 30, 2000, were financed with internally generated funds.
The Company meets its cash needs through a combination of internally
generated funds, permanent financing and short-term borrowings. The Company
expects that internally generated funds will be adequate during 2000 to meet
anticipated construction expenditures, while maturities of long-term debt at
OG&E will require permanent financings, with the amount and type dependent on
market conditions at the time. OG&E has long-term debt of $110 million maturing
in October 2000, which it expects to refinance and accordingly, this debt is
reflected as non-current on the accompanying balance sheets. Enogex has
long-term debt of $58 million and $1 million maturing in the third and fourth
quarters of 2000, respectively. Management anticipates that cash flows from
operations and short-term debt will be sufficient to retire the $59 million in
long-term debt at Enogex. Short-term borrowings will continue to be used to meet
temporary cash requirements. In January 2000, the Company increased its line of
credit from $200 million to $300 million, with $200 million to expire on January
15, 2001, and $100 million to expire on January 15, 2004.
The Company acquired two gas turbine generators for use at OG&E's Horseshoe
Lake Generating Station. These two generators were brought on line on June 14
and July 16, 2000 and will each produce approximately 44 megawatts of additional
peak-load generating capacity. The total cost of this project is expected to be
approximately $47 million. In August 1999, OG&E announced the reactivation of
two of its generators at its Mustang Generating Station, which have been idle
for several years. These two Mustang Station generators were both brought on
line July 21, 2000 and together produce approximately 115 megawatts of
additional peak-load generating capacity. The total cost of this reactivation
project is expected to be approximately $7 million. Together, these four
generators increased OG&E's electric generating capacity by approximately 4
percent.
The Company's capital structure and cash flow remained strong throughout
the current periods. The Company's combined cash and cash equivalents increased
approximately $10.5 million during the six months ended June 30, 2000. The
increase reflects the Company's cash flow from operations, proceeds from
long-term debt and sale of assets, net of retirement of long-term debt,
construction expenditures, short-term debt and dividend payments.
As discussed previously, on July 1, 1999, Enogex completed its acquisition
of Transok for $710.3 million, which includes assumption of $173 million of
long-term debt. The purchase of Transok was temporarily funded through a $560
million revolving credit agreement with a
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consortium of banks with Bank One, N.A. serving as agent. On October 21, 1999,
the financing trust subsidiary of the Company issued $200 million of 8.375
percent trust preferred securities and all of the proceeds were used to repay a
portion of outstanding borrowings under the revolving credit agreement
implemented in connection with the acquisition of Transok.
On January 14, 2000, Enogex sold $400 million of 8.125 percent senior
unsecured notes due January 15, 2010. Enogex entered into a series of interest
rate swap agreements to manage interest costs associated with this $400 million
issue. The effect of these swap agreements reduces the overall effective
interest rate from 8.125 percent to 6.6875 percent during the first year. The
proceeds from the sale of this new debt were used to repay the remaining balance
of the temporary short-term debt Enogex owed the Company associated with the
Transok acquisition and for general corporate purposes.
Like any business, the Company is subject to numerous contingencies, many
of which are beyond its control. For discussion of significant contingencies
that could affect the Company, reference is made to Part II, Item 1 - "Legal
Proceedings" of this Form 10-Q, to Part II, Item 1 - "Legal Proceedings" in the
Company's Form 10-Q for the quarter ended March 31, 2000 and to "Management's
Discussion and Analysis" and Notes 10 and 11 of Notes to the Consolidated
Financial Statements in the Company's 1999 Form 10-K.
REGULATION AND RATES
OG&E's retail electric tariffs in Oklahoma are regulated by the OCC, and in
Arkansas by the APSC. The issuance of certain securities by OG&E is also
regulated by the OCC and the APSC. OG&E's wholesale electric tariffs, short-term
borrowing authorization and accounting practices are subject to the jurisdiction
of the FERC. The Secretary of the Department of Energy has jurisdiction over
some of OG&E's facilities and operations.
RECENT REGULATORY MATTERS
On January 12, 2000, the OCC Staff (the "Staff") filed three applications
to address various aspects of OG&E's electric rates. Two of the applications
were expected, while the third pertains to recoveries under OG&E's fuel
adjustment clause. The first application relates to the completion on March 1,
2000, of the recovery pursuant to the APC Rider of the amortization premium paid
by OG&E when it acquired Enogex in 1986 and the resulting removal of this $12.8
million ($10.7 million in the Oklahoma Jurisdiction) from the amounts currently
being paid annually by OG&E to Enogex and being recovered by OG&E from its
ratepayers. OG&E consented to this action and in March 2000, the OCC approved
the APC Rider for $10.7 million annually.
The second application relates to a review of the GEP Rider which, as part
of the OCC's 1997 Order, was scheduled for review in March 2000. OG&E collected
approximately $20.8 million pursuant to the GEP Rider during 1999. On April 4,
2000, the Staff filed testimony proposing an annual GEP Rider incentive of $7.07
million for OG&E, compared initially to $13.26 million under the then-current
GEP Rider incentive factors. The GEP Rider was designed
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so that when OG&E's average annual cost of fuel per kwh was less than 96.261
percent of the average non-nuclear fuel cost per kwh of certain other
investor-owned utilities in the region, OG&E was allowed to collect, through the
GEP Rider, one-third of the amount by which OG&E's average annual cost of fuel
was below 96.261 percent of the average of the other specified utilities. If
OG&E's fuel cost exceeded 103.739 percent of the stated average, the Company was
not allowed to recover one-third of the fuel costs above that average from
Oklahoma customers. In its April 4, 2000 testimony, the Staff stated that they
continued to support incentive programs that reward superior performance, but in
their view the existing GEP Rider was not functioning as the Staff had
originally envisioned it.
In June 2000, the OCC approved the GEP Rider for $6.6 million annually and
the following four changes: (i) modifying OG&E's peer group to include utilities
with a higher coal-to-gas generation mix; (ii) reducing the amount of fuel costs
that can be recovered if OG&E's costs exceed the new peer group by changing the
percentage above which OG&E will not be allowed to recover one-third of the fuel
costs from Oklahoma customers from 103.739 percent to 101.0 percent; (iii)
reducing OG&E's share of cost savings as compared to its new peer group from 33
percent to 30 percent; and (iv) limiting to $10.0 million the amount of any
awards paid to OG&E or penalties charged to OG&E.
The final application relates to a review of 1999 fuel cost recoveries.
OG&E assumes that this application also will be used to address the competitive
bid process of its gas transportation service. In February 1997, the OCC issued
an order (the "1997 Order") that, among other things, directed OG&E to commence
competitively bid gas transportation service to its gas-fired plants no later
than April 30, 2000. The order also set annual compensation for the
transportation services provided by Enogex to OG&E at $41.3 million annually
until March 1, 2000, at which time the rate would drop to $28.5 million
(reflecting the completion of the recovery from ratepayers of the amortization
premium paid by OG&E when it acquired Enogex in 1986) and remain at that level
until competitively-bid gas transportation begins. Final firm bids were
submitted by Enogex and other pipelines on April 15, 1999. In July 1999, OG&E
filed an application with the OCC requesting approval of a performance-based
rate plan for its Oklahoma retail customers from April 2000 until the
introduction of customer choice for electric power in July 2002. As part of this
application, OG&E stated that Enogex had submitted the only viable bid ($33.4
million per year) for gas transportation to its six gas-fired power plants that
were the subject of the competitive bid. As part of its application to the OCC,
OG&E offered to discount Enogex's bid from $33.4 million annually to $25.2
million annually. OG&E has executed a new gas transportation contract with
Enogex under which Enogex continues to serve the needs of OG&E's power plants at
a price to be paid by OG&E of $33.4 million annually and, if OG&E's proposal had
been approved by the OCC, OG&E would have recovered a portion of such amount
($25.2 million) from its ratepayers. The Staff, the Office of the Oklahoma
Attorney General and a coalition of industrial customers filed testimony
questioning various parts of OG&E's performance-based rate plan, including the
result of the competitive bid process, and suggested, among other things, that
the bidding process be repeated or that gas transportation service to five of
OG&E's gas-fired plants be awarded to parties other than Enogex. The Staff also
filed testimony stating in substance that OG&E's electric rates as a whole were
appropriate and did not warrant a rate review. OG&E negotiated with these
parties in an effort to settle all
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issues (including the competitive bid process) associated with its application
for a performance-based rate plan. When these negotiations failed, OG&E withdrew
its application, which withdrawal was approved by the OCC in December 1999. OG&E
recently entered into a stipulation (the "Stipulation") with the Staff, the
Office of the Attorney General and a coalition of industrial customers regarding
the competitive bid process of its gas transportation service. The Stipulation
(which, with one exception, has been signed by all parties to the proceeding)
permits OG&E to recover $25.2 million annually for gas transportation services
to be provided by Enogex pursuant to the competitive bid process. The
Stipulation is scheduled to be presented for approval to an Administrative Law
Judge ("ALJ") in September 2000. The decision of the ALJ will then be presented
to the OCC for its approval.
STATE RESTRUCTURING INITIATIVES
OKLAHOMA: As previously reported, Oklahoma enacted in April 1997 the
Electric Restructuring Act of 1997 (the "Act"), which is designed to provide for
choice by retail customers of their electric supplier by July 1, 2002. Various
amendments to the Act were enacted in 1999 and 1998. Additional implementing
legislation needs to be adopted by the Oklahoma legislature to address many
specific issues associated with the Act and with deregulation. In May 2000, a
bill addressing the specific issues of deregulation was passed in the Oklahoma
State Senate and then was defeated in the Oklahoma House of Representatives. The
Company cannot predict what, if any, legislation will be adopted at the next
legislative session. Nevertheless, the Company expects to remain a competitive
supplier of electricity.
ARKANSAS: In April 1999, Arkansas became the 18th state to pass a law
calling for restructuring of the electric utility industry at the retail level.
The new law targets customer choice of electricity providers by January 1, 2002.
The new law also provides that utilities owning or controlling transmission
assets must transfer control of such transmission assets to an independent
system operator, independent transmission company or regional transmission
group, if any such organization has been approved by the FERC. Other provisions
of the new law permit municipal electric systems to opt in or out, permit
recovery of stranded costs and transition costs and require filing of unbundled
rates for generation, transmission, distribution and customer service. OG&E
filed preliminary business separation plans with the APSC on August 8, 2000. The
APSC has established a timetable to establish rules implementing the Arkansas
restructuring statutes. The new law will significantly affect OG&E's future
Arkansas operations. OG&E's electric service area includes parts of western
Arkansas, including Ft. Smith, the second-largest metropolitan market in the
state.
NATIONAL ENERGY LEGISLATION
In December 1999, the FERC issued Order 2000 to advance the formation of
Regional Transmission Organizations ("RTOs"). The rule requires that each public
utility that owns, operates or controls facilities for the transmission of
electric energy in interstate commerce file by October 15, 2000, a proposal with
respect to forming and participating in an RTO. The FERC also codified minimum
characteristics and functions that a transmission entity must satisfy in order
to be considered an RTO. The FERC's goal is to promote efficiency in wholesale
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electricity markets and to ensure that electricity consumers pay the lowest
price possible for reliable service. The FERC expects that the RTOs will be
operational by December 15, 2001.
REPORT OF BUSINESS SEGMENTS
The Company's electric utility operations are conducted through OG&E, an
operating public utility engaged in the generation, transmission, distribution,
and sale of electric energy. The non-utility operations are conducted through
Enogex. Enogex is engaged in gathering and processing natural gas, producing
natural gas liquids, transporting natural gas through its pipelines in Oklahoma
and Arkansas for various customers (including OG&E), marketing electricity,
natural gas and natural gas liquids and investing in the drilling for and
production of crude oil and natural gas. The following is the Company's business
segment results for the current periods.
<TABLE>
<CAPTION>
3 Months Ended 6 Months Ended
June 30 June 30
2000 1999 2000 1999
-------------------------------- ---------------------------------
(DOLLARS IN THOUSANDS)
================================================================================================================
<S> <C> <C> <C> <C>
Operating Information:
Operating Revenues
Electric utility..................... $ 335,573 $ 314,102 $ 580,905 $ 564,246
Non-utility.......................... 465,704 191,967 830,818 346,317
Intersegment revenues (A)............ (74,373) (55,208) (103,238) (81,497)
----------------------------------------------------------------------------------------------------------------
Total.............................. $ 726,904 $ 450,861 $ 1,308,485 $ 829,066
================================================================================================================
Net Income
Electric utility..................... $ 29,561 $ 33,729 $ 26,335 $ 43,918
Non-utility.......................... 2,183 4,015 6,185 4,958
----------------------------------------------------------------------------------------------------------------
Total.............................. $ 31,744 $ 37,744 $ 32,520 $ 48,876
================================================================================================================
<FN>
(A) Intersegment revenues are recorded at prices comparable to those of
unaffiliated customers and are affected by regulatory considerations.
</FN>
</TABLE>
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PART II. OTHER INFORMATION
ITEM 1 LEGAL PROCEEDINGS
Reference is made to Item 3 of the Company's 1999 Form 10-K and to Part II,
Item 1 of the Company's Form 10-Q for the quarter-ended March 31, 2000 for a
description of certain legal proceedings presently pending. There are no new
significant cases to report against the Company or its subsidiaries and there
have been no notable changes in the previously reported proceedings, except as
set forth below:
Reference is made to paragraph 5 of Item 3 of the Company's 1999 Form 10-K
for a description of the lawsuit brought by Melvin Scoggin and Oak Tree
Resources, LLC (collectively, the "plaintiffs") against Enogex. The plaintiffs
have appealed the decision of the trial court granting summary judgment in favor
of Enogex. The Company continues to believe that this case is without merit.
ITEM 4 SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
(a) The Company's Annual Meeting of Shareowners was held on May 18, 2000.
(b) Not applicable.
(c) The matters voted upon and the results of the voting at the Annual
Meeting were as follows:
(1) The Shareowners voted to elect the Company's nominees for
election to the Board of Directors as follows:
William E. Durrett - 60,436,559 votes for election and
996,283 votes withheld
H. L. Hembree, III - 60,458,992 votes for election and 937,850
votes withheld
Steven E. Moore - 60,529,760 votes for election and 903,082
votes withheld
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ITEM 6 EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
27.01 - Financial Data Schedule.
(b) Reports on Form 8-K
None
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
OGE ENERGY CORP.
(Registrant)
By /s/ Donald R. Rowlett
----------------------------------------------
Donald R. Rowlett
Vice President and Controller
(On behalf of the registrant and in
his capacity as Chief Accounting Officer)
August 11, 2000
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