<PAGE> 1
--------------------------------------------------------------------------------
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
---------------
FORM 10-Q
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2000
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
ACT OF 1934
FOR THE TRANSITION PERIOD FROM ____________ TO ____________
COMMISSION FILE NO. 1-13726
CHESAPEAKE ENERGY CORPORATION
(Exact name of registrant as specified in its charter)
OKLAHOMA 73-1395733
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
6100 NORTH WESTERN AVENUE
OKLAHOMA CITY, OKLAHOMA 73118
(Address of principal executive offices) (Zip Code)
(405) 848-8000
(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 [ ]
At November 10, 2000, there were 152,106,700 shares of the registrant's
$.01 par value Common Stock outstanding.
--------------------------------------------------------------------------------
<PAGE> 2
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
INDEX TO FORM 10-Q FOR THE QUARTER ENDED SEPTEMBER 30, 2000
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
PART I. FINANCIAL INFORMATION
Item 1. Consolidated Financial Statements:
Consolidated Balance Sheets at September 30, 2000 and
December 31, 1999 (Unaudited) 3
Consolidated Statements of Operations for the Three Months and
Nine Months Ended September 30, 2000 and 1999 (Unaudited) 4
Consolidated Statements of Cash Flows for the Nine Months Ended
September 30, 2000 and 1999 (Unaudited) 5
Consolidated Statements of Comprehensive Income for the Three Months
and Nine Months Ended September 30, 2000 and 1999 (Unaudited) 6
Notes to Consolidated Financial Statements (Unaudited) 7
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations 21
Item 3. Quantitative and Qualitative Disclosures About Market Risks 27
PART II. OTHER INFORMATION
Item 1. Legal Proceedings 30
Item 2. Changes in Securities and Use of Proceeds 31
Item 3. Defaults Upon Senior Securities or Dividend Arrearages 31
Item 4. Submission of Matters to a Vote of Security Holders 31
Item 5. Other Information 31
Item 6. Exhibits and Reports on Form 8-K 32
</TABLE>
2
<PAGE> 3
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
<TABLE>
<CAPTION>
SEPTEMBER 30, DECEMBER 31,
2000 1999
------------- ------------
($ IN THOUSANDS)
<S> <C> <C>
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ...................................................... $ 12,727 $ 38,658
Restricted cash ................................................................ -- 192
Accounts receivable:
Oil and gas sales ............................................................ 36,124 17,045
Oil and gas marketing sales .................................................. 35,295 18,199
Joint interest and other, net of allowances of $1,101,000 and $3,218,000,
respectively ............................................................... 21,545 11,247
Related parties .............................................................. 4,948 4,574
Inventory ...................................................................... 3,274 4,582
Other .......................................................................... 3,274 3,049
------------ ------------
Total current assets .................................................... 117,187 97,546
------------ ------------
PROPERTY AND EQUIPMENT:
Oil and gas properties, at cost based on full-cost accounting:
Evaluated oil and gas properties ............................................. 2,482,001 2,315,348
Unevaluated properties ....................................................... 30,351 40,008
Less: accumulated depreciation, depletion and amortization ................... (1,744,006) (1,670,542)
------------ ------------
768,346 684,814
Other property and equipment ................................................... 72,094 67,712
Less: accumulated depreciation and amortization ................................ (35,987) (33,429)
------------ ------------
Total property and equipment ............................................ 804,453 719,097
------------ ------------
INVESTMENT IN GOTHIC ENERGY CORPORATION .......................................... 114,366 10,000
------------ ------------
OTHER ASSETS ..................................................................... 24,025 23,890
------------ ------------
TOTAL ASSETS ..................................................................... $ 1,060,031 $ 850,533
============ ============
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES:
Notes payable and current maturities of long-term debt ......................... $ 817 $ 763
Accounts payable ............................................................... 31,520 24,822
Accrued liabilities and other .................................................. 49,713 34,713
Revenues and royalties due others .............................................. 30,004 27,888
------------ ------------
Total current liabilities ............................................... 112,054 88,186
------------ ------------
LONG-TERM DEBT, NET .............................................................. 971,040 964,097
------------ ------------
REVENUES AND ROYALTIES DUE OTHERS ................................................ 7,825 9,310
------------ ------------
DEFERRED INCOME TAXES ............................................................ 9,068 6,484
------------ ------------
STOCKHOLDERS' EQUITY (DEFICIT):
Preferred Stock, $.01 par value, 10,000,000 shares authorized; 624,037 and
4,596,400 shares of 7% cumulative convertible stock issued and outstanding
at September 30, 2000 and December 31, 1999, respectively, entitled in
liquidation (including dividends in arrears) to $35.6 million and
$249.1 million, respectively ................................................. 31,202 229,820
Common Stock, par value of $.01, 250,000,000 shares authorized;
156,711,224 and 105,858,580 shares issued at September 30, 2000 and
December 31, 1999, respectively .............................................. 1,567 1,059
Paid-in capital ................................................................ 951,077 682,905
Accumulated earnings (deficit) ................................................. (1,007,126) (1,093,929)
Accumulated other comprehensive income (loss) .................................. (3,922) 196
Less: treasury stock, at cost; 3,806,185 and 10,856,185 common shares at
September 30, 2000 and December 31, 1999, respectively ....................... (12,754) (37,595)
------------ ------------
Total stockholders' equity (deficit) .................................... (39,956) (217,544)
------------ ------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) ............................. $ 1,060,031 $ 850,533
============ ============
</TABLE>
The accompanying notes are an integral part of these consolidated
financial statements.
3
<PAGE> 4
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30, SEPTEMBER 30,
---------------------------- ----------------------------
2000 1999 2000 1999
------------ ------------ ------------ ------------
<S> <C> <C> <C> <C>
REVENUES:
Oil and gas sales ......................................... $ 123,971 $ 78,521 $ 311,485 $ 198,599
Oil and gas marketing sales ............................... 44,211 23,619 105,821 50,110
------------ ------------ ------------ ------------
Total revenues ........................................ 168,182 102,140 417,306 248,709
------------ ------------ ------------ ------------
OPERATING COSTS:
Production expenses ....................................... 11,696 11,747 36,822 36,922
Production taxes .......................................... 6,198 3,652 17,131 8,440
General and administrative ................................ 3,377 2,736 9,597 10,028
Oil and gas marketing expenses ............................ 42,917 22,851 102,583 47,809
Oil and gas depreciation, depletion and amortization ...... 25,227 22,816 74,587 70,202
Depreciation and amortization of other assets ............. 1,849 1,840 5,551 5,978
------------ ------------ ------------ ------------
Total operating costs ................................. 91,264 65,642 246,271 179,379
------------ ------------ ------------ ------------
INCOME FROM OPERATIONS ..................................... 76,918 36,498 171,035 69,330
------------ ------------ ------------ ------------
OTHER INCOME (EXPENSE):
Interest and other income ................................. 867 2,686 3,726 6,526
Interest expense .......................................... (21,680) (20,420) (64,357) (60,569)
------------ ------------ ------------ ------------
Total other income (expense) .......................... (20,813) (17,734) (60,631) (54,043)
------------ ------------ ------------ ------------
INCOME BEFORE INCOME TAXES ................................. 56,105 18,764 110,404 15,287
INCOME TAX EXPENSE ......................................... 1,416 649 2,879 975
------------ ------------ ------------ ------------
NET INCOME ................................................. 54,689 18,115 107,525 14,312
Preferred stock dividends ................................. (965) (4,381) (7,914) (12,433)
Gain (loss) on redemption of preferred stock .............. (5,321) -- 6,574 --
------------ ------------ ------------ ------------
NET INCOME AVAILABLE TO COMMON SHAREHOLDERS ................ $ 48,403 $ 13,734 $ 106,185 $ 1,879
============ ============ ============ ============
EARNINGS PER COMMON SHARE:
Basic ..................................................... $ .33 $ .14 $ .88 $ .02
============ ============ ============ ============
Assuming Dilution ......................................... $ .31 $ .13 $ .73 $ .02
============ ============ ============ ============
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT
SHARES OUTSTANDING:
Basic ..................................................... 146,593 97,126 121,089 97,126
============ ============ ============ ============
Assuming dilution ......................................... 158,847 103,576 147,428 101,625
============ ============ ============ ============
</TABLE>
The accompanying notes are an integral part of these consolidated
financial statements.
4
<PAGE> 5
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
<TABLE>
<CAPTION>
NINE MONTHS ENDED
SEPTEMBER 30,
----------------------------
2000 1999
------------ ------------
($ IN THOUSANDS)
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income .................................................... $ 107,525 $ 14,312
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation, depletion and amortization ..................... 77,434 73,735
Amortization of loan costs ................................... 2,704 2,445
Amortization of bond discount ................................ 63 63
Loss (gain) on sale of fixed assets and other ................ 8 (377)
Equity in losses of equity investees ......................... 131 306
Bad debt expense ............................................. 256 --
Other ........................................................ (47) --
Deferred income taxes ........................................ 2,879 975
------------ ------------
Cash provided by operating activities before changes in
current assets and liabilities .......................... 190,953 91,459
Changes in current assets and liabilities .................... (16,239) 2,682
------------ ------------
Cash provided by operating activities ...................... 174,714 94,141
------------ ------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Exploration and development of oil and gas properties ......... (127,811) (106,413)
Purchases of oil and gas properties ........................... (36,315) (11,077)
Sales of oil and gas properties ............................... 1,429 36,365
Sales of non-oil and gas assets ............................... 1,134 5,438
Additions to other property and equipment ..................... (5,707) (475)
Investment in Gothic Energy Corporation ....................... (24,622) --
Additions to other long-term investments ...................... (6,194) --
Long-term loans made to third parties ......................... -- (523)
Other ......................................................... (2,482) (675)
------------ ------------
Cash used in investing activities .......................... (200,568) (77,360)
------------ ------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term borrowings ............................ 166,000 29,000
Payments on long-term borrowings .............................. (158,500) (54,000)
Cash payments with preferred stock swaps ...................... (8,269) --
Cash received from exercise of stock options .................. 1,005 419
Purchase of treasury stock .................................... -- (53)
------------ ------------
Cash provided by (used in) financing activities ............ 236 (24,634)
------------ ------------
EFFECT OF CHANGES IN EXCHANGE RATE ON CASH ...................... (313) 3,705
------------ ------------
NET DECREASE IN CASH AND CASH EQUIVALENTS ....................... (25,931) (4,148)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD .................. 38,658 29,520
------------ ------------
CASH AND CASH EQUIVALENTS, END OF PERIOD ........................ $ 12,727 $ 25,372
============ ============
</TABLE>
The accompanying notes are an integral part of these consolidated
financial statements.
5
<PAGE> 6
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(UNAUDITED)
<TABLE>
<CAPTION>
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30, SEPTEMBER 30,
---------------------------- ----------------------------
2000 1999 2000 1999
------------ ------------ ------------ ------------
($ IN THOUSANDS)
<S> <C> <C> <C> <C>
Net income .......................................................... $ 54,689 $ 18,115 $ 107,525 $ 14,312
Other comprehensive income (loss) - foreign currency translation
adjustments ....................................................... (1,165) 80 (4,118) 3,705
------------ ------------ ------------ ------------
Comprehensive income ................................................ $ 53,524 $ 18,195 $ 103,407 $ 18,017
============ ============ ============ ============
</TABLE>
The accompanying notes are an integral part of these consolidated
financial statements.
6
<PAGE> 7
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2000
(UNAUDITED)
1. ACCOUNTING PRINCIPLES
The accompanying unaudited consolidated financial statements of Chesapeake
Energy Corporation (the "Parent") and Subsidiaries (collectively with the
Parent, the "Company" or "Chesapeake") have been prepared in accordance with the
instructions to Form 10-Q as prescribed by the Securities and Exchange
Commission. This Form 10-Q should be read in conjunction with the Company's
December 31, 1999 Form 10-K. All material adjustments (consisting solely of
normal recurring adjustments) which, in the opinion of management, are necessary
for a fair presentation of the results for the interim periods have been
reflected. The results for the three and nine months ended September 30, 2000
are not necessarily indicative of the results to be expected for the full year.
This Form 10-Q relates to the three and nine months ended September 30, 2000
(the "Current Quarter" and "Current Period," respectively) and September 30,
1999 (the "Prior Quarter" and "Prior Period," respectively).
2. LEGAL PROCEEDINGS
Bayard Securities Litigation
This putative class action alleging violations of the Securities Act of 1933 and
the Oklahoma Securities Act was first filed in February 1998 against the Company
and others on behalf of investors who purchased common stock of Bayard Drilling
Technologies, Inc. ("Bayard") in, or traceable to, its initial public offering
in November 1997. Total proceeds of the offering were $254 million, of which the
Company received net proceeds of $90 million as a selling shareholder.
Plaintiffs allege that the Company, a major customer of Bayard's drilling
services and the owner of 30.1% of Bayard's common stock outstanding prior to
the offering, was a controlling person of Bayard. Alleged defective disclosures
are claimed to have resulted in a decline in Bayard's share price following the
public offering. Plaintiffs seek a determination that the suit is a proper class
action and damages in an unspecified amount or rescission, together with
interest and costs of litigation, including attorneys' fees.
On August 24, 1999, the court dismissed plaintiffs' claims against the Company
under Section 15 of the Securities Act of 1933 alleging that the Company was a
"controlling person" of Bayard. Claims under Section 11 of the Securities Act of
1933 and Section 408 of the Oklahoma Securities Act continue to be asserted
against the Company. The Company believes that it has meritorious defenses to
these claims and intends to defend this action vigorously. No estimate of loss
or range of estimate of loss, if any, can be made at this time. Bayard, which
was acquired by Nabors Industries, Inc. in April 1999, has been reimbursing the
Company for its costs of defense as incurred.
Patent Litigation
On September 21, 1999, judgment was entered in favor of the Company in a patent
infringement lawsuit tried to the U.S. District Court for the Northern District
of Texas, Fort Worth Division. Filed in October 1996, the lawsuit asserted that
the Company had infringed a patent belonging to Union Pacific Resources Company.
The court declared the patent invalid, held that the Company could not have
infringed the patent, dismissed all of UPRC's claims with prejudice and assessed
court costs against UPRC. Appeals of the judgment by both the Company and UPRC
are pending in the Federal Circuit Court of Appeals. The Company has appealed
the trial court's ruling denying the Company's request for attorneys' fees.
Management is unable to predict the outcome of these appeals, but believes the
invalidity of the patent will be upheld on appeal.
West Panhandle Field Cessation Cases
A subsidiary of the Company, Chesapeake Panhandle Limited Partnership ("CP")
(f/k/a MC Panhandle, Inc.), and two subsidiaries of Kinder Morgan, Inc. are
defendants in 13 lawsuits filed between June 1997 and January 1999 by royalty
owners seeking the cancellation of oil and gas leases in the West Panhandle
Field in Texas. The Company acquired MC Panhandle, Inc. on April 28, 1998. MC
Panhandle, Inc. has owned the leases since
7
<PAGE> 8
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2000
(UNAUDITED)
January 1, 1997, and the co-defendants are prior lessees. Plaintiffs claim the
leases terminated upon the cessation of production for various periods occurring
primarily during the 1960s. In addition, plaintiffs seek to recover conversion
damages, exemplary damages, attorneys' fees and interest. Defendants assert that
any cessation of production was excused and have pled affirmative defenses of
limitations, waiver, temporary estoppel, laches and title by adverse possession.
Four of the 13 cases have been tried, no trial dates have been set for the other
cases.
Of the ten cases filed in the District Court of Moore County, Texas, 69th
Judicial District, three have been tried to a jury. Judgment has been entered
against CP and its co-defendants in all three cases, although there was
initially a jury verdict in two of the cases in favor of defendants. The
Company's aggregate liability for these trial court judgments is $1.3 million of
actual damages and $1.2 million of exemplary damages, and jointly and severally
with the other two defendants, $1.5 million of actual damages and $337,000 of
attorneys' fees in the event of an appeal, sanctions, interest and court costs.
The trial court also quieted title to the leases in dispute in plaintiffs. CP
and the other defendants have each appealed the judgments and posted supersedeas
bonds. In October 2000, the appellate court issued decisions in two of these
cases sustaining the trial court's finding that the leases had terminated due to
a cessation of production and that the plaintiffs were entitled to actual
damages and attorneys' fees. However, the appellate court reduced the actual
damages awards in the two cases by an aggregate of $612,000 and reversed the
exemplary damages award of $1.2 million against each of the three defendants. CP
and the other defendants have filed motions for rehearing.
There are three related cases pending in other courts. One was tried in the U.S.
District Court, Northern District of Texas, Amarillo Division, and resulted in a
jury verdict for CP and its co-defendants. Judgment has not yet been entered in
that case.
The Company has previously established an accrued liability that management
believes will be sufficient to cover the estimated costs of litigation for each
of these cases. Because of the inconsistent verdicts reached by the juries in
the four cases tried to date and because the amount of damages sought is not
specified in all of the other cases, the outcome of the remaining trials and the
amount of damages that might ultimately be awarded could differ from
management's estimates. Management believes, however, that the leases are valid,
there is no basis for exemplary damages, fraud or bad faith trespass. CP and the
other defendants intend to vigorously defend against the plaintiffs' claims.
The Company is currently involved in various other routine disputes incidental
to its business operations. While it is not possible to determine the ultimate
disposition of these matters, management, after consultation with legal counsel,
is of the opinion that the final resolution of all such currently pending or
threatened litigation is not likely to have a material adverse effect on the
consolidated financial position or results of operations of the Company.
3. NET INCOME PER SHARE
Statement of Financial Accounting Standards No. 128, Earnings Per Share ("SFAS
128") requires presentation of "basic" and "diluted" earnings per share, as
defined, on the face of the statements of operations for all entities with
complex capital structures. SFAS 128 requires a reconciliation of the numerator
and denominator of the basic and diluted EPS computations.
The following weighted securities were not included in the calculation of
diluted earnings per share, as the effect was antidilutive:
o For the Current Quarter, the Current Period, the Prior Quarter and the
Prior Period, outstanding options to purchase 0.3 million, 0.7 million, 0.8
million and 2.3 million shares of common stock at a weighted average
8
<PAGE> 9
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2000
(UNAUDITED)
exercise price of $15.65, $10.49, $9.81 and $5.00, respectively, were
antidilutive because the exercise prices of the options were greater than
the average market price of the Company's common stock.
o For the Prior Quarter and the Prior Period, the assumed conversion of the
outstanding preferred stock (convertible into 33 million common shares in
the Prior Quarter and the Prior Period) was not included as the effect was
antidilutive.
o In the Current Quarter, the calculation does not include the effect of the
assumed conversion at the beginning of the period of 933,000 preferred
shares exchanged for common shares during the period as the effect was
antidilutive.
A reconciliation for the Current Quarter, Prior Quarter and Current Period and
Prior Period is as follows:
9
<PAGE> 10
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2000
(UNAUDITED)
<TABLE>
<CAPTION>
INCOME SHARES PER SHARE
(NUMERATOR) (DENOMINATOR) AMOUNT
-------------- -------------- --------------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C>
FOR THE QUARTER ENDED SEPTEMBER 30, 2000:
BASIC EPS
Income available to common stockholders ................................... $ 48,403 146,593 $ .33
==============
EFFECT OF DILUTIVE SECURITIES
Assumed conversion of 624,037 shares of
preferred stock at beginning of period:
Common shares assumed issued ......................................... -- 4,489
Preferred stock dividends ............................................ 546 --
Employee stock options ................................................. -- 7,765
-------------- --------------
DILUTED EPS
Income available to common stockholders
and assumed conversions ................................................ $ 48,949 158,847 $ .31
============== ============== ==============
FOR THE QUARTER ENDED SEPTEMBER 30, 1999:
BASIC EPS
Income available to common stockholders ................................. $ 13,734 97,126 $ 0.14
==============
EFFECT OF DILUTIVE SECURITIES
Employee stock options .................................................. -- 6,450
-------------- --------------
DILUTED EPS
Income available to common stockholders
and assumed conversions .............................................. $ 13,734 103,576 $ 0.13
============== ============== ==============
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2000:
BASIC EPS
Income available to common stockholders ................................... $ 106,185 121,089 $ .88
==============
EFFECT OF DILUTIVE SECURITIES
Assumed conversion at the beginning of
the period of preferred shares exchanged during the period:
Common shares assumed issued ......................................... -- 15,282
Preferred stock dividends ............................................ 6,276 --
Gain on redemption of preferred stock ................................ (6,574) --
Assumed conversion of 624,037 shares of preferred stock at beginning
of period:
Common shares assumed issued ......................................... -- 4,489
Preferred stock dividends ............................................ 1,638 --
Employee stock options .................................................. -- 6,568
-------------- --------------
DILUTED EPS
Income available to common stockholders
and assumed conversions ................................................ $ 107,525 147,428 $ .73
============== ============== ==============
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999:
BASIC EPS
Income available to common stockholders ................................... $ 1,879 97,126 $ 0.02
==============
EFFECT OF DILUTIVE SECURITIES
Employee stock options .................................................. -- 4,499
-------------- --------------
DILUTED EPS
Income available to common stockholders
and assumed conversions ................................................ $ 1,879 101,625 $ 0.02
============== ============== ==============
</TABLE>
In the Current Quarter, the Company engaged in a number of unsolicited stock
exchange transactions with institutional investors. The Company exchanged a
total of 9.2 million newly issued shares of common stock for 933,000 shares of
its issued and outstanding preferred stock with a liquidation value of $46.7
million plus dividends in arrears of $6.1 million. All preferred shares acquired
in these transactions were cancelled and retired and have the status of
authorized but unissued shares of undesignated preferred stock. A loss on
redemption of the preferred shares equal to $5.3 million was recognized as a
decrease to net income available to common shareholders in the Current Quarter
in determining basic earnings per share. The loss represented the excess of (i)
the market value of the common stock issued in exchange for the preferred shares
over (ii) the liquidation value of the preferred shares that were retired plus
dividends in arrears which had reduced prior EPS.
10
<PAGE> 11
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2000
(UNAUDITED)
In the Current Period, a total of 43.4 million shares of common stock, plus a
cash payment of $8.3 million, were exchanged for 3,972,363 shares of preferred
stock. These transactions reduced (i) the number of preferred shares from 4.6
million to 0.6 million, (ii) the liquidation value of the preferred stock from
$229.8 million to $31.2 million, and (iii) dividends in arrears by $22.9 million
to $4.4 million. A gain on redemption of all preferred shares exchanged during
the Current Period of $6.6 million ($5.3 million loss related to the Current
Quarter) is reflected in net income available to common shareholders in
determining basic earnings per share.
The Company may acquire additional shares of preferred stock in the future
through negotiations with individual holders and, beginning May 1, 2001, may
redeem outstanding shares of preferred stock for $52.45 per share plus
accumulated and unpaid dividends in cash and/or common stock.
4. SENIOR NOTES
9.625% Notes
The Company has outstanding $500 million in aggregate principal amount of 9.625%
senior notes which mature May 1, 2005. The 9.625% notes bear interest at the
rate of 9.625%, payable semiannually on each May 1 and November 1. The 9.625%
notes are senior, unsecured obligations of the Parent and are fully and
unconditionally guaranteed, jointly and severally, by the Guarantor
Subsidiaries.
9.125% Notes
The Company has outstanding $120 million in aggregate principal amount of 9.125%
senior notes which mature April 15, 2006. The 9.125% notes bear interest at an
annual rate of 9.125%, payable semiannually on each April 15 and October 15. The
9.125% notes are senior, unsecured obligations of the Parent and are fully and
unconditionally guaranteed, jointly and severally, by the Guarantor
Subsidiaries.
7.875% Notes
The Company has outstanding $150 million in aggregate principal amount of 7.875%
senior notes which mature March 15, 2004. The 7.875% notes bear interest at the
rate of 7.875%, payable semiannually on each March 15 and September 15. The
7.875% notes are senior, unsecured obligations of the Parent and are fully and
unconditionally guaranteed, jointly and severally, by the Guarantor
Subsidiaries.
8.5% Notes
The Company has outstanding $150 million in aggregate principal amount of 8.5%
senior notes which mature March 15, 2012. The 8.5% notes bear interest at the
rate of 8.5%, payable semiannually on each March 15 and September 15. The 8.5%
notes are senior, unsecured obligations of the Parent and are fully and
unconditionally guaranteed, jointly and severally, by the Guarantor
Subsidiaries.
The Parent is a holding company and owns no operating assets and has no
significant operations independent of its subsidiaries. The Parent's obligations
under its senior notes have been fully and unconditionally guaranteed, on a
joint and several basis, by each of the Parent's "Restricted Subsidiaries" (as
defined in the respective indentures governing the senior notes) (collectively,
the "Guarantor Subsidiaries"). Each of the Guarantor Subsidiaries is a direct or
indirect wholly-owned subsidiary of the Parent.
11
<PAGE> 12
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2000
(UNAUDITED)
The senior note Indentures contain certain covenants, including covenants
limiting the Parent and the Guarantor Subsidiaries with respect to asset sales,
restricted payments, the incurrence of additional indebtedness and the issuance
of preferred stock, liens, sale and leaseback transactions, lines of business,
dividend and other payment restrictions affecting Guarantor Subsidiaries,
mergers or consolidations, and transactions with affiliates. The Company is
obligated to repurchase the 9.625% and 9.125% senior notes in the event of a
change of control or certain asset sales.
These senior note indentures also limit the Company's ability to make restricted
payments (as defined), including the payment of preferred stock dividends,
unless certain tests are met. From December 31, 1998 through March 31, 2000, the
Company was unable to meet the requirements to incur additional unsecured
indebtedness, and consequently was not able to pay cash dividends on its 7%
cumulative convertible preferred stock. The Company had accumulated dividends in
arrears of $4.4 million related to its preferred stock as of September 30, 2000.
As a result of the Company's failure to pay dividends for six quarterly periods,
the holders of preferred stock were entitled to elect two new directors to the
Board following May 1, 2000. On September 22, 2000, the Company declared a
regular quarterly dividend and a special dividend equal to all unpaid dividends
on its 7% cumulative convertible preferred stock, both payable November 1, 2000
to shareholders of record on October 16, 2000. The total combined dividend of
$7.444 per share was paid November 1, 2000, eliminating the right of preferred
stockholders to elect directors.
Set forth below are condensed consolidating financial statements of the
Guarantor Subsidiaries, the Company's subsidiaries which are not guarantors of
the senior notes (the "Non-Guarantor Subsidiary") and the Parent. Separate
financial statements of each Guarantor Subsidiary have not been provided because
management has determined that they are not material to investors.
Chesapeake Energy Marketing, Inc. ("CEMI") was a Non-Guarantor Subsidiary for
all periods presented. During the Current Quarter, the Company formed Chesapeake
Merger 2000 Corp. for the purpose of effecting the pending merger with Gothic
Energy Corporation. This subsidiary is a Non-Guarantor Subsidiary which has no
assets or operations. All of the Parent's other subsidiaries were Guarantor
Subsidiaries during all periods presented.
12
<PAGE> 13
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING BALANCE SHEET
AS OF SEPTEMBER 30, 2000
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ...................... $ (13,459) $ 3,568 $ 22,618 $ -- $ 12,727
Accounts receivable, net ....................... 75,010 41,354 -- (18,452) 97,912
Inventory ...................................... 2,948 326 -- -- 3,274
Other .......................................... 2,724 14 536 -- 3,274
------------ ------------ ------------ ------------ ------------
Total current assets ........................ 67,223 45,262 23,154 (18,452) 117,187
------------ ------------ ------------ ------------ ------------
PROPERTY AND EQUIPMENT:
Evaluated oil and gas properties ............... 2,482,001 -- -- -- 2,482,001
Unevaluated properties ......................... 30,351 -- -- -- 30,351
Other property and equipment ................... 30,178 20,567 21,349 -- 72,094
Less: accumulated depreciation,
depletion and amortization ................... (1,759,695) (18,056) (2,242) -- (1,779,993)
------------ ------------ ------------ ------------ ------------
Total property and equipment ................ 782,835 2,511 19,107 -- 804,453
------------ ------------ ------------ ------------ ------------
INVESTMENTS IN SUBSIDIARIES AND
INTERCOMPANY ADVANCES .......................... 912,162 -- 373,864 (1,286,026) --
------------ ------------ ------------ ------------ ------------
INVESTMENT IN GOTHIC ENERGY
CORPORATION .................................... -- -- 114,366 -- 114,366
------------ ------------ ------------ ------------ ------------
OTHER ASSETS ..................................... 6,109 8,316 17,253 (7,653) 24,025
------------ ------------ ------------ ------------ ------------
TOTAL ASSETS ..................................... $ 1,768,329 $ 56,089 $ 547,744 $ (1,312,131) $ 1,060,031
============ ============ ============ ============ ============
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES:
Notes payable and current maturities
of long-term debt ............................ $ 817 $ -- $ -- $ -- $ 817
Accounts payable and other ..................... 66,053 33,090 30,662 (18,568) 111,237
------------ ------------ ------------ ------------ ------------
Total current liabilities ................... 66,870 33,090 30,662 (18,568) 112,054
------------ ------------ ------------ ------------ ------------
LONG-TERM DEBT, NET .............................. 51,817 -- 919,223 -- 971,040
------------ ------------ ------------ ------------ ------------
REVENUES AND ROYALTIES DUE
OTHERS ......................................... 7,825 -- -- -- 7,825
------------ ------------ ------------ ------------ ------------
DEFERRED INCOME TAXES ............................ 9,068 -- -- -- 9,068
------------ ------------ ------------ ------------ ------------
INTERCOMPANY PAYABLES ............................ 1,467,724 (756) (1,467,067) 99 --
------------ ------------ ------------ ------------ ------------
STOCKHOLDERS' EQUITY (DEFICIT):
Common stock ................................... 26 1 1,558 (18) 1,567
Other .......................................... 164,999 23,754 1,063,368 (1,293,644) (41,523)
------------ ------------ ------------ ------------ ------------
165,025 23,755 1,064,926 (1,293,662) (39,956)
------------ ------------ ------------ ------------ ------------
TOTAL LIABILITIES AND
STOCKHOLDERS' EQUITY (DEFICIT) ................. $ 1,768,329 $ 56,089 $ 547,744 $ (1,312,131) $ 1,060,031
============ ============ ============ ============ ============
</TABLE>
13
<PAGE> 14
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING BALANCE SHEET
AS OF DECEMBER 31, 1999
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARY PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
ASSETS
CURRENT ASSETS:
Cash and cash equivalents ...................... $ (6,964) $ 20,409 $ 25,405 $ -- $ 38,850
Accounts receivable, net ....................... 45,170 18,297 73 (12,475) 51,065
Inventory ...................................... 4,183 399 -- -- 4,582
Other .......................................... 1,997 700 352 -- 3,049
------------ ------------ ------------ ------------ ------------
Total current assets ................... 44,386 39,805 25,830 (12,475) 97,546
------------ ------------ ------------ ------------ ------------
PROPERTY AND EQUIPMENT:
Evaluated oil and gas properties ............... 2,311,633 3,715 -- -- 2,315,348
Unevaluated properties ......................... 40,008 -- -- -- 40,008
Other property and equipment ................... 29,088 20,521 18,103 -- 67,712
Less: accumulated depreciation,
depletion and amortization .................. (1,683,890) (18,205) (1,876) -- (1,703,971)
------------ ------------ ------------ ------------ ------------
Total property and equipment ........... 696,839 6,031 16,227 -- 719,097
------------ ------------ ------------ ------------ ------------
INVESTMENTS IN SUBSIDIARIES AND
INTERCOMPANY ADVANCES .......................... 806,180 -- 493,738 (1,299,918) --
------------ ------------ ------------ ------------ ------------
INVESTMENT IN GOTHIC ENERGY
CORPORATION .................................... 10,000 -- -- -- 10,000
OTHER ASSETS ..................................... 6,402 8,409 16,765 (7,686) 23,890
------------ ------------ ------------ ------------ ------------
TOTAL ASSETS ..................................... $ 1,563,807 $ 54,245 $ 552,560 $ (1,320,079) $ 850,533
============ ============ ============ ============ ============
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES:
Notes payable and current
maturities of long-term debt ................ $ -- $ 763 $ -- $ -- $ 763
Accounts payable and other ..................... 63,194 19,265 17,466 (12,502) 87,423
------------ ------------ ------------ ------------ ------------
Total current liabilities .............. 63,194 20,028 17,466 (12,502) 88,186
------------ ------------ ------------ ------------ ------------
LONG-TERM DEBT, NET .............................. 43,500 1,437 919,160 -- 964,097
------------ ------------ ------------ ------------ ------------
REVENUES AND ROYALTIES DUE
OTHERS ......................................... 9,310 -- -- -- 9,310
------------ ------------ ------------ ------------ ------------
DEFERRED INCOME TAXES ............................ 6,484 -- -- -- 6,484
------------ ------------ ------------ ------------ ------------
INTERCOMPANY PAYABLES ............................ 1,356,466 (2,450) (1,354,043) 27 --
------------ ------------ ------------ ------------ ------------
STOCKHOLDERS' EQUITY (DEFICIT):
Common stock ................................... 27 1 1,048 (17) 1,059
Other .......................................... 84,826 35,229 968,929 (1,307,587) (218,603)
------------ ------------ ------------ ------------ ------------
84,853 35,230 969,977 (1,307,604) (217,544)
------------ ------------ ------------ ------------ ------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
(DEFICIT) ........................................ $ 1,563,807 $ 54,245 $ 552,560 $ (1,320,079) $ 850,533
============ ============ ============ ============ ============
</TABLE>
14
<PAGE> 15
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
FOR THE THREE MONTHS ENDED SEPTEMBER 30, 2000
REVENUES:
Oil and gas sales .............................. $ 123,971 $ -- $ -- $ -- $ 123,971
Oil and gas marketing sales .................... -- 98,035 -- (53,824) 44,211
------------ ------------ ------------ ------------ ------------
Total revenues .............................. 123,971 98,035 -- (53,824) 168,182
------------ ------------ ------------ ------------ ------------
OPERATING COSTS:
Production expenses and taxes .................. 17,894 -- -- -- 17,894
General and administrative ..................... 2,997 346 34 -- 3,377
Oil and gas marketing expenses ................. -- 96,741 -- (53,824) 42,917
Oil and gas depreciation, depletion
and amortization ............................. 25,227 -- -- -- 25,227
Other depreciation and amortization ............ 991 20 838 -- 1,849
------------ ------------ ------------ ------------ ------------
Total operating costs ....................... 47,109 97,107 872 (53,824) 91,264
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) FROM OPERATIONS .................... 76,862 928 (872) -- 76,918
------------ ------------ ------------ ------------ ------------
OTHER INCOME (EXPENSE):
Interest and other income ...................... 645 166 20,965 (20,909) 867
Interest expense ............................... (21,727) -- (20,862) 20,909 (21,680)
------------ ------------ ------------ ------------ ------------
Total other income (expense) ................ (21,082) 166 103 -- (20,813)
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES ................ 55,780 1,094 (769) -- 56,105
INCOME TAX EXPENSE ............................... 1,416 -- -- -- 1,416
------------ ------------ ------------ ------------ ------------
NET INCOME (LOSS) ................................ $ 54,364 $ 1,094 $ (769) $ -- $ 54,689
============ ============ ============ ============ ============
FOR THE THREE MONTHS ENDED SEPTEMBER 30, 1999
REVENUES:
Oil and gas sales .............................. $ 77,927 $ 594 $ -- $ -- $ 78,521
Oil and gas marketing sales .................... -- 60,568 -- (36,949) 23,619
------------ ------------ ------------ ------------ ------------
Total revenues .............................. 77,927 61,162 -- (36,949) 102,140
------------ ------------ ------------ ------------ ------------
OPERATING COSTS:
Production expenses and taxes .................. 15,156 243 -- -- 15,399
General and administrative ..................... 2,514 201 21 -- 2,736
Oil and gas marketing expenses ................. -- 59,800 -- (36,949) 22,851
Oil and gas depreciation, depletion
and amortization ............................. 22,568 248 -- -- 22,816
Other depreciation and amortization ............ 1,005 20 815 -- 1,840
------------ ------------ ------------ ------------ ------------
Total operating costs ....................... 41,243 60,512 836 (36,949) 65,642
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) FROM OPERATIONS .................... 36,684 650 (836) -- 36,498
------------ ------------ ------------ ------------ ------------
OTHER INCOME (EXPENSE):
Interest and other income ...................... 1,487 935 29,789 (29,525) 2,686
Interest expense ............................... (29,376) (45) (20,524) 29,525 (20,420)
------------ ------------ ------------ ------------ ------------
Total other income (expense) ................ (27,889) 890 9,265 -- (17,734)
------------ ------------ ------------ ------------ ------------
INCOME BEFORE INCOME TAXES ....................... 8,795 1,540 8,429 -- 18,764
INCOME TAX EXPENSE ............................... 649 -- -- -- 649
------------ ------------ ------------ ------------ ------------
NET INCOME ....................................... $ 8,146 $ 1,540 $ 8,429 $ -- $ 18,115
============ ============ ============ ============ ============
</TABLE>
15
<PAGE> 16
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2000
REVENUES:
Oil and gas sales .............................. $ 311,138 $ 347 $ -- $ -- $ 311,485
Oil and gas marketing sales .................... -- 247,133 -- (141,312) 105,821
------------ ------------ ------------ ------------ ------------
Total revenues .............................. 311,138 247,480 -- (141,312) 417,306
------------ ------------ ------------ ------------ ------------
OPERATING COSTS:
Production expenses and taxes .................. 53,873 80 -- -- 53,953
General and administrative ..................... 8,558 936 103 -- 9,597
Oil and gas marketing expenses ................. -- 243,895 -- (141,312) 102,583
Oil and gas depreciation, depletion
and amortization ............................. 74,486 101 -- -- 74,587
Other depreciation and amortization ............ 3,025 60 2,466 -- 5,551
------------ ------------ ------------ ------------ ------------
Total operating costs ....................... 139,942 245,072 2,569 (141,312) 246,271
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) FROM OPERATIONS .................... 171,196 2,408 (2,569) -- 171,035
------------ ------------ ------------ ------------ ------------
OTHER INCOME (EXPENSE):
Interest and other income ...................... 2,608 969 62,877 (62,728) 3,726
Interest expense ............................... (64,166) (34) (62,885) 62,728 (64,357)
------------ ------------ ------------ ------------ ------------
Total other income (expense) ................ (61,558) 935 (8) -- (60,631)
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES ................ 109,638 3,343 (2,577) -- 110,404
INCOME TAX EXPENSE ............................... 2,879 -- -- -- 2,879
------------ ------------ ------------ ------------ ------------
NET INCOME (LOSS) ................................ $ 106,759 $ 3,343 $ (2,577) $ -- $ 107,525
============ ============ ============ ============ ============
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999
REVENUES:
Oil and gas sales .............................. $ 198,005 $ 594 $ -- $ -- $ 198,599
Oil and gas marketing sales .................... -- 133,826 -- (83,716) 50,110
------------ ------------ ------------ ------------ ------------
Total revenues .............................. 198,005 134,420 -- (83,716) 248,709
------------ ------------ ------------ ------------ ------------
OPERATING COSTS:
Production expenses and taxes .................. 45,119 243 -- -- 45,362
General and administrative ..................... 8,978 982 68 -- 10,028
Oil and gas marketing expenses ................. -- 131,525 -- (83,716) 47,809
Oil and gas depreciation, depletion
and amortization ............................. 69,954 248 -- -- 70,202
Other depreciation and amortization ............ 3,481 60 2,437 -- 5,978
------------ ------------ ------------ ------------ ------------
Total operating costs ....................... 127,532 133,058 2,505 (83,716) 179,379
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) FROM OPERATIONS .................... 70,473 1,362 (2,505) -- 69,330
------------ ------------ ------------ ------------ ------------
OTHER INCOME (EXPENSE):
Interest and other income ...................... 2,194 3,780 88,117 (87,565) 6,526
Interest expense ............................... (86,791) (45) (61,298) 87,565 (60,569)
------------ ------------ ------------ ------------ ------------
Total other income (expense) ................ (84,597) 3,735 26,819 -- (54,043)
------------ ------------ ------------ ------------ ------------
INCOME (LOSS) BEFORE INCOME TAXES ................ (14,124) 5,097 24,314 -- 15,287
INCOME TAX EXPENSE ............................... 975 -- -- -- 975
------------ ------------ ------------ ------------ ------------
NET INCOME (LOSS) ................................ $ (15,099) $ 5,097 $ 24,314 $ -- $ 14,312
============ ============ ============ ============ ============
</TABLE>
16
<PAGE> 17
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2000
CASH FLOWS FROM OPERATING ACTIVITIES ............. $ 175,178 $ (15,301) $ 14,837 $ -- $ 174,714
------------ ------------ ------------ ------------ ------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and gas properties, net .................... (164,212) 1,515 -- -- (162,697)
Proceeds from sale of other assets ............. 1,134 -- -- -- 1,134
Investment in Gothic ........................... -- -- (24,622) -- (24,622)
Other investments .............................. (4,194) -- (2,000) -- (6,194)
Other .......................................... (4,172) (46) (3,971) -- (8,189)
------------ ------------ ------------ ------------ ------------
(171,444) 1,469 (30,593) -- (200,568)
------------ ------------ ------------ ------------ ------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Net proceeds from borrowings ................... 7,500 -- -- -- 7,500
Cash payment on preferred stock swaps .......... -- -- (8,269) -- (8,269)
Cash received from exercise of stock
options....................................... -- -- 1,005 -- 1,005
Intercompany advances, net ..................... (17,224) (3,009) 20,233 -- --
------------ ------------ ------------ ------------ ------------
(9,724) (3,009) 12,969 -- 236
------------ ------------ ------------ ------------ ------------
EFFECT OF EXCHANGE RATE CHANGES
ON CASH ........................................ (313) -- -- -- (313)
------------ ------------ ------------ ------------ ------------
Net increase (decrease) in cash ................ (6,303) (16,841) (2,787) -- (25,931)
Cash, beginning of period ...................... (7,156) 20,409 25,405 -- 38,658
------------ ------------ ------------ ------------ ------------
Cash, end of period ............................ $ (13,459) $ 3,568 $ 22,618 $ -- $ 12,727
============ ============ ============ ============ ============
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999
CASH FLOWS FROM OPERATING ACTIVITIES ............. $ 55,261 $ 3,363 $ 35,517 $ -- $ 94,141
------------ ------------ ------------ ------------ ------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and gas properties, net .................... (79,920) (1,205) -- -- (81,125)
Proceeds from sale of other assets ............. 1,990 3,448 -- -- 5,438
Other .......................................... (1,659) 1,208 (1,222) -- (1,673)
------------ ------------ ------------ ------------ ------------
(79,589) 3,451 (1,222) -- (77,360)
------------ ------------ ------------ ------------ ------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Net payments on borrowings ..................... (25,000) -- -- -- (25,000)
Cash paid for purchase of treasury stock ....... -- (53) -- -- (53)
Cash received from exercise of stock
options....................................... -- -- 419 -- 419
Intercompany advances, net ..................... 55,027 5,050 (60,077) -- --
------------ ------------ ------------ ------------ ------------
30,027 4,997 (59,658) -- (24,634)
------------ ------------ ------------ ------------ ------------
EFFECT OF EXCHANGE RATE CHANGES
ON CASH ........................................ 3,705 -- -- -- 3,705
------------ ------------ ------------ ------------ ------------
Net increase (decrease) in cash ................ 9,404 11,811 (25,363) -- (4,148)
Cash, beginning of period ...................... (17,319) 7,000 39,839 -- 29,520
------------ ------------ ------------ ------------ ------------
Cash, end of period ............................ $ (7,915) $ 18,811 $ 14,476 $ -- $ 25,372
============ ============ ============ ============ ============
</TABLE>
17
<PAGE> 18
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
FOR THE THREE MONTHS ENDED SEPTEMBER 30, 2000:
Net income (loss) .............................. $ 54,364 $ 1,094 $ (769) $ -- $ 54,689
Other comprehensive income (loss) -
foreign currency translation ................. (1,165) -- -- -- (1,165)
------------ ------------ ------------ ------------ ------------
Comprehensive income (loss) .................... $ 53,199 $ 1,094 $ (769) $ -- $ 53,524
============ ============ ============ ============ ============
FOR THE THREE MONTHS ENDED SEPTEMBER 30, 1999:
Net income (loss) .............................. $ 8,146 $ 1,540 $ 8,429 $ -- $ 18,115
Other comprehensive income (loss) -
foreign currency translation ................. 80 -- -- -- 80
------------ ------------ ------------ ------------ ------------
Comprehensive income (loss) .................... $ 8,226 $ 1,540 $ 8,429 $ -- $ 18,195
============ ============ ============ ============ ============
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2000:
Net income (loss) .............................. $ 106,759 $ 3,343 $ (2,577) $ -- $ 107,525
Other comprehensive income (loss) -
foreign currency translation ................. (4,118) -- -- -- (4,118)
------------ ------------ ------------ ------------ ------------
Comprehensive income (loss) .................... $ 102,641 $ 3,343 $ (2,577) $ -- $ 103,407
============ ============ ============ ============ ============
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999:
Net income (loss) .............................. $ (15,099) $ 5,097 $ 24,314 $ -- $ 14,312
Other comprehensive income (loss) -
foreign currency translation ................. 3,705 -- -- -- 3,705
------------ ------------ ------------ ------------ ------------
Comprehensive income (loss) .................... $ (11,394) $ 5,097 $ 24,314 $ -- $ 18,017
============ ============ ============ ============ ============
</TABLE>
18
<PAGE> 19
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
5. INVESTMENT IN GOTHIC ENERGY CORPORATION ("GOTHIC")
In a series of private transactions from June 27, 2000 through September 21,
2000, CEMI purchased 99.8% of Gothic's $104 million of 14.125% Series B senior
secured discount notes for total consideration of $80.8 million, comprised of
$17.2 million in cash and $63.6 million of Chesapeake common stock (8,914,210
shares valued at $7.13 per share), as adjusted by make-whole adjustments settled
as of September 30, 2000 and received in October 2000. The final make-whole
adjustment related to the Company's acquisition of senior secured discount
notes, which occurred subsequent to September 30, 2000, will be settled on
November 14, 2000 with the return of 38,435 shares of Chesapeake common stock to
the Company. The discount notes accrete at a rate per annum of 14.125%,
compounded semiannually to an aggregate principal amount of $104.0 million at
May 1, 2002. Thereafter, the discount notes accrue interest at the rate of
14.125% per annum, payable in cash semiannually in arrears on May 1 and November
1 of each year commencing November 1, 2002. The discount notes mature on May 1,
2006 and are secured by the stock of Gothic Production Corporation, a
wholly-owned subsidiary of Gothic.
On September 1, 2000, Chesapeake purchased $20 million of the $235 million of
11.125% senior secured notes issued by Gothic Production Corporation for $22.3
million of Chesapeake common stock (3,694,939 shares valued at $6.0371 per
share, subject to adjustment), in a private transaction. The make-whole
adjustment related to this purchase was determined in November 2000 and will
result in a cash payment of $974,450 to the Company. The senior secured notes
mature on May 1, 2005, bear interest at the rate of 11.125% per annum, payable
semiannually in cash on May 1 and November 1 of each year, and are secured by
oil and gas interests held by Gothic Production Corporation.
On September 8, 2000, Chesapeake entered into an Agreement and Plan of Merger to
acquire the common stock of Gothic for 4.0 million shares of Chesapeake common
stock. Upon the closing of the transaction, Gothic's shareholders will own
approximately 2.5% of Chesapeake's common stock. The total acquisition cost to
Chesapeake, including the Gothic notes described above, will be approximately
$345 million, plus transaction expenses and adjusted for any working capital at
the time of the merger. The Gothic acquisition is subject to approval by
Gothic's shareholders and other closing conditions. Completion of the
transaction is expected in January 2001.
Also included in the Company's investment in Gothic is the Company's April 1998
investment in Gothic's 12% Preferred Stock with a carrying value of $10.0
million as well as other miscellaneous acquisition-related costs.
6. REVOLVING CREDIT FACILITY
At September 30, 2000, the Company had a $100 million revolving bank credit
facility, maturing in July 2002, with a committed borrowing base of $100
million. As of September 30, 2000, the Company had borrowed $51 million under
this facility. Borrowings under the facility are secured by certain producing
oil and gas properties and bear interest at variable rates, which averaged 9.82%
per annum as of September 30, 2000.
Bear, Stearns & Co. Inc. has agreed to provide a $275 million standby
commitment, consisting of a $175 million term credit facility and a $100 million
revolving credit facility. The term credit facility may be used to repurchase
any of Gothic Production Corporation's 11.125% senior secured notes tendered to
Chesapeake following the closing of the Gothic acquisition. If used, the
revolving credit facility will replace Chesapeake's existing revolving credit
facility. Chesapeake has incurred $0.7 million of the $3.2 million of projected
pre-closing costs for the new facility and will incur an additional $2.75
million if the credit facility is used.
19
<PAGE> 20
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
7. RECENTLY ISSUED ACCOUNTING STANDARDS
On June 15, 1998, the Financial Accounting Standards Board issued FAS No. 133,
Accounting for Derivative Instruments and Hedging Activities. FAS 133
establishes a new model for accounting for derivatives and hedging activities
and supersedes and amends a number of existing standards. FAS 133 (as amended by
FAS 137 and FAS 138) is effective for all fiscal quarters of fiscal years
beginning after June 15, 2000.
FAS 133 standardizes the accounting for derivative instruments by requiring that
all derivatives be recognized as assets and liabilities and measured at fair
value. The accounting for changes in the fair value of derivatives (gains and
losses) depends on (i) whether the derivative is designated and qualifies as a
hedge, and (ii) the type of hedging relationship that exists. Changes in the
fair value of derivatives that are not designated as hedges or that do not meet
the hedge accounting criteria in FAS 133 are required to be reported in
earnings. In addition, all hedging relationships must be designated, reassessed
and documented pursuant to the provisions of FAS 133. The Company predicts that
its commodity derivatives will be designated as hedges in accordance with the
relevant accounting criteria and believes the implementation of FAS 133 will not
have a material impact on the Company's financial condition or results of
operations. The Company does not believe that its interest rate swap will be
designated as a hedge pursuant to FAS 133. However, in accordance with certain
"knockout" provisions contained within the interest rate swap agreement, the
Company's management believes the fair market value of the swap at September
30, 2000 is immaterial. Management will continue to assess the fair value of
the interest rate swap in future periods.
20
<PAGE> 21
PART I. FINANCIAL INFORMATION
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
RESULTS OF OPERATIONS
Three Months Ended September 30, 2000 vs. September 30, 1999
General. For the three months ended September 30, 2000 (the "Current Quarter"),
the Company realized net income of $54.7 million, or $0.31 per diluted common
share. This compares to net income of $18.1 million, or $0.13 per diluted common
share, in the three months ended September 30, 1999 (the "Prior Quarter").
Oil and Gas Sales. During the Current Quarter, oil and gas sales increased 58%
to $124.0 million from $78.5 million in the Prior Quarter. For the Current
Quarter, the Company produced 33.7 billion cubic feet equivalent ("bcfe"),
consisting of 0.8 million barrels of oil ("mmbo") and 29.1 billion cubic feet of
natural gas ("bcf"), compared to 0.9 mmbo and 27.4 bcf, or 32.7 bcfe, in the
Prior Quarter. Average oil prices realized were $28.25 per barrel of oil ("bo")
in the Current Quarter compared to $18.90 per bo in the Prior Quarter, an
increase of 49%. Average gas prices realized were $3.52 per thousand cubic feet
("mcf") in the Current Quarter compared to $2.26 per mcf in the Prior Quarter,
an increase of 56%.
For the Current Quarter, the Company realized an average price of $3.68 per
thousand cubic feet equivalent ("mcfe"), compared to $2.40 per mcfe in the Prior
Quarter. The Company's hedging activities resulted in decreased oil and gas
revenues of $11.7 million, or $0.35 per mcfe, in the Current Quarter, compared
to decreased oil and gas revenues of $2.0 million, or $0.06 per mcfe, in the
Prior Quarter.
The following table shows the Company's production by region for the Current
Quarter and the Prior Quarter:
<TABLE>
<CAPTION>
FOR THE THREE MONTHS ENDED SEPTEMBER 30,
------------------------------------------
2000 1999
------------------- -------------------
OPERATING AREAS Mmcfe PERCENT Mmcfe PERCENT
--------------- -------- -------- -------- --------
<S> <C> <C> <C> <C>
Mid-Continent .... 20,027 59% 16,696 51%
Gulf Coast ....... 9,014 27 10,777 33
Canada ........... 2,654 8 3,038 9
Permian Basin .... 1,650 5 1,563 5
Other Areas ...... 362 1 588 2
-------- -------- -------- --------
Total ....... 33,707 100% 32,662 100%
======== ======== ======== ========
</TABLE>
Natural gas production represented approximately 86% of the Company's total
production volume on an equivalent basis in the Current Quarter, compared to 84%
in the Prior Quarter.
Oil and Gas Marketing Sales. The Company realized $44.2 million in oil and gas
marketing sales to third parties in the Current Quarter, with corresponding oil
and gas marketing expenses of $42.9 million, for a margin of $1.3 million. This
compares to sales of $23.6 million, expenses of $22.9 million, and a margin of
$0.7 million in the Prior Quarter. The increase in marketing sales and cost of
sales was due primarily to higher oil and gas prices in the Current Quarter as
compared to the Prior Quarter.
Production Expenses. Production expenses remained constant at $11.7 million in
the Current Quarter and the Prior Quarter. On a unit of production basis,
production expenses were $0.35 and $0.36 per mcfe in the Current and Prior
Quarters, respectively. The Company anticipates production expenses will not
vary significantly from current levels during the remainder of 2000.
Production Taxes. Production taxes, which consist primarily of wellhead
severance taxes, were $6.2 million and $3.7 million in the Current and Prior
Quarters, respectively. On a per unit basis, production taxes were $0.18 per
mcfe in the Current Quarter compared to $0.11 per mcfe in the Prior Quarter.
The increase in the Current Quarter
21
<PAGE> 22
is due to higher oil and gas prices. In general, production taxes are
calculated using value-based formulas that produce higher per unit costs
when oil and gas prices are higher.
General and Administrative. General and administrative expenses ("G&A"), which
are net of capitalized internal payroll and non-payroll expenses, were $3.4
million in the Current Quarter compared to $2.7 million in the Prior Quarter.
The Company capitalized $1.5 million of internal costs in the Current Quarter
directly related to the Company's oil and gas exploration and development
efforts, compared to $0.3 million in the Prior Quarter. The increase in
capitalized internal costs is primarily due to the addition of technical
employees and other related costs. The Company anticipates that G&A costs during
the remainder of 2000 will remain at approximately the same level as the Current
Quarter.
Oil and Gas Depreciation, Depletion and Amortization. Depreciation, depletion
and amortization of oil and gas properties ("DD&A") for the Current Quarter was
$25.2 million, compared to $22.8 million in the Prior Quarter. The DD&A rate per
mcfe increased from $0.70 in the Prior Quarter to $0.75 in the Current Quarter.
The Company expects the DD&A rate to increase slightly during the remainder of
2000, and expects it to increase further in 2001 upon the completion of the
pending acquisition of Gothic Energy Corporation.
Depreciation and Amortization of Other Assets. Depreciation and amortization of
other assets ("D&A") was $1.8 million in the Current Quarter and in the Prior
Quarter. The Company anticipates D&A will continue at current levels during the
remainder of 2000.
Interest and Other Income. Interest and other income for the Current Quarter was
$0.9 million compared to $2.7 million in the Prior Quarter. Included in the
Prior Quarter's results is a $0.5 million gain from the sale of the Company's
interest in a gas processing plant plus income earned on various investments.
Interest Expense. Interest expense increased to $21.7 million in the Current
Quarter from $20.4 million in the Prior Quarter as a result of lower capitalized
interest and higher amounts of indebtedness. In addition to the interest expense
reported, the Company capitalized $0.6 million of interest during the Current
Quarter compared to $0.8 million capitalized in the Prior Quarter.
Provision for Income Taxes. The Company recorded income tax expense of $1.4
million for the Current Quarter and $0.6 million in the Prior Quarter. The
income tax expense recorded in both the Current Quarter and Prior Quarter is
related to the Company's Canadian operations. At September 30, 2000, the Company
had a U.S. net operating loss carryforward of approximately $629.3 million for
regular federal income taxes which will expire in future years beginning in
2007. Management continues to evaluate the Company's deferred tax assets. If
oil and gas prices as well as improvements in the Company's operating
performance continue to strengthen and stabilize in future periods, all or
a portion of the valuation allowance may be reversed as early as the fourth
quarter.
Nine Months Ended September 30, 2000 vs. September 30, 1999
General. For the nine months ended September 30, 2000 (the "Current Period"),
the Company realized net income of $107.5 million, or $0.73 per diluted common
share. This compares to net income of $14.3 million, or $0.02 per diluted common
share, in the nine months ended September 30, 1999 (the "Prior Period").
Oil and Gas Sales. During the Current Period, oil and gas sales increased to
$311.5 million from $198.6 million, an increase of $112.9 million, or 57%. For
the Current Period, the Company produced 2.4 mmbo and 87.2 bcf, compared to 3.2
mmbo and 80.1 bcf in the Prior Period. Average oil prices realized were $25.70
per barrel in the Current Period compared to $14.79 per barrel in the Prior
Period, an increase of 74%. Average gas prices realized were $2.86 per mcf in
the Current Period compared to $1.88 per mcf in the Prior Period, an increase of
52%.
For the Current Period, the Company realized an average price of $3.06 per mcfe,
compared to $2.00 per mcfe in the Prior Period. The Company's hedging activities
resulted in decreased oil and gas revenues of $24.9 million, or $0.24 per mcfe,
in the Current Period, compared to increased oil and gas revenues of $1.2
million, or $0.01 per mcfe, in the Prior Period.
22
<PAGE> 23
The following table shows the Company's production by region for the Current
Period and the Prior Period:
<TABLE>
<CAPTION>
FOR THE NINE MONTHS ENDED SEPTEMBER 30,
------------------------------------------
2000 1999
------------------- -------------------
OPERATING AREAS Mmcfe PERCENT Mmcfe PERCENT
--------------- -------- -------- -------- --------
<S> <C> <C> <C> <C>
Mid-Continent .... 57,806 57% 50,278 50%
Gulf Coast ....... 27,846 27 33,629 34
Canada ........... 9,158 9 8,603 9
Permian Basin .... 4,778 5 4,032 4
Other areas ...... 2,135 2 2,998 3
-------- -------- -------- --------
Total ....... 101,723 100% 99,540 100%
======== ======== ======== ========
</TABLE>
Natural gas production represented approximately 86% of the Company's total
production volume on an equivalent basis in the Current Period, compared to 80%
in the Prior Period.
Oil and Gas Marketing Sales. The Company realized $105.8 million in oil and gas
marketing sales to third parties in the Current Period, with corresponding oil
and gas marketing expenses of $102.6 million for a margin of $3.2 million. This
compares to sales of $50.1 million and expenses of $47.8 million in the Prior
Period for a margin of $2.3 million. The increase in marketing sales and cost of
sales was due primarily to higher oil and gas prices in the Current Period as
compared to the Prior Period and the Company's initial marketing of oil which
began in June 1999.
Production Expenses. Production expenses decreased to $36.8 million in the
Current Period, a $0.1 million decrease from $36.9 million incurred in the Prior
Period. On a production unit basis, production expenses were $0.36 and $0.37 per
mcfe in the Current and Prior Periods, respectively.
Production Taxes. Production taxes, which consist primarily of wellhead
severance taxes, were $17.1 million and $8.4 million in the Current and Prior
Periods, respectively. This increase was the result of increased natural gas
production and higher oil and gas prices. On a per unit basis, production taxes
were $0.17 per mcfe in the Current Period compared to $0.08 per mcfe in the
Prior Period.
General and Administrative. G&A, which is net of capitalized internal payroll
and non-payroll expenses, was $9.6 million in the Current Period compared to
$10.0 million in the Prior Period. This decrease was primarily due to cost
efficiencies that were initiated in 1999 and fully realized in 2000 and an
increase in capitalized internal costs between periods. The Company capitalized
$4.9 million of internal costs in the Current Period directly related to the
Company's oil and gas exploration and development efforts, compared to $2.3
million in the Prior Period. The increase in capitalized internal costs is
primarily due to the addition of technical employees and other related costs.
Oil and Gas Depreciation, Depletion and Amortization. DD&A for the Current
Period was $74.6 million, compared to $70.2 million in the Prior Period. This
increase was caused by increased production as well as an increase in the DD&A
rate per mcfe from $0.71 to $0.73 in the Prior and Current Periods,
respectively.
Depreciation and Amortization of Other Assets. D&A decreased to $5.6 million in
the Current Period compared to $6.0 million in the Prior Period.
Interest and Other Income. Interest and other income for the Current Period was
$3.7 million compared to $6.5 million in the Prior Period. The Prior Period
results include a $1.7 million gain on the sale of certain marketing assets
located in the Mid-Continent, as well as a $0.5 million gain from the sale of
the Company's interest in a gas processing plant.
Interest. Interest expense increased to $64.4 million in the Current Period from
$60.6 million in the Prior Period as a result of lower capitalized interest and
higher amounts of indebtedness. The Company capitalized $1.9 million of interest
during the Current Period compared to $2.7 million capitalized in the Prior
Period.
23
<PAGE> 24
Provision for Income Taxes. The Company recorded income tax expense of $2.9
million for the Current Period, compared to $1.0 million in the Prior Period.
The income tax expense in both periods is entirely related to the Company's
operations in Canada. Management continues to evaluate the Company's deferred
tax assets. If oil and gas prices as well as improvements in the Company's
operating performance continue to strengthen and stabilize in future periods,
all or a portion of the valuation allowance may be reversed as early as the
fourth quarter.
RISK MANAGEMENT ACTIVITIES
See Item 3 - "Quantitative and Qualitative Disclosures About Market Risks."
LIQUIDITY AND CAPITAL RESOURCES
The Company had working capital of $5.1 million at September 30, 2000, including
a cash balance of $12.7 million. The Company has a $100 million revolving bank
credit facility, which matures in July 2002, with a committed borrowing base of
$100 million. As of September 30, 2000, the Company had borrowed $51.0 million
under this facility. Borrowings under the facility are secured by certain
producing oil and gas properties and bear interest at variable rates, which
averaged 9.82% per annum as of September 30, 2000.
In a series of private transactions from June 27, 2000 through September 21,
2000, CEMI purchased 99.8% of Gothic's $104 million of 14.125% Series B senior
secured discount notes for total consideration of $80.8 million, comprised of
$17.2 million in cash and $63.6 million of Chesapeake common stock (8,914,210
shares valued at $7.13 per share), as adjusted by make-whole adjustments settled
as of September 30, 2000 and received in October 2000. The final make-whole
adjustment related to the Company's acquisition of senior secured discount
notes, which occurred subsequent to September 30, 2000, will be settled on
November 14, 2000 with the return of 38,435 shares of Chesapeake common stock to
the Company. The discount notes accrete at a rate per annum of 14.125%,
compounded semiannually to an aggregate principal amount of $104.0 million at
May 1, 2002. Thereafter, the discount notes accrue interest at the rate of
14.125% per annum, payable in cash semiannually in arrears on May 1 and November
1 of each year commencing November 1, 2002. The discount notes mature on May 1,
2006 and are secured by the stock of Gothic Production Corporation, a
wholly-owned subsidiary of Gothic.
On September 1, 2000, Chesapeake purchased $20 million of the $235 million of
11.125% senior secured notes issued by Gothic Production Corporation for $22.3
million of Chesapeake common stock (3,694,939 shares valued at $6.0371 per
share, subject to adjustment), in a private transaction. The make-whole
adjustment related to this purchase was determined in November 2000 and will
result in a cash payment of $974,450 to the Company. The senior secured notes
mature on May 1, 2005, bear interest at the rate of 11.125% per annum, payable
semiannually in cash on May 1 and November 1 of each year, and are secured by
oil and gas interests held by Gothic Production Corporation.
On September 8, 2000, Chesapeake entered into an Agreement and Plan of Merger to
acquire the common stock of Gothic for 4.0 million shares of Chesapeake common
stock. Upon the closing of the transaction, Gothic's shareholders will own
approximately 2.5% of Chesapeake's common stock. The total acquisition cost to
Chesapeake, including the Gothic notes described above, will be approximately
$345 million, plus transaction expenses and adjusted for any working capital at
the time of the merger. The Gothic acquisition is subject to approval by
Gothic's shareholders and other closing conditions. Completion of the
transaction is expected in January 2001.
At September 30, 2000, the Company's senior notes represented $919.2 million of
its $971.0 million of long-term liabilities. Debt ratings for the senior notes
are B2 by Moody's Investors Service and B by Standard & Poor's Corporation as of
September 30, 2000. On July 5, 2000, Standard & Poor's Corporation placed its
ratings of the Company on credit watch with positive implications. There are no
scheduled principal payments required on any of the senior notes until March
2004, when $150 million is due.
The senior note indentures restrict the ability of the Company and its
restricted subsidiaries to incur additional indebtedness. This restriction does
not affect the Company's ability to borrow under or expand its secured
24
<PAGE> 25
commercial bank facility. As of September 30, 2000, the Company estimates that
secured commercial bank indebtedness of $147.5 million could have been incurred
under the indentures. The indenture restrictions do not apply to borrowings
incurred by CEMI, an unrestricted subsidiary.
The senior note indentures also limit the Company's ability to make restricted
payments (as defined), including the payment of preferred stock dividends,
unless certain tests are met. From December 31, 1998 through March 31, 2000, the
Company was unable to meet the requirements to incur additional unsecured
indebtedness, and consequently was not able to pay cash dividends on its 7%
cumulative convertible preferred stock. The Company had accumulated dividends in
arrears of $4.4 million related to its preferred stock as of September 30, 2000.
As a result of the Company's failure to pay dividends for six quarterly periods,
the holders of preferred stock were entitled to elect two new directors to the
Board following May 1, 2000. On September 22, 2000, the Company declared a
regular quarterly dividend and a special dividend equal to all unpaid dividends
on its preferred stock ($4.6 million in the aggregate through October 31, 2000).
The total combined dividend of $7.444 per share was paid November 1, 2000,
eliminating the right of preferred stockholders to elect directors.
In the Current Quarter, the Company engaged in unsolicited transactions in which
a total of 9.2 million shares of common stock (newly issued shares) were
exchanged for 933,000 shares of its issued and outstanding preferred stock with
a liquidation value of $46.7 million plus dividends in arrears of $6.1 million.
A total of 43.4 million shares of common stock, plus a cash payment of $8.3
million, were exchanged for 3,972,363 shares of preferred stock during the
Current Period. These transactions have reduced (i) the number of preferred
shares from 4.6 million to 0.6 million, (ii) the liquidation value of the
preferred stock from $229.8 million to $31.2 million, and (iii) dividends in
arrears through September 30, 2000 by $22.9 million to $4.4 million. A gain on
redemption of all preferred shares exchanged during the Current Period of $6.6
million ($5.3 million loss related to the Current Quarter) is reflected in net
income available to common shareholders in determining basic earnings per share
for the Current Period.
The Company may acquire additional shares of preferred stock in the future
through negotiations with individual holders and, beginning May 1, 2001, may
redeem outstanding shares of preferred stock for $52.45 per share plus
accumulated and unpaid dividends in cash and/or common stock.
The Company believes it has adequate resources, including cash on hand and
budgeted cash flow from operations, to fund its capital expenditure budget for
exploration and development activities during 2000, which are currently
estimated to be approximately $150 million. Based on current oil and gas prices,
the Company expects to generate excess cash flow that will be available to fund
acquisitions, reduce debt, make preferred stock dividend payments, acquire
Gothic debt securities or a combination of the above.
If the Gothic merger is completed, holders of Gothic Production Corporation's
11.125% senior secured notes will have the right, but not the obligation, to
require Chesapeake to repurchase their notes at a purchase price equal to 101%
of the principal amount of the notes, plus accrued and unpaid interest to the
date of repurchase. Chesapeake presently holds $20 million of the $235 million
principal amount of senior secured notes outstanding. Bear, Stearns & Co. Inc.
has agreed to provide a $275 million standby commitment, consisting of a $175
million term credit facility and a $100 million revolving credit facility. The
term credit facility may be used to repurchase any of Gothic Production
Corporation's senior secured notes tendered to Chesapeake. If used, the
revolving credit facility will replace Chesapeake's existing revolving credit
facility. Chesapeake has incurred $0.7 million of the $3.2 million of projected
pre-closing costs for the new facility and will incur an additional $2.75
million if the credit facility is used.
The Company's cash provided by operating activities increased 86% to $174.7
million during the Current Period compared to $94.1 million during the Prior
Period. The increase was due primarily to higher oil and gas prices realized
during the Current Period.
Cash used in investing activities increased to $200.6 million during the Current
Period from $77.4 million in the Prior Period. During the Current Period the
Company expended approximately $103.0 million to initiate drilling on 203 gross
(104.3 net) wells and invested approximately $19.0 million in leasehold
acquisitions. This compares
25
<PAGE> 26
to $90.0 million to initiate drilling on 142 gross (83.8 net) wells and $16.4
million to purchase leasehold in the Prior Period. During the Current Period,
the Company had acquisitions of oil and gas properties of $36.3 million,
divestitures of oil and gas properties of $1.4 million, and cash payments of
$24.6 million related to the investment in Gothic (prior to the receipt of $6.1
million in cash related to make-whole adjustments settled as of September 30,
2000 and received in October 2000). This compares to acquisitions of $11.1
million and divestitures of $36.4 million in the Prior Period. During the
Current Period, the Company invested $4.2 million in Advanced Drilling
Technologies, L.L.C., a 50% Chesapeake-owned drilling rig company which
presently owns five rigs that are either drilling or are being refurbished for
drilling. The Company anticipates that its share of the capital costs related to
these five rigs will total $8.0 million.
There was $0.2 million of cash provided by financing activities in the Current
Period, compared to $24.6 million used in the Prior Period. The activity in the
Current Period and the Prior Period reflects the net increase in borrowings
under the Company's commercial bank credit facility of $7.5 million in the
Current Period and the net decrease in borrowings of $25.0 million in the Prior
Period. The activity also reflects cash payments of $8.3 million made in
connection with the preferred stock swaps in the Current Period and cash
received through the exercise of stock options in both periods.
RECENTLY ISSUED ACCOUNTING STANDARDS
On June 15, 1998, the Financial Accounting Standards Board issued FAS No. 133,
Accounting for Derivative Instruments and Hedging Activities. FAS 133
establishes a new model for accounting for derivatives and hedging activities
and supersedes and amends a number of existing standards. FAS 133 (as amended by
FAS 137 and FAS 138) is effective for all fiscal quarters of fiscal years
beginning after June 15, 2000.
FAS 133 standardizes the accounting for derivative instruments by requiring that
all derivatives be recognized as assets and liabilities and measured at fair
value. The accounting for changes in the fair value of derivatives (gains and
losses) depends on (i) whether the derivative is designated and qualifies as a
hedge, and (ii) the type of hedging relationship that exists. Changes in the
fair value of derivatives that are not designated as hedges or that do not meet
the hedge accounting criteria in FAS 133 are required to be reported in
earnings. In addition, all hedging relationships must be designated, reassessed
and documented pursuant to the provisions of FAS 133. The Company predicts that
its commodity derivatives will be designated as hedges in accordance with the
relevant accounting criteria and believes the implementation of FAS 133 will not
have a material impact on the Company's financial condition or results of
operations. The Company does not believe that its interest rate swap will be
designated as a hedge pursuant to FAS 133. However, in accordance with certain
"knockout" provisions contained within the interest rate swap agreement, the
Company's management believes the fair market value of the swap at September
30, 2000 is immaterial. Management will continue to assess the fair value of
the interest rate swap in future periods.
FORWARD LOOKING STATEMENTS
This Form 10-Q includes "forward-looking statements" within the meaning of
Section 27A of the Securities Act of 1933 and Section 21E of the Securities
Exchange Act of 1934. Forward-looking statements include statements regarding
oil and gas reserve estimates, planned capital expenditures, expected oil and
gas production, the Company's financial position, business strategy and other
plans and objectives for future operations, expected future expenses,
realization of deferred tax assets, the proposed acquisition of Gothic and the
combined entity's financial operations. Although the Company believes that the
expectations reflected in these and other forward-looking statements are
reasonable, it can give no assurance that such expectations will prove to have
been correct. Various factors could cause actual results to differ materially
from those expected by the Company, including, without limitation, factors
discussed under Risk Factors in the proxy statement/prospectus for the Gothic
acquisition dated November 1, 2000, a form of which is included in the Company's
registration statement on Form S-4 (file no. 333-47330) filed with the
Securities and Exchange Commission on November 1, 2000. Such factors are
substantial indebtedness, fluctuations in the prices of oil and gas, need to
replace reserves, substantial capital requirements, uncertainties inherent in
estimating quantities of oil and gas reserves, projecting future rates of
production and the timing of development expenditures, operating risks,
restrictions imposed by lenders, the effects of governmental and environmental
regulation, pending or future litigation, conflicts of interest our CEO and COO
may have, and uncertainties related to the proposed business combination with
Gothic. Readers are cautioned not to place undue reliance on these
forward-looking statements, which speak only as of the date this report is
filed, and the Company undertakes no obligation to update this information.
26
<PAGE> 27
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKS
COMMODITY PRICE RISK
The Company's results of operations are highly dependent upon the prices
received for oil and natural gas production.
COMMODITY HEDGING ACTIVITIES
Periodically the Company utilizes hedging strategies to hedge the price of a
portion of its future oil and gas production. These strategies include:
(i) swap arrangements that establish an index-related price above which
the Company pays the counterparty and below which the Company is
paid by the counterparty,
(ii) the purchase of index-related puts that provide for a "floor" price
below which the counterparty pays the Company the amount by which
the price of the commodity is below the contracted floor,
(iii) the sale of index-related calls that provide for a "ceiling" price
above which the Company pays the counterparty the amount by which
the price of the commodity is above the contracted ceiling, and
(iv) basis protection swaps, which are arrangements that guarantee the
price differential of oil or gas from a specified delivery point or
points,
(v) collar arrangements that establish an index-related price below
which the counterparty pays the Company and a separate
index-related price above which the Company pays the counterparty.
As market conditions warrant, the Company may also elect to settle a hedging
transaction prior to its scheduled maturity date and, as a result, lock in a
gain or loss on the transaction.
Results from commodity hedging transactions are reflected in oil and gas sales
to the extent related to the Company's oil and gas production. The Company only
enters into commodity hedging transactions related to the Company's oil and gas
production volumes or CEMI's physical purchase or sale commitments. Gains or
losses on crude oil and natural gas hedging transactions are recognized as price
adjustments in the months of related production.
As of September 30, 2000, the Company had the following open natural gas swap
arrangements designed to hedge a portion of the Company's domestic gas
production for periods after September 2000:
<TABLE>
<CAPTION>
NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (MMBTU) (PER MMBTU)
------ --------- ------------
<S> <C> <C>
October 2000..................................... 930,000 $ 2.57
</TABLE>
If the swap arrangement listed above had been settled on September 30, 2000, the
Company would have incurred a loss of $2.6 million. Subsequent to September 30,
2000 the Company settled the October 2000 natural gas swap for a loss of $3.3
million, which will be recognized as a price adjustment in October 2000.
On June 2, 2000, the Company entered into a natural gas basis protection swap
transaction for 13,500,000 MMBtu for the period of January 2001 through March
2001. This transaction requires that the counterparty pay the Company if the
NYMEX price exceeds the Houston Ship Channel Beaumont/Texas Index by more than
$0.0675 for each of the related months of production. If the NYMEX price less
$0.0675 does not exceed the Houston Ship Channel Beaumont/Texas Index for each
month, the Company will pay the counterparty. Gains or losses on basis swap
transactions are recognized as price adjustments in the month of related
production.
The Company also had closed a transaction designed to hedge a portion of the
Company's domestic natural gas production as of September 30, 2000. The net
unrecognized loss resulting from this transaction, $0.7 million as of September
30, 2000, will be recognized as a price adjustment in October 2000, the month of
related production.
Subsequent to September 30, 2000, the Company entered into natural gas collar
transactions designed to hedge 60,000 MMBtu per day throughout 2001 at an
average NYMEX-defined high strike price of $6.08 per MMBtu and an average
NYMEX-defined low strike price of $4.00 per MMBtu. In addition, the Company
entered into the following natural gas swap arrangements designed to hedge a
portion of the Company's domestic gas production for periods after September
2000:
27
<PAGE> 28
<TABLE>
<CAPTION>
MONTHLY NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (MMBTU) (PER MMBTU)
------ --------- ------------
<S> <C> <C>
December 2000.............................................. 1,860,000 $ 5.8350
January 2001............................................... 2,480,000 5.8425
February 2001.............................................. 2,240,000 5.4788
March 2001................................................. 2,480,000 4.9013
April 2001................................................. 2,480,000 4.6575
May 2001................................................... 2,480,000 4.5600
June 2001.................................................. 1,200,000 4.4900
July 2001.................................................. 1,240,000 4.4900
August 2001 ............................................... 1,240,000 4.4900
September 2001............................................. 1,200,000 4.4900
</TABLE>
As of September 30, 2000, the Company had the following open crude oil swap
arrangements designed to hedge a portion of the Company's domestic crude oil
production for periods after September 2000:
<TABLE>
<CAPTION>
MONTHLY NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (BBLS) (PER BBL)
------ ------- ------------
<S> <C> <C>
October 2000............................................... 125,000 $28.42
November 2000.............................................. 125,000 28.42
December 2000.............................................. 125,000 28.42
</TABLE>
If the swap arrangements listed above had been settled on September 30, 2000,
the Company would have incurred a loss of $1.7 million. Subsequent to September
30, 2000, the Company entered into crude oil swap arrangements designed to hedge
5,000 barrels per day at a NYMEX Index strike price of $29.76 per barrel in
January through December 2001.
In addition to commodity hedging transactions related to the Company's oil and
gas production, CEMI periodically enters into various hedging transactions
designed to hedge against physical purchase and sale commitments made by CEMI.
Gains or losses on these transactions are recorded as adjustments to oil and gas
marketing sales in the consolidated statements of operations and are not
considered by management to be material.
INTEREST RATE RISK
The Company also utilizes hedging strategies to manage fixed-interest rate
exposure. Through the use of a swap arrangement, the Company has reduced its
interest expense by $2.7 million from May 1998 through September 2000. During
the Current Quarter, the Company's interest rate swap resulted in a $75,000
increase in interest expense. The terms of the swap agreement are as follows:
<TABLE>
<CAPTION>
MONTHS NOTIONAL AMOUNT FIXED RATE FLOATING RATE
------ --------------- ---------- -------------
<S> <C> <C> <C>
May 1998 - April 2001 $230,000,000 7% Average of three-month Swiss Franc LIBOR,
Deutsche Mark and Australian Dollar plus
300 basis points
May 2001 - April 2008 $230,000,000 7% Three-month LIBOR (USD) plus 300 basis points
</TABLE>
If the floating rate is less than the fixed rate, the counterparty will pay the
Company accordingly. If the floating rate exceeds the fixed rate, the Company
will pay the counterparty. The interest rate swap agreement contains a "knockout
provision" whereby the agreement will terminate on or after May 1, 2001 if the
average closing price for the previous twenty business days for the shares of
the Company's common stock is greater than or equal to $7.50 per share. The
agreement also provides for a maximum floating rate of 8.5% from May 2001
through April 2008.
As of September 30, 2000, based upon prevailing interest rates, the present
value of the Company's estimated future obligations under the interest rate swap
agreement, without ascribing any value to the knock-out provision, was $18.0
million. However, because of the knock-out provision discussed above and the
volatility of interest rates, the Company does not believe that this worst-case
scenario is a fair measure of the market value of the swap agreement and,
therefore, would not pay this amount to cancel the transaction. Results from
interest rate hedging transactions are reflected as adjustments to interest
expense in the corresponding months covered by the swap agreement.
The table below presents principal cash flows and related weighted average
interest rates by expected maturity dates. The fair value of the long-term debt
has been estimated based on quoted market prices.
28
<PAGE> 29
<TABLE>
<CAPTION>
SEPTEMBER 30, 2000
-------------------------------------------------------------------------------------
YEARS OF MATURITY
-------------------------------------------------------------------------------------
2000 2001 2002 2003 2004 THEREAFTER TOTAL FAIR VALUE
-------- -------- -------- -------- -------- ---------- -------- ----------
($ IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
LIABILITIES:
Long-term debt, including current
portion - fixed rate ............... $ 0.2 $ 0.8 $ 0.6 $ -- $ 150.0 $ 770.0 $ 921.6 $ 894.7
Average interest rate .............. 9.1% 9.1% 9.1% -- 7.9% 9.3% 9.1% --
Long-term debt - variable rate ....... $ -- $ -- $ 51.0 $ -- $ -- $ -- $ 51.0 $ 51.0
Average interest rate .............. -- -- 10.0% -- -- -- 10.0% --
</TABLE>
29
<PAGE> 30
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
Chesapeake is subject to ordinary routine litigation incidental to its business.
In addition, Chesapeake and certain of its officers and directors are defendants
in other pending actions which are described in Part I, Item 3 of the Company's
Annual Report on Form 10-K for the year ended December 31, 1999. Subsequently,
in October 2000, there were appellate decisions in two oil and gas lease
cancellation cases pending against one of our subsidiaries.
Our subsidiary, Chesapeake Panhandle Limited Partnership ("CP") (f/k/a MC
Panhandle, Inc.), and two subsidiaries of Kinder Morgan, Inc. are defendants in
13 lawsuits filed between June 1997 and January 1999 by royalty owners seeking
the cancellation of oil and gas leases in the West Panhandle Field in Texas. MC
Panhandle, Inc., which we acquired in April 1998, has owned the leases since
January 1, 1997. The co-defendants are prior lessees.
The plaintiffs in these cases claim the leases terminated upon the cessation of
production for various periods primarily during the 1960s. In addition, the
plaintiffs seek to recover conversion damages, exemplary damages, attorneys'
fees and interest. Defendants assert that any cessation of production was
excused and have pled affirmative defenses of limitations, waiver, temporary
estoppel, laches and title by adverse possession. Four of the 13 cases have been
tried, and there have been appellate decisions in the following two cases tried
in the District Court of Moore County, Texas, 69th Judicial District. No trial
dates have been set for the other cases.
Joseph H. Pool, et al. v. NGPL, et al., No. 98-30, first filed December 17,
1997, refiled May 11, 1998, jury trial in June 1999, verdict for CP and
co-defendants. The jury found plaintiffs' claims were barred by laches and
adverse possession. On September 28, 1999, the court granted plaintiffs' motion
for judgment notwithstanding verdict and entered judgment in favor of
plaintiffs. In addition to quieting title to the leases (including existing gas
wells and all attached equipment) in plaintiffs, the court awarded actual
damages as of June 28, 1999 of $545,000 from CP and $235,000 jointly and
severally from the other two defendants. The court further awarded, jointly and
severally from all defendants, $77,500 of attorneys' fees in the event of an
appeal, $1,900 of sanctions, interest and court costs. CP and the other two
defendants filed an appeal of the judgment in the Court of Appeals for the
Seventh District of Texas in Amarillo on October 12, 1999, and they have each
posted a supersedeas bond. On October 12, 2000, the Court of Appeals issued a
decision sustaining the trial court's finding that the leases had terminated due
to a cessation of production and that the plaintiffs were entitled to actual
damages and attorneys' fees. However, the award was reduced by $161,750, by way
of additional offset for lease operating expenses which were improperly excluded
by the jury. CP and the other defendants have filed a motion for rehearing.
Joseph H. Pool, et al. v. NGPL, et al., No. 98-36, first filed February 2, 1998,
refiled May 20, 1998, jury trial in July 1999, verdict for plaintiffs. The jury
found that the defendants were bad-faith trespassers and produced gas from the
leases as a result of fraud. On September 28, 1999, the court entered final
judgment for plaintiffs terminating the leases, quieting title to the leases
(including existing gas wells and all attached equipment) in plaintiffs as of
June 1, 1999 and awarding actual damages of $1.5 million, attorneys' fees of
$97,500 in the event of an appeal, interest and court costs. CP's liability for
this award is joint and several with the other two defendants. The court also
awarded exemplary damages of $1.2 million against each of CP and the other two
defendants. CP and the other two defendants filed an appeal of the judgment in
the Court of Appeals for the Seventh District of Texas in Amarillo on October
12, 1999, and they have each posted a supersedeas bond. On October 12, 2000, the
Court of Appeals issued a decision sustaining the trial court's finding that the
leases had terminated due to a cessation of production and that the plaintiffs
were entitled to actual damages and attorneys' fees. However, the court reduced
the damages award to $1,049,500, based on the application of a two-year statute
of limitations, and reversed all of the $3.6 million exemplary damages award,
finding there was no legal basis for such an award. CP and the other defendants
have filed a motion for rehearing.
We have previously established an accrued liability we believe will be
sufficient to cover the estimated costs of litigation for each of the pending
lease cancellation cases. Because of the inconsistent verdicts reached by the
juries in the four cases tried to date and because the amount of damages sought
is not specified in all of the other
30
<PAGE> 31
cases, the outcome of the remaining trials and the amount of damages that might
ultimately be awarded could differ from management's estimates. We believe,
however, that the leases are valid, there is no basis for exemplary damages,
fraud or bad faith trespass. CP and the other defendants intend to vigorously
defend against the plaintiffs' claims.
ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS
During the quarter ended September 30, 2000, the Company exchanged 9,211,259
shares of common stock for 933,000 shares of its outstanding preferred stock in
private transactions with institutional investors. The exchanges were exempt
from registration under Section 3(a) (9) of the Securities Act of 1933 inasmuch
as the Company exchanged securities exclusively with its existing shareholders
and no commission or other remuneration was paid with respect to the exchanges.
On June 27, 2000 and August 31, 2000, Chesapeake's wholly-owned subsidiary,
Chesapeake Energy Marketing, Inc., acquired 99.7% of the 14.125% senior secured
discount notes of Gothic Energy Corporation having a total accreted value of
$80.7 million (face amount of $103.7 million) for 8,914,210 shares of newly
issued Chesapeake common stock and $17.2 million of cash, as adjusted by
make-whole adjustments settled as of September 30, 2000. The final make-whole
adjustment related to the Company's acquisition of senior secured discount
notes, which occurred subsequent to September 30, 2000, will be settled on
November 14, 2000 with the return of 38,435 shares of Chesapeake common stock to
the Company. The shares were exchanged in private transactions pursuant to the
exemption from registration provided by Section 4(2) of the Securities Act.
On September 1, 2000, Chesapeake purchased $20 million of the $235 million of
11.125% senior secured notes issued by Gothic's operating subsidiary for $22.3
million of Chesapeake common stock (3,694,939 shares valued at $6.0371 per
share, subject to adjustment) in a private transaction in reliance on the
exemption from registration provided by Section 4(2) of the Securities Act. The
make-whole adjustment related to this purchase was determined in November 2000
and will result in a cash payment of $974,450 to the Company.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES OR DIVIDEND ARREARAGES
August 1, 2000 was the seventh consecutive payment date on which the Company
failed to pay dividends on its 7% cumulative convertible preferred stock.
Dividends accrue at the annual rate of $3.50 per share. Dividends which are not
declared and paid when due compound quarterly on each dividend payment date at
the dividend payment rate. Unpaid dividends on 624,037 shares outstanding as of
September 30, 2000 were $4.4 million. On September 22, 2000, the Company
declared a regular quarterly dividend and a special dividend equal to all unpaid
dividends on its preferred stock. The total combined dividend of $7.444 per
share, $4.6 million in the aggregate, was paid November 1, 2000. Additional
information on preferred stock dividends is provided in Part I, Item 2 under
"Liquidity and Capital Resources," the seventh and eighth paragraphs of which
are incorporated herein by reference.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
- Not applicable
ITEM 5. OTHER INFORMATION
- Not applicable
31
<PAGE> 32
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
The following exhibits are filed as a part of this report:
Exhibit No.
27 Financial Data Schedule
(b) Reports on Form 8-K
During the quarter ended September 30, 2000, the Company filed
the following Current Reports on Form 8-K:
On July 20, 2000, the Company filed a current report on Form 8-K
reporting under Item 5 that the Company formed a 2.2 million acre coal
bed methane joint venture in Oklahoma's Arkoma Basin.
On July 28, 2000, the Company filed a current report on Form 8-K
reporting under Item 5 that the Company issued a press release
reporting earnings, cash flow and EBITDA in the second quarter of 2000.
On September 13, 2000, the Company filed a current report on Form 8-K
reporting under Item 5 that the Company issued a press release
announcing completion of a definitive merger agreement to acquire
Gothic Energy Corporation.
32
<PAGE> 33
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.
CHESAPEAKE ENERGY CORPORATION
-----------------------------
(Registrant)
November 14, 2000 /s/ Aubrey K. McClendon
----------------------------- -----------------------------
Date Aubrey K. McClendon
Chairman and
Chief Executive Officer
November 14, 2000 /s/ Marcus C. Rowland
----------------------------- -----------------------------
Date Marcus C. Rowland
Executive Vice President and
Chief Financial Officer
<PAGE> 34
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<S> <C>
27 Financial Data Schedule
</TABLE>
