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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 MARCH 31, 2001

[ ] 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 May 10, 2001, there were 163,988,384 shares of our $.01 par value
common stock outstanding.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

INDEX TO FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2001

PART I. FINANCIAL INFORMATION
PAGE
----

Item 1. Consolidated Financial Statements:

Consolidated Balance Sheets at December 31, 2000 and
March 31, 2001 (Unaudited) 3

Consolidated Statements of Operations for the Three Months Ended
March 31, 2000 and 2001 (Unaudited) 4

Consolidated Statements of Cash Flows for the Three Months Ended
March 31, 2000 and 2001 (Unaudited) 5

Consolidated Statements of Comprehensive Income for the Three Months
Ended March 31, 2000 and 2001 (Unaudited) 6

Notes to Consolidated Financial Statements (Unaudited) 7

Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations 19

Item 3. Quantitative and Qualitative Disclosures About Market Risks 24

PART II. OTHER INFORMATION

Item 1. Legal Proceedings 28

Item 2. Changes in Securities and Use of Proceeds 28

Item 3. Defaults Upon Senior Securities or Dividend Arrearages 28

Item 4. Submission of Matters to a Vote of Security Holders 28

Item 5. Other Information 28

Item 6. Exhibits and Reports on Form 8-K 28

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS
(UNAUDITED)

DECEMBER 31, MARCH 31,
ASSETS 2000 2001
----------- -----------
($ IN THOUSANDS)

CURRENT ASSETS:
Cash and cash equivalents ................................................. $ -- $ 21,203
Restricted cash ........................................................... 3,500 --
Accounts receivable:
Oil and natural gas sales ............................................... 50,109 64,164
Oil and natural gas marketing sales ..................................... 46,953 43,664
Joint interest and other, net of allowances of $1,085,000 and
$1,071,000, respectively .............................................. 15,998 20,294
Related parties ......................................................... 4,383 6,772
Deferred income tax asset ................................................. 40,819 42,000
Short-term derivative instruments ......................................... -- 3,452
Inventory ................................................................. 3,167 3,614
Other ..................................................................... 1,997 1,857
----------- -----------
Total Current Assets ................................................ 166,926 207,020
----------- -----------
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on full-cost accounting:
Evaluated oil and natural gas properties ................................ 2,590,512 3,088,525
Unevaluated properties .................................................. 25,685 44,752
Less: accumulated depreciation, depletion and amortization .............. (1,770,827) (1,807,316)
----------- -----------
845,370 1,325,961
Other property and equipment .............................................. 79,898 100,763
Less: accumulated depreciation and amortization ........................... (37,034) (37,939)
----------- -----------
Total Property and Equipment ........................................ 888,234 1,388,785
----------- -----------
OTHER ASSETS:
Investment in Gothic Energy Corporation ................................... 126,434 --
Deferred income tax asset ................................................. 229,823 186,773
Long-term derivative instruments .......................................... -- 8,022
Long-term investments, other .............................................. 2,000 11,892
Other assets .............................................................. 27,009 15,362
----------- -----------
Total Other Assets .................................................. 385,266 222,049
----------- -----------
TOTAL ASSETS ................................................................ $ 1,440,426 $ 1,817,854
=========== ===========

LIABILITIES AND STOCKHOLDERS' EQUITY

CURRENT LIABILITIES:
Notes payable and current maturities of long-term debt .................... $ 836 $ 855
Accounts payable .......................................................... 62,940 66,570
Accrued property acquisitions ............................................. 22,530 36,400
Accrued interest .......................................................... 17,537 35,278
Other accrued liabilities ................................................. 21,637 32,805
Revenues and royalties due others ......................................... 35,682 44,976
Income tax payable ........................................................ 1,539 3,600
----------- -----------
Total Current Liabilities ........................................... 162,701 220,484
----------- -----------
LONG-TERM DEBT, NET ......................................................... 944,845 1,140,738
----------- -----------
REVENUES AND ROYALTIES DUE OTHERS ........................................... 7,798 13,227
----------- -----------
DEFERRED INCOME TAX LIABILITY ............................................... 11,850 13,216
----------- -----------
CONTINGENCIES (NOTE 2)
STOCKHOLDERS' EQUITY:
Preferred Stock, $.01 par value, 10,000,000 shares authorized;
624,037 shares of 7% cumulative convertible stock issued and
outstanding at December 31, 2000 and March 31, 2001, entitled
in liquidation to $31.2 million ......................................... 31,202 31,202
Common Stock, par value of $.01, 250,000,000 shares authorized;
157,819,171 and 163,944,466 shares issued at December 31, 2000
and March 31, 2001, respectively ........................................ 1,578 1,639
Paid-in capital ........................................................... 963,584 1,007,656
Accumulated deficit ....................................................... (659,286) (590,090)
Accumulated other comprehensive income (loss) ............................. (3,901) (236)
Less: treasury stock, at cost; 4,788,747 and 4,792,529 common
shares at December 31, 2000 and March 31, 2001, respectively ............ (19,945) (19,982)
----------- -----------
Total Stockholders' Equity .......................................... 313,232 430,189
----------- -----------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY .................................. $ 1,440,426 $ 1,817,854
=========== ===========

The accompanying notes are an integral part of these
consolidated financial statements.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)

THREE MONTHS ENDED
MARCH 31,
-----------------------
2000 2001
--------- ---------
($ IN THOUSANDS,
EXCEPT PER SHARE DATA)

REVENUES:
Oil and natural gas sales ....................................... $ 87,293 $ 221,219
Oil and natural gas marketing sales ............................. 27,368 56,165
--------- ---------
Total Revenues .............................................. 114,661 277,384
--------- ---------

OPERATING COSTS:
Production expenses ............................................. 12,545 17,788
Production taxes ................................................ 5,216 14,295
General and administrative ...................................... 3,032 4,001
Oil and natural gas marketing expenses .......................... 26,544 54,478
Oil and natural gas depreciation, depletion and amortization .... 24,483 38,173
Depreciation and amortization of other assets ................... 1,866 1,953
--------- ---------
Total Operating Costs ....................................... 73,686 130,688
--------- ---------

INCOME FROM OPERATIONS ........................................... 40,975 146,696
--------- ---------

OTHER INCOME (EXPENSE):
Interest and other income ....................................... 1,192 569
Interest expense ................................................ (20,864) (25,889)
Gothic standby credit facility costs ............................ -- (3,392)
--------- ---------
Total Other Income (Expense) ................................ (19,672) (28,712)
--------- ---------

INCOME BEFORE INCOME TAX ......................................... 21,303 117,984
INCOME TAX EXPENSE ............................................... 101 47,696
--------- ---------
NET INCOME ....................................................... 21,202 70,288
Preferred stock dividends ....................................... (4,042) (546)
Gain on repurchase of preferred stock ........................... 10,414 --
--------- ---------
NET INCOME AVAILABLE TO COMMON SHAREHOLDERS ...................... $ 27,574 $ 69,742
========= =========

EARNINGS PER COMMON SHARE:
Basic ........................................................... $ 0.27 $ 0.44
========= =========
Assuming dilution ............................................... $ 0.15 $ 0.41
========= =========

WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT
SHARES OUTSTANDING (IN THOUSANDS):
Basic ........................................................... 101,681 157,707
========= =========
Assuming dilution ............................................... 140,130 170,326
========= =========

The accompanying notes are an integral part of these
consolidated financial statements.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)

THREE MONTHS ENDED
MARCH 31,
-----------------------
2000 2001
--------- ---------
($ IN THOUSANDS)

CASH FLOWS FROM OPERATING ACTIVITIES:
Net income ....................................................... $ 21,202 $ 70,288
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation, depletion and amortization ........................ 25,440 39,116
Provision for deferred income taxes ............................. 101 47,696
Gothic standby credit facility costs ............................ -- 3,392
Amortization of loan costs ...................................... 909 1,010
Amortization of bond discount ................................... 21 19
Accretion of note premium ....................................... -- (704)
(Gain) loss on sale of fixed assets and other ................... (100) 25
Other ........................................................... 119 64
--------- ---------
Cash provided by operating activities before changes in
current assets and liabilities ............................. 47,692 160,906

Changes in current assets and liabilities ....................... (9,477) 45,443
--------- ---------
Cash provided by operating activities ......................... 38,215 206,349
--------- ---------

CASH FLOWS FROM INVESTING ACTIVITIES:
Exploration and development of oil and natural gas properties .... (40,252) (109,859)
Acquisitions of oil and natural gas properties ................... (4,564) (43,980)
Divestitures of oil and natural gas properties ................... 985 140
Other proceeds from sales ........................................ 177 35
Other property and equipment additions ........................... (1,191) (13,060)
Other ............................................................ (2,045) (443)
--------- ---------
Cash used in investing activities ............................. (46,890) (167,167)
--------- ---------

CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term borrowings ............................... 45,000 93,000
Payments on long-term borrowings ................................. (48,500) (103,500)
Cash payments to redeem debt ..................................... -- (8,255)
Cash dividends paid on preferred stock ........................... -- (546)
Cash received from exercise of stock options ..................... 226 2,191
--------- ---------
Cash used in financing activities ............................. (3,274) (17,110)
--------- ---------

EFFECT OF CHANGES IN EXCHANGE RATE ON CASH ......................... (478) (869)
--------- ---------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS ............... (12,427) 21,203
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD ..................... 38,658 --
--------- ---------
CASH AND CASH EQUIVALENTS, END OF PERIOD ........................... $ 26,231 $ 21,203
========= =========

The accompanying notes are an integral part of these
consolidated financial statements.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(UNAUDITED)

THREE MONTHS ENDED
MARCH 31,
---------------------
2000 2001
-------- --------
($ IN THOUSANDS)

Net income .......................................................... $ 21,202 $ 70,288
Other Comprehensive Income, net of income tax:
Foreign currency translation adjustments ......................... (478) (3,219)
Cumulative effect of accounting change for financial
derivatives .................................................... -- (53,580)
Change in fair value of derivative instruments ................... -- 42,138
Fair value of derivatives reclassified to earnings ............... -- 18,326
-------- --------
Other comprehensive income .......................................... $ 20,724 $ 73,953
======== ========

The accompanying notes are an integral part of these
consolidated financial statements.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2001
(UNAUDITED)

1. BASIS OF PRESENTATION AND ACCOUNTING POLICIES

Principles of Consolidation - The accompanying unaudited consolidated financial
statements of Chesapeake Energy Corporation and Subsidiaries have been prepared
in accordance with the instructions to Form 10-Q as prescribed by the Securities
and Exchange Commission. 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 months ended March 31, 2001 are not necessarily
indicative of the results to be expected for the full year. This Form 10-Q
relates to the three months ended March 31, 2000 and March 31, 2001.

Change in Accounting Method - Effective January 1, 2001, we adopted Statement of
Financial Accounting Standards No. 133, Accounting for Derivative Instruments
and Hedging Activities. This statement establishes accounting and reporting
standards requiring that derivative instruments (including certain derivative
instruments embedded in other contracts) be recorded at fair market value and
included in the balance sheet as assets or liabilities. The accounting for
changes in the fair value of a derivative instrument depends on the intended use
of the derivative and the resulting designation, which is established at the
inception of a derivative. Special accounting for qualifying hedges allows a
derivative's gains and losses to offset related results of the hedged item in
the statement of operations. For derivative instruments designated as cash flow
hedges, changes in fair value, to the extent the hedge is effective, are
recognized in other comprehensive income until the hedged item is recognized in
earnings. Hedge effectiveness is measured at least quarterly based on the
relative changes in fair value between the derivative contract and the hedged
item over time. Any change in fair value resulting from ineffectiveness, as
defined by SFAS 133, is recognized immediately in earnings. The net gain or loss
recognized in earnings during the Current Quarter representing the amount of the
hedges' ineffectiveness was insignificant.

Adoption of SFAS 133 at January 1, 2001 resulted in the recognition of $9.3
million of current derivative assets and $98.6 million in current derivative
liabilities. The cumulative effect of the accounting change decreased
accumulated other comprehensive income by $53.6 million, net of income taxes,
but did not have an effect on our net income or earnings per share amounts.

The estimates of fair values from fixed-price contracts are computed based on
the difference between the prices provided by the fixed-price contracts and
forward market prices as of the specified date. Forward market prices for
natural gas and crude oil are dependent upon supply and demand factors in the
forward market and are subject to significant volatility. The fair value
estimates are subject to change as forward market prices change.

The estimated fair values of our fixed-price contracts as of March 31, 2001 are
provided below. The associated carrying values of these contracts are equal to
the estimated fair values for each related period.

MARCH 31,
2001
----------------
($ in thousands)

Derivative assets:
Fixed-price natural gas cap swaps .... $ 18,808
Fixed-price crude oil swaps .......... 5,056
Derivative liabilities:
Fixed-price natural gas swaps ........ (12,390)
--------
Total ................................ $ 11,474
========

From time to time, we have utilized and expect to continue to utilize derivative
financial instruments with respect to a portion of our oil and gas production to
achieve a more predictable cash flow by reducing our exposure to price
fluctuations. These transactions generally are swaps and collars and are entered
into with major financial institutions

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2001
(UNAUDITED)

or commodities trading institutions. Derivative financial instruments are
intended to reduce our exposure to declines in the market price of natural
gas and crude oil.

We expect to transfer approximately $3.5 million (pre-tax) of the balance in
accumulated other comprehensive income, based upon the market prices at March
31, 2001, to earnings during the next 12 months when the forecasted transactions
actually occur. All forecasted transactions currently being hedged are expected
to occur by December 2002.

2. CONTINGENCIES

West Panhandle Field Cessation Cases. One of our subsidiaries, Chesapeake
Panhandle Limited Partnership ("CP") (f/k/a MC Panhandle, Inc.), and two
subsidiaries of Kinder Morgan, Inc. have been 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 have claimed the
leases terminated upon the cessation of production for various periods,
primarily during the 1960s. In addition, the plaintiffs have sought to recover
conversion damages, exemplary damages, attorneys' fees and interest. The
defendants have asserted 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 three of them. In January 2001, the principal
plaintiffs in eight of ten cases tried or pending in the District Court of Moore
County, Texas, 69th Judicial District agreed to settle their claims. We do not
consider our portion of the settlement material to our financial condition or
results of operations.

There are five related West Panhandle cessation cases which continue to be
pending, two in the District Court of Moore County, Texas, 69th Judicial
District, one in the District Court of Carson County, Texas, 100th Judicial
District, and two in the U.S. District Court, Northern District of Texas,
Amarillo Division. In one of the Moore County cases, CP and the other defendants
have appealed a January 2000 judgment notwithstanding verdict in favor of
plaintiffs. In addition to quieting title to the lease (including existing gas
wells and all attached equipment) in plaintiffs, the court awarded actual
damages against CP in the amount of $716,400 and exemplary damages in the amount
of $25,000. The court further awarded, jointly and severally from all
defendants, $160,000 in attorneys' fees and interest and court costs. On March
28, 2001, the Amarillo Court of Appeals reversed and rendered the judgment in
favor of CP and the other defendants, finding that the subject leases had been
revived as a matter of law, making all other issues moot. In the other Moore
County, Texas case, in June 1999, the court granted plaintiffs' motion for
summary judgment in part, finding that the lease had terminated due to the
cessation of production, subject to the defendants' affirmative defenses. In
February 2001, the court granted plaintiffs' motion for summary judgment on
defendants' affirmative defenses but reversed its ruling that the lease had
terminated as a matter of law. In one of the U.S. District Court cases, after a
trial in May 1999, the jury found plaintiffs' claims were barred by the payment
of shut-in royalties, laches and revivor. Plaintiffs have moved for a new trial.
There are motions pending in the remaining two cases, one of which is scheduled
for a jury trial in October 2001.

We have previously established an accrued liability we believe will be
sufficient to cover the estimated costs of litigation for each of the pending
cases and the settlement consideration under the terms of the settlement
agreement mentioned above. 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 pending cases, the outcome of any future trials
and the amount of damages that might ultimately be awarded could differ from
management's estimates. CP and the other defendants intend to vigorously defend
against the plaintiffs' claims.

Chesapeake 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

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2001
(UNAUDITED)

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 Chesapeake.

Due to the nature of the oil and gas business, Chesapeake and its subsidiaries
are exposed to possible environmental risks. Chesapeake has implemented various
policies and procedures to avoid environmental contamination and risks from
environmental contamination. Chesapeake is not aware of any potential material
environmental issues or claims.

3. NET INCOME (LOSS) PER SHARE

Statement of Financial Accounting Standards No. 128, Earnings Per Share,
requires presentation of "basic" and "diluted" earnings per share, as defined,
on the face of the statement of operations for all entities with complex capital
structures. SFAS 128 requires a reconciliation of the numerators and
denominators of the basic and diluted EPS computations.

A reconciliation for the quarters ended March 31, 2000 and 2001 is as follows
(in thousands, except per share data):

INCOME SHARES PER SHARE
(NUMERATOR) (DENOMINATOR) AMOUNT
----------- ------------- ---------

FOR THE QUARTER ENDED MARCH 31, 2000:
BASIC EPS
Income available to common stockholders ......... $ 27,574 101,681 $0.27
=====

EFFECT OF DILUTIVE SECURITIES
Assumed conversion at the beginning of
the period of preferred stock
exchanged during the period:
Common shares assumed issued .................. -- 32,951
Preferred stock dividends ..................... 4,042 --
Gain on repurchase of preferred stock ......... (10,414) --
Employee stock options .......................... -- 5,498
-------- --------

DILUTED EPS
Income available to common stockholders
and assumed conversions ...................... $ 21,202 140,130 $0.15
======== ======== =====

FOR THE QUARTER ENDED MARCH 31, 2001:
BASIC EPS
Income available to common stockholders ......... $ 69,742 157,707 $0.44
=====

EFFECT OF DILUTIVE SECURITIES
Preferred stock dividends ....................... 546 --
Assumed conversion of 624,037 shares of
preferred stock at the beginning of period .... -- 4,489
Employee stock options .......................... -- 8,130
-------- --------

DILUTED EPS
Income available to common stockholders
and assumed conversions ...................... $ 70,288 170,326 $0.41
======== ======== =====

For the three months ended March 31, 2000 and 2001, outstanding options to
purchase 1.1 million and 0.1 million shares of common stock at a weighted
average exercise price of $7.99 and $25.00, respectively, were antidilutive
because the exercise prices of the options were greater than the average market
price of the common stock.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2001
(UNAUDITED)

4. SENIOR NOTES

On January 16, 2001, we acquired the 11.125% senior secured notes in connection
with the Gothic acquisition. See note 5. At March 31, 2001, there was
outstanding $202.3 million principal amount of 11.125% senior secured notes due
2005 which had been issued by Gothic Production Corporation and guaranteed by
Gothic Energy Corporation. The 11.125% senior secured notes were collateralized
by a second priority lien on substantially all of the natural gas and oil
properties owned by Gothic Production Corporation. The notes were redeemable at
Gothic Production Corporation's option on or after May 1, 2002 at the redemption
prices set forth in the indenture or prior to May 1, 2002 at the make-whole
prices set forth in the indenture. In April 2001, we purchased $3.0 million of
these notes for total consideration of $3.5 million, including $0.1 million in
interest and $0.4 million in premium. On May 7, 2001, the remaining $199.3
million was redeemed for total consideration of $222.5 million, including $0.4
million in interest and $22.8 million in redemption premium.

On April 22, 1998, we issued $500 million principal amount of 9.625% senior
notes due 2005. The 9.625% senior notes were redeemable at our option at any
time on or after May 1, 2002 at the redemption prices set forth in the indenture
or at the make-whole prices, as set forth in the indenture, if redeemed prior to
May 1, 2002. In April 2001, we purchased $140.7 million of these notes for total
consideration of $160.2 million, including a $13.6 million premium and interest
of $5.9 million. On May 7, 2001, the remaining $359.3 million was redeemed for
total consideration of $393.3 million, including $0.6 million of interest and
$33.4 million of redemption premium.

On March 17, 1997, we issued $150 million principal amount of 7.875% senior
notes due 2004. The 7.875% senior notes are redeemable at our option at any time
prior to March 15, 2004 at the make-whole prices determined in accordance with
the indenture.

Also on March 17, 1997, we issued $150 million principal amount of 8.5% senior
notes due 2012. The 8.5% senior notes are redeemable at our option at any time
prior to March 15, 2004 at the make-whole prices determined in accordance with
the indenture and, on or after March 15, 2004, at the redemption prices set
forth in the indenture. During the quarter ended March 31, 2001, Chesapeake
purchased and subsequently retired $7.5 million of these notes for total
consideration of $7.4 million, including accrued interest of $7.5 million.

On April 9, 1996, we issued $120 million principal amount of 9.125% senior notes
due 2006. The 9.125% senior notes were redeemable at our option at any time
prior to April 15, 2001 at the make-whole prices determined in accordance with
the indenture and, on or after April 15, 2001, at the redemption prices set
forth in the indenture. On May 7, 2001, we redeemed these notes for total
consideration of $126.1 million, including $0.6 million in interest and $5.5
million of redemption premium.

Chesapeake is a holding company and owns no operating assets and has no
significant operations independent of its subsidiaries. Our obligations under
the 9.625% senior notes, the 7.875% senior notes, the 8.5% senior notes and the
9.125% senior notes have been fully and unconditionally guaranteed, on a joint
and several basis, by each of our "Restricted Subsidiaries" (as defined in the
respective indentures governing these notes) (collectively, the "guarantor
subsidiaries"). Each guarantor subsidiary is a direct or indirect wholly-owned
subsidiary.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2001
(UNAUDITED)

Set forth below are condensed consolidating financial statements of the
guarantor subsidiaries and our subsidiaries which are not guarantors of the
senior notes. Chesapeake Energy Marketing, Inc. was a non-guarantor subsidiary
for all periods presented. Carmen Acquisition Corp. was also a non-guarantor
subsidiary in the current period presented. Upon the acquisition of Gothic
Energy Corporation and Gothic Production Corporation on January 16, 2001, these
subsidiaries were non-guarantor subsidiaries. As of May 7, 2001, all of the
Gothic Production Corporation 11.125% senior secured notes were purchased or
redeemed and both subsidiaries became guarantor subsidiaries on May 14, 2001.
Based on these events, we have presented Gothic Energy Corporation and Gothic
Production Corporation as guarantor subsidiaries for the current period. All of
our other wholly-owned subsidiaries were guarantor subsidiaries during all
periods presented.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

CONDENSED CONSOLIDATING BALANCE SHEET
AS OF DECEMBER 31, 2000
($ IN THOUSANDS)

NON-
GUARANTOR GUARANTOR
SUBSIDIARIES SUBSIDIARY PARENT ELIMINATIONS CONSOLIDATED
------------ ---------- ----------- ------------ ------------

ASSETS
CURRENT ASSETS:
Cash and cash equivalents ........................ $ (19,868) $ 7,200 $ 12,668 $ -- $ --
Restricted cash .................................. 3,500 -- -- -- 3,500
Accounts receivable .............................. 91,903 46,903 -- (21,363) 117,443
Deferred income tax asset ........................ -- -- 40,819 -- 40,819
Inventory ........................................ 3,040 127 -- -- 3,167
Other ............................................ 1,997 -- -- -- 1,997
----------- ----------- ----------- ----------- -----------
Total Current Assets ....................... 80,572 54,230 53,487 (21,363) 166,926
----------- ----------- ----------- ----------- -----------
PROPERTY AND EQUIPMENT:
Oil and natural gas properties ................... 2,590,512 -- -- -- 2,590,512
Unevaluated leasehold ............................ 25,685 -- -- -- 25,685
Other property and equipment ..................... 30,670 23,246 25,982 -- 79,898
Less: accumulated depreciation, depletion and
amortization ................................... (1,787,314) (18,153) (2,394) -- (1,807,861)
----------- ----------- ----------- ----------- -----------
Net Property and Equipment ................. 859,553 5,093 23,588 -- 888,234
----------- ----------- ----------- ----------- -----------
OTHER ASSETS:
Investments in subsidiaries and
intercompany advances .......................... -- -- (612,832) 612,832 --
Investment in Gothic Energy Corporation .......... -- 9,732 116,702 -- 126,434
Deferred tax asset ............................... -- -- 229,823 -- 229,823
Other assets ..................................... 9,890 418 89,516 (70,815) 29,009
----------- ----------- ----------- ----------- -----------
Total Other Assets ......................... 9,890 10,150 (176,791) 542,017 385,266
----------- ----------- ----------- ----------- -----------
TOTAL ASSETS ....................................... $ 950,015 $ 69,473 $ (99,716) $ 520,654 $ 1,440,426
=========== =========== =========== =========== ===========

LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)

CURRENT LIABILITIES:
Notes payable and current maturities of
long-term debt ................................. $ 836 $ -- $ -- $ -- $ 836
Accounts payable and other ....................... 118,620 49,613 19,090 (25,458) 161,865
----------- ----------- ----------- ----------- -----------
Total Current Liabilities .................. 119,456 49,613 19,090 (25,458) 162,701
----------- ----------- ----------- ----------- -----------
LONG-TERM DEBT ..................................... 92,321 -- 919,244 (66,720) 944,845
----------- ----------- ----------- ----------- -----------
REVENUES AND ROYALTIES DUE OTHERS .................. 7,798 -- -- -- 7,798
----------- ----------- ----------- ----------- -----------
DEFERRED INCOME TAX LIABILITY ...................... 11,850 -- -- -- 11,850
----------- ----------- ----------- ----------- -----------
INTERCOMPANY PAYABLES .............................. 1,351,144 138 (1,351,282) -- --
----------- ----------- ----------- ----------- -----------
STOCKHOLDERS' EQUITY (DEFICIT):
Common Stock ..................................... 26 1 1,569 (18) 1,578
Other ............................................ (632,580) 19,721 311,663 612,850 311,654
----------- ----------- ----------- ----------- -----------
(632,554) 19,722 313,232 612,832 313,232
----------- ----------- ----------- ----------- -----------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
(DEFICIT) .......................................... $ 950,015 $ 69,473 $ (99,716) $ 520,654 $ 1,440,426
=========== =========== =========== =========== ===========

12
13

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

CONDENSED CONSOLIDATING BALANCE SHEET
AS OF MARCH 31, 2001
($ IN THOUSANDS)

NON-
GUARANTOR GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------ ----------- ------------ ------------

ASSETS
CURRENT ASSETS:
Cash and cash equivalents ....................... $ (30,140) $ 523 $ 50,820 $ -- $ 21,203
Accounts receivable ............................. 113,974 43,614 1,776 (24,470) 134,894
Deferred income tax asset ....................... -- -- 42,000 -- 42,000
Short-term derivative instruments ............... 3,452 -- -- -- 3,452
Inventory ....................................... 2,860 754 -- -- 3,614
Other ........................................... 1,846 11 -- -- 1,857
----------- ----------- ----------- ----------- -----------
Total Current Assets .................... 91,992 44,902 94,596 (24,470) 207,020
----------- ----------- ----------- ----------- -----------
PROPERTY AND EQUIPMENT:
Oil and natural gas properties .................. 3,088,525 -- -- -- 3,088,525
Unevaluated leasehold ........................... 44,752 -- -- -- 44,752
Other property and equipment .................... 48,203 23,153 29,407 -- 100,763
Less: accumulated depreciation,
depletion and amortization ................... (1,824,408) (18,282) (2,565) -- (1,845,255)
----------- ----------- ----------- ----------- -----------
Net Property and Equipment .............. 1,357,072 4,871 26,842 -- 1,388,785
----------- ----------- ----------- ----------- -----------
OTHER ASSETS:
Investments in subsidiaries and
intercompany advances ......................... -- -- (363,994) 363,994 --
Deferred income tax asset ....................... (2,444) -- 189,217 -- 186,773
Long-term derivative instruments ................ 8,022 -- -- -- 8,022
Long-term investments, other .................... -- 9,892 2,000 -- 11,892
Other assets .................................... 1,744 399 84,035 (70,816) 15,362
----------- ----------- ----------- ----------- -----------
Total Other Assets ........................ 7,322 10,291 (88,742) 293,178 222,049
----------- ----------- ----------- ----------- -----------
TOTAL ASSETS ...................................... $ 1,456,386 $ 60,064 $ 32,696 $ 268,708 $ 1,817,854
=========== =========== =========== =========== ===========

LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)

CURRENT LIABILITIES:
Notes payable and current
maturities of long-term debt ................. $ 855 $ -- $ -- $ -- $ 855
Accounts payable and other ...................... 180,436 40,031 27,703 (28,541) 219,629
----------- ----------- ----------- ----------- -----------
Total Current Liabilities ............... 181,291 40,031 27,703 (28,541) 220,484
----------- ----------- ----------- ----------- -----------
LONG-TERM DEBT .................................... 295,428 -- 912,030 (66,720) 1,140,738
----------- ----------- ----------- ----------- -----------
REVENUES AND ROYALTIES DUE
OTHERS .......................................... 13,227 -- -- -- 13,227
----------- ----------- ----------- ----------- -----------
DEFERRED INCOME TAXES ............................. 13,216 -- -- -- 13,216
----------- ----------- ----------- ----------- -----------
INTERCOMPANY PAYABLES ............................. 1,358,598 (1,902) (1,356,671) (25) --
----------- ----------- ----------- ----------- -----------
STOCKHOLDERS' EQUITY (DEFICIT):
Common Stock .................................... 67 1 1,629 (58) 1,639
Other ........................................... (405,441) 21,934 448,005 364,052 428,550
----------- ----------- ----------- ----------- -----------
(405,374) 21,935 449,634 363,994 430,189
----------- ----------- ----------- ----------- -----------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
(DEFICIT) ....................................... $ 1,456,386 $ 60,064 $ 32,696 $ 268,708 $ 1,817,854
=========== =========== =========== =========== ===========

13
14

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
($ IN THOUSANDS)

GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- --------- ------------ ------------

FOR THE THREE MONTHS ENDED MARCH 31, 2000:
REVENUES:
Oil and natural gas sales .................... $ 86,946 $ 347 $ -- $ -- $ 87,293
Oil and natural gas marketing sales .......... -- 69,125 -- (41,757) 27,368
--------- --------- --------- --------- ---------
Total Revenues ............................ 86,946 69,472 -- (41,757) 114,661
--------- --------- --------- --------- ---------
OPERATING COSTS:
Production expenses and taxes ................ 17,681 80 -- -- 17,761
General and administrative ................... 2,720 291 21 -- 3,032
Oil and natural gas marketing expenses ....... -- 68,301 -- (41,757) 26,544
Oil and natural gas depreciation,
depletion and amortization ................. 24,383 100 -- -- 24,483
Other depreciation and amortization .......... 1,026 20 820 -- 1,866
--------- --------- --------- --------- ---------
Total Operating Costs ..................... 45,810 68,792 841 (41,757) 73,686
--------- --------- --------- --------- ---------
INCOME (LOSS) FROM OPERATIONS .................. 41,136 680 (841) -- 40,975
--------- --------- --------- --------- ---------
OTHER INCOME (LOSS):
Interest and other income .................... 798 336 20,967 (20,909) 1,192
Interest expense ............................. (20,955) (34) (20,784) 20,909 (20,864)
Equity in net earnings of subsidiaries ....... -- -- 21,860 (21,860) --
--------- --------- --------- --------- ---------
Total Other Income (Expense) .............. (20,157) 302 22,043 (21,860) (19,672)
--------- --------- --------- --------- ---------
INCOME (LOSS) BEFORE INCOME TAXES .............. 20,979 982 21,202 (21,860) 21,303
INCOME TAX EXPENSE (BENEFIT) ................... 101 -- -- -- 101
--------- --------- --------- --------- ---------
NET INCOME (LOSS) .............................. $ 20,878 $ 982 $ 21,202 $ (21,860) $ 21,202
========= ========= ========= ========= =========

FOR THE THREE MONTHS ENDED MARCH 31, 2001:
REVENUES:
Oil and natural gas sales .................... $ 221,219 $ -- $ -- $ -- $ 221,219
Oil and natural gas marketing sales .......... -- 133,913 -- (77,748) 56,165
--------- --------- --------- --------- ---------
Total Revenues ............................ 221,219 133,913 -- (77,748) 277,384
--------- --------- --------- --------- ---------
OPERATING COSTS:
Production expenses and taxes ................ 32,083 -- -- -- 32,083
General and administrative ................... 3,543 350 108 -- 4,001
Oil and natural gas marketing expenses ....... -- 132,226 -- (77,748) 54,478
Oil and natural gas depreciation,
depletion and amortization ................. 38,173 -- -- -- 38,173
Other depreciation and amortization .......... 1,062 20 871 -- 1,953
--------- --------- --------- --------- ---------
Total Operating Costs ..................... 74,861 132,596 979 (77,748) 130,688
--------- --------- --------- --------- ---------
INCOME (LOSS) FROM OPERATIONS .................. 146,358 1,317 (979) -- 146,696
--------- --------- --------- --------- ---------
OTHER INCOME (LOSS):
Interest and other income .................... 442 75 22,734 (22,682) 569
Interest expense ............................. (27,814) (1) (20,756) 22,682 (25,889)
Gothic standby credit facility costs ......... -- -- (3,392) -- (3,392)
Equity in net earnings of subsidiaries ....... -- -- 71,724 (71,724) --
--------- --------- --------- --------- ---------
Total Other Income (Expense) .............. (27,372) 74 70,310 (71,724) (28,712)
--------- --------- --------- --------- ---------
INCOME (LOSS) BEFORE INCOME TAXES .............. 118,986 1,391 69,331 (71,724) 117,984
INCOME TAX EXPENSE (BENEFIT) ................... 48,097 556 (957) -- 47,696
--------- --------- --------- --------- ---------
NET INCOME (LOSS) .............................. $ 70,889 $ 835 $ 70,288 $ (71,724) $ 70,288
========= ========= ========= ========= =========

14
15

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
($ IN THOUSANDS)

GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- --------- ------------ ------------

FOR THE THREE MONTHS ENDED MARCH 31, 2000:
CASH FLOWS FROM OPERATING ACTIVITIES ........... $ 29,595 $ (289) $ 8,909 $ -- $ 38,215
--------- --------- --------- --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and natural gas properties, net .......... (47,546) 3,715 -- -- (43,831)
Proceeds from sale of assets ................. 177 -- -- -- 177
Additions to other property and equipment .... (753) (16) (422) -- (1,191)
Other additions .............................. (35) -- (2,010) -- (2,045)
--------- --------- --------- --------- ---------
(48,157) 3,699 (2,432) -- (46,890)
--------- --------- --------- --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES ........... 12,159 (788) (14,645) -- (3,274)
--------- --------- --------- --------- ---------
EFFECT OF CHANGES IN EXCHANGE RATE ON CASH ..... (478) -- -- -- (478)
--------- --------- --------- --------- ---------
NET INCREASE (DECREASE) IN CASH ................ (6,881) 2,622 (8,168) -- (12,427)
CASH, BEGINNING OF PERIOD ...................... (7,156) 20,409 25,405 -- 38,658
--------- --------- --------- --------- ---------
CASH, END OF PERIOD ............................ $ (14,037) $ 23,031 $ 17,237 $ -- $ 26,231
========= ========= ========= ========= =========

FOR THE THREE MONTHS ENDED MARCH 31, 2001:
CASH FLOWS FROM OPERATING ACTIVITIES ........... $ 200,370 $ (1,721) $ 7,700 $ -- $ 206,349
--------- --------- --------- --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and natural gas properties, net .......... (153,699) -- -- -- (153,699)
Proceeds from sale of assets ................. 35 -- -- -- 35
Additions to other property and equipment .... (8,745) (890) (3,425) -- (13,060)
Other additions .............................. 170 -- (613) -- (443)
--------- --------- --------- --------- ---------
(162,239) (890) (4,038) -- (167,167)
--------- --------- --------- --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES ........... (47,534) (4,066) 34,490 -- (17,110)
--------- --------- --------- --------- ---------
EFFECT OF CHANGES IN EXCHANGE RATE ON CASH ..... (869) -- -- -- (869)
--------- --------- --------- --------- ---------
NET INCREASE (DECREASE) IN CASH ................ (10,272) (6,677) 38,152 -- 21,203
CASH, BEGINNING OF PERIOD ...................... (19,868) 7,200 12,668 -- --
--------- --------- --------- --------- ---------
CASH, END OF PERIOD ............................ $ (30,140) $ 523 $ 50,820 $ -- $ 21,203
========= ========= ========= ========= =========

15
16

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
($ IN THOUSANDS)

GUARANTOR NON-GUARANTOR
SUBSIDIARIES SUBSIDIARIES PARENT ELIMINATIONS CONSOLIDATED
------------ ------------- -------- ------------ ------------

FOR THE THREE MONTHS ENDED MARCH 31, 2000:
Net income (loss) ..................................... $ 20,878 $ 982 $ 21,202 $(21,860) $ 21,202
Other Comprehensive Income, net of income tax:
Foreign currency translation ........................ (478) -- -- -- (478)
-------- -------- -------- -------- --------
Other comprehensive income (loss) ..................... $ 20,400 $ 982 $ 21,202 $(21,860) $ 20,724
-------- ======== ======== ======== ========

FOR THE THREE MONTHS ENDED MARCH 31, 2001:
Net income (loss) ..................................... $ 70,889 $ 835 $ 70,288 $(71,724) $ 70,288
Other Comprehensive Income, net of income tax:
Foreign currency translation ........................ (3,219) -- -- -- (3,219)
Cumulative effect of accounting change for
financial derivatives ............................. (53,580) -- -- -- (53,580)
Change in fair value of derivative instruments ...... 42,138 -- -- -- 42,138
Fair value of derivatives reclassified to earnings... 18,326 -- -- -- 18,326
-------- -------- -------- -------- --------
Other comprehensive income (loss) ..................... $ 74,554 $ 835 $ 70,288 $(71,724) $ 73,953
-------- ======== ======== ======== ========

16
17

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

5. ACQUISITION OF GOTHIC ENERGY CORPORATION

We completed the acquisition of Gothic Energy Corporation on January 16, 2001 by
merging a wholly-owned subsidiary into Gothic. We issued a total of 4.0 million
shares in the merger. Gothic shareholders (other than Chesapeake) received
0.1908 of a share of Chesapeake common stock (valued at $7.00 per share which
was based on the value of Chesapeake common stock on the day before the merger
was announced) for each share of Gothic common stock. In addition, outstanding
warrants and options to purchase Gothic common stock were converted to the right
to purchase Chesapeake common stock (1.1 million shares as of March 31, 2001 at
an average price of $12.28 per share) based on the merger exchange ratio. Prior
to the merger, Chesapeake purchased substantially all of Gothic's 14.125% senior
secured discount notes for total consideration valued at $80.8 million in cash
and Chesapeake common stock. Prior to the merger, we also purchased $31.6
million principal amount of 11.125% senior secured notes due 2005 issued by
Gothic's operating subsidiary and guaranteed by Gothic. The consideration for
this purchase consisted of cash and Chesapeake common stock valued at $34.8
million. Subsequent to the acquisition, we redeemed all remaining 14.125% senior
secured discount notes for total consideration of $243,000. In February 2001,
we purchased $1.0 million principal amount of Gothic senior secured notes
tendered pursuant to a change-of-control offer at a purchase price of 101%.
During April and May 2001, we purchased or redeemed the remaining $202.3 million
principal amount of the 11.125% senior secured notes for total consideration of
$225.9 million, including premium of $23.1 million and interest of $0.5 million.
Subsequently, Gothic Energy Corporation and Gothic Production Corporation became
guarantor subsidiaries of Chesapeake's senior notes.

The acquisition of Gothic was accounted for using the purchase method as of
January 1, 2001 because we had effective control as of that date, and the
results of operations of Gothic have been included since that date.

The following unaudited pro forma information has been prepared assuming Gothic
had been acquired as of the beginning of the period presented. The pro forma
information is presented for information purposes only and is not necessarily
indicative of what would have occurred if the acquisition had been made as of
that date. In addition, the pro forma information is not intended to be a
projection of future results and does not reflect any efficiencies that may
result from the integration of Gothic.

Pro Forma Information (Unaudited)
(In thousands, except per share data)

THREE MONTHS ENDED
MARCH 31, 2000
------------------

Revenues .......................................... $129,476
Income before income taxes ........................ $ 20,075
Net income ........................................ $ 19,312
Earnings per common share -- basic ................ $ 0.22
Earnings per common share -- assuming dilution .... $ 0.13

6. SUBSEQUENT EVENTS

$800 Million Senior Notes Issuance

On March 30, 2001, we entered into an agreement to issue $800 million of 8.125%
senior notes due 2011. The transaction closed and we issued the notes on April
6, 2001. During April 2001, we used a portion of the offering proceeds to
purchase $140.7 million of the 9.625% senior notes and $3.0 million of the
11.125% senior secured notes. On May 7, 2001, we redeemed $120 million of our
9.125% senior notes, $359.3 million of our 9.625% senior notes and $199.3
million principal amount of 11.125% senior secured notes of Gothic Production
Corporation, a Chesapeake subsidiary. The purchase and redemption of these notes
included payment of aggregate make-whole and redemption premiums of $75.6
million. An extraordinary loss of approximately $44.0 million, net of tax, will
be recognized in the second quarter of 2001 related to these purchases and
redemptions. The refinancing lowered the interest rate and extended the maturity
of approximately 74% of our senior notes. The 8.125% senior notes were not
initially registered under the Securities Act of 1933. Pursuant to a
registration rights agreement with the initial purchasers, we have agreed to
enable the holders of the notes to exchange the notes for publicly registered
notes with identical terms.

17
18

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

Preferred Stock Redemption

On May 1, 2001, we redeemed all of the outstanding shares of our 7% cumulative
convertible preferred stock at a redemption price of $52.45 per share, payable
in 5.7 shares of common stock and cash of $2.45. Prior to redemption, the
preferred stock was convertible into common stock at a conversion price of $6.95
per share. At March 31, 2001, there were 624,037 shares of preferred stock
outstanding. Thereafter and prior to redemption, 622,768 shares of preferred
stock were converted into 4,480,171 shares of common stock. On the redemption
date, the remaining 1,269 shares of preferred stock were redeemed for 7,239
shares of common stock and cash in the amount of $3,115, including cash in lieu
of fractional shares. Whether the shares had been converted or were redeemed,
holders of preferred stock on April 3, 2001, the record date for the last
regular quarterly dividend on the preferred stock, received the cash dividend
paid on May 1, 2001.

Commitment for Revolving Credit Facility

We have received a commitment from Bear, Stearns & Co. Inc. and Union Bank of
California, N.A. to establish a $225 million senior secured revolving credit
facility for the company. The maturity date for this facility may be extended to
the fourth anniversary from closing, which is expected to occur in June 2001.
Borrowings under the facility will be collateralized by certain producing oil
and gas properties and will bear interest at an initial rate of London Interbank
Offered Rate (LIBOR) plus 2.25%. Unused portions of the facility will accrue a
commitment fee of 0.50% . On May 2, 2001, we received a temporary increase in
our existing credit facility to $150 million, pending the closing of this $225
million committed facility, to fund the repurchase of a portion of our notes
redeemed on May 7, 2001.

7. SEGMENT INFORMATION

Chesapeake has two reportable segments under SFAS No. 131, Disclosures about
Segments of an Enterprise and Related Information, consisting of exploration and
production, and marketing. The reportable segment information can be derived
from note 4 as Chesapeake Energy Marketing, Inc., which is our marketing
segment, is the only material non-guarantor subsidiary for all income statement
periods presented.

18
19

PART I. FINANCIAL INFORMATION

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS

RESULTS OF OPERATIONS -- Three Months Ended March 31, 2001 ("Current Quarter")
vs. March 31, 2000 ("Prior Quarter")

General. For the three months ended March 31, 2001, we realized net income of
$70.3 million, or $0.41 per diluted common share. This compares to net income of
$21.2 million, or $0.15 per diluted common share, in the three months ended
March 31, 2000.

Acquisition of Gothic Energy Corporation. We completed the acquisition of Gothic
Energy Corporation on January 16, 2001 by a merging a wholly-owned subsidiary
into Gothic. We issued 4.0 million shares in the merger along with additional
warrants and options in exchange for the outstanding Gothic warrants and
options. Prior to the merger, Chesapeake purchased substantially all of Gothic's
14.125% senior secured discount notes for total consideration of $80.8 million
in cash and Chesapeake common stock. We also purchased $31.6 million principal
amount of 11.125% senior secured notes due 2005 issued by Gothic's operating
subsidiary for total consideration of $34.8 million in cash and Chesapeake
common stock. Subsequent to the acquisition, we redeemed all remaining 14.125%
senior secured discount notes for total consideration of $243,000 and purchased
or redeemed the remaining $202.3 million of 11.125% senior secured notes for
total consideration of $225.9 million. On May 14, 2001, Gothic Energy
Corporation and Gothic Production Corporation became guarantor subsidiaries of
Chesapeake's senior notes.

During 2000, we obtained a standby commitment for a $275 million credit
facility, consisting of a $175 million term loan and a $100 million revolving
credit facility which, if needed, would have replaced our existing revolving
credit facility. The term loan was available to provide funds to repurchase any
of Gothic Production Corporation's 11.125% senior secured notes tendered
following the closing of the Gothic acquisition pursuant to a change-of-control
offer to purchase. In February 2001, we purchased $1.0 million of notes tendered
for 101% of such amount. We did not use the standby credit facility and the
commitment terminated on February 23, 2001. Chesapeake incurred $3.4 million of
costs for the standby facility which were recognized in the Current Quarter.

Oil and Natural Gas Sales. During the Current Quarter, oil and natural gas sales
increased 153% to $221.2 million from $87.3 million in the Prior Quarter. For
the Current Quarter, we produced 40.2 billion cubic feet equivalent, consisting
of 0.7 million barrels of oil and 36.0 billion cubic feet of natural gas,
compared to 0.9 mmbo and 28.7 bcf, or 33.9 bcfe, in the Prior Quarter. The
production increase is primarily the result of the Gothic acquisition. Average
oil prices realized were $29.01 per barrel of oil in the Current Quarter
compared to $24.58 per bo in the Prior Quarter, an increase of 18%. Average
natural gas prices realized were $5.59 per thousand cubic feet in the Current
Quarter compared to $2.30 per mcf in the Prior Quarter, an increase of 143%.

For the Current Quarter, we realized an average price of $5.51 per thousand
cubic feet equivalent, compared to $2.57 per mcfe in the Prior Quarter. Our
hedging activities resulted in decreased oil and natural gas revenues of $30.5
million, or $0.76 per mcfe, in the Current Quarter, compared to decreases in oil
and natural gas revenues of $2.2 million, or $0.06 per mcfe, in the Prior
Quarter.

The following table shows our production by region for the Prior Quarter and the
Current Quarter:

FOR THE THREE MONTHS ENDED MARCH 31,
-----------------------------------------
2000 2001
----------------- ------------------
OPERATING AREAS (mmcfe) PERCENT (mmcfe) PERCENT
- ----------------- ------- ------- ------- -------

Mid-Continent .... 19,033 56% 26,721 66%
Gulf Coast ....... 10,182 30 8,298 21
Canada ........... 2,925 9 2,688 7
Permian Basin .... 1,605 5 1,539 4
Other areas ...... 186 -- 910 2
------ ------ ------ ------
Total ....... 33,931 100% 40,156 100%
====== ====== ====== ======

19
20

Natural gas production represented approximately 90% of our total production
volume on an equivalent basis in the Current Quarter, compared to 85% in the
Prior Quarter.

Oil and Natural Gas Marketing Sales. We realized $56.2 million in oil and
natural gas marketing sales for third parties in the Current Quarter, with
corresponding oil and natural gas marketing expenses of $54.5 million, for a
margin of $1.7 million. This compares to sales of $27.4 million, expenses of
$26.5 million, and a margin of $0.9 million in the Prior Quarter. The increase
in marketing sales and cost of sales was due primarily to higher oil and natural
gas prices in the Current Quarter as compared to the Prior Quarter.

Production Expenses. Production expenses increased to $17.8 million in the
Current Quarter, a $5.3 million increase from the $12.5 million of production
expenses incurred in the Prior Quarter. On a unit of production basis,
production expenses were $0.44 and $0.37 per mcfe in the Current and Prior
Quarters, respectively. The increase in production expenses between periods is
due primarily to the additional costs associated with properties acquired since
the Prior Quarter, the increase in ad valorem taxes due to higher commodity
prices, and the overall increase in costs for goods and services that all oil
and gas producers are experiencing.

Production Taxes. Production taxes, which consist primarily of wellhead
severance taxes, were $14.3 million and $5.2 million in the Current and Prior
Quarters, respectively. On a per unit basis, production taxes were $0.36 per
mcfe in the Current Quarter compared to $0.15 per mcfe in the Prior Quarter. The
increase in the Current Quarter is due to higher oil and natural gas prices. In
general, production taxes are calculated using value-based formulas that produce
higher per unit costs when oil and natural gas prices increase.

Oil and Gas Depreciation, Depletion and Amortization. Depreciation, depletion
and amortization of oil and natural gas properties for the Current Quarter was
$38.2 million, compared to $24.5 million in the Prior Quarter. The DD&A rate per
mcfe, which is a function of capitalized costs, future development costs and the
related underlying reserves in the periods presented, increased from $0.72 in
the Prior Quarter to $0.95 in the Current Quarter. This increase is a result of
the Gothic acquisition and escalating drilling and equipment costs in 2001.
Chesapeake's DD&A rate in the future will be a function of the results of future
acquisition, exploration, development and production results, however, our rate
is expected to trend upward in 2001 based on projected higher drilling,
completion and acquisition costs throughout the oil and gas industry.

Depreciation and Amortization of Other Assets. Depreciation and amortization of
other assets was $2.0 million in the Current Quarter compared to $1.9 million in
the Prior Quarter. We anticipate D&A will continue at current levels during the
remainder of 2001.

General and Administrative. General and administrative expenses, which are net
of capitalized internal costs, were $4.0 million in the Current Quarter compared
to $3.0 million in the Prior Quarter. The increase was due primarily to an
increase in the number of employees and the general increase in overhead
associated with the growth of Chesapeake. We capitalized $1.8 million of
internal costs in the Current Quarter directly related to our oil and natural
gas exploration and development efforts, compared to $1.9 million in the Prior
Quarter. We anticipate that G&A costs during the remainder of 2001 will remain
at approximately the same level as the Current Quarter.

Interest and Other Income. Interest and other income for the Current Quarter was
$0.6 million compared to $1.2 million in the Prior Quarter.

Interest Expense. Interest expense increased to $25.9 million in the Current
Quarter from $20.9 million in the Prior Quarter. The increase in the Current
Quarter was due to the interest on Gothic Production's senior secured notes. In
addition to the interest expense reported, we capitalized $0.9 million of
interest during the Current Quarter compared to $0.7 million capitalized in the
Prior Quarter.

Provision for Income Taxes. During the Current Quarter, we recorded income tax
expense of $47.7 million on pre-tax income of $118.0 million, compared to income
tax expense of $0.1 million on $21.3 million of pre-tax income in the Prior
Quarter. The Prior Quarter expense related to our Canadian operations only. The
Prior Quarter U.S. tax expense was offset by a valuation allowance which had
been established due to uncertainty surrounding our ability to utilize tax net
operating loss carryforwards prior to their expiration. Based upon various
factors, management

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determined that a valuation allowance was no longer required as of December 31,
2000 and as a result we recognized income tax expense in the Current Quarter.

RISK MANAGEMENT ACTIVITIES

See Item 3 -- "Quantitative and Qualitative Disclosures About Market Risks."

LIQUIDITY AND CAPITAL RESOURCES

Chesapeake had a working capital deficit of $13.5 million at March 31, 2001
including a cash balance of $21.2 million. We have a $100 million revolving bank
credit facility, which matures in July 2002, with a committed borrowing base of
$100 million. On May 2, 2001 we received a temporary increase to $150 million,
pending the closing of our $225 million committed facility, to fund the
repurchase of a portion of our senior notes redeemed on May 7, 2001. As of March
31, 2001, we had borrowed $14.5 million under this facility and had $15.4
million of the facility securing various letters of credit. Borrowings under the
facility are secured by certain producing oil and natural gas properties and
bear interest at variable rates, which averaged 8.8% per annum as of March 31,
2001. Interest is payable quarterly calculated at .50% to 1.25%, depending on
utilization, plus the higher of (a) the Union Bank of California reference rate
or (b) the federal funds rate plus .50% per year. We may elect to convert a
portion of our borrowings to interest calculated under a LIBOR plus 2.00% to
2.75%, depending on utilization. We are required to pay a commitment fee on the
unused portion of the borrowing base equal to 0.375% per annum due quarterly.

We have received a commitment from Bear, Stearns & Co. Inc. and Union Bank of
California, N.A. for a $225 million senior secured revolving credit facility.
The maturity date for the facility may be extended to the fourth anniversary
from closing, which is expected to occur in June 2001. Borrowings under the
facility will be collateralized by certain producing oil and gas properties and
will bear interest at an initial rate of LIBOR plus 2.25%. Unused portions of
the facility will accrue a commitment fee of 0.50%.

At March 31, 2001, our senior notes represented $1.1 billion of our long-term
debt. During the Current Quarter, we purchased and subsequently retired $7.3
million of our 8.5% senior notes due 2012 for total consideration of $7.4
million, including accrued interest of $0.2 million.

On March 30, 2001, we entered into an agreement to issue $800 million of 8.125%
senior notes due 2011. The transaction closed and we issued the notes on April
6, 2001. During April 2001, we used a portion of the offering proceeds to
purchase $140.7 million of our 9.625% senior notes and $3.0 million of the
11.125% senior secured notes of Gothic Production Corporation, a Chesapeake
subsidiary. On May 7, 2001, we redeemed $120 million of our 9.125% senior notes,
$359.3 million of our 9.625% senior notes and $199.3 million of Gothic
Production's 11.125% senior secured notes. The purchase and redemption of these
notes included payment of aggregate make-whole and redemption premiums of $75.6
million. An extraordinary loss of approximately $44.0 million, net of tax, will
be recognized in the second quarter of 2001 related to these purchases and
redemptions. The refinancing lowered the interest rate and extended the maturity
of approximately 74% of our senior notes. The 8.125% senior notes were not
initially registered under the Securities Act of 1933. Pursuant to a
registration rights agreement with the initial purchasers, we have agreed to
enable the holders of the notes to exchange the notes for publicly registered
notes with identical terms.

Following the note redemptions, our senior notes consist of the following: $800
million principal amount of 8.125% senior notes due 2011, $150 million principal
amount of 7.875% senior notes due 2004 and $142.7 million principal amount of
8.5% senior notes due 2012. Debt ratings for the senior notes are B2 by Moody's
Investor Service and B+ by Standard & Poor's Ratings Services as of May 1,
2001. Debt ratings for our existing secured bank credit facility is Ba3 by
Moody's Investor Service and BB by Standard & Poor's Ratings Services. The
pending credit facility has received a rating of BB by Standard & Poor's Ratings
Services. There are no scheduled principal payments required on any of the
senior notes until March 2004, when $150 million is due.

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The 8.125% senior notes are unsecured senior obligations of Chesapeake and rank
equally with all of our other unsecured indebtedness. All of our wholly owned
subsidiaries except Chesapeake Energy Marketing, Inc. and Carmen Acquisition
Corp. guarantee the notes, including Gothic Energy Corporation and Gothic
Production Corporation as of May 14, 2001. We may redeem all or some of the
notes at any time after April 1, 2006 and prior to such date pursuant to
make-whole provisions in the indenture.

The indenture for the 8.125% senior notes contains covenants limiting our
ability and our restricted subsidiaries' ability to incur additional
indebtedness; pay dividends on our capital stock or redeem, repurchase or retire
our capital stock or subordinated indebtedness; make investments and other
restricted payments; create restrictions on the payment of dividends or other
amounts to us from our restricted subsidiaries; incur liens; engage in
transactions with affiliates; sell assets; and consolidate, merge or transfer
assets. The debt incurrence covenant does not affect our ability to borrow under
or expand our secured commercial bank facility. As of March 31, 2001, we
estimate that secured commercial bank indebtedness of approximately $900 million
could have been incurred under the indenture. The indenture covenants do not
apply to CEMI, an unrestricted subsidiary.

We believe we have adequate resources, including cash on hand and budgeted cash
flow from operations to fund our capital expenditure budget for exploration and
development activities during 2001, which are currently estimated to be
approximately $325 million. However, lower oil and gas prices, unfavorable
drilling results or other factors could cause us to reduce our drilling program,
which is largely discretionary. Based on our current cash flow assumptions, we
expect to have an additional $250 to $300 million available for acquisitions,
debt repayment and general corporate purposes in 2001.

Our cash provided by operating activities increased 440% to $206.3 million
during the Current Quarter compared to $38.2 million during the Prior Quarter.
The increase was due primarily to higher oil and natural gas prices realized
during the Current Quarter and the acquisition of Gothic Energy Corporation on
January 16, 2001.

Cash used in investing activities increased to $167.2 million during the Current
Quarter from $46.9 million in the Prior Quarter. During the Current Quarter we
expended approximately $95.5 million to initiate drilling on 163 (80.8 net)
wells and invested approximately $14.4 million in leasehold acquisitions. This
compares to $34.8 million to initiate drilling on 51 (27.7 net) wells and $5.4
million to purchase leasehold in the Prior Quarter. During the Current Quarter,
we had acquisitions of oil and natural gas properties of $44.0 million and
divestitures of oil and natural gas properties of $0.1 million. This compares to
acquisitions of $4.6 million and divestitures of $1.0 million in the Prior
Quarter. During the Current Quarter, we had additional investments in drilling
equipment and office buildings.

There was $17.1 million of cash used in financing activities in the Current
Quarter, compared to $3.3 million in the Prior Quarter. The activity in the
Current Quarter reflects the net reduction in borrowings under our commercial
bank credit facility of $10.5 million, partially offset by cash received through
the exercise of stock options and $8.3 million in cash used to redeem a portion
of our senior notes.

FORWARD-LOOKING STATEMENTS

This report 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 give our current expectations or forecasts
of future events. They include statements regarding oil and gas reserve
estimates, planned capital expenditures, the drilling of oil and gas wells and
future acquisitions, expected oil and gas production, cash flow and

anticipated liquidity, business strategy and other plans and objectives for
future operations, expected future expenses and utilization of net operating
loss carryforwards.

Although we believe the expectations and forecasts reflected in these and other
forward-looking statements are reasonable, we can give no assurance they will
prove to have been correct. They can be affected by inaccurate assumptions or by
known or unknown risks and uncertainties. Factors that could cause actual
results to differ materially from expected results are described under "Risk
Factors" in our Form 10-K, as amended, for the year ended December 31, 2000 and
include:

o the volatility of oil and gas prices,

o our substantial indebtedness,

o our commodity price risk management activities,

o our ability to replace reserves,

o the availability of capital,

o uncertainties inherent in estimating quantities of oil and gas
reserves,

o projecting future rates of production and the timing of development
expenditures,

o uncertainties in evaluating oil and gas reserves of acquired
properties and associated potential liabilities,

o drilling and operating risks,

o our ability to generate future taxable income sufficient to utilize
our NOLs before expiration,

o future ownership changes which could result in additional limitations
to our NOLs,

o adverse effects of governmental and environmental regulation,

o losses possible from pending or future litigation,

o the strength and financial resources of our competitors, and

o the loss of officers or key employees

We caution you not to place undue reliance on these forward-looking statements,
which speak only as of the date of this report, and we undertake no obligation
to update this information. We urge you to carefully review and consider the
disclosures made in this and our other reports filed with the SEC that attempt
to advise interested parties of the risks and factors that may affect our
business.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKS

COMMODITY PRICE RISK

Chesapeake's results of operations are highly dependent upon the prices received
for oil and natural gas production.

HEDGING ACTIVITIES

Periodically Chesapeake utilizes hedging strategies to hedge the price of a
portion of its future oil and natural gas production. These strategies include:

o swap arrangements that establish an index-related price above which we
pay the counterparty and below which we are paid by the counterparty
(counterparty payments in some contracts are subject to a cap),

o the purchase of index-related puts that provide for a "floor" price
below which the counterparty pays us the amount by which the price of
the commodity is below the contracted floor,

o the sale of index-related calls that provide for a "ceiling" price
above which we pay the counterparty the amount by which the price of
the commodity is above the contracted ceiling,

o basis protection swaps, which are arrangements that guarantee the
price differential of oil or natural gas from a specified delivery
point or points, and

o collar arrangements that establish an index-related price below which
the counterparty pays us and a separate index-related price above
which we pay the counterparty.

Commodity markets are volatile, and as a result, our hedging activity is
dynamic. As market conditions warrant, we may elect to settle a hedging
transaction prior to its scheduled maturity date.

Results from commodity hedging transactions are reflected in oil and natural gas
sales to the extent related to our oil and natural gas production. We only enter
into commodity hedging transactions related to our oil and natural gas
production volumes or physical purchase or sale commitments of our marketing
subsidiary. Gains or losses on crude oil and natural gas hedging transactions
are recognized as price adjustments in the months of related production.

See Note 1 to our Consolidated Financial Statements for a discussion of
activities involving derivative financial instruments during the first quarter
2001.

As of March 31, 2001, we had the following open natural gas swap arrangements
designed to hedge a portion of our domestic gas production for periods after
March 2001:

NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (mmbtu) (per mmbtu)
- ------------------- --------- -----------

April 2001 ........ 5,400,000 $4.84
May 2001 .......... 6,200,000 4.73
June 2001 ......... 4,800,000 4.75
July 2001 ......... 4,960,000 4.75
August 2001 ....... 4,960,000 4.74
September 2001 .... 4,800,000 4.72
October 2001 ...... 1,860,000 5.20

Subsequent to March 31, 2001, we settled the natural gas swaps for April and May
2001. Losses of $3.3 million and $1.5 million will be recognized as price
adjustments in April and May 2001, respectively.

As of March 31, 2001, we had the following open natural gas collar transactions
designed to hedge a portion of our domestic gas production for periods after
March 2001:

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NYMEX NYMEX
DEFINED DEFINED
VOLUME LOW HIGH
MONTHS (mmbtu) STRIKE PRICE STRIKE PRICE
- ------------------- --------- ------------ ------------

April 2001 ........ 1,800,000 $ 4.00 $ 6.08
May 2001 .......... 1,860,000 4.00 6.08
June 2001 ......... 2,400,000 4.25 6.26
July 2001 ......... 2,480,000 4.25 6.26
August 2001 ....... 2,480,000 4.25 6.26
September 2001 .... 2,400,000 4.25 6.26
October 2001 ...... 1,860,000 4.00 6.08
November 2001 ..... 1,800,000 4.00 6.08
December 2001 ..... 1,860,000 4.00 6.08
January 2002 ...... 620,000 4.00 5.75
February 2002 ..... 560,000 4.00 5.75
March 2002 ........ 620,000 4.00 5.75
April 2002 ........ 1,200,000 4.00 5.38
May 2002 .......... 1,240,000 4.00 5.38
June 2002 ......... 1,200,000 4.00 5.38
July 2002 ......... 1,240,000 4.00 5.38
August 2002 ....... 1,240,000 4.00 5.38
September 2002 .... 1,200,000 4.00 5.38
October 2002 ...... 1,240,000 4.00 5.38
November 2002 ..... 600,000 4.00 5.75
December 2002 ..... 620,000 4.00 5.75

Subsequent to March 31, 2001, we settled the natural gas collars for April and
May 2001 for no gain or loss.

As of March 31, 2001, we had the following open natural gas cap-swap
arrangements designed to hedge a portion of our domestic natural gas production
for periods after March 2001. These transactions require that we pay the
counterparty if the NYMEX price exceeds an average NYMEX-defined strike price.
If the NYMEX price is less than the strike price, the counterparty pays us.
However, the counterparty's payment is capped.

NYMEX CAPPED
INDEX LOW
VOLUME STRIKE PRICE STRIKE PRICE
MONTHS (mmbtu) (per mmbtu) (per mmbtu)
- ------------------- --------- ----------- -----------

May 2001 .......... 1,860,000 $ 5.76 $ 4.59
June 2001 ......... 1,800,000 5.81 4.64
July 2001 ......... 1,860,000 5.85 4.68
August 2001 ....... 1,860,000 5.87 4.70
September 2001 .... 1,800,000 5.83 4.66
October 2001 ...... 1,860,000 5.83 4.66
November 2001 ..... 2,400,000 6.00 4.78
December 2001 ..... 2,480,000 6.10 4.88
January 2002 ...... 2,790,000 6.03 4.81
February 2002 ..... 2,520,000 5.82 4.60
March 2002 ........ 2,790,000 5.48 4.26
April 2002 ........ 5,700,000 4.85 3.85
May 2002 .......... 5,890,000 4.81 3.81
June 2002 ......... 5,700,000 4.80 3.80
July 2002 ......... 5,890,000 4.81 3.81
August 2002 ....... 5,890,000 4.81 3.81
September 2002 .... 5,700,000 4.81 3.81
October 2002 ...... 5,890,000 4.80 3.80
November 2002 ..... 2,100,000 4.97 3.97
December 2002 ..... 2,170,000 5.06 4.06

Subsequent to March 31, 2001, we settled the May 2001 natural gas cap-swaps for
a gain of $1.5 million.

During the quarter ended March 31, 2001, we settled the basis protection swaps
for the periods of January, February and March 2001 for a net loss of $0.2
million. As of March 31, 2001, we had no open basis protection swaps; however,
we may enter into basis protection swaps in the future.

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As of March 31, 2001, we had the following open crude oil swap arrangements
designed to hedge a portion of our domestic crude oil production for periods
after March 2001:

NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (bbls) (per bbl)
- ------------------- ------- ------------

April 2001 ........ 160,000 $ 29.80
May 2001 .......... 165,000 29.75
June 2001 ......... 160,000 29.71
July 2001 ......... 165,000 29.68
August 2001 ....... 165,000 29.65
September 2001 .... 160,000 29.62
October 2001 ...... 165,000 29.59
November 2001 ..... 160,000 29.56
December 2001 ..... 165,000 29.54

Subsequent to March 31, 2001, we settled the crude oil swap for April 2001 for a
gain of $0.3 million which will be recognized as a price adjustment in April
2001.

Subsequent to March 31, 2001, we entered into the following natural gas swap
arrangements designed to hedge a portion of our domestic gas production for
periods after March 2001:

NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (mmbtu) (per mmbtu)
- ------------------- --------- ------------

June 2001 ......... 2,400,000 $ 5.03
July 2001 ......... 2,480,000 5.08
August 2001 ....... 2,480,000 5.14
September 2001 .... 2,400,000 5.15
October 2001 ...... 2,480,000 5.17
November 2001 ..... 2,400,000 5.32

Subsequent to March 31, 2001, we entered into the following natural gas
cap-swaps designed to hedge a portion of our domestic natural gas production for
periods after March 2001. These transactions require that we pay the
counterparty if the NYMEX price exceeds an average NYMEX-defined strike price.
If the NYMEX price is less than the strike price, the counterparty pays us.
However, the counterparty's payment is capped.

NYMEX CAPPED
INDEX LOW
VOLUME STRIKE PRICE STRIKE PRICE
MONTHS (mmbtu) (per mmbtu) (per mmbtu)
- ------------------- --------- ----------- -----------

October 2001 ...... 620,000 $ 5.99 $ 4.49
November 2001 ..... 1,800,000 5.77 4.27
December 2001 ..... 1,860,000 5.88 4.38
January 2002 ...... 1,860,000 5.91 4.41
February 2002 ..... 1,680,000 5.72 4.22
March 2002 ........ 1,860,000 5.37 3.87

Subsequent to March 31, 2001, we entered into crude oil cap-swaps designed to
hedge 2,000 bbls per day for calendar year 2002. This transaction requires that
we pay the counterparty if the NYMEX price exceeds an average strike price of
$25.15 per bbl for each of the related months of production. If the NYMEX price
is less than the strike price, the counterparty pays us. However, the
counterparty's payment is capped at the strike price less $5.00 per bbl.

In addition to commodity hedging transactions related to our oil and gas
production, our marketing subsidiary, CEMI, periodically enters into various
hedging transactions designed to hedge against physical purchase and sale
commitments it makes. 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 material by management.

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INTEREST RATE RISK

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. See "Liquidity and Capital
Resources" in Item 2 above for a description of our debt refinancing subsequent
to March 31, 2001.

MARCH 31, 2001
-----------------------------------------------------------------------------------
YEARS OF MATURITY
-----------------------------------------------------------------------------------
2001 2002 2003 2004 2005 THEREAFTER TOTAL FAIR VALUE
------ ------ ------ ------ ------ ---------- -------- ----------
($ IN MILLIONS)

LIABILITIES:
Long-term debt, including current
portion -- fixed rate .............. $ 0.9 $ 0.4 $ -- $142.7 $702.3 $270.0 $1,116.3 $1,135.8
Average interest rate ................ 9.1% 9.1% -- 7.9% 10.1% 8.8% 9.5% --

Long-term debt -- variable rate ...... $ -- $ 14.5 $ -- $ -- $ -- $ -- $ 14.5 $ 14.5

Average interest rate ................ -- 9.3% -- -- -- -- 9.3% --

Changes in interest rates affect the amount of interest we earn on our cash,
cash equivalents and short-term investments and the interest rate we pay on
borrowings under our credit facility. We are not presently using any interest
rate derivative instruments to manage exposure to interest rate changes. All of
our other long-term indebtedness is fixed rate and therefore does not expose us
to the risk of earnings or cash flow loss due to changes in market interest
rates.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We are subject to ordinary routine litigation incidental to our business. In
addition, Chesapeake is a defendant in other pending actions which are described
in Item 3 of our Annual Report on Form 10-K for the year ended December 31,
2000.

ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS

In two purchase transactions which closed on March 30, 2001, we issued 1,117,216
shares of our common stock in exchange for 1,349,500 shares of common stock of
RAM Energy, Inc., representing 49.5% of its outstanding equity securities, held
by two of its shareholders. Our shares were valued at $8.854 per share, or $9.9
million in total. We also received an option granted by one of the shareholders
to purchase an additional 1.0% of RAM Energy's outstanding equity securities.
The option is exercisable for a year beginning in February 2002 for an aggregate
exercise price of $202,000 in cash. Both shareholders represented that they are
accredited investors as defined in Regulation D under the Securities Act of 1933
and are sophisticated investors. The shares we issued were not registered under
the Securities Act of 1933 in reliance on the exemption from registration
provided by Section 4(2) of the Act. We granted registration rights with respect
to the shares issued and have agreed to cover any shortfall if the holders sell
the shares at a price that is less than $8.854 per share during the 90-day
period following the effective date of the registration statement covering the
shares.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES OR DIVIDEND ARREARAGES

- -- Not applicable

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

- -- Not applicable

ITEM 5. OTHER INFORMATION

- -- Not applicable

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K [UPDATE]

(a) Exhibits

The following exhibits are filed as a part of this report:

Exhibit No.

4.1.1 Fifth Supplemental Indenture, dated November 19, 1999,
to Indenture dated as of March 15, 1997 among the Registrant, as issuer, its
subsidiaries signatory thereto, as Subsidiary Guarantors, and United States
Trust Company of New York, as Trustee, with respect to 7-7/8% Senior Notes due
2004.

4.2.1 Fifth Supplemental Indenture, dated November 19, 1999,
to Indenture dated as of March 15, 1997 among the Registrant, as issuer, its
subsidiaries signatory thereto, as Subsidiary Guarantors, and United States
Trust Company of New York, as Trustee, with respect to 8-1/2% Senior Notes due
2012.

4.6 Indenture dated as of April 6, 2001 among the
Registrant, as issuer, its subsidiaries signatory thereto, as Subsidiary
Guarantors, and United States Trust Company of New York, as Trustee, with
respect to 8.125% Senior Notes due 2011. First Supplemental Indenture dated May
14, 2001.

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(b) Reports on Form 8-K

During the quarter ended March 31, 2001, we filed the
following Current Reports on Form 8-K:

On January 17, 2001, we filed a current report on Form 8-K reporting under Item
5 that we had issued a press release announcing completion of the acquisition of
Gothic Energy Corporation on January 16, 2001.

On January 24, 2001, we filed a current report on Form 8-K under Item 9
reporting the posting on our web site of operating assumptions being used in our
projections for the first quarter and full year 2001.

On January 31, 2001, we filed an amended current report on Form 8-K reporting
under Item 2 the completion of the merger of our acquisition subsidiary into
Gothic Energy Corporation on January 16, 2001 and providing Gothic's financial
statements and pro forma financial information under Item 7.

On February 6, 2001, we filed a current report on Form 8-K reporting under Item
5 that we had issued a press release announcing our 2000 earnings.

On February 6, 2001, we filed a current report on Form 8-K under Item 9
reporting the posting on our web site of operating assumptions being used in our
projections for the first quarter and full year 2001.

On February 13, 2001, we filed a current report on Form 8-K reporting under Item
5 that we had issued a press release announcing proved reserves, finding costs
for 2000 and further exploratory success from the Georgetown formation.

On February 21, 2001, we filed a current report on Form 8-K reporting under Item
5 that we had issued a press release announcing record results for fourth
quarter and full year 2000.

On March 27, 2001, we filed a current report on Form 8-K reporting under Item 5
that we had issued a press release announcing a preferred stock cash dividend
and redemption of our preferred shares.

On March 29, 2001, we filed a current report on Form 8-K reporting under Item 5
that we had issued a press release announcing a proposed $800 million senior
notes offering to replace existing senior notes.

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)

By: /s/ Aubrey K. McClendon
------------------------------
Aubrey K. McClendon
Chairman and
Chief Executive Officer

May 15, 2001 By: /s/ Marcus C. Rowland
- --------------------------- -----------------------------
Date Marcus C. Rowland
Executive Vice President and
Chief Financial Officer

EXHIBIT INDEX

EXHIBIT
NUMBER DESCRIPTION
- ------ -----------

4.1.1 Fifth Supplemental Indenture, dated November 19, 1999, to Indenture
dated as of March 15, 1997 among the Registrant, as issuer, its
subsidiaries signatory thereto, as Subsidiary Guarantors, and United
States Trust Company of New York, as Trustee, with respect to 7-7/8%
Senior Notes due 2004.

4.2.1 Fifth Supplemental Indenture, dated November 19, 1999, to Indenture
dated as of March 15, 1997 among the Registrant, as issuer, its
subsidiaries signatory thereto, as Subsidiary Guarantors, and United
States Trust Company of New York, as Trustee, with respect to 8-1/2%
Senior Notes due 2012.

4.6 Indenture dated as of April 6, 2001 among the Registrant, as issuer,
its subsidiaries signatory thereto, as Subsidiary Guarantors, and
United States Trust Company of New York, as Trustee, with respect to
8.125% Senior Notes due 2011. First Supplemental Indenture dated May
14, 2001.