<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 MARCH 31, 1999
[ ] 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 April 30, 1999, there were 96,910,308 shares of the registrant's $.01 par
value Common Stock outstanding.
================================================================================
<PAGE> 2
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
INDEX TO FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 1999
PART I. FINANCIAL INFORMATION
<TABLE>
<CAPTION>
PAGE
----
<S> <C> <C> <C>
Item 1. Consolidated Financial Statements:
Consolidated Balance Sheets at March 31, 1999 (Unaudited) and
December 31, 1998 3
Consolidated Statements of Operations for the Three Months Ended
March 31, 1999 and 1998 (Unaudited) 4
Consolidated Statements of Cash Flows for the Three Months Ended
March 31, 1999 and 1998 (Unaudited) 5
Notes to Consolidated Financial Statements (Unaudited) 6
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations 14
Item 3. Quantitative and Qualitative Disclosures About Market Risks 20
PART II. OTHER INFORMATION
Item 1. Legal Proceedings 22
Item 2. Changes in Securities and Use of Proceeds 22
Item 3. Defaults Upon Senior Securities 22
Item 4. Submission of Matters to a Vote of Security Holders 22
Item 5. Other Information 22
Item 6. Exhibits and Reports on Form 8-K 22
</TABLE>
2
<PAGE> 3
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
<TABLE>
<CAPTION>
MARCH 31, DECEMBER 31,
1999 1998
----------- -----------
(UNAUDITED)
($ IN THOUSANDS)
<S> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents .............................................................. $ 10,803 $ 29,520
Restricted cash ........................................................................ 946 5,754
Accounts receivable:
Oil and gas sales ..................................................................... 9,131 13,835
Oil and gas marketing sales ........................................................... 15,224 19,636
Joint interest and other, net of allowance for doubtful
accounts of $3.2 million and $3.2 million............................................ 12,906 27,373
Related parties ....................................................................... 13,726 15,455
Inventory .............................................................................. 5,389 5,325
Other .................................................................................. 2,070 1,101
----------- -----------
Total Current Assets ................................................................ 70,195 117,999
----------- -----------
PROPERTY AND EQUIPMENT:
Oil and gas properties, at cost based on full-cost accounting:
Evaluated oil and gas properties ...................................................... 2,192,636 2,142,943
Unevaluated properties ................................................................ 49,502 52,687
Less: accumulated depreciation, depletion and amortization ............................ (1,597,697) (1,574,282)
----------- -----------
644,441 621,348
Other property and equipment ........................................................... 79,368 79,718
Less: accumulated depreciation and amortization ........................................ (38,287) (37,075)
----------- -----------
Total Property and Equipment ........................................................ 685,522 663,991
----------- -----------
OTHER ASSETS ............................................................................. 29,532 30,625
----------- -----------
TOTAL ASSETS ........................................................................ $ 785,249 $ 812,615
=========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES:
Notes payable .......................................................................... $ 25,000 $ 25,000
Accounts payable ....................................................................... 26,482 36,854
Accrued liabilities and other .......................................................... 46,376 46,572
Revenues and royalties due others ...................................................... 16,252 22,858
----------- -----------
Total Current Liabilities ........................................................... 114,110 131,284
----------- -----------
LONG-TERM DEBT, NET ...................................................................... 919,097 919,076
----------- -----------
REVENUES AND ROYALTIES DUE OTHERS ........................................................ 11,744 10,823
----------- -----------
STOCKHOLDERS' EQUITY (DEFICIT):
Preferred Stock, $.01 par value, 10,000,000 shares authorized;
4,600,000 shares of 7% cumulative convertible stock issued and
outstanding at March 31, 1999 and December 31, 1998,
liquidation preference of $230 million plus accrued but
unpaid dividends of $8.1 million and $4.0 million at .................................. 230,000 230,000
March 31, 1999 and December 31, 1998, respectively
Common Stock, $.01 par value, 250,000,000 shares authorized;
105,213,750 shares issued at March 31, 1999 and December 31, 1998, respectively........ 1,052 1,052
Paid-in capital ........................................................................ 682,263 682,263
Accumulated deficit .................................................................... (1,139,145) (1,127,195)
Accumulated other comprehensive income (loss) .......................................... (3,910) (4,726)
Less: treasury stock, at cost; 8,503,300 shares at March 31, 1999
and December 31, 1998 ................................................................. (29,962) (29,962)
----------- -----------
Total Stockholders' Equity (Deficit) ................................................ (259,702) (248,568)
----------- -----------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) ..................................... $ 785,249 $ 812,615
=========== ===========
</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
MARCH 31,
------------------------
1999 1998
--------- ---------
<S> <C> <C>
REVENUES:
Oil and gas sales ......................................... $ 51,806 $ 50,241
Oil and gas marketing sales ............................... 13,871 26,524
--------- ---------
Total revenues ........................................ 65,677 76,765
--------- ---------
OPERATING COSTS:
Production expenses ....................................... 13,992 7,894
Production taxes .......................................... 1,990 1,544
Oil and gas marketing expenses ............................ 13,285 26,261
Impairment of oil and gas properties ...................... -- 250,000
Oil and gas depreciation, depletion and amortization ...... 23,153 31,342
Depreciation and amortization of other assets ............. 2,166 1,380
General and administrative ................................ 4,024 4,380
--------- ---------
Total operating costs ................................. 58,610 322,801
--------- ---------
INCOME (LOSS) FROM OPERATIONS .............................. 7,067 (246,036)
--------- ---------
OTHER INCOME (EXPENSE):
Interest and other income ................................. 873 224
Interest expense .......................................... (19,890) (10,688)
--------- ---------
Total other income (expense) .......................... (19,017) (10,464)
--------- ---------
OPERATING LOSS BEFORE INCOME TAX ........................... (11,950) (256,500)
--------- ---------
INCOME TAX EXPENSE:
Current ................................................... -- --
Deferred .................................................. -- --
--------- ---------
Total income tax expense .............................. -- --
--------- ---------
NET LOSS ................................................... (11,950) (256,500)
PREFERRED STOCK DIVIDENDS .................................. (4,026) --
--------- ---------
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS .................. $ (15,976) $(256,500)
========= =========
LOSS PER COMMON SHARE (BASIC AND ASSUMING DILUTION) ........ $ (0.17) $ (3.19)
========= =========
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT
SHARES OUTSTANDING
Basic and Assuming Dilution ............................... 96,710 80,330
========= =========
</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>
THREE MONTHS ENDED
MARCH 31,
------------------------
1999 1998
--------- ---------
($ IN THOUSANDS)
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss ................................................................................... $ (11,950) $(256,500)
Adjustments to reconcile net loss to net cash provided by
operating activities:
Depreciation, depletion and amortization .................................................. 24,550 32,326
Impairment of oil and gas assets .......................................................... -- 250,000
Amortization of loan costs ................................................................ 769 396
Amortization of bond discount ............................................................. 21 21
Loss on sale of fixed assets and other .................................................... 78 368
Equity in losses of equity investees ...................................................... -- 22
Bad debt expense .......................................................................... -- 604
--------- ---------
Cash provided by operating activities before changes in
current assets and liabilities ....................................................... 13,468 27,237
Changes in current assets and liabilities ................................................. 12,830 21,948
--------- ---------
Cash provided by operating activities ................................................... 26,298 49,185
--------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Exploration, development and acquisition of oil and gas properties ......................... (49,030) (148,782)
Proceeds from sale of assets ............................................................... 3,584 --
Repayment of long-term loan ................................................................ -- 2,000
Additions to other property and equipment .................................................. (712) (19,684)
Other ...................................................................................... 327 --
--------- ---------
Cash used in investing activities ....................................................... (45,831) (166,466)
--------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term borrowings ......................................................... -- 145,000
Payments on long-term borrowings ........................................................... -- (120,000)
Cash received from exercise of stock options ............................................... -- 61
Other financing ............................................................................ -- 305
--------- ---------
Cash provided by financing activities ................................................... -- 25,366
--------- ---------
EFFECT OF CHANGES IN EXCHANGE RATE ON CASH ................................................... 816 --
--------- ---------
NET DECREASE IN CASH AND CASH EQUIVALENTS .................................................... (18,717) (91,915)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD ............................................... 29,520 123,860
--------- ---------
CASH AND CASH EQUIVALENTS, END OF PERIOD ..................................................... $ 10,803 $ 31,945
========= =========
</TABLE>
<TABLE>
<CAPTION>
THREE MONTHS ENDED
MARCH 31,
---------------------
1999 1998
------- ---------
($ IN THOUSANDS)
<S> <C> <C>
DETAILS OF ACQUISITION OF HUGOTON ENERGY CORPORATION:
Fair value of assets acquired .............................................................. $ -- $ 336,517
Liabilities acquired ....................................................................... $ -- $(128,146)
Stock issued ............................................................................... $ -- $(206,321)
Fair value of Hugoton stock options converted
into Chesapeake stock options ............................................................ $ -- $ (2,050)
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
5
<PAGE> 6
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 1999
(UNAUDITED)
1. ACCOUNTING PRINCIPLES
The accompanying unaudited consolidated financial statements of Chesapeake
Energy Corporation and Subsidiaries (the "Company") 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, 1999 are not necessarily
indicative of the results to be expected for the full fiscal year.
This Form 10-Q relates to the three months ended March 31, 1999 (the "Current
Quarter") and March 31, 1998 (the "Prior Quarter").
2. LEGAL PROCEEDINGS
The Company and certain of its officers and directors are defendants in a
consolidated class action suit alleging violations of the Securities Exchange
Act of 1934. The plaintiffs assert that the defendants made material
misrepresentations and failed to disclose material facts about the success of
the Company's exploration efforts in the Louisiana Trend. As a result, the
complaint alleges, the price of the Company's common stock was artificially
inflated from January 25, 1996 until June 27, 1997, when the Company issued a
press release announcing disappointing drilling results in the Louisiana Trend
and a full-cost ceiling writedown to be reflected in its June 30, 1997 financial
statements. The plaintiffs further allege that certain of the named individual
defendants sold common stock during the class period when they knew or should
have known adverse nonpublic information. The plaintiffs seek a determination
that the suit is a proper class action and damages in an unspecified amount,
together with interest and costs of litigation, including attorneys' fees. The
Company and the individual defendants believe that these claims are without
merit and have filed a motion to dismiss. No estimate of loss or range of
estimate of loss, if any, can be made at this time.
Another purported class action alleging violations of the Securities Act of 1933
and the Oklahoma Securities Act is pending against the Company and others on
behalf of investors who purchased common stock of Bayard Drilling Technologies,
Inc. ("Bayard") in its initial public offering in November 1997. Total proceeds
of the offering were $254 million, of which the Company received net proceeds of
$90.2 million as a selling shareholder. Plaintiffs allege that the Company,
which owned 30.1% of Bayard's common stock outstanding prior to the offering,
was a controlling person of Bayard. Plaintiffs also allege that the Company had
established an interlocking financial relationship with Bayard and was a
customer of Bayard's drilling services under allegedly below-market terms.
Plaintiffs also note the fact that three executive officers and directors of the
Company were formerly directors of Bayard. Plaintiffs assert that the Bayard
prospectus contained material omissions and misstatements relating to (i) the
Company's financial "problems" and their impact on Bayard's operating results,
(ii) increased costs associated with Bayard's growth strategy, (iii) undisclosed
pending related-party transactions between Bayard and third parties other than
the Company, (iv) Bayard's planned use of offering proceeds and (v) Bayard's
capital expenditures and liquidity. The alleged defective disclosures are
claimed to have resulted in a decline in Bayard's share price following the
public offering. The 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. The Company
believes that these actions are without merit and has filed a motion to dismiss.
No estimate of loss or range of estimate of loss, if any, can be made at this
time.
In October 1996, Union Pacific Resources Company ("UPRC") sued the Company
alleging infringement of a patent for a drilling method, tortious interference
with confidentiality contracts between UPRC and certain of its former employees
and misappropriation of proprietary information of UPRC. UPRC's claims against
the Company are based on services provided to the Company by a third party
vendor controlled by former UPRC employees. UPRC
6
<PAGE> 7
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 1999
(UNAUDITED)
is seeking injunctive relief, damages of an unspecified amount, including
actual, enhanced, consequential and punitive damages, interest, costs and
attorneys' fees. In May 1998, the court ruled as a matter of law that UPRC's
tort claims for misappropriation of trade secrets and tortious interference with
business relations are barred by the statute of limitations. Further, the court
found that UPRC's claim for inducement to infringe its patent for a drillbit
steering method is barred as to any wells drilled by the Company prior to August
14, 1995. The only issues remaining in the case involve the validity, potential
infringement and value, if any, of UPRC's patent. The Company believes that it
has meritorious defenses to UPRC's allegations and has petitioned the court to
declare the UPRC patent invalid. Various motions for summary judgment are
pending. The issues of validity and infringement are set for trial beginning
June 7, 1999. No estimate of a probable loss or range of estimate of a probable
loss, if any, can be made at this time; however, in reports filed in the
proceeding, experts for UPRC claim that damages could be as much as $18 million
while Company experts state that the amount should not exceed $25,000, in each
case based on a reasonable royalty.
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. IMPAIRMENT OF OIL AND GAS PROPERTIES
The Company incurred an impairment of oil and gas properties charge of $250
million in the Prior Quarter. This writedown was caused by several factors,
including the effects of accounting for the acquisition of Hugoton Energy
Corporation ("Hugoton") using the purchase accounting method, oil prices
declining from $17.62 at December 31, 1997 to $13.92 at March 31, 1998, gas
prices declining from $2.29 at December 31, 1997 to $2.01 at March 31, 1998 and
higher drilling and completion costs compared to previous estimates.
Additionally, lower oil and gas prices at March 31, 1998 and higher drilling
costs caused downward revisions in the Company's proved reserves as certain
proved undeveloped reserves previously estimated by the Company were rendered
uneconomic and therefore excluded by the Company from its proved reserves.
4. NET INCOME (LOSS) PER SHARE
In February 1997, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 128, Earnings Per Share ("SFAS 128"). SFAS
128 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. For the Current Quarter and Prior Quarter
there was no difference between actual weighted average shares outstanding,
which are used in computing basic EPS and diluted weighted average shares, which
are used in computing diluted EPS. Options to purchase 13.7 million shares and
10.2 million shares of common stock at a weighted average exercise price of
$1.71 and $5.69 were outstanding during the Current Quarter and Prior Quarter,
respectively, but were not included in the computation of diluted EPS because
the effect of these outstanding options would be antidilutive.
7
<PAGE> 8
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 1999
(UNAUDITED)
5. SENIOR NOTES
10.5% Notes
The Company had outstanding at March 31, 1998, $90 million in aggregate
principal amount of 10.5% Senior Notes due 2002. The 10.5% Notes were senior,
unsecured obligations of the Company and were fully and unconditionally
guaranteed, jointly and severally, by Guarantor Subsidiaries (as defined below).
All outstanding 10.5% Notes were acquired by the Company effective April 30,
1998.
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 Company 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 Company 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 Company 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 Company and are fully and
unconditionally guaranteed, jointly and severally, by the Guarantor
Subsidiaries.
The Company is a holding company and owns no operating assets and has no
significant operations independent of its subsidiaries. The Company's
obligations under its Senior Notes have been fully and unconditionally
guaranteed, on a joint and several basis, by each of the Company'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 Company.
The Senior Note Indentures contain certain covenants, including covenants
limiting the Company 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.
8
<PAGE> 9
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 1999
(UNAUDITED)
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. As of December 31, 1998 and March 31, 1999, the
Company was unable to meet the requirements to incur additional unsecured
indebtedness, and consequently was not able to pay the quarterly cash dividend
of $4.0 million on its 7% cumulative convertible preferred stock on February 1,
1999 or May 1, 1999. Subsequent payments will be subject to the same
restrictions and are dependent upon variables that are beyond the Company's
ability to predict. This restriction does not affect the Company's ability to
borrow under or expand its secured commercial bank facility. If the Company
fails to pay dividends for six quarterly periods, the holders of preferred stock
would be entitled to elect two additional members to the Board.
Set forth below are condensed consolidating financial statements of the
Guarantor Subsidiaries, the Company's subsidiaries which are not guarantors of
the Senior Notes (the "Non-Guarantor Subsidiaries") and the Company. Separate
financial statements of each Guarantor Subsidiary have not been provided because
management has determined that they are not material to investors.
As of and for the three months ended March 31, 1999, the Non-Guarantor
Subsidiary was Chesapeake Energy Marketing, Inc. ("CEMI"). As of and for the
three months ended March 31, 1998, the Non-Guarantor Subsidiaries were CEMI,
Chesapeake Acquisition Corporation and subsidiaries of those companies. For both
periods, the remaining subsidiaries of the Company were Guarantor Subsidiaries.
9
<PAGE> 10
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING BALANCE SHEET
AS OF MARCH 31, 1999
($ IN THOUSANDS)
ASSETS
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR COMPANY
SUBSIDIARIES SUBSIDIARIES (PARENT) ELIMINATIONS CONSOLIDATED
----------- ------------- ----------- ------------ ------------
<S> <C> <C> <C> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents .................. $ (14,000) $ 11,407 $ 14,342 $ -- $ 11,749
Accounts receivable, net ................... 33,347 24,124 325 (6,809) 50,987
Inventory .................................. 5,001 388 -- -- 5,389
Other ...................................... 1,707 2 361 -- 2,070
----------- ----------- ----------- ----------- -----------
Total Current Assets .................... 26,055 35,921 15,028 (6,809) 70,195
----------- ----------- ----------- ----------- -----------
PROPERTY AND EQUIPMENT:
Oil and gas properties ..................... 2,192,636 -- -- -- 2,192,636
Unevaluated leasehold ...................... 49,502 -- -- -- 49,502
Other property and equipment ............... 46,351 15,304 17,713 -- 79,368
Less: accumulated depreciation,
depletion and amortization ............... (1,626,372) (8,109) (1,503) -- (1,635,984)
----------- ----------- ----------- ----------- -----------
Total Property & Equipment .............. 662,117 7,195 16,210 -- 685,522
----------- ----------- ----------- ----------- -----------
INVESTMENTS IN SUBSIDIARIES AND
INTERCOMPANY ADVANCES ...................... 473,578 -- 493,738 (967,316) --
----------- ----------- ----------- ----------- -----------
OTHER ASSETS ................................. 10,258 540 18,734 -- 29,532
----------- ----------- ----------- ----------- -----------
TOTAL ASSETS ............................ $ 1,172,008 $ 43,656 $ 543,710 $ (974,125) $ 785,249
=========== =========== =========== =========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES:
Notes payable and current maturities
of long-term debt ........................ $ 25,000 $ -- $ -- $ -- $ 25,000
Accounts payable and other ................. 57,169 12,653 26,110 (6,822) 89,110
----------- ----------- ----------- ----------- -----------
Total Current Liabilities ............... 82,169 12,653 26,110 (6,822) 114,110
----------- ----------- ----------- ----------- -----------
LONG-TERM DEBT ............................... -- -- 919,097 -- 919,097
----------- ----------- ----------- ----------- -----------
REVENUES PAYABLE ............................. 11,744 -- -- -- 11,744
----------- ----------- ----------- ----------- -----------
INTERCOMPANY PAYABLES ........................ 1,379,792 (55) (1,379,750) 13 --
----------- ----------- ----------- ----------- -----------
STOCKHOLDERS' EQUITY (DEFICIT):
Common Stock ............................... 26 1 1,042 (17) 1,052
Other ...................................... (301,723) 31,057 977,211 (967,299) (260,754)
----------- ----------- ----------- ----------- -----------
Total Stockholders' Equity (Deficit) .... (301,697) 31,058 978,253 (967,316) (259,702)
----------- ----------- ----------- ----------- -----------
TOTAL LIABILITIES AND
STOCKHOLDERS' EQUITY (DEFICIT) ........ $ 1,172,008 $ 43,656 $ 543,710 $ (974,125) $ 785,249
=========== =========== =========== =========== ===========
</TABLE>
10
<PAGE> 11
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING BALANCE SHEET
AS OF DECEMBER 31, 1998
($ IN THOUSANDS)
ASSETS
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR COMPANY
SUBSIDIARIES SUBSIDIARIES (PARENT) ELIMINATIONS CONSOLIDATED
------------ ------------- ----------- ------------ ------------
<S> <C> <C> <C> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents ................. $ (11,565) $ 7,000 $ 39,839 $ -- $ 35,274
Accounts receivable ....................... 54,384 29,641 270 (7,996) 76,299
Inventory ................................. 4,919 406 -- -- 5,325
Other ..................................... 721 15 365 -- 1,101
----------- ----------- ----------- ----------- -----------
Total Current Assets ................... 48,459 37,062 40,474 (7,996) 117,999
----------- ----------- ----------- ----------- -----------
PROPERTY AND EQUIPMENT:
Oil and gas properties .................... 2,142,943 -- -- -- 2,142,943
Unevaluated leasehold ..................... 52,687 -- -- -- 52,687
Other property and equipment .............. 47,628 15,109 16,981 -- 79,718
Less: accumulated depreciation,
depletion and amortization .............. (1,601,931) (8,036) (1,390) -- (1,611,357)
----------- ----------- ----------- ----------- -----------
Total Property & Equipment ............. 641,327 7,073 15,591 -- 663,991
----------- ----------- ----------- ----------- -----------
INVESTMENTS IN SUBSIDIARIES AND
INTERCOMPANY ADVANCES ..................... 473,578 -- 481,150 (954,728) --
----------- ----------- ----------- ----------- -----------
OTHER ASSETS ................................ 10,610 560 19,455 -- 30,625
----------- ----------- ----------- ----------- -----------
TOTAL ASSETS ........................... $ 1,173,974 $ 44,695 $ 556,670 $ (962,724) $ 812,615
=========== =========== =========== =========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
CURRENT LIABILITIES:
Notes payable and current maturities
of long-term debt ....................... $ 25,000 $ -- $ -- $ -- $ 25,000
Accounts payable and other ................ 80,786 15,992 17,529 (8,023) 106,284
----------- ----------- ----------- ----------- -----------
Total Current Liabilities .............. 105,786 15,992 17,529 (8,023) 131,284
----------- ----------- ----------- ----------- -----------
LONG-TERM DEBT .............................. -- -- 919,076 -- 919,076
----------- ----------- ----------- ----------- -----------
REVENUES PAYABLE ............................ 10,823 -- -- -- 10,823
----------- ----------- ----------- ----------- -----------
INTERCOMPANY PAYABLES ....................... 1,338,948 11,376 (1,350,351) 27 --
----------- ----------- ----------- ----------- -----------
STOCKHOLDERS' EQUITY (DEFICIT):
Common Stock .............................. 26 1 1,042 (17) 1,052
Other ..................................... (281,609) 17,326 969,374 (954,711) (249,620)
----------- ----------- ----------- ----------- -----------
Total Stockholders' Equity (Deficit) ... (281,583) 17,327 970,416 (954,728) (248,568)
----------- ----------- ----------- ----------- -----------
TOTAL LIABILITIES AND
STOCKHOLDERS' EQUITY (DEFICIT) ....... $ 1,173,974 $ 44,695 $ 556,670 $ (962,724) $ 812,615
=========== =========== =========== =========== ===========
</TABLE>
11
<PAGE> 12
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR COMPANY
SUBSIDIARIES SUBSIDIARIES (PARENT) ELIMINATIONS CONSOLIDATED
------------ -------------- --------- ------------ ------------
<S> <C> <C> <C> <C> <C>
FOR THE THREE MONTHS ENDED MARCH 31, 1999
REVENUES:
Oil and gas sales ......................... $ 51,209 $ -- $ -- $ 597 $ 51,806
Oil and gas marketing sales ............... -- 35,435 -- (21,564) 13,871
--------- --------- --------- --------- ---------
Total Revenues ......................... 51,209 35,435 -- (20,967) 65,677
--------- --------- --------- --------- ---------
OPERATING COSTS:
Production expenses and taxes ............. 15,982 -- -- -- 15,982
Oil and gas marketing expenses ............ -- 34,252 -- (20,967) 13,285
Oil and gas depreciation, depletion
and amortization ........................ 23,153 -- -- -- 23,153
Other depreciation and amortization ....... 1,338 20 808 -- 2,166
General and administrative ................ 3,522 457 45 -- 4,024
--------- --------- --------- --------- ---------
Total Operating Costs .................. 43,995 34,729 853 (20,967) 58,610
--------- --------- --------- --------- ---------
INCOME (LOSS) FROM OPERATIONS ............... 7,214 706 (853) -- 7,067
--------- --------- --------- --------- ---------
OTHER INCOME (LOSS):
Interest and other income ................. 267 437 29,140 (28,971) 873
Interest expense .......................... (28,406) -- (20,455) 28,971 (19,890)
--------- --------- --------- --------- ---------
(28,139) 437 8,685 -- (19,017)
--------- --------- --------- --------- ---------
INCOME (LOSS) BEFORE INCOME TAXES ........... (20,925) 1,143 7,832 -- (11,950)
INCOME TAX EXPENSE (BENEFIT) ................ -- -- -- -- --
--------- --------- --------- --------- ---------
NET INCOME (LOSS) ........................... $ (20,925) $ 1,143 $ 7,832 $ -- $ (11,950)
========= ========= ========= ========= =========
FOR THE THREE MONTHS ENDED MARCH 31, 1998
REVENUES:
Oil and gas sales ......................... $ 41,803 $ 7,812 $ -- $ 626 $ 50,241
Oil and gas marketing sales ............... -- 47,725 -- (21,201) 26,524
--------- --------- --------- --------- ---------
Total Revenues ......................... 41,803 55,537 -- (20,575) 76,765
--------- --------- --------- --------- ---------
OPERATING COSTS:
Production expenses and taxes ............. 6,901 2,537 -- -- 9,438
Oil and gas marketing expenses ............ -- 46,836 -- (20,575) 26,261
Impairment of oil and gas properties ...... 83,500 166,500 -- -- 250,000
Oil and gas depreciation, depletion
and amortization ........................ 26,121 5,221 -- -- 31,342
Other depreciation and amortization ....... 806 77 497 -- 1,380
General and administrative ................ 3,755 593 32 -- 4,380
--------- --------- --------- --------- ---------
Total Operating Costs .................. 121,083 221,764 529 (20,575) 322,801
--------- --------- --------- --------- ---------
INCOME (LOSS) FROM OPERATIONS ............... (79,280) (166,227) (529) -- (246,036)
--------- --------- --------- --------- ---------
OTHER INCOME (LOSS):
Interest and other income ................. (28) 142 20,035 (19,925) 224
Interest .................................. (17,482) (1,741) (11,390) 19,925 (10,688)
--------- --------- --------- --------- ---------
(17,510) (1,599) 8,645 -- (10,464)
--------- --------- --------- --------- ---------
INCOME (LOSS) BEFORE INCOME TAXES ........... (96,790) (167,826) 8,116 -- (256,500)
INCOME TAX EXPENSE (BENEFIT) ................ -- -- -- -- --
--------- --------- --------- --------- ---------
NET INCOME (LOSS) ........................... $ (96,790) $(167,826) $ 8,116 $ -- $(256,500)
========= ========= ========= ========= =========
</TABLE>
12
<PAGE> 13
CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
($ IN THOUSANDS)
<TABLE>
<CAPTION>
GUARANTOR NON-GUARANTOR COMPANY
SUBSIDIARIES SUBSIDIARIES (PARENT) ELIMINATIONS CONSOLIDATED
------------ ------------- --------- ------------ ------------
<S> <C> <C> <C> <C> <C>
FOR THE THREE MONTHS ENDED MARCH 31, 1999
CASH FLOWS FROM OPERATING ACTIVITIES ............ $ 1,617 $ 7,490 $ 17,191 $ -- $ 26,298
--------- --------- --------- --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and gas properties ......................... (49,030) -- -- -- (49,030)
Proceeds from sale of assets ................... 3,584 -- -- -- 3,584
Additions to other property and equipment ...... 240 (195) (757) -- (712)
Other .......................................... 327 -- -- -- 327
--------- --------- --------- --------- ---------
(44,879) (195) (757) -- (45,831)
--------- --------- --------- --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES ............. -- -- -- -- --
--------- --------- --------- --------- ---------
EFFECT OF CHANGES IN EXCHANGE RATE ON CASH ....... 816 -- -- -- 816
--------- --------- --------- --------- ---------
NET INCREASE (DECREASE) IN CASH .................. (42,446) 7,295 16,434 -- (18,717)
CASH, BEGINNING OF PERIOD ........................ (17,319) 7,000 39,839 -- 29,520
--------- --------- --------- --------- ---------
CASH, END OF PERIOD .............................. $ (59,765) $ 14,295 $ 56,273 $ -- $ 10,803
========= ========= ========= ========= =========
FOR THE THREE MONTHS ENDED MARCH 31, 1998
CASH FLOWS FROM OPERATING ACTIVITIES ............. $(128,409) $ 161,162 $ 16,432 $ -- $ 49,185
--------- --------- --------- --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and gas properties ......................... (114,478) (34,304) -- -- (148,782)
Repayment of long-term loan .................... 2,000 -- -- -- 2,000
Other .......................................... (21,538) 2,313 (459) -- (19,684)
--------- --------- --------- --------- ---------
(134,016) (31,991) (459) -- (166,466)
--------- --------- --------- --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings ....................... -- -- 145,000 -- 145,000
Payments on borrowings ......................... -- -- (120,000) -- (120,000)
Cash received from exercise of stock options ... -- -- 61 -- 61
Other financing ................................ -- 305 -- -- 305
Intercompany advances, net ..................... 245,547 (134,327) (111,220) -- --
--------- --------- --------- --------- ---------
245,547 (134,022) (86,159) -- 25,366
--------- --------- --------- --------- ---------
NET INCREASE (DECREASE) IN CASH .................. (16,878) (4,851) (70,186) -- (91,915)
CASH, BEGINNING OF PERIOD ........................ (589) 13,999 110,450 -- 123,860
--------- --------- --------- --------- ---------
CASH, END OF PERIOD .............................. $ (17,467) $ 9,148 $ 40,264 $ -- $ 31,945
========= ========= ========= ========= =========
</TABLE>
13
<PAGE> 14
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, 1999 vs. March 31, 1998
General. For the three months ended March 31, 1999 (the "Current Quarter"), the
Company realized a net loss of $12.0 million, or a net loss of $0.17 per common
share after deducting preferred dividends of $4.0 million. This compares to a
net loss of $256.5 million, or $3.19 per common share, in the three months ended
March 31, 1998 (the "Prior Quarter"). The loss in the Current Quarter was
primarily caused by low oil and gas prices during the Current Quarter. The loss
in the Prior Quarter was primarily caused by a $250.0 million asset writedown
recorded under the full-cost method of accounting. The asset writedown was
primarily caused by the acquisition of Hugoton Energy Corporation ("Hugoton") in
March 1998 for consideration in excess of the present value (10% discount) of
the future net revenues of the proved reserves acquired as of March 31, 1998
(approximately $150 million of the writedown) and by decreases in oil and gas
prices from December 31, 1997 to March 31, 1998. See "Impairment of Oil and Gas
Properties".
Oil and Gas Sales. During the Current Quarter, oil and gas sales increased 3% to
$51.8 million from $50.2 million in the Prior Quarter. For the Current Quarter,
the Company produced 33.3 billion cubic feet equivalent ("bcfe"), consisting of
1.3 million barrels of oil ("mmbo") and 25.7 billion cubic feet of natural gas
("bcf"), compared to 1.2 mmbo and 15.9 bcf, or 23.0 bcfe, in the Prior Quarter.
Average oil prices realized were $10.92 per barrel of oil ("bo") in the Current
Quarter compared to $14.84 in the Prior Quarter, a decrease of 26%. Average gas
prices realized were $1.48 per thousand cubic feet ("mcf") in the Current
Quarter compared to $2.06 per mcf in the Prior Quarter, a decrease of 28%.
For the Current Quarter, the Company realized an average price of $1.56 per
thousand cubic feet equivalent ("mcfe"), compared to $2.19 per mcfe in the Prior
Quarter. The Company's hedging activities resulted in increased oil and gas
revenues of $0.4 million, or $0.01 per mcfe, in the Current Quarter, compared to
increases in oil and gas revenues of $1.8 million, or $0.08 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 MARCH 31,
--------------------------------------------------------
1999 1998
----------------------- ----------------------
OPERATING AREAS (mmcfe) PERCENT (mmcfe) PERCENT
- ---------------------------------------- ------ ------- ------ -------
<S> <C> <C> <C> <C>
Mid-Continent .......................... 16,974 51% 7,646 33%
Gulf Coast ............................. 10,694 32 12,054 53
Canada ................................. 2,431 7 730 3
Other Areas ............................ 3,213 10 2,533 11
------ ------ ------ ------
Total ............................. 33,312 100% 22,963 100%
====== ====== ====== ======
</TABLE>
Natural gas production represented approximately 77% of the Company's total
production volume on an equivalent basis in the Current Quarter, compared to 69%
in the Prior Quarter. This increase in natural gas production as a percentage of
total production was primarily the result of new gas production acquired by the
Company on or after March 1, 1998 primarily in the Mid-Continent and Canada.
Oil and Gas Marketing Sales. The Company realized $13.9 million in oil and gas
marketing sales for third parties in the Current Quarter, with corresponding oil
and gas marketing expenses of $13.3 million, for a margin of $0.6 million. This
compares to sales of $26.5 million, expenses of $26.3 million, and a margin of
$0.2 million in the Prior Quarter. The decrease in marketing sales and cost of
sales was due primarily to lower oil and gas prices and lower third party sales
in the Current Quarter as compared to the Prior Quarter. The increase in gross
margin between periods was due primarily to the operating results of certain gas
gathering, transportation and marketing assets which were acquired subsequent to
March 31, 1998.
14
<PAGE> 15
Production Expenses and Taxes. Production expenses increased to $14.0 million in
the Current Quarter, a $6.1 million increase from the $7.9 million incurred in
the Prior Quarter. On a unit of production basis, production expenses were $0.42
and $0.34 per mcfe in the Current and Prior Quarters, respectively. The primary
reason for the increase in production expenses was the increased lifting costs
associated with oil and gas reserves acquired on or after March 1, 1998. The
majority of reserves acquired during 1998 were located in the Mid-Continent and
are more expensive to operate as compared to the Company's historical production
base. The Company anticipates production expenses will not vary significantly
from current levels during the remainder of 1999.
Production taxes, which consist primarily of well-head severance taxes, were
$2.0 million and $1.5 million in the Current and Prior Quarters, respectively.
On a per unit basis, production taxes were $0.06 per mcfe in the Current Quarter
compared to $0.07 per mcfe in the Prior Quarter.
Impairment of Oil and Gas Properties. The Company utilizes the full-cost method
to account for its investments in oil and gas properties. Under this method, all
costs of acquisition, exploration and development of oil and gas reserves
(including such costs as leasehold acquisition costs, geological and geophysical
expenditures, certain capitalized internal costs, dry hole costs and tangible
and intangible development costs) are capitalized as incurred. These oil and gas
property costs, including the estimated future capital expenditures to develop
the proved undeveloped reserves are depleted and charged to operations using the
unit-of-production method based on the ratio of current production to proved oil
and gas reserves as estimated by the Company's independent engineering
consultants and Company engineers. Costs directly associated with the
acquisition and evaluation of unproved properties are excluded from the
amortization computation until it is determined whether or not proved reserves
can be assigned to the property or whether impairment has occurred. To the
extent that capitalized costs of oil and gas properties, net of accumulated
depreciation, depletion and amortization and related deferred income taxes,
exceed the discounted future net revenues of proved oil and gas properties, such
excess costs are charged to operations.
The Company incurred an impairment of oil and gas properties charge of $250
million in the Prior Quarter, compared to no impairment in the Current Quarter.
The Prior Quarter writedown was caused by several factors, including the Hugoton
acquisition, oil prices declining from $17.62 at December 31, 1997 to $13.92 at
March 31, 1998, gas prices declining from $2.29 at December 31, 1997 to $2.01 at
March 31, 1998 and higher drilling and completion costs compared to previous
estimates. Additionally, lower oil and gas prices at March 31, 1998 and higher
drilling costs caused downward revisions in the Company's proved reserves as
certain proved undeveloped reserves previously estimated by the Company were
rendered uneconomic and therefore not included in the Company's evaluation of
its proved reserves.
The primary reason for the impairment charge was the completion of the
acquisition in March 1998 of Hugoton, which was accounted for using the purchase
method. The purchase price, which was established in November 1997 when the
acquisition was announced (based on a Chesapeake common stock price of $8.00 per
share), was allocated almost entirely to Hugoton's evaluated oil and gas
properties. Based upon reserve estimates as of March 31, 1998, the portion of
the purchase price which was allocated to evaluated oil and gas properties
exceeded the associated discounted future net revenues from Hugoton's estimated
proved reserves by approximately $150 million.
Oil and Gas Depreciation, Depletion and Amortization. Depreciation, depletion
and amortization of oil and gas properties ("DD&A") for the Current Quarter was
$23.2 million, compared to $31.3 million in the Prior Quarter. This decrease was
caused by a decrease in the DD&A rate per mcfe from $1.36 to $0.70 in the Prior
and Current Quarters, respectively, offset by increased production between
periods. The decrease in the DD&A rate per mcfe is due primarily to the
impairment of oil and gas properties recorded during 1998. The Company expects
DD&A will increase slightly from current levels during the remainder of 1999.
Depreciation and Amortization of Other Assets. Depreciation and amortization of
other assets ("D&A") increased to $2.2 million in the Current Quarter compared
to $1.4 million in the Prior Quarter. This increase in D&A was caused by
increased investments in depreciable buildings and equipment acquired during
1998 and increased amortization of debt issuance costs as a result of the
issuance of Senior Notes in April 1998. The Company anticipates D&A to continue
at current levels during the remainder of 1999.
15
<PAGE> 16
General and Administrative. General and administrative expenses ("G&A"), which
are net of capitalized internal payroll and non-payroll expenses, were $4.0
million in the Current Quarter compared to $4.4 million in the Prior Quarter.
The decrease was due primarily to overhead charges incurred during the Prior
Quarter associated with Hugoton which were subsequently eliminated as Hugoton's
operations were integrated into the Company's operations. The Company
capitalized $1.2 million of internal costs in the Current Quarter directly
related to the Company's oil and gas exploration and development efforts,
compared to $2.1 million in the Prior Quarter. The Company anticipates that G&A
costs will decrease slightly during the remainder of 1999.
Interest and Other Income. Interest and other income for the Current Quarter was
$0.9 million compared to $0.2 million in the Prior Quarter. The increase was due
primarily to losses of $0.4 million incurred in the Prior Quarter related to the
sale of assets as well as other individually insignificant items.
Interest Expense. Interest expense increased to $19.9 million in the Current
Quarter from $10.7 million in the Prior Quarter. This increase was a result of
interest expense in the Current Quarter on the $500 million principal amount of
9.625% Senior Notes issued in April 1998, offset by lower interest expense
resulting from the early retirement of the Company's $90 million principal
amount of 10.5% Senior Notes in April 1998. In addition to the interest expense
reported, the Company capitalized $1.1 million of interest during the Current
Quarter compared to $2.3 million capitalized in the Prior Quarter.
Provision for Income Taxes. The Company recorded no income tax expense for the
Current Quarter or Prior Quarter. At March 31, 1999, the Company had a net
operating loss carryforward of approximately $600 million for regular federal
income taxes which will expire in future years beginning in 2007. Management
believes that it cannot be demonstrated at this time that it is more likely than
not that the deferred income tax assets generated for U.S. income tax purposes,
comprised primarily of the net operating loss carryforward, will be realizable
in future years, and therefore a valuation allowance of $458 million has been
recorded.
RISK MANAGEMENT ACTIVITIES
See Item 3 - "Quantitative and Qualitative Disclosures About Market Risks".
LIQUIDITY AND CAPITAL RESOURCES
The Company had a working capital deficit of $43.9 million at March 31, 1999 and
a cash balance of $10.8 million. The Company has a $50 million revolving bank
credit facility, which matures in August 1999, with an initial committed
borrowing base of $50 million. As of March 31, 1999, the Company had borrowed
$25 million under this facility, which was included in the working capital
deficit as a short-term obligation. Borrowings under the facility are secured by
certain producing oil and gas properties and bear interest at a rate of 7.75%
per annum as of March 31, 1999. The Company is currently negotiating with the
lender to renew the revolving bank credit facility under similar terms and
conditions. However, no assurance can be given that the facility will be renewed
or, if it is renewed, that the terms and conditions will be similar to the
existing facility.
Two of the Company's senior note indentures contain financial covenants which
restrict the ability of the Company and its restricted subsidiaries to incur
additional indebtedness and to make restricted payments, such as paying cash
dividends and repurchasing Company stock. These restrictions do not affect the
Company's ability to borrow under or expand its secured commercial bank
facility. The Company estimates that it could have incurred up to $112 million
of secured commercial bank indebtedness as of March 31, 1999 under the most
restrictive of its indenture debt incurrence tests.
As of December 31, 1998 and March 31, 1999, the Company was unable to meet the
restricted payment test under these indentures, including the requirement that
the Company be able to incur additional unsecured indebtedness. As a result, the
Company was not able to pay cash dividends on its 7% cumulative convertible
preferred stock on February 1, 1999 or May 1, 1999. Subsequent dividend payments
will be subject to the same restrictions and are dependent upon variables that
are beyond the Company's ability to predict. If the Company fails to pay
dividends
16
<PAGE> 17
for six quarterly periods, the holders of preferred stock would be entitled to
nominate two additional members to the board.
None of the senior note indenture covenants apply to CEMI, an unrestricted
subsidiary of the Company. The Company's Board of Directors has authorized CEMI
to purchase up to $10 million of the Company's senior notes and preferred stock.
In April 1999, CEMI purchased 3,600 shares of preferred stock for an aggregate
purchase price of $53,000, or $14.63 per share, in an open market transaction.
On April 22, 1999, CEMI commenced an offer to purchase up to 666,667 shares of
preferred stock at $15.00 per share ($10 million in the aggregate, plus fees and
expenses). The offer expires May 20, 1999, unless extended. It is not known how
many shares of preferred stock CEMI will acquire, if any, pursuant to the offer
to purchase.
Debt ratings for the senior notes are B3 by Moody's Investors Service and B by
Standard & Poor's Corporation as of May 14, 1999, and both have the Company on
review with negative implications. There are no scheduled principal payments
required on any of the Company's senior notes until March 2004.
The Company believes it has adequate resources, including cash on hand, budgeted
cash flow from operations and proceeds from miscellaneous asset sales, to fund
its capital expenditure budget for 1999, which is currently estimated to be
approximately $90-$95 million for exploration and development activities and $25
million for property acquisitions. The Company anticipates proceeds from
miscellaneous asset sales will be approximately $50 million during 1999.
However, lower oil and gas prices or unfavorable drilling results could cause
the Company to further reduce its drilling program.
The Company's cash provided by operating activities decreased 47% to $26.3
million during the Current Quarter compared to $49.2 million during the Prior
Quarter. The decrease was due primarily to lower oil and gas prices realized
during the Current Quarter.
Cash used in investing activities decreased to $45.8 million during the Current
Quarter from $166.5 million in the Prior Quarter. The Company completed several
acquisitions requiring cash in the Prior Quarter which totaled $82 million,
compared to $4.4 million in the Current Quarter, and significantly reduced its
drilling activity and leasehold acquisitions in the Current Quarter compared to
the Prior Quarter. During the Current Quarter the Company expended approximately
$40.2 million to initiate drilling on 41 gross (25.6 net) wells and invested
approximately $4.4 million in leasehold acquisitions. This compares to $62
million to initiate drilling on 52 gross (32.9 net) wells and $5 million to
purchase leasehold in the Prior Quarter. Also during the Current Quarter, the
Company sold $2.5 million of oil and gas properties, and had other fixed asset
sales of $1.1 million.
There was no cash provided by financing activities in the Current Quarter,
compared to $25.4 million in the Prior Quarter. During the Prior Quarter, the
Company retired $120 million in bank debt which it assumed at the completion of
the Hugoton acquisition. The Company refinanced the Hugoton debt and obtained
additional working capital of $25 million with proceeds from the Company's
commercial bank credit facility.
YEAR 2000
Project. The Company has placed a high priority on proactively resolving
computer or embedded chip problems related to the "Year 2000" which may have
adverse material effects on its continuing operations or cash flow. This problem
would be caused by the inability of a component (software, hardware or equipment
with embedded microprocessors) to correctly process date data in and between the
20th and 21st centuries, and therefore fail to properly perform its intended
functions and/or to exchange correct date data with other components. This
problem would most typically be caused by erroneous date calculations, which
result from using two digits to signify a year (century implied), handling leap
years incorrectly or the use of "special" values that can be confused with
legitimate calendar dates. The scope of the Year 2000 project includes
conducting an inventory of the Company's software, hardware and "embedded
systems" equipment, assessing potential for failure and the associated risk,
prioritizing the need for remedial actions, identifying an appropriate action,
then implementing and testing. In addition, the Company is taking a similar
approach to mitigating risks associated with the Year 2000 readiness of material
17
<PAGE> 18
business partners (vendors, suppliers, customers, etc.). The project will also
identify contingency plans to cope with unexpected events resulting from Year
2000 issues.
Beginning in mid-1997, the Company began an assessment of its core financial and
operational software systems. Three critical systems were identified with date
sensitivities: oil and gas financial accounting, production accounting and
land/lease administration. A Year 2000 compliant release of the oil and gas
financial accounting package in use at the Company is available and has been
scheduled for implementation during the third quarter of 1999. The production
accounting system in use at the Company is also scheduled for upgrade to a Year
2000 compliant version during the first half of 1999. The timing of these
upgrades has been scheduled to be concurrent with the respective vendors'
support requirements and to take advantage of additional feature or performance
enhancements. A project has been underway since early 1997 to implement a
completely revamped version of the land/lease administration package in use at
the Company to provide significantly increased functionality and reliability.
The terms of this development arrangement stipulated Year 2000 compliance.
Preliminary versions of the system have been installed and are being tested. As
part of the testing, Year 2000 compliance will be assured. Assessment continues
for lower priority software systems.
In addition, the Year 2000 compliant AS/400, on which the accounting package
resides, was upgraded to provide additional capacity in late 1997. Operating
system upgrades will be implemented in the near future for the Windows NT based
servers to complete their remediation.
Other activities either already underway or scheduled include testing of desktop
PCs, assessment of material business partners and inventory of embedded systems
in field locations. The following table summarizes the current overall status of
the project with anticipated completion dates:
<TABLE>
<CAPTION>
PHASE
---------------------------------------------
ASSESSMENT/ REMEDIATION/
COMPONENT INVENTORY PRIORITIZATION CONTINGENCY
------------------------------------- ---------- -------------- --------------
<S> <C> <C> <C>
Software March 1999 May 1999 September 1999
Hardware March 1999 May 1999 June 1999
Business partners March 1999 May 1999 June 1999
Embedded systems (non-IT systems) June 1999 July 1999 September 1999
</TABLE>
In addition to the above, during the third quarter of 1999 the Company will
develop an overall contingency plan to assure continued operations which will
include precautionary measures.
Cost. To date, the Company has incurred minimal consulting costs for Year 2000
project planning and scope definition. The Company acquired a Year 2000
assessment and testing suite for approximately $50,000. Contract staff will be
used to assist in the financial systems upgrade at a projected cost of $70,000.
For currently identified software systems requiring a Year 2000 upgrade, the
vendor is providing that upgrade under the terms of existing maintenance
agreements, and thus no additional license or upgrade fees are required. In all
cases these upgrades had been previously scheduled to maintain desired vendor
support and no upgrade project schedule has been accelerated to achieve Year
2000 compliance, nor has any project been deferred because of Year 2000 concerns
or efforts. An accurate cost cannot be determined prior to conclusion of the
assessment/prioritization phase, but it is expected total project expenditures,
including the use of outside consultants, should not exceed $1 million. This
does not include any costs which may be assessed by joint venture partners on
properties not operated by the Company.
Risks/Contingency. The failure to remediate critical systems (software, hardware
or embedded systems), or the failure of a material business partner to resolve
critical Year 2000 issues, could have a serious adverse impact on the ability of
the Company to continue operations and meet obligations. At the current time, it
is believed that any interruption in operation will be minor and short-lived and
will pose no safety or environmental risks. However, until all assessment phases
have been completed, it is impossible to accurately identify the risks, quantify
potential impacts or establish a contingency plan. The Company has not yet
clearly identified the most reasonably likely worst case scenario if the Company
and material business partners do not achieve Year 2000 compliance on a timely
basis. The Company currently intends to complete its contingency planning by
September 30, 1999, with testing and training to take place early in the fourth
quarter.
18
<PAGE> 19
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"). FAS
133 establishes a new model for accounting for derivatives and hedging
activities and supersedes and amends a number of existing standards. FAS 133 is
effective for all fiscal quarters of fiscal years beginning after June 15, 1999.
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 has not yet
determined the impact that adoption of FAS 133 will have on the financial
statements.
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. All statements other than statements of historical facts
included in this Form 10-Q, including, without limitation, 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, and Year 2000 compliance efforts, are
forward-looking statements. Although the Company believes that the expectations
reflected in such forward-looking statements are reasonable, it can give no
assurance that such expectations will prove to have been correct. Factors that
could cause actual results to differ materially from those expected by the
Company, including, without limitation, factors discussed under Risk Factors in
the Company's Form 10-K for the period ended December 31, 1998, are substantial
indebtedness, impairment of asset value, need to replace reserves, substantial
capital requirements, ability to supplement capital resources with asset sales,
fluctuations in the prices of oil and gas, uncertainties inherent in estimating
quantities of oil and gas reserves, projecting future rates of production and
the timing of development expenditures, competition, operating risks,
restrictions imposed by lenders, liquidity and capital requirements, the effects
of governmental and environmental regulation, pending patent and securities
litigation, adverse changes in the market for the Company's oil and gas
production and the Company's ability to successfully address Year 2000 issues.
Readers are cautioned not to place undue reliance on these forward-looking
statements, which speak only as of the date hereof. The Company undertakes no
obligation to release publicly the result of any revisions to these
forward-looking statements that may be made to reflect events or circumstances
after the date hereof, including, without limitation, changes in the Company's
business strategy or planned capital expenditures, or to reflect the occurrence
of unanticipated events.
19
<PAGE> 20
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKS
COMMODITY PRICE RISK
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. Results
from 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
hedging transactions related to the Company's oil and gas production volumes or
physical purchase or sale commitments of its oil and gas marketing subsidiary.
Gains or losses on crude oil and natural gas hedging transactions are recognized
as price adjustments in the months of related production.
As of March 31, 1999, the Company had the following natural gas swap
arrangements designed to hedge a portion of the Company's domestic gas
production for periods after March 1999:
<TABLE>
<CAPTION>
MONTHLY NYMEX-INDEX
VOLUME STRIKE PRICE
MONTHS (MMBTU) (PER MMBTU)
--------------------------- --------- ------------
<S> <C> <C>
April 1999................. 4,500,000 $ 1.968
May 1999................... 4,600,000 $ 1.968
June 1999.................. 4,500,000 $ 1.925
July 1999.................. 4,650,000 $ 1.925
August 1999................ 4,650,000 $ 1.925
September 1999............. 4,500,000 $ 1.925
</TABLE>
The Company also entered into additional transactions designed to hedge a
portion of the Company's domestic oil and gas production. Such transactions,
along with those listed above, were closed as of April 13, 1999. The net gains
resulting from these transactions equal $3.4 million, and will be recognized as
price adjustments in the months of related production and can be summarized as
follows ($ in 000's):
<TABLE>
<CAPTION>
HEDGING GAINS (LOSSES)
-------------------------------------
MONTH GAS OIL TOTAL
--------------- ----------- ----------- --------
<S> <C> <C> <C>
April.......... $ 1,386 $ (72) $ 1,314
May............ 1,327 (74) 1,253
June........... 232 (71) 161
July........... 210 (73) 137
August......... 180 (73) 107
September...... 144 (70) 74
October........ 421 (72) 349
November....... 102 (69) 33
December....... -- (71) (71)
-------- ------ -------
$ 4,002 $ (645) $ 3,357
-------- ------ -------
</TABLE>
20
<PAGE> 21
As of March 31, 1999, the Company had the following natural gas swap
arrangements designed to hedge a portion of the Company's Canadian gas
production for periods after March 1999:
<TABLE>
<CAPTION>
INDEX STRIKE PRICE
VOLUME (PER MMBTU)
MONTHS (MMBTU) (IN US $)
---------------------------------------- ---------------- ------------------
<S> <C> <C>
April 1999.............................. 570,000 $1.60
May 1999................................ 589,000 $1.60
June 1999............................... 570,000 $1.60
July 1999............................... 589,000 $1.60
August 1999............................. 589,000 $1.60
September 1999.......................... 570,000 $1.60
October 1999............................ 589,000 $1.60
</TABLE>
If the swap arrangements listed above had been settled on March 31, 1999, the
Company would have incurred a loss of $0.3 million. On May 11, 1999 the above
swap arrangements for August, September and October were closed. The net loss
resulting from these transactions of $0.6 million (in US $) will be recognized
as price adjustments in the months of related production.
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 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 believes it can
benefit from stable or falling interest rates and reduce its current interest
expense. During the Current Quarter, the Company's interest rate swap resulted
in a $0.5 million reduction of interest expense.
The table below presents principal cash flows and related weighted average
interest rates by expected maturity dates. As of March 31, 1999, the carrying
amounts of short-term borrowings are representative of fair values because of
the short-term maturity of these instruments. The fair value of the long-term
debt has been estimated based on quoted market prices.
<TABLE>
<CAPTION>
MARCH 31, 1999
-------------------------------------------------------------------------------------------
EXPECTED FISCAL YEAR OF MATURITY
-------------------------------------------------------------------------------------------
1999 2000 2001 2002 2003 THEREAFTER TOTAL FAIR.VALUE
-------- ------ ------ ------ ------ ---------- ------ ------------
LIABILITIES: ($ IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Short-term debt - variable rate .... $ 25 $ -- $ -- $ -- $ -- $ -- $ 25 $ 25
Average interest rate ............ 7.75% -- -- -- -- --
Long-term debt, including current
portion - fixed rate .......... $ -- $ -- $ -- $ -- $ -- $ 920 $ 920 $ 750
Average interest rate ............ -- -- -- -- -- 9.1%
</TABLE>
21
<PAGE> 22
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
The Company is subject to ordinary routine litigation incidental to its
business. In addition, the Company and certain of its officers and directors are
defendants in other pending actions which are described in Item 3 of the
Company's Annual Report on Form 10-K for the year ended December 31, 1998.
ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS
- - Not applicable
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
- - 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
(a) Exhibits
The following exhibits are filed as a part of this report:
Exhibit No.
-----------
12 Schedule of Ratios
27 Financial Data Schedule
(b) Reports on Form 8-K
During the quarter ended March 31, 1999, the Company filed the
following Current Report on Form 8-K dated:
March 19, 1999 reporting 1998 year-end financial and operating
results.
22
<PAGE> 23
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)
May 14, 1999 /s/ Aubrey K. McClendon
------------------ --------------------------------------
Date Aubrey K. McClendon
Chairman and
Chief Executive Officer
May 14, 1999 /s/ Marcus C. Rowland
------------------ --------------------------------------
Date Marcus C. Rowland
Executive Vice President and
Chief Financial Officer
23
<PAGE> 24
Index to Exhibits
<TABLE>
<CAPTION>
Exhibit No. Description
- ----------- -----------
<S> <C>
12 Schedule of Ratios
27 Financial Data Schedule
</TABLE>
<PAGE> 1
EXHIBIT 12
SCHEDULE OF RATIOS
<TABLE>
<CAPTION>
3 Months 3 Months
Ended Ended
March 31, March 31,
1999 1998
--------- ---------
($ in 000's)
<S> <C> <C>
RATIO OF EARNINGS TO FIXED CHARGES
Income before income taxes and extraordinary item ............ $(11,950) $(258,500)
Interest ..................................................... 19,890 10,688
Preferred Stock Dividends .................................... 4,028 --
Bond discount amortization (a) ............................... -- --
Loan cost amortization ....................................... 21 21
-------- ---------
Earnings ..................................................... $ 11,987 $(245,791)
Interest expense ............................................. $ 19,890 $ 10,688
Capitalized interest ......................................... 1,060 2,252
Preferred Stock Dividends .................................... 4,026 --
Bond discount amortization (a) ............................... -- --
Loan cost amortization ....................................... 21 21
-------- ---------
Fixed Charges ................................................ $ 24,987 $ 12,961
Ratio ........................................................ 0.48 (18.96)
(A) Bond discount excluded since its included in interest expense
Insufficient coverage ........................................ $ 13,000 $ 258,752
</TABLE>
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM BALANCE
SHEET AS OF MARCH 31, 1999 AND STATEMENT OF INCOME FOR THE THREE MONTHS ENDED
MARCH 31, 1999
</LEGEND>
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 3-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-START> JAN-01-1999
<PERIOD-END> MAR-31-1999
<CASH> 11,749
<SECURITIES> 0
<RECEIVABLES> 54,196
<ALLOWANCES> 3,209
<INVENTORY> 5,389
<CURRENT-ASSETS> 70,195
<PP&E> 2,321,506
<DEPRECIATION> 1,635,984
<TOTAL-ASSETS> 785,249
<CURRENT-LIABILITIES> 114,110
<BONDS> 919,097
0
230,000
<COMMON> 1,052
<OTHER-SE> (490,754)
<TOTAL-LIABILITY-AND-EQUITY> 785,249
<SALES> 65,677
<TOTAL-REVENUES> 66,550
<CGS> 58,610
<TOTAL-COSTS> 78,500
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 19,890
<INCOME-PRETAX> (11,950)
<INCOME-TAX> 0
<INCOME-CONTINUING> (11,950)
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> (11,950)
<EPS-PRIMARY> (.17)
<EPS-DILUTED> (.17)
</TABLE>
