Press Releases
Chesapeake Energy Corporation
The company's 2003 first quarter net income available to common shareholders of $70.0 million included a $17.2 million after-tax risk management gain (a non-cash item resulting from the application of SFAS 133 to the company's derivative contracts that do not qualify for hedge accounting) and a $2.4 million after-tax gain resulting from the cumulative effect of an accounting change for the adoption of SFAS 143 for asset retirement obligations.
Production for the 2003 first quarter was 56.8 billion cubic feet of natural gas equivalent (bcfe), comprised of 50.4 billion cubic feet of natural gas (bcf) (89%) and 1.06 million barrels of oil (mmbo) (11%). Oil and natural gas production increased 35% from the 2002 first quarter and 15% compared to the 2002 fourth quarter. The 2003 first quarter marked Chesapeake's seventh consecutive quarter of production growth compared to seven consecutive quarters of production decline in the industry. During the past seven quarters, Chesapeake's production has increased 45%, for an average per quarter growth rate of 6%. Reserve growth during the 2003 first quarter was also significant as production of 57 bcfe was replaced by 660 bcfe of new proved reserves (a 1,150% reserve replacement rate). This growth was comprised of 564 bcfe from acquisitions, 82 bcfe from drilling and 14 bcfe from positive revisions.
Average prices realized during the 2003 first quarter (after hedging) were $27.27 per barrel of oil (bo) and $4.51 per thousand cubic feet of natural gas (mcf), for a realized gas equivalent price of $4.52 per thousand cubic feet of natural gas equivalent (mcfe).
Key Operational and Financial Statistics for the 2003 First Quarter
The table below summarizes Chesapeake's key statistics during the 2003 first quarter and compares them to the 2002 fourth quarter and the 2002 first quarter:
Key Operations or Financial Statistics: Three Months Ended:
3/31/03 12/31/02 3/31/02
Average daily production (in mmcfe) 631 538 466
Gas as % of total production 89 89 88
Natural gas production (in bcf) 50.4 43.9 36.9
Average realized gas price ($/mcf) (A) 4.51 4.00 3.30
Oil production (in mbbls) 1,060 941 830
Average realized oil price ($/bbl) (A) 27.27 24.67 24.05
Natural gas equivalent production (in bcfe) 56.8 49.5 41.9
Gas equivalent realized price ($/mcfe) (A) 4.52 4.01 3.39
General and administrative costs ($/mcfe) .10 .11 .10
Production taxes ($/mcfe) .33 .21 .12
Lease operating expenses ($/mcfe) .55 .54 .53
Interest expense ($/mcfe) .62 .63 .64
DD&A of oil and gas properties ($/mcfe) 1.35 1.28 1.16
Operating cash flow ($ in millions) (B) 167.7 128.2 85.9
Operating cash flow ($/mcfe) 2.96 2.59 2.05
Net income (loss) available to common
shareholders ($ in millions) 70.0 23.7 (30.1)
(A) includes the effects of hedging
(B) cash flow provided by operating activities before changes in assets
and liabilities
Updated 2003 Second Quarter and Full Year Forecasts Attached
Chesapeake's updated second quarter 2003 and full-year 2003 forecasts are attached to this release in a revised Outlook dated April 28, 2003. The most significant change in the Outlook is an increase in projected 2003 second quarter and full-year production volumes. For the second quarter and full- year 2003, Chesapeake now believes it will produce 61 - 62 bcfe and 240 - 245 bcfe. These increased production ranges are primarily attributable to Chesapeake's deep drilling programs generating better than previously forecasted production volumes. The company has now increased its second quarter and full-year production estimates by 7% and 4%, respectively, since the beginning of the year.
In addition, Chesapeake took advantage of a two-week period of relatively weak gas prices in late March and early April to reduce its 2003 gas hedges to 53 bcf. In doing so, the company locked in $9 million of hedging gains and increased to 69% its exposure to market prices for remaining estimated 2003 gas production levels. Chesapeake may reinstate some or all of these hedges if gas prices increase this spring or summer.
Management Comments
Aubrey K. McClendon, Chesapeake's Chief Executive Officer, commented, "We are pleased to announce Chesapeake's very strong first quarter earnings, exceptional growth in proved reserves and production, low operating costs, high operating margins and increased production forecasts for the remainder of 2003. Chesapeake's value-creating financial and operating results are being driven by its distinctive Mid-Continent focus on successful deep-gas exploration and small to medium-sized acquisitions. Because of the company's unique scale, its technological advantages and its unrivaled Mid-Continent 3-D seismic and leasehold inventory, we believe Chesapeake's production and reserve growth trends are sustainable and should enable the company to continue generating significant increases in shareholder value in the years ahead."
Conference Call Information
A conference call has been scheduled for Tuesday morning, April 29, 2003 at 9:00 am EDT to discuss the earnings release. The telephone number to access the conference call is 913.981.5533. For those unable to participate in the conference call, a replay will be available from 12:00 pm EDT on Tuesday, April 29 through midnight Monday, May 12, 2003. The number to access the conference call replay is 719.457.0820 and the passcode is 643335. The conference call will also be simulcast live on the Internet and can be accessed at www.chkenergy.com by selecting "Conference Calls" under the "Investor Relations" section. The webcast of the conference call will be available on the website for one year.
This document 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. Statements concerning the fair values of derivative contracts and their estimated contribution to our future results of operations are based upon market information as of a specific date. These market prices are subject to significant volatility. 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 Item 1 of our 2002 Form 10-K and subsequent filings with the Securities and Exchange Commission and include the volatility of oil and gas prices, our substantial indebtedness, the strength and financial resources of our competitors, the cost and availability of drilling and production services, our commodity price risk management activities, including counterparty contract performance risk, uncertainties inherent in estimating quantities of oil and gas reserves, projecting future rates of production and the timing of development expenditures, our ability to replace reserves, the availability of capital, uncertainties in evaluating oil and gas reserves of acquired properties and associated potential liabilities, declines in the values of our oil and gas properties resulting in ceiling test write-downs, drilling and operating risks, our ability to generate future taxable income sufficient to utilize our NOLs before expiration, future ownership changes which could result in additional limitations to our NOLs, adverse effects of governmental and environmental regulation, losses possible from pending or future litigation and 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 document, 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 Securities and Exchange Commission that attempt to advise interested parties of the risks and factors that may affect our business.
Chesapeake Energy Corporation is one of the 8 largest independent natural gas producers in the U.S. Headquartered in Oklahoma City, the company's operations are focused on exploratory and developmental drilling and producing property acquisitions in the Mid-Continent region of the United States. The company's Internet address is www.chkenergy.com .
CHESAPEAKE ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
($ in 000's, except per share data)
(unaudited)
THREE MONTHS ENDED: March 31, 2003 March 31, 2002
$ $/mcfe $ $/mcfe
REVENUES:
Oil and gas sales 256,332 4.52 141,971 3.39
Risk management income (loss) 27,710 0.49 (79,468) (1.90)
Oil and gas marketing sales 90,308 1.59 27,333 0.65
Total revenues 374,350 6.60 89,836 2.14
OPERATING COSTS:
Production expenses 31,457 0.55 22,060 0.53
Production taxes 18,597 0.33 5,216 0.12
General and administrative 5,665 0.10 4,294 0.10
Oil and gas marketing expenses 89,358 1.58 26,507 0.63
Depreciation, depletion, and
amortization of oil and
gas properties 76,614 1.35 48,619 1.16
Depreciation and amortization
of other assets 3,684 0.06 3,110 0.08
Total operating costs 225,375 3.97 109,806 2.62
INCOME (LOSS) FROM OPERATIONS 148,975 2.63 (19,970) (0.48)
OTHER INCOME (EXPENSE):
Interest and other income 763 0.01 1,545 0.03
Interest expense (35,027) (0.62) (26,960) (0.64)
Loss on repurchases of debt --- --- (591) (0.01)
Total other income (expense) (34,264) (0.61) (26,006) (0.62)
Income (Loss) Before Income
Taxes and Cumulative
Effect of Accounting Change 114,711 2.02 (45,976) (1.10)
Income Tax Expense (Benefit) 43,591 0.77 (18,390) (0.44)
NET INCOME (LOSS) BEFORE CUMULATIVE
EFFECT OF ACCOUNTING CHANGE 71,120 1.25 (27,586) (0.66)
Cumulative Effect of Accounting
Change, Net of Tax 2,389 0.04 --- ---
NET INCOME (LOSS) 73,509 1.29 (27,586) (0.66)
Preferred Stock Dividends (3,526) (0.06) (2,532) (0.06)
NET INCOME (LOSS) AVAILABLE TO COMMON
SHAREHOLDERS 69,983 1.23 (30,118) (0.72)
EARNINGS PER COMMON SHARE:
Basic
Income (Loss) Before Cumulative
Effect of Accounting Change $0.34 $(0.18)
Cumulative Effect of Accounting
Change 0.01 ---
Net Income (Loss) $0.35 $(0.18)
Assuming dilution
Income (Loss) Before Cumulative
Effect of Accounting Change $0.31 $(0.18)
Cumulative Effect of Accounting
Change 0.01 ---
Net Income (Loss) $0.32 $(0.18)
WEIGHTED AVERAGE COMMON AND COMMON
EQUIVALENT SHARES OUTSTANDING:
Basic 197,608 165,372
Assuming dilution 230,672 165,372
CHESAPEAKE ENERGY CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
(in 000's)
(unaudited)
March 31, December 31,
2003 2002
Cash and cash equivalents $38,337 $247,719
Other current assets 303,990 187,598
TOTAL CURRENT ASSETS 342,327 435,317
Property and equipment (net) 3,354,042 2,389,884
Deferred tax asset --- 2,071
Other assets 73,213 48,336
TOTAL ASSETS $3,769,582 $2,875,608
Current liabilities $340,534 $265,552
Long term debt 1,948,725 1,651,198
Long term liabilities 67,412 50,983
Deferred tax liability 40,368 ---
TOTAL LIABILITIES 2,397,039 1,967,733
STOCKHOLDERS' EQUITY 1,372,543 907,875
TOTAL LIABILITIES & STOCKHOLDERS'
EQUITY $3,769,582 $2,875,608
COMMON SHARES OUTSTANDING 213,749 190,144
CHESAPEAKE ENERGY CORPORATION
RECONCILIATION OF CERTAIN FINANCIAL MEASURES
(in 000's)
(unaudited)
THREE MONTHS ENDED: March 31, March 31,
2003 2002
CASH PROVIDED BY OPERATING ACTIVITIES $99,052 $117,297
Adjustments:
Changes in assets and liabilities 68,661 (31,385)
OPERATING CASH FLOW* $167,713 $85,912
* Operating cash flow represents net cash provided by operating activities before changes in assets and liabilities. Operating cash flow is presented because management believes it is a useful adjunct to net cash provided by operating activities under accounting principles generally accepted in the United States (GAAP). Operating cash flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities and to service debt. This measure is widely used by investors and rating agencies in the valuation, comparison, rating and investment recommendations of companies within the oil and gas exploration and production industry. Operating cash flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity.
THREE MONTHS ENDED: March 31, March 31,
2003 2002
Net income (loss) before cumulative
effect of accounting change $71,120 $(27,586)
Income tax expense (benefit) 43,591 (18,390)
Interest expense 35,027 26,960
Depreciation and amortization of other assets 3,684 3,110
Depreciation, depletion and amortization
of oil and gas properties 76,614 48,619
EBITDA** $230,036 $32,713
** EBITDA represents net income (loss) before cumulative effect of accounting change, income tax expense (benefit), interest expense, and depreciation, depletion and amortization expense. EBITDA is presented as a supplemental financial measurement in the evaluation of our business. We believe that it provides additional information regarding our ability to meet our future debt service, capital expenditures and working capital requirements. This measure is widely used by investors and rating agencies in the valuation, comparison, rating and investment recommendations of companies. EBITDA is also a financial measurement that, with certain negotiated adjustments, is reported to our banks under our bank credit facilities and is used in our financial covenants under our bank credit facilities and our indentures governing our senior notes. EBITDA is not a measure of financial performance under GAAP. Accordingly, it should not be considered as a substitute for net income (loss), income (loss) from operations, or cash flow provided by operating activities prepared in accordance with GAAP. EBITDA is reconciled to cash provided by operating activities as follows:
THREE MONTHS ENDED: March 31, March 31,
2003 2002
CASH PROVIDED BY OPERATING ACTIVITIES $99,052 $117,297
Changes in assets and liabilities 68,661 (31,385)
Interest expense 35,027 26,960
Risk management income (loss) 27,710 (79,468)
Other non-cash items (414) (691)
EBITDA $230,036 $32,713
OUTLOOK
April 28, 2003
Quarter Ending June 30, 2003; Year Ending December 31, 2003.
We have adopted a policy of periodically providing investors with guidance on certain factors that affect our future financial performance. As of April 28, 2003, we are using the following key operating assumptions in our projections for the second quarter of 2003 and full year 2003.
The primary changes from our April 9, 2003 guidance are explained as follows:
1) We have updated the projected effects from changes in our hedging
positions.
2) We have included our expectations for future NYMEX oil and gas prices
to illustrate hedging effects only, they are not a forecast of our
expectations for 2003 oil and natural gas prices.
3) We have increased our projected production for the remainder of 2003.
Quarter Ending Year Ending
June 30, 2003 December 31, 2003
Estimated Production
Oil - Mbo 950 - 1,000 3,600 - 3,700
Gas - Bcf 55 - 56 218 - 223
Gas Equivalent - Bcfe 61 - 62 240 - 245
NYMEX Prices (for calculation of
hedging effects only)
Oil - $/Bo $25.33 $26.80
Gas - $/Mcf $5.05 $5.41
Estimated Corporate Differentials
to NYMEX Prices
Oil - $/Bo -$2.00 -$1.92
Gas - $/Mcf -$0.50 - $0.60 -$0.50 - $0.60
Estimated Hedging Effects (based
on expected NYMEX prices above)
Oil - $/Bo +$2.39 +$0.70
Gas - $/Mcf +$0.21 -$0.23
Operating Costs per Mcfe
Production expense $0.53 - 0.57 $0.53 - 0.57
Production taxes (generally
7% of O&G revenues) $0.31 - 0.33 $0.31 - 0.33
General and administrative $0.09 - 0.10 $0.09 - 0.10
DD&A - oil and gas $1.32 - 1.37 $1.32 - 1.37
Depreciation of other assets $0.08 - 0.10 $0.08 - 0.10
Interest expense $0.65 - 0.70 $0.65 - 0.70
Other Income and Expense per Mcfe (A)
Marketing and Other income $0.02 - 0.04 $0.02 - 0.04
Book Tax Rate - All Deferred 38% 38%
Equivalent Shares Outstanding
Basic 215,000 m 212,000 m
Diluted 262,000 m 255,000 m
Capital Expenditures:
Drilling, Land and Seismic $150 - $155 mm $575 - $600 mm
(A) Does not include non-cash risk management income or loss (SFAS 133)
or the cumulative effect of the adoption of SFAS 143.
Commodity Hedging Activities
Periodically the Company utilizes hedging strategies to hedge the price of a portion of its future oil and gas production. These strategies include:
(i) swap arrangements that establish an index-related price above which
the Company pays the counterparty and below which the Company is
paid by the counterparty,
(ii) the purchase of index-related puts that provide for a "floor" price
below which the counterparty pays the Company the amount by which
the price of the commodity is below the contracted floor,
(iii) the sale of index-related calls that provide for a "ceiling" price
above which the Company pays the counterparty the amount by which
the price of the commodity is above the contracted ceiling,
(iv) basis protection swaps, which are arrangements that guarantee the
price differential of oil or gas from a specified delivery point or
points,
(v) collar arrangements that establish an index-related price below
which the counterparty pays the Company and a separate index-related
price above which the Company pays the counterparty, and
Commodity markets are volatile, and as a result, Chesapeake's hedging activity is dynamic. As market conditions warrant, the Company may elect to settle a hedging transaction prior to its scheduled maturity date and, as a result, realize a gain or loss on the transaction.
Results from commodity hedging transactions are reflected in oil and gas sales to the extent related to the Company's oil and gas production. The Company only enters into commodity hedging transactions related to the Company's oil and gas production volumes or Chesapeake Energy Marketing, Inc.'s physical purchase or sale commitments. Gains or losses on crude oil and natural gas hedging transactions are recognized as price adjustments in the months of related production.
The Company has entered into the following natural gas hedging arrangements:
% Hedged
Avg. Avg. NYMEX
NYMEX Price
Open Strike Including Assuming
Straight Price Gain from Open & Gas Open
Swaps Of Open Closed Closed Production Swap
(mmcf) Swaps Swaps Positions Of: Positions
2003:
2nd Qtr 21,550 $4.81 $0.20 $5.01 55,000 39%
3rd Qtr 16,560 $4.68 $0.11 $4.79 57,000 29%
4th Qtr 14,420 $4.85 $0.17 $5.02 58,000 25%
Remaining 2003 52,530 $4.78 $0.16 $4.94 170,000 31%
2004:
1st Qtr 600 $5.68 $1.33 $7.01 59,000 1%
The Company has entered into the following natural gas basis hedging arrangements:
Annual Assuming Flat Gas
Volume (mmcf) NYMEX less: Production of: % Hedged
2003 Remaining 107,800 0.188
2003 Total 143,250 0.182 220,000 65%
2004 157,380 0.173 223,000 71%
2005 109,500 0.156 223,000 49%
2006 47,450 0.155 223,000 21%
2007 63,875 0.166 223,000 29%
2008 64,050 0.166 223,000 29%
2009 36,500 0.160 223,000 16%
622,005 0.169*
* weighted average
The Company has entered into the following crude oil hedging arrangements:
Avg. NYMEX
Volume Strike
(Mbo) Price
Q2 - 2003* 819.0 28.12
Q3 - 2003* 828.0 28.12
Q4 - 2003* 828.0 28.12
Remaining 2003 2,475.0 28.12
* Swaps with a knockout price of $21.00 for days in which NYMEX closes below $21.00.
SOURCE: Chesapeake Energy Corporation
CONTACT: Marc Rowland, Executive Vice President and Chief Financial
Officer, +1-405-879-9232, or Tom Price, Jr., Senior Vice President-Investor
Relations, +1-405-879-9257, both of Chesapeake Energy Corporation
Web site: http://www.chkenergy.com/
Company News On-Call: http://www.prnewswire.com/comp/138877.html
