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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
Date of Report (Date of earliest event reported): August 10, 2021
CHK-20210810_G1.JPG
CHESAPEAKE ENERGY CORPORATION
(Exact name of Registrant as specified in its Charter)
Oklahoma 1-13726 73-1395733
(State or other jurisdiction of
incorporation) 		(Commission File No.) (IRS Employer Identification No.)
6100 North Western Avenue Oklahoma City OK 73118
(Address of principal executive offices) (Zip Code)
(405) 848-8000
(Registrant’s telephone number, including area code)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
☐ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
☐ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
☐ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Trading Symbol Name of each exchange on which registered
Common Stock, $0.01 par value per share CHK The Nasdaq Stock Market LLC
Class A Warrants to purchase Common Stock CHKEW The Nasdaq Stock Market LLC
Class B Warrants to purchase Common Stock CHKEZ The Nasdaq Stock Market LLC
Class C Warrants to purchase Common Stock CHKEL The Nasdaq Stock Market LLC
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§ 230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§ 240.12b-2 of this chapter).
Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐


Item 2.02 Results of Operations and Financial Condition.

On August 10, 2021, Chesapeake Energy Corporation (“Chesapeake”) issued a press release reporting financial and operational results for the second quarter of 2021. A copy of the press release, financial information and outlook are attached as Exhibit 99.1, Exhibit 99.2 and Exhibit 99.3, respectively, to this Current Report on Form 8-K.

The information in the press release is being furnished, not filed, pursuant to Item 2.02. Accordingly, the information in the press release will not be incorporated by reference into any registration statement filed by Chesapeake under the Securities Act of 1933, as amended, except as set forth by specific reference in such filing.

Item 7.01 Regulation FD Disclosure.

On August 11, 2021, Chesapeake will make a presentation about its financial and operating results for the second quarter of 2021, as noted in the press release described in Item 2.02 above. Chesapeake has made the presentation available on its website at http://investors.chk.com/

This information is being furnished, not filed, pursuant to Item 7.01. Accordingly, this information will not be incorporated by reference into any registration statement filed by Chesapeake Energy Corporation under the Securities Act of 1933, as amended, except as set forth by specific reference in such filing.

Item 9.01 Financial Statements and Exhibits.

(d)    Exhibits
Exhibit No. Document Description
Chesapeake Energy Corporation press release dated August 10, 2021
Supplemental Financial Information
Outlook as of August 10, 2021
104.0 Cover Page Interactive Data File (embedded within the Inline XBRL document)



SIGNATURE
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 hereunto duly authorized.
CHESAPEAKE ENERGY CORPORATION
By:  /s/ DOMENIC J. DELL’OSSO, JR.
Domenic J. Dell’Osso, Jr.
Executive Vice President and Chief Financial Officer
Date:  August 10, 2021

Exhibit 99.1
N E W S   R E L E A S E
CHESAPEAKELOGOCOLORA40.JPG

FOR IMMEDIATE RELEASE
AUGUST 10, 2021
CHESAPEAKE ENERGY CORPORATION REPORTS 2021 SECOND QUARTER RESULTS
OKLAHOMA CITY, August 10, 2021 – Chesapeake Energy Corporation (NASDAQ:CHK) today reported 2021 second quarter results. Highlights include:
•Net cash provided by operating activities of $394 million, resulting in unrestricted cash balance of $612 million
•Net loss totaled $439 million, or $4.48 per diluted share; adjusted net income(1) of $181 million, or $1.64 per diluted share
•Adjusted EBITDAX(1) of $429 million; free cash flow of $292 million; net debt(1) at June 30 to 2021E adjusted EBITDAX ratio of 0.3x
•Initiating variable return program to deliver 50% of free cash flow(1) to shareholders on a quarterly basis, payable in the 2022 first quarter
•Announced responsibly sourced gas (RSG) partnership; first company seeking to certify and continuously monitor production across two major shale gas basins
•Positive 2021 guidance adjustments include increasing adjusted EBITDAX, raising oil and gas production estimates due to lower base decline rates, lower general and administrative (G&A) expenses, and no change in capital spending
(1) A Non-GAAP measure as defined in the supplemental financial tables available on the company's website at www.chk.com.
Mike Wichterich, Chesapeake’s Board Chairman and Interim Chief Executive Officer, commented, “Behind our talented employees, Chesapeake executed another quarter of strong results, improving our guidance outlook for the rest of the year as our base production decline rates continue to improve and general and administrative (G&A) expenses continue to fall. In addition, Chesapeake is pleased to launch a variable return program designed to deliver 50% of free cash flow to shareholders in cash on a quarterly basis. Chesapeake remains well positioned to responsibly deliver sustainable returns and cash flow through consistent quarterly performance.”
Base Dividend Information and Establishing Variable Return Program
During the 2021 second quarter, Chesapeake generated $394 million of operating cash flow and ended the quarter with $612 million of cash on hand. Consistent with the company’s strong liquidity and free cash flow generation, Chesapeake's Board of Directors declared a quarterly dividend on its common shares of $0.34375 per share. The dividend will be payable on September 9, 2021 to shareholders of record at the close of business on August 24, 2021. Additionally, Chesapeake announced the establishment of a variable return program to deliver 50% of the previous quarter’s free cash flow to investors in cash, payable the following quarter, and beginning with results from the 2021 fourth quarter.
Operations Update
Chesapeake continues to see lower base production decline rates which helped achieve an average net production rate of approximately 433,000 boe per day (approximately 77% natural gas and 23% total liquids) during the 2021 second quarter. Chesapeake is currently operating seven rigs across all its business units, with three rigs in the Marcellus Shale in Pennsylvania, three rigs located in the Haynesville Shale in Louisiana and one rig in the South Texas Eagle Ford Shale.
INVESTOR CONTACT: MEDIA CONTACT: CHESAPEAKE ENERGY CORPORATION
Brad Sylvester, CFA
(405) 935-8870
ir@chk.com
Gordon Pennoyer
(405) 935-8878
media@chk.com
6100 North Western Avenue
P.O. Box 18496
Oklahoma City, OK 73154

ESG Update
In July 2021, Chesapeake announced a partnership with MiQ and Equitable Origin to independently certify and continuously monitor its natural gas production across two major shale gas basins, the Marcellus in Pennsylvania and the Haynesville in Louisiana, making Chesapeake the first company seeking to certify two basins for the industry. The MiQ certification will provide a verified approach to tracking the company’s initiative to reduce its methane intensity to 0.09% by 2025, as well as support Chesapeake in its overall objective of achieving net-zero direct greenhouse gas emissions by 2035. The company has recently entered into, and is continuing to pursue, supply agreements providing certified RSG gas in the Marcellus Shale from its initial results under a previous pilot with Project Canary.
Additionally, in July the company began utilizing its first electric stimulation fleet in the Marcellus Shale to further reduce diesel usage in its fracture stimulations. The electric fleet will displace 100% of Chesapeake's associated diesel consumption during the stimulation operation, resulting in lower GHG emissions while also reducing the audible noise level with electric equipment. The company estimates that the use of this electric fleet alone could displace a total of up to approximately 4.4 million gallons of diesel per year. The company also plans to begin utilizing a Tier 4 dual-fuel fracture stimulation fleet in its Haynesville operations beginning in September 2021, reducing its diesel usage further.
2021 Outlook Update
In a positive update to 2021 guidance, Chesapeake increased its expected 2021 adjusted EBITDAX range to approximately $1.8 to $1.9 billion, up 16% from $1.55 to $1.65 billion previously. In addition, the company increased its total annual production, affirmed its commitment to disciplined spending with no change to its previous capital program and reduced its annual G&A expense guidance by approximately $25 million, or 15% (using midpoints).
Conference Call Information
Chesapeake will conduct a conference call to discuss these results on Wednesday, August 11, 2021 at 9:00 am EDT. The telephone number to access the conference call is 888-317-6003 or 412-317-6061 for international callers. The passcode for the call is 2789084.
Financial Statements and Guidance Documents
The company’s 2021 second quarter financial and operational results, along with non-GAAP measures that adjust for items that are typically excluded by securities analysts, and management’s updated guidance for the remainder of 2021 are available on the company's website at www.chk.com.
Non-GAAP Financial Measures
This news release includes non-GAAP financial measures. Such non-GAAP measures should be not considered as an alternative to GAAP measures. Reconciliations of these non-GAAP measures and other disclosures are provided with the supplemental financial tables available on the company's website at www.chk.com.
Fresh Start Accounting and Predecessor and Successor Periods
In connection with our emergence from bankruptcy on February 9, 2021, Chesapeake qualified for and applied fresh start accounting. In applying fresh start accounting, Chesapeake allocated its reorganization value to its individual assets based on their estimated fair values. Accordingly, the consolidated financial statements after February 9, 2021 are not comparable with the consolidated financial statements as of or prior to that date. References to "Successor" refer to the post-emergence reorganized Chesapeake after February 9, 2021, and references to "Predecessor" refer to pre-emergence Chesapeake for periods on or before February 9, 2021.
2

Headquartered in Oklahoma City, Chesapeake Energy Corporation's (NASDAQ: CHK) operations are focused on discovering and responsibly developing its large and geographically diverse resource base of unconventional oil and natural gas assets onshore in the United States.
Forward-Looking Statements
This news release and the accompanying outlook include "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 are statements other than statements of historical fact. They include statements that give our current expectations, management's outlook guidance or forecasts of future events, expected natural gas and oil growth trajectory, projected cash flow and liquidity, our ability to enhance our cash flow and financial flexibility, dividend plans, future production and commodity mix, plans and objectives for future operations, ESG initiatives, the ability of our employees, portfolio strength and operational leadership to create long-term value, and the assumptions on which such statements are based. Although we believe the expectations and forecasts reflected in the forward-looking statements are reasonable, we can give no assurance they will prove to have been correct. They can be affected by inaccurate or changed assumptions or by known or unknown risks and uncertainties.
Factors that could cause actual results to differ materially from expected results include those described under "Risk Factors" in Item 1A of our annual report on Form 10-K and any updates to those factors set forth in Chesapeake's subsequent quarterly reports on Form 10-Q or current reports on Form 8-K (available at http://www.chk.com/investors/sec-filings). These risk factors include: the impact of the COVID-19 pandemic and its effect on the company's business, financial condition, employees, contractors and vendors, and on the global demand for oil and natural gas and U.S. and world financial markets; the volatility of oil, natural gas and NGL prices; the limitations our level of indebtedness may have on our financial flexibility; our inability to access the capital markets on favorable terms; the availability of cash flows from operations and other funds to fund cash dividends, to finance reserve replacement costs or satisfy our debt obligations; write-downs of our oil and natural gas asset carrying values due to low commodity prices; our ability to replace reserves and sustain production; uncertainties inherent in estimating quantities of oil, natural gas and NGL reserves and projecting future rates of production and the amount and timing of development expenditures; our ability to generate profits or achieve targeted results in drilling and well operations; leasehold terms expiring before production can be established; commodity derivative activities resulting in lower prices realized on oil, natural gas and NGL sales; the need to secure derivative liabilities and the inability of counterparties to satisfy their obligations; adverse developments or losses from pending or future litigation and regulatory proceedings, including royalty claims; charges incurred in response to market conditions; drilling and operating risks and resulting liabilities; effects of environmental protection laws and regulations on our business; legislative and regulatory initiatives further regulating hydraulic fracturing; our need to secure adequate supplies of water for our drilling operations and to dispose of or recycle the water used; impacts of potential legislative and regulatory actions addressing climate change; federal and state tax proposals affecting our industry; potential OTC derivatives regulation limiting our ability to hedge against commodity price fluctuations; competition in the oil and gas exploration and production industry; a deterioration in general economic, business or industry conditions; negative public perceptions of our industry; limited control over properties we do not operate; pipeline and gathering system capacity constraints and transportation interruptions; terrorist activities and cyber-attacks adversely impacting our operations; and an interruption in operations at our headquarters due to a catastrophic event.
In addition, disclosures concerning the estimated contribution of derivative contracts to our future results of operations are based upon market information as of a specific date. These market prices are subject to significant volatility. Our production forecasts are also dependent upon many assumptions, including estimates of production decline rates from existing wells and the outcome of future drilling activity. We caution you not to place undue reliance on our forward-looking statements that speak only as of the date of this news release, and we undertake no obligation to update any of the information provided in this release, except as required by applicable law. In addition, this news release contains time-sensitive information that reflects management's best judgment only as of the date of this news release.

3
Exhibit 99.2
CHESAPEAKE ENERGY CORPORATION - SUPPLEMENTAL TABLES
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1


CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited)
Successor Predecessor
($ in millions) June 30,
2021 		December 31,
2020
Assets
Current assets:
Cash and cash equivalents $ 612  $ 279 
Restricted cash 10  — 
Accounts receivable, net 674  746 
Short-term derivative assets —  19 
Other current assets 58  64 
Total current assets 1,354  1,108 
Property and equipment:
Oil and natural gas properties, successful efforts method
     Proved oil and natural gas properties 4,960  25,734 
     Unproved properties 442  1,550 
     Other property and equipment 491  1,754 
Total property and equipment 5,893  29,038 
Less: accumulated depreciation, depletion and amortization (346) (23,806)
Property and equipment held for sale, net 3  10 
Total property and equipment, net 5,550  5,242 
Other long-term assets 95  234 
Total assets $ 6,999  $ 6,584 
Liabilities and stockholders' equity (deficit)
Current liabilities:
Accounts payable $ 281  $ 346 
Current maturities of long-term debt —  1,929 
Accrued interest 24  3 
Short-term derivative liabilities 780  93 
Other current liabilities 781  723 
Total current liabilities 1,866  3,094 
Long-term debt, net 1,261  — 
Long-term derivative liabilities 211  44 
Asset retirement obligations, net of current portion 241  139 
Other long-term liabilities 7  5 
Liabilities subject to compromise —  8,643 
Total liabilities 3,586  11,925 
Contingencies and commitments
Stockholders’ equity (deficit):
Predecessor preferred stock, $0.01 par value, 20,000,000 shares authorized: 0 and 5,563,458 shares outstanding —  1,631 
Predecessor common stock, $0.01 par value, 22,500,000 shares authorized: 0 and 9,780,547 shares issued —  — 
Predecessor additional paid-in capital —  16,937 
Predecessor accumulated other comprehensive income —  45 
Successor common stock, $0.01 par value, 450,000,000 shares authorized: 97,954,037 and 0 shares issued 1  — 
Successor additional paid-in capital 3,590  — 
Accumulated deficit (178) (23,954)
Total stockholders’ equity (deficit) 3,413  (5,341)
Total liabilities and stockholders’ equity (deficit) $ 6,999  $ 6,584 
2

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
Successor Predecessor
Three Months Ended
June 30, 2021 		Three Months Ended
June 30, 2020
($ in millions except per share data)
Revenues and other:
Oil, natural gas and NGL $ 892  $ 440 
Marketing 539  240 
Oil and natural gas derivatives (740) (173)
Gains on sales of assets 2  — 
Total revenues and other 693  507 
Operating expenses:
Production 74  91 
Gathering, processing and transportation 211  270 
Severance and ad valorem taxes 41  25 
Exploration 1  130 
Marketing 535  242 
General and administrative 24  112 
Separation and other termination costs 11  22 
Depreciation, depletion and amortization 229  158 
Impairments 1  — 
Other operating income, net (4) (2)
Total operating expenses 1,123  1,048 
Loss from operations (430) (541)
Other income (expense):
Interest expense (18) (137)
Gains on purchases or exchanges of debt —  2 
Other income 9  6 
Reorganization items, net —  394 
Total other income (expense) (9) 265 
Loss before income taxes (439) (276)
Income tax benefit —  — 
Net loss (439) (276)
Net loss attributable to noncontrolling interests —  — 
Net loss attributable to Chesapeake (439) (276)
Preferred stock dividends —  — 
Net loss available to common stockholders $ (439) $ (276)
Loss per common share:
Basic $ (4.48) $ (28.22)
Diluted $ (4.48) $ (28.22)
Weighted average common shares outstanding (in thousands):
Basic 97,931  9,779 
Diluted 97,931  9,779 
3

Successor Predecessor
Period from February 10, 2021 through June 30, 2021 Period from January 1, 2021 through February 9, 2021 Six Months Ended
June 30, 2020
($ in millions except per share data)
Revenues and other:
Oil, natural gas and NGL $ 1,445  $ 398  $ 1,334 
Marketing 816  239  964 
Oil and natural gas derivatives (694) (382) 734 
Gains on sales of assets 6  5  — 
Total revenues and other 1,573  260  3,032 
Operating expenses:
Production 114  32  213 
Gathering, processing and transportation 322  102  555 
Severance and ad valorem taxes 65  18  79 
Exploration 2  2  412 
Marketing 815  237  988 
General and administrative 39  21  177 
Separation and other termination costs 11  22  27 
Depreciation, depletion and amortization 351  72  761 
Impairments 1  —  8,522 
Other operating expense (income), net (2) (12) 66 
Total operating expenses 1,718  494  11,800 
Loss from operations (145) (234) (8,768)
Other income (expense):
Interest expense (30) (11) (282)
Gains on purchases or exchanges of debt —  —  65 
Other income (expense) 31  2  (11)
Reorganization items, net —  5,569  394 
Total other income 1  5,560  166 
Income (loss) before income taxes (144) 5,326  (8,602)
Income tax benefit
—  (57) (13)
Net income (loss) (144) 5,383  (8,589)
Net loss attributable to noncontrolling interests —  —  16 
Net income (loss) attributable to Chesapeake (144) 5,383  (8,573)
Preferred stock dividends —  —  (22)
Net income (loss) available to common stockholders $ (144) $ 5,383  $ (8,595)
Earnings (loss) per common share:
Basic $ (1.47) $ 550.35  $ (880.18)
Diluted $ (1.47) $ 534.51  $ (880.18)
Weighted average common shares outstanding (in thousands):
Basic 97,922  9,781  9,765 
Diluted 97,922  10,071  9,765 

4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
Successor Predecessor
  Three Months Ended
June 30, 2021 		Three Months Ended
June 30, 2020
($ in millions)
Cash flows from operating activities:
Net loss $ (439) $ (276)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation, depletion and amortization 229  158 
Derivative losses, net 740  173 
Cash receipts (payments) on derivative settlements, net (113) 791 
Stock-based compensation 3  4 
Gains on sales of assets (2) — 
Impairments 1  — 
Non-cash reorganization items, net —  (449)
Exploration 1  127 
Gains on purchases or exchanges of debt —  (2)
Other (7) (30)
Changes in assets and liabilities (19) (120)
Net cash provided by operating activities 394  376 
Cash flows from investing activities:
Capital expenditures (149) (349)
Proceeds from divestitures of property and equipment 2  4 
Net cash used in investing activities (147) (345)
Cash flows from financing activities:
Proceeds from pre-petition revolving credit facility borrowings —  1,475 
Payments on pre-petition revolving credit facility borrowings —  (1,446)
Proceeds from warrant exercise 2  — 
Debt issuance and other financing costs —  (55)
Cash paid to purchase debt —  (2)
Cash paid for common stock dividends (34) — 
Other (1) (3)
Net cash used in financing activities (33) (31)
Net increase in cash, cash equivalents and restricted cash 214  — 
Cash, cash equivalents and restricted cash, beginning of period 408  82 
Cash, cash equivalents and restricted cash, end of period $ 622  $ 82 
Cash and cash equivalents $ 612  $ 82 
Restricted cash 10  — 
Total cash, cash equivalents and restricted cash $ 622  $ 82 
5

Successor Predecessor
  Period from February 10, 2021 through June 30, 2021 Period from January 1, 2021 through February 9, 2021 Six Months Ended
June 30, 2020
($ in millions)
Cash flows from operating activities:
Net income (loss) $ (144) $ 5,383  $ (8,589)
Adjustments to reconcile net income (loss) to cash provided by operating activities:
Depreciation, depletion and amortization 351  72  761 
Deferred income tax benefit —  (57) (10)
Derivative (gains) losses, net 694  382  (734)
Cash receipts (payments) on derivative settlements, net (145) (17) 880 
Stock-based compensation 3  3  9 
Gains on sales of assets (6) (5) — 
Impairments 1  —  8,522 
Non-cash reorganization items, net —  (6,680) (449)
Exploration 1  2  406 
Gains on purchases or exchanges of debt —  —  (65)
Other (3) 45  1 
Changes in assets and liabilities 51  851  41 
Net cash provided by (used in) operating activities 803  (21) 773 
Cash flows from investing activities:
Capital expenditures (226) (66) (867)
Proceeds from divestitures of property and equipment 6  —  11 
Net cash used in investing activities (220) (66) (856)
Cash flows from financing activities:
Proceeds from Exit Credit Facility - Tranche A Loans 30  —  — 
Payments on Exit Credit Facility - Tranche A Loans (80) (479) — 
Proceeds from pre-petition revolving credit facility borrowings —  —  3,806 
Payments on pre-petition revolving credit facility borrowings —  —  (3,467)
Payments on DIP Facility borrowings —  (1,179) — 
Proceeds from issuance of senior notes, net —  1,000  — 
Proceeds from issuance of common stock —  600  — 
Proceeds from warrant exercise 2  —  — 
Debt issuance and other financing costs (3) (8) (55)
Cash paid to purchase debt —  —  (95)
Cash paid for common stock dividends (34) —  — 
Cash paid for preferred stock dividends —  —  (22)
Other (2) —  (8)
Net cash provided by (used in) financing activities (87) (66) 159 
Net increase (decrease) in cash, cash equivalents and restricted cash 496  (153) 76 
Cash, cash equivalents and restricted cash, beginning of period 126  279  6 
Cash, cash equivalents and restricted cash, end of period $ 622  $ 126  $ 82 
Cash and cash equivalents $ 612  $ 40  $ 82 
Restricted cash 10  86  — 
Total cash, cash equivalents and restricted cash $ 622  $ 126  $ 82 
6

OIL, NATURAL GAS AND NGL PRODUCTION AND AVERAGE SALES PRICES (unaudited)
Successor
Three Months Ended June 30, 2021
  Oil Natural Gas NGL Total
  MBbl
per day 		$/Bbl MMcf
per day 		$/Mcf MBbl
per day 		$/Bbl MBoe
per day 		$/Boe
Appalachia —  —  1,279  1.94  —  —  213  11.67 
Gulf Coast —  —  531  2.57  —  —  88  15.40 
South Texas 37  66.13  108  2.55  16  23.86  72  43.73 
Brazos Valley 27  64.83  35  1.81  4  17.95  37  51.63 
Powder River Basin 10  64.27  57  3.10  3  30.39  23  40.13 
Total 74  65.41  2,010  2.17  23  23.90  433  22.64 
Average Realized Price 48.64  2.12  23.89  19.51 
Predecessor
Three Months Ended June 30, 2020
  Oil Natural Gas NGL Total
  MBbl
per day 		$/Bbl MMcf
per day 		$/Mcf MBbl
per day 		$/Bbl MBoe
per day 		$/Boe
Appalachia —  —  1,051  1.38  —  —  175  8.26 
Gulf Coast —  —  502  1.46  —  —  84  8.75 
South Texas 40  20.15  117  1.95  16  9.68  75  15.76 
Brazos Valley 36  23.42  49  0.69  6  1.93  50  17.58 
Powder River Basin 13  23.80  52  1.44  3  10.59  25  16.96 
Mid-Continent 4  24.41  35  1.50  3  8.03  12  13.39 
Total 93  22.06  1,806  1.42  28  7.86  421  11.46 
Average Realized Price 89.51  2.17  7.86  29.51 
7

Successor
Period from February 10, 2021 through June 30, 2021
  Oil Natural Gas NGL Total
  MBbl
per day 		$/Bbl MMcf
per day 		$/Mcf MBbl
per day 		$/Bbl MBoe
per day 		$/Boe
Appalachia —  —  1,280  2.15  —  —  213  12.93 
Gulf Coast —  —  529  2.61  —  —  88  15.65 
South Texas 37  64.70  108  3.46  15  25.29  71  44.93 
Brazos Valley 28  63.32  35  4.32  4  17.44  37  52.92 
Powder River Basin 10  62.42  57  3.71  4  31.98  23  41.00 
Total 75  63.89  2,009  2.43  23  24.99  432  23.68 
Predecessor
Period from January 1, 2021 through February 9, 2021
Oil Natural Gas NGL Total
MBbl
per day 		$/Bbl MMcf
per day 		$/Mcf MBbl
per day 		$/Bbl MBoe
per day 		$/Boe
Appalachia —  —  1,233  2.42  —  —  206  14.49 
Gulf Coast —  —  543  2.44  —  —  90  14.62 
South Texas 42  54.12  127  3.00  14  26.04  78  39.20 
Brazos Valley 32  52.37  38  1.14  4  16.09  42  42.23 
Powder River Basin 10  51.96  61  2.92  4  34.31  24  34.25 
Total 84  53.21  2,002  2.45  22  25.92  440  22.63 
Non-GAAP Combined
Six Months Ended June 30, 2021
Oil Natural Gas NGL Total
MBbl
per day 		$/Bbl MMcf
per day 		$/Mcf MBbl
per day 		$/Bbl MBoe
per day 		$/Boe
Appalachia —  —  1,270  2.21  —  —  212  13.26 
Gulf Coast —  —  532  2.57  —  —  88  15.41 
South Texas 39  62.12  112  3.35  15  25.45  72  43.57 
Brazos Valley 28  60.63  36  3.56  4  17.15  39  50.33 
Powder River Basin 10  60.15  58  3.53  4  32.56  23  39.44 
Total 77  61.31  2,008  2.43  23  25.19  434  23.44 
Average Realized Price 47.40  2.41  25.19  20.85 
Predecessor
Six Months Ended June 30, 2020
  Oil Natural Gas NGL Total
  MBbl
per day 		$/Bbl MMcf
per day 		$/Mcf MBbl
per day 		$/Bbl MBoe
per day 		$/Boe
Appalachia —  —  1,013  1.66  —  —  168  9.99 
Gulf Coast —  —  529  1.58  —  —  88  9.46 
South Texas 52  37.49  138  2.08  18  10.79  92  26.17 
Brazos Valley 38  35.62  59  0.63  7  3.82  56  25.77 
Powder River Basin 15  34.71  71  1.69  4  12.37  32  22.40 
Mid-Continent 4  36.35  42  1.93  3  11.37  14  19.14 
Total 109  36.39  1,852  1.64  32  9.48  450  16.28 
Average Realized Price 71.35  2.16  9.48  26.89 
8

GROSS MARGIN (unaudited)
Successor Predecessor
Three Months Ended
June 30, 		Three Months Ended
June 30,
2021 2020
($ in millions, except per unit) $ $/Boe $ $/Boe
Appalachia
Oil, natural gas and NGL sales $ 226  $ 11.67  $ 131  $ 8.26 
Production expenses 9  $ 0.44  7  $ 0.46 
Gathering, processing and transportation expenses 79  $ 4.07  73  $ 4.61 
Severance and ad valorem taxes 3  $ 0.14  1  $ 0.07 
Gross margin $ 135  $ 7.02  $ 50  $ 3.12 
Gulf Coast
Oil, natural gas and NGL sales $ 124  $ 15.40  $ 67  $ 8.75 
Production expenses 11  $ 1.30  11  $ 1.41 
Gathering, processing and transportation expenses 25  $ 3.15  40  $ 5.20 
Severance and ad valorem taxes 5  $ 0.54  4  $ 0.63 
Gross margin $ 83  $ 10.41  $ 12  $ 1.51 
South Texas
Oil, natural gas and NGL sales $ 285  $ 43.73  $ 108  $ 15.77 
Production expenses 29  $ 4.46  25  $ 3.72 
Gathering, processing and transportation expenses 79  $ 12.11  123  $ 17.94 
Severance and ad valorem taxes 16  $ 2.38  8  $ 1.15 
Gross margin $ 161  $ 24.78  $ (48) $ (7.04)
Brazos Valley
Oil, natural gas and NGL sales $ 173  $ 51.63  $ 80  $ 17.51 
Production expenses 18  $ 5.41  22  $ 4.91 
Gathering, processing and transportation expenses 3  $ 1.06  5  $ 1.13 
Severance and ad valorem taxes 10  $ 3.01  7  $ 1.49 
Gross margin $ 142  $ 42.15  $ 46  $ 9.98 
Powder River Basin
Oil, natural gas and NGL sales $ 84  $ 40.13  $ 39  $ 16.91 
Production expenses 7  $ 3.61  10  $ 4.13 
Gathering, processing and transportation expenses 25  $ 11.69  23  $ 10.05 
Severance and ad valorem taxes 7  $ 3.86  4  $ 1.56 
Gross margin $ 45  $ 20.97  $ 2  $ 1.17 
Mid-Continent
Oil, natural gas and NGL sales $ —  $ —  $ 15  $ 13.35 
Production expenses —  $ —  16  $ 13.94 
Gathering, processing and transportation expenses —  $ —  6  $ 5.70 
Severance and ad valorem taxes —  $ —  1  $ 1.10 
Gross margin $ —  $ —  $ (8) $ (7.39)
Successor Predecessor Non-GAAP Combined Predecessor
Period from February 10, 2021 through
June 30, 		Period from
January 1, 2021 through
February 9, 		Six Months Ended
June 30, 		Six Months Ended
June 30,
2021 2021 2021 2020
($ in millions, except per unit) $ $/Boe $ $/Boe $ $/Boe $ $/Boe
Appalachia
Oil, natural gas and NGL sales $ 389  $ 12.93  $ 119  $ 14.49  $ 508  $ 13.26  $ 306  $ 9.99 
Production expenses 14  $ 0.46  4  $ 0.50  18  $ 0.47  16  $ 0.52 
Gathering, processing and transportation expenses 121  $ 4.02  34  $ 4.17  155  $ 4.06  144  $ 4.72 
Severance and ad valorem taxes 4  $ 0.12  1  $ 0.07  5  $ 0.11  3  $ 0.09 
Gross margin $ 250  $ 8.33  $ 80  $ 9.75  $ 330  $ 8.62  $ 143  $ 4.66 
Gulf Coast
Oil, natural gas and NGL sales $ 194  $ 15.65  $ 53  $ 14.62  $ 247  $ 15.41  $ 151  $ 9.46 
Production expenses 17  $ 1.37  4  $ 1.12  21  $ 1.31  22  $ 1.36 
Gathering, processing and transportation expenses 36  $ 2.90  11  $ 2.93  47  $ 2.91  91  $ 5.68 
Severance and ad valorem taxes 7  $ 0.55  2  $ 0.54  9  $ 0.54  10  $ 0.65 
Gross margin $ 134  $ 10.83  $ 36  $ 10.03  $ 170  $ 10.65  $ 28  $ 1.77 
South Texas
Oil, natural gas and NGL sales $ 449  $ 44.93  $ 122  $ 39.20  $ 571  $ 43.57  $ 436  $ 26.17 
Production expenses 43  $ 4.32  12  $ 3.90  55  $ 4.22  61  $ 3.66 
Gathering, processing and transportation expenses 121  $ 12.06  42  $ 13.35  163  $ 12.37  232  $ 13.90 
Severance and ad valorem taxes 25  $ 2.46  8  $ 2.53  33  $ 2.48  27  $ 1.61 
Gross margin $ 260  $ 26.09  $ 60  $ 19.42  $ 320  $ 24.50  $ 116  $ 7.00 
Brazos Valley
Oil, natural gas and NGL sales $ 281  $ 52.92  $ 71  $ 42.23  $ 352  $ 50.33  $ 260  $ 25.74 
Production expenses 28  $ 5.26  9  $ 4.85  37  $ 5.16  50  $ 4.95 
Gathering, processing and transportation expenses 5  $ 1.06  3  $ 1.92  8  $ 1.26  14  $ 1.37 
Severance and ad valorem taxes 17  $ 3.27  5  $ 2.99  22  $ 3.20  23  $ 2.31 
Gross margin $ 231  $ 43.33  $ 54  $ 32.47  $ 285  $ 40.71  $ 173  $ 17.11 
Powder River Basin
Oil, natural gas and NGL sales $ 132  $ 41.00  $ 33  $ 34.25  $ 165  $ 39.44  $ 130  $ 22.38 
Production expenses 12  $ 3.88  3  $ 3.37  15  $ 3.76  28  $ 4.81 
Gathering, processing and transportation expenses 39  $ 12.03  12  $ 12.53  51  $ 12.15  58  $ 10.05 
Severance and ad valorem taxes 12  $ 3.88  2  $ 2.88  14  $ 3.64  13  $ 2.27 
Gross margin $ 69  $ 21.21  $ 16  $ 15.47  $ 85  $ 19.89  $ 31  $ 5.25 
Mid-Continent
Oil, natural gas and NGL sales $ —  $ —  $ —  $ —  $ —  $ —  $ 51  $ 19.27 
Production expenses —  $ —  —  $ —  —  $ —  36  $ 13.94 
Gathering, processing and transportation expenses —  $ —  —  $ —  —  $ —  16  $ 6.14 
Severance and ad valorem taxes —  $ —  —  $ —  —  $ —  3  $ 1.06 
Gross margin $ —  $ —  $ —  $ —  $ —  $ —  $ (4) $ (1.87)
9

CAPITAL EXPENDITURES ACCRUED (unaudited)
Successor Predecessor
Three Months Ended
June 30, 2021 		Three Months Ended
June 30, 2020
($ in millions)
Drilling and completion capital expenditures:
Appalachia $ 65  $ 57 
Gulf Coast 63  33 
South Texas 21  22 
Brazos Valley 13  22 
Powder River Basin 4  6 
Total drilling and completion capital expenditures 166  140 
Leasehold and additions to other PP&E 2  6 
Capitalized interest 2  5 
Total capital expenditures $ 170  $ 151 

Successor Predecessor Non-GAAP Combined Predecessor
Period from February 10, 2021 through
June 30, 2021 		Period from
January 1, 2021 through
February 9, 2021 		Six Months Ended
June 30, 2021 		Six Months Ended
June 30, 2020
($ in millions)
Drilling and completion capital expenditures:
Appalachia $ 104  $ 30  $ 134  $ 120 
Gulf Coast 74  22  96  62 
South Texas 25  4  29  156 
Brazos Valley 17  5  22  176 
Powder River Basin 5  —  5  89 
Retained assets 225  61  286  603 
Mid-Continent —  —  —  2 
Total drilling and completion capital expenditures 225  61  286  605 
Leasehold and additions to other PP&E 3  —  3  19 
Capitalized interest 3  1  4  11 
Total capital expenditures $ 231  $ 62  $ 293  $ 635 
10

OIL AND NATURAL GAS HEDGING POSITIONS AS OF JULY 30, 2021
Crude Oil Swaps
Volume
(MMBbls) 		Avg. NYMEX
Price of Swaps
Q3 2021(a)
4.6  $ 42.62 
Q4 2021 4.3  $ 42.62 
Total 2021 8.9  $ 42.62 
Total 2022 11.2  $ 44.30 
Total 2023 1.9  $ 47.17 
Oil Basis Protection Swaps
Volume
(MMBbls) 		Avg. NYMEX
plus/(minus)
Q3 2021(a)
3.5  $ 0.50 
Q4 2021 3.5  $ 0.50 
Total 2021 7.0  $ 0.50 
Total 2022 6.0  $ 0.34 
Natural Gas Swaps
Volume
(Bcf) 		Avg. NYMEX
Price of Swaps
Q3 2021(a)
127  $ 2.66 
Q4 2021 115  $ 2.67 
Total 2021 242  $ 2.67 
Total 2022 249  $ 2.55 
Total 2023 45  $ 2.75 
Natural Gas Two-Way Collars
Volume
(Bcf) 		Avg. NYMEX
Bought Put Price 		Avg. NYMEX
Sold Call Price
Q3 2021(a)
8  $ 2.80  $ 3.29 
Q4 2021 8  $ 2.80  $ 3.29 
Total 2021 16  $ 2.80  $ 3.29 
Total 2022 96  $ 2.45  $ 2.88 
Natural Gas Basis Protection Swaps
Volume
(Bcf) 		Avg. NYMEX
plus/(minus)
Q3 2021(a)
58  $ (0.75)
Q4 2021 34  $ (0.34)
Total 2021 92  $ (0.60)
Total 2022 66  $ 0.43 
Total 2023 23  $ 0.76 
____________________________________________
(a)Includes amounts settled in July and August 2021.
11

NON-GAAP FINANCIAL MEASURES

As a supplement to the financial results prepared in accordance with U.S. GAAP, Chesapeake’s quarterly earnings releases contain certain financial measures that are not prepared or presented in accordance with U.S. GAAP. These non-GAAP financial measures include Adjusted Net Income (Loss) Attributable to Chesapeake, Adjusted EBITDAX, Free Cash Flow and Net Debt. A reconciliation of each financial measure to its most directly comparable GAAP financial measure is included in the tables below.

These financial measures are non-GAAP and should not be considered as an alternative to, or more meaningful than, net income (loss), earnings (loss) per common share or cash flow provided by operating activities prepared in accordance with GAAP.

Chesapeake believes that the non-GAAP measures presented, when viewed in combination with its financial measures prepared in accordance with GAAP, provide useful information as they exclude certain items management believes affects the comparability of operating results. Management believes these adjusted financial measures are a meaningful adjunct to earnings and cash flows calculated in accordance with GAAP because (a) management uses these financial measures to evaluate the company’s trends and performance relative to other oil and natural gas producing companies, (b) these financial measures are comparable to estimates provided by securities analysts, and (c) items excluded generally are one-time items or items whose timing or amount cannot be reasonably estimated. Accordingly, any guidance provide by the company generally excludes information regarding these types of items.

Because not all companies use identical calculations, Chesapeake’s non-GAAP measures may not be comparable to similar titled measures of other companies.

12

RECONCILIATION OF ADJUSTED NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE (unaudited)
Successor Predecessor
Three Months Ended
June 30, 2021 		Three Months Ended
June 30, 2020
$ $/Share $ $/Share
($ in millions, except per share data)
Net loss available to common stockholders (GAAP) $ (439) $ (4.48) $ (276) $ (28.22)
Effect of dilutive securities —  —  —  — 
Diluted loss available to common stockholders (GAAP) $ (439) $ (4.48) $ (276) $ (28.22)
Adjustments:
Unrealized losses on oil, natural gas and NGL derivatives 617  6.30  864  88.35 
Separation and other termination costs 11  0.11  22  2.25 
Gains on sales of assets (2) (0.02) —  — 
Other operating income (4) (0.04) (2) (0.20)
Impairments 1  0.01  —  — 
Gains on purchases or exchanges of debt —  —  (2) (0.20)
G&A reorganization expenses —  —  43  4.40 
Reorganization items, net —  —  (394) (40.29)
Other (3) (0.03) (1) (0.10)
 Effect of dilutive securities —  (0.21) —  (2.23)
Adjusted net income attributable to common stockholders (Non-GAAP) $ 181  $ 1.64  $ 254  $ 23.76 












13

Successor Predecessor
Period from
February 10, 2021 through
June 30, 2021 		Period from
January 1, 2021 through
February 9, 2021 		Six Months Ended
June 30, 2020
$ $/Share $ $/Share $ $/Share
($ in millions, except per share data)
Net income (loss) available to common stockholders (GAAP) $ (144) $ (1.47) $ 5,383  $ 550.35  $ (8,595) $ (880.18)
Effect of dilutive securities —  —  —  (14.84) —  — 
Diluted income (loss) available to common stockholders (GAAP) $ (144) $ (1.47) $ 5,383  $ 534.51  $ (8,595) $ (880.18)
Adjustments:
Unrealized losses on oil, natural gas and NGL derivatives 504  5.15  369  36.64  135  13.82 
Separation and other termination costs 11  0.11  22  2.18  27  2.76 
Gains on sales of assets (6) (0.06) (5) (0.50) —  — 
Other operating expense (income) (2) (0.02) (12) (1.19) 66  6.76 
Impairments 1  0.01  —  —  8,522  872.71 
Exploration expense - impairment of unproved properties —  —  —  —  272  27.85 
Noncontrolling interests - impairment of unproved properties —  —  —  —  (16) (1.64)
Gains on purchases or exchanges of debt —  —  —  —  (65) (6.66)
G&A reorganization expenses —  —  —  —  43  4.40 
Reorganization items, net —  —  (5,569) (552.97) (394) (40.35)
Other (24) (0.25) —  —  22  2.25 
Tax effect of adjustments(a)
—  —  (57) (5.66) (11) (1.13)
Effect of dilutive securities —  (0.36) —  —  —  (0.03)
Adjusted net income available to common stockholders (Non-GAAP)
340  3.11  131  13.01  6  0.56 
Preferred stock dividends —  —  —  —  22  2.06 
Adjusted net income attributable to Chesapeake (Non-GAAP) $ 340  $ 3.11  $ 131  $ 13.01  $ 28  $ 2.62 
(a)
2021 Predecessor Period includes an income tax benefit of $57 million attributed to deferred income tax effects associated with predecessor accumulated other comprehensive income, eliminated in fresh start accounting. 2020 Predecessor Period includes a deferred tax benefit attributed to the reconciling adjustments using a 0.14% effective tax rate.
14

RECONCILIATION OF NET INCOME (LOSS) TO ADJUSTED EBITDAX (unaudited)
Successor Predecessor
Three Months Ended
June 30, 2021 		Three Months Ended
June 30, 2020
($ in millions)
Net loss (GAAP) $ (439) $ (276)
Adjustments:
Interest expense 18  137 
Depreciation, depletion and amortization 229  158 
Exploration 1  130 
Unrealized losses on oil, natural gas and NGL derivatives 617  864 
Separation and other termination costs 11  22 
Gains on sales of assets (2) — 
Other operating income (4) (2)
Impairments 1  — 
Gains on purchases or exchanges of debt —  (2)
G&A reorganization expenses —  43 
Reorganization items, net —  (394)
Other (3) (1)
Adjusted EBITDAX (Non-GAAP) $ 429  $ 679 

Successor Predecessor Non-GAAP Combined Predecessor
Period from February 10, 2021 through June 30, 2021 Period from January 1, 2021 through February 9, 2021 Six Months Ended
June 30, 2021 		Six Months Ended
June 30, 2020
($ in millions)
Net income (loss) (GAAP) $ (144) $ 5,383  $ 5,239  $ (8,589)
Adjustments:
Interest expense 30  11  41  282 
Income tax benefit —  (57) (57) (13)
Depreciation, depletion and amortization 351  72  423  761 
Exploration 2  2  4  412 
Unrealized losses on oil, natural gas and NGL derivatives 504  369  873  135 
Separation and other termination costs 11  22  33  27 
Gains on sales of assets (6) (5) (11) — 
Other operating expense (income) (2) (12) (14) 66 
Impairments 1  —  1  8,522 
Gains on purchases or exchanges of debt —  —  —  (65)
G&A reorganization expenses —  —  —  43 
Reorganization items, net —  (5,569) (5,569) (394)
Other (24) —  (24) 22 
Adjusted EBITDAX (Non-GAAP) $ 723  $ 216  $ 939  $ 1,209 

15

FREE CASH FLOW
Successor Predecessor
Three Months Ended
June 30, 2021 		Three Months Ended
June 30, 2020
($ in millions)
Net cash provided by operating activities (GAAP) $ 394  $ 376 
Cash paid for reorganization items, net 47  55 
Capital expenditures (149) (349)
Free cash flow (Non-GAAP) $ 292  $ 82 

Successor Predecessor Non-GAAP Combined Predecessor
Period from February 10, 2021 through June 30, 2021 Period from January 1, 2021 through February 9, 2021 Six Months Ended
June 30, 2021 		Six Months Ended
June 30, 2020
($ in millions)
Net cash provided by (used in) operating activities (GAAP) $ 803  $ (21) $ 782  $ 773 
Cash paid for reorganization items, net 65  66  131  55 
Capital expenditures (226) (66) (292) (867)
Free cash flow (Non-GAAP) $ 642  $ (21) $ 621  $ (39)

NET DEBT
Successor
June 30, 2021
($ in millions)
Total debt (GAAP) $ 1,261 
Premiums and issuance costs on debt (40)
Principal amount of debt 1,221 
Cash and cash equivalents (612)
Net debt (Non-GAAP) $ 609 
16
Exhibit 99.3
CHESAPEAKE ENERGY CORPORATION - MANAGEMENT’S OUTLOOK AS OF AUGUST 10, 2021

Chesapeake periodically provides guidance on certain factors that affect the company’s future financial performance. New information or changes from the company's May 11, 2021 outlook are italicized bold below.
Year Ending
12/31/2021
Total production:
Oil - mmbbls 23.5 - 25.5
NGL - mmbbls 6.5 - 8.5
Natural gas - bcf 725 - 745
Total daily rate - mboe per day 415 - 435
Estimated basis to NYMEX prices, based on 7/30/21 strip prices:
Oil - $/bbl ($0.90) - ($1.30)
Natural gas - $/mcf ($0.40) - ($0.50)
NGL - realizations as a % of WTI 40% - 45%
Operating costs per boe of projected production:
Production expense $1.85 - $2.15
Gathering, processing and transportation expenses
$4.90 - $5.40
Oil - $/bbl $2.65 - $2.85
Natural Gas - $/mcf $0.90 - $1.00
Severance and ad valorem taxes $0.90 - $1.10
General and administrative(a)
$0.75 - $0.95
Depreciation, depletion and amortization expense
$5.00 - $6.00
Marketing net margin and Other ($ in millions) $0 - $10
Interest expense ($ in millions)(b)
$70 - $80
Cash taxes ($ in millions) $0 - $20
Adjusted EBITDAX, based on 7/30/21 strip prices ($ in millions)(c)
$1,800 - $1,900
Total capital expenditures ($ in millions) $670 - $740
(a) Includes ~$0.08/boe of expenses associated with stock-based compensation, which are recorded in general and administrative expenses in Chesapeake's Condensed Consolidated Statement of Operations.
(b) Includes ~$15 million of non-cash interest expense due to timing of interest payments in 2021.
(c) Adjusted EBITDAX is a non-GAAP measure used by management to evaluate the company's operational trends and performance relative to other oil and natural gas producing companies. Adjusted EBITDAX excludes certain items that management believes affect the comparability of operating results. The most directly comparable GAAP measure is net income (loss), but it is not possible, without unreasonable efforts, to identify the amount or significance of events or transactions that may be included in future GAAP net income (loss) but that management does not believe to be representative of underlying business performance. The company further believes that providing estimates of the amounts that would be required to reconcile forecasted adjusted EBITDAX to forecasted GAAP net income (loss) would imply a degree of precision that may be confusing or misleading to investors. Items excluded from net income to arrive at adjusted EBITDAX include interest expense, income taxes, depreciation, depletion and amortization expense, and exploration expense as well as one-time items or items whose timing or amount cannot be reasonably estimated.
1