UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended ~~March 31,~~June 30, 2020

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE 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 incorporation or organization)			(I.R.S. Employer 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)



Securities Registered Pursuant to Section 12(b) of the Act:
Title of Each Class	Trading ~~Symbol(s)~~Symbol⁽¹⁾	Name of Each Exchange on Which Registered
Common Stock, par value $0.01	~~CHK~~CHKAQ	~~New York Stock Exchange~~N/A
6.625% Senior Notes due 2020	~~CHK20A~~*	~~New York Stock Exchange~~N/A
6.875% Senior Notes due 2020	~~CHK20~~*	~~New York Stock Exchange~~N/A
6.125% Senior Notes due 2021	~~CHK21~~*	~~New York Stock Exchange~~N/A
5.375% Senior Notes due 2021	~~CHK21A~~*	~~New York Stock Exchange~~N/A
4.875% Senior Notes due 2022	~~CHK22~~*	~~New York Stock Exchange~~N/A
5.75% Senior Notes due 2023	~~CHK23~~*	~~New York Stock Exchange~~N/A
4.5% Cumulative Convertible Preferred Stock	~~CHK Pr D~~*	~~New York Stock Exchange~~N/A

⁽¹⁾ On June 29, 2020, our common stock was suspended from trading on the New York Stock Exchange (the “NYSE”). On June 30, 2020, our common stock began trading on the OTC Pink Marketplace maintained by the OTC Markets Group, Inc. under the symbol “CHKAQ.” On July 20, 2020, the NYSE filed a Form 25 delisting our common stock, senior notes and cumulative convertible preferred stock from trading on the NYSE, which delisting became effective 10 days after the filing of the Form 25. In accordance with Rule 12d2-2 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), the de-registration of our common stock, senior notes and cumulative convertible preferred stock under Section 12(b) of the Exchange Act will become effective 90 days from the date of the Form 25 filing.

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 ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large Accelerated Filer ☒ Accelerated Filer ☐ Non-accelerated Filer ☐

Smaller Reporting Company ☐ 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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of ~~May~~August 7, 2020, there were ~~9,783,101~~9,780,335 shares of our $0.01 par value common stock outstanding.

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

INDEX TO FORM 10-Q FOR THE QUARTER ENDED ~~MARCH 31,~~JUNE 30, 2020



	PART I. FINANCIAL INFORMATION	Page
Item 1.	Condensed Consolidated Financial Statements (Unaudited)
	Condensed Consolidated Balance Sheets as of ~~March 31,~~June 30, 2020 and December 31, 2019	34
	Condensed Consolidated Statements of Operations for the Three and Six Months Ended ~~March 31,~~June 30, 2020 and 2019	56
	Condensed Consolidated Statements of Comprehensive Income for the Three and Six Months Ended ~~March 31,~~June 30, 2020 and 2019	67
	Condensed Consolidated Statements of Cash Flows for the ~~Three~~Six Months Ended ~~March 31,~~June 30, 2020 and 2019	78
	Condensed Consolidated Statements of Stockholders’ Equity for the Three and Six Months Ended ~~March 31,~~June 30, 2020 and 2019	910
	Notes to the Condensed Consolidated Financial Statements (Unaudited)
	Note 1. Chapter 11 Proceedings	11
	Note 2. Basis of Presentation and Summary of Significant Accounting Policies	10
	~~Note 2. Going Concern~~	1115
	Note 3. Earnings per Share	1217
	Note 4. Debt	1318
	Note 5. Contingencies and Commitments	1521
	Note 6. Other Liabilities	1623
	Note 7. Revenue	1724
	Note 8. Income Taxes	1826
	Note 9. Equity	2028
	Note 10. Share-Based Compensation	2029
	Note 11. Derivative and Hedging Activities	2332
	Note 12. Exploration Expense	2836
	Note 13. Impairments	2837
	Note 14. Capitalized Exploratory Well Costs	2938
	Note 15. Investments	2938
	Note 16. Other Operating Expense	2938
	Note 17. Separation and Other Termination Costs	38
	Note 18. Condensed Combined Debtor-in-Possession Financial Information	39
	Note 19. Subsequent Events	3042
	Supplementary ~~Data~~Information	3143
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3244
	Liquidity and Capital Resources	3447
	Results of Operations for the Three and Six Months Ended ~~March 31,~~June 30, 2020 and 2019	39
	~~Financial and Non-Financial Disclosures for Certain Securities Registered or Being Registered~~	4552
Item 3.	Quantitative and Qualitative Disclosure About Market Risk	4963
Item 4.	Controls and Procedures	5064
	PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	5165
Item 1A.	Risk Factors	5165
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	5371
Item 3.	Defaults Upon Senior Securities	5371
Item 4.	Mine Safety Disclosures	5371
Item 5.	Other Information	5371
Item 6.	Exhibits	5472
Signatures		5574

Table of Contents

~~PART I. FINANCIAL INFORMATION~~


ITEM 1.	Condensed Consolidated Financial Statements

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	March 31, 2020			December 31, 2019			June 30, 2020			December 31, 2019
	($ in millions)
ASSETS							($ in millions)
CURRENT ASSETS:
Cash and cash equivalents ($2 and $2 attributable to our VIE)	$	82		$	6		$	82		$	6
Accounts receivable, net	762			990			513			990
Short-term derivative assets	884			134			—			134
Other current assets	90			121			95			121
Total Current Assets	1,818			1,251			690			1,251
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on successful efforts accounting:
Proved oil and natural gas properties ($755 and $755 attributable to our VIE)	31,251			30,765			31,401			30,765
Unproved properties	1,870			2,173			1,743			2,173
Other property and equipment	1,812			1,810			1,803			1,810
Total Property and Equipment, at Cost	34,933			34,748			34,947			34,748
Less: accumulated depreciation, depletion and amortization (($748) and ($713) attributable to our VIE)	(29,110		)	(20,002		)	(29,255		)	(20,002		)
Property and equipment held for sale, net	10			10			10			10
Total Property and Equipment, Net	5,833			14,756			5,702			14,756
LONG-TERM ASSETS:
Other long-term assets	157			186			161			186
TOTAL ASSETS	$	7,808		$	16,193		$	6,553		$	16,193

TABLE OF CONTENTS

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED BALANCE SHEETS – (Continued)

(Unaudited)


	March 31, 2020			December 31, 2019			June 30, 2020			December 31, 2019
	($ in millions)
LIABILITIES AND EQUITY (DEFICIT)							($ in millions)
CURRENT LIABILITIES:
Accounts payable	$	552		$	498		$	39		$	498
Current maturities of long-term debt, net	420			385			1,929			385
Accrued interest	136			75			3			75
Short-term derivative liabilities	—			2			—			2
Other current liabilities ($1 and $1 attributable to our VIE)	1,152			1,432
Other current liabilities (nominal and $1 attributable to our VIE)							418			1,432
Total Current Liabilities	2,260			2,392			2,389			2,392
LONG-TERM LIABILITIES:
Long-term debt, net	9,163			9,073			—			9,073
Long-term derivative liabilities	22			2			—			2
Asset retirement obligations, net of current portion	206			200			209			200
Other long-term liabilities	81			125			8			125
Total Long-Term Liabilities	9,472			9,400
Liabilities subject to compromise							8,135			—
Total Liabilities							10,741			11,792
CONTINGENCIES AND COMMITMENTS (Note 5)
EQUITY:
Chesapeake Stockholders’ Equity:
EQUITY (DEFICIT):
Chesapeake Stockholders’ Equity (Deficit):
Preferred stock, $0.01 par value, 20,000,000 shares authorized 5,563,458 shares outstanding	1,631			1,631			1,631			1,631
Common stock, $0.01 par value, 22,500,000 and 15,000,000 shares authorized: 9,783,773 and 9,772,793 shares issued^(a)	—			—
Common stock, $0.01 par value, 22,500,000 and 15,000,000 shares authorized: 9,780,202 and 9,772,793 shares issued^(a)							—			—
Additional paid-in capital^(a)	16,920			16,973			16,924			16,973
Accumulated deficit	(22,517		)	(14,220		)	(22,793		)	(14,220		)
Accumulated other comprehensive income	21			12			29			12
Less: treasury stock, at cost; 0 and 26,224 common shares^(a)	—			(32		)	—			(32		)
Total Chesapeake Stockholders’ Equity (Deficit)	(3,945		)	4,364			(4,209		)	4,364
Noncontrolling interests	21			37			21			37
Total Equity (Deficit)	(3,924		)	4,401			(4,188		)	4,401
TOTAL LIABILITIES AND EQUITY	$	7,808		$	16,193
TOTAL LIABILITIES AND EQUITY (DEFICIT)							$	6,553		$	16,193


(a)	Amounts and shares have been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 179 for additional information.

TABLE OF CONTENTS

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Three Months Ended March 31,							Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019				2020			2019			2020			2019
	($ in millions except per share data)							($ in millions except per share data)
REVENUES AND OTHER:
Oil, natural gas and NGL	$	1,801		$	929			$	267		$	1,454		$	2,068		$	2,383
Marketing	724			1,233				240			916			964			2,149
Total Revenues	2,525			2,162				507			2,370			3,032			4,532
Other	16			15				14			15			30			30
Gains on sales of assets	—			19				—			1			—			20
Total Revenues and Other	2,541			2,196				521			2,386			3,062			4,582
OPERATING EXPENSES:
Oil, natural gas and NGL production	122			115				91			144			213			259
Oil, natural gas and NGL gathering, processing and transportation	285			274				270			271			555			545
Severance and ad valorem taxes	54			51				25			62			79			113
Exploration	282			24				130			15			412			39
Marketing	746			1,230				242			940			988			2,170
General and administrative	65			103				112			89			177			192
Restructuring and other termination costs	5			—
Separation and other termination costs								22			—			27			—
Provision for legal contingencies, net	1			—				7			3			8			3
Depreciation, depletion and amortization	603			519				158			580			761			1,099
Impairments	8,522			1				—			1			8,522			2
Other operating expense	83			61				5			3			88			64
Total Operating Expenses	10,768			2,378				1,062			2,108			11,830			4,486
LOSS FROM OPERATIONS	(8,227		)	(182		)
INCOME (LOSS) FROM OPERATIONS								(541		)	278			(8,768		)	96
OTHER INCOME (EXPENSE):
Interest expense	(145		)	(161		)
Interest expense (contractual interest for the three and six months ended June 30, 2020 of $173 and $355)								(137		)	(175		)	(282		)	(336		)
Losses on investments	(23		)	(1		)		—			(23		)	(23		)	(24		)
Gains on purchases or exchanges of debt	63			—				2			—			65			—
Other income	6			9				6			18			12			27
Total Other Expense	(99		)	(153		)
LOSS BEFORE INCOME TAXES	(8,326		)	(335		)
Reorganization items, net								394			—			394			—
Total Other Income (Expense)								265			(180		)	166			(333		)
INCOME (LOSS) BEFORE INCOME TAXES								(276		)	98			(8,602		)	(237		)
Income tax benefit	(13		)	(314		)		—			—			(13		)	(314		)
NET LOSS	(8,313		)	(21		)
NET INCOME (LOSS)								(276		)	98			(8,589		)	77
Net loss attributable to noncontrolling interests	16			—				—			—			16			—
NET LOSS ATTRIBUTABLE TO CHESAPEAKE	(8,297		)	(21		)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE								(276		)	98			(8,573		)	77
Preferred stock dividends	(22		)	(23		)		—			(23		)	(22		)	(46		)
NET LOSS AVAILABLE TO COMMON STOCKHOLDERS	$	(8,319	)	$	(44	)
LOSS PER COMMON SHARE:^(a)
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS								$	(276	)	$	75		$	(8,595	)	$	31
EARNINGS (LOSS) PER COMMON SHARE:^(a)
Basic	$	(852.97	)	$	(6.37	)		$	(28.22	)	$	9.21		$	(880.18	)	$	4.12
Diluted	$	(852.97	)	$	(6.37	)		$	(28.22	)	$	9.21		$	(880.18	)	$	4.12
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in thousands):^(a)							WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in thousands):^(a)
Basic	9,753			6,902				9,779			8,141			9,765			7,524
Diluted	9,753			6,902				9,779			8,141			9,765			7,524


(a)	All share and per share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 179 for additional information.

TABLE OF CONTENTS

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

Three Months Ended
March 31,
2020 2019
($ in millions)
NET LOSS $ (8,313 ) $ (21 )
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Reclassification of losses on settled derivative instruments^(a)
9
10
Other Comprehensive Income 9
10
COMPREHENSIVE LOSS (8,304 ) (11 )
COMPREHENSIVE LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS 16
—
COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE $ (8,288 ) $ (11 )



	Three Months Ended June 30,					Six Months Ended June 30,
	2020			2019		2020			2019
	($ in millions)
NET INCOME (LOSS)	$	(276	)	$	98	$	(8,589	)	$	77
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Reclassification of losses on settled derivative instruments^(a)	8			8		17			18
Other Comprehensive Income	8			8		17			18
COMPREHENSIVE INCOME (LOSS)	(268		)	106		(8,572		)	95
COMPREHENSIVE (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	—			—		16			—
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	$	(268	)	$	106	$	(8,556	)	$	95


(a)	Deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

TABLE OF CONTENTS

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Three Months Ended March 31,						Six Months Ended June 30,
	2020			2019			2020			2019
	($ in millions)						($ in millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
NET LOSS	$	(8,313	)	$	(21	)
NET INCOME (LOSS)							$	(8,589	)	$	77
ADJUSTMENTS TO RECONCILE NET LOSS TO CASH PROVIDED BY OPERATING ACTIVITIES:
Depreciation, depletion and amortization	603			519			761			1,099
Deferred income tax benefit	(10		)	(314		)	(10		)	(314		)
Derivative (gains) losses, net	(907		)	304			(734		)	30
Cash receipts on derivative settlements, net	89			14			880			15
Stock-based compensation	5			6			9			17
Gains on sales of assets	—			(19		)	—			(20		)
Impairments	8,522			1			8,522			2
Non-cash reorganization items, net							(449		)	—
Exploration	279			18			406			25
Losses on investments	23			1			23			18
Gains on purchases or exchanges of debt	(63		)	—			(65		)	—
Other	8			40			(22		)	41
Changes in assets and liabilities	161			(93		)	41			(137		)
Net Cash Provided By Operating Activities	397			456			773			853
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(501		)	(515		)	(843		)	(1,070		)
Business combination, net	—			(353		)	—			(353		)
Acquisitions of proved and unproved properties	(6		)	(6		)	(9		)	(17		)
Proceeds from divestitures of proved and unproved properties	7			26			7			82
Additions to other property and equipment	(11		)	(9		)	(15		)	(18		)
Proceeds from sales of other property and equipment	—			1			4			4
Net Cash Used In Investing Activities	(511		)	(856		)	(856		)	(1,372		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	2,331			3,572
Payments on revolving credit facility borrowings	(2,021		)	(3,136		)
Proceeds from pre-petition revolving credit facility borrowings							3,806			6,416
Payments on pre-petition revolving credit facility borrowings							(3,467		)	(5,452		)
Cash paid to purchase debt	(93		)	(1		)	(95		)	(381		)
DIP credit facility financing costs							(55		)	—
Cash paid for preferred stock dividends	(22		)	(23		)	(22		)	(46		)
Other	(5		)	(8		)	(8		)	(18		)
Net Cash Provided By Financing Activities	190			404			159			519
Net increase in cash and cash equivalents	76			4			76			—
Cash and cash equivalents, beginning of period	6			4			6			4
Cash and cash equivalents, end of period	$	82		$	8		$	82		$	4

TABLE OF CONTENTS

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS – (Continued)

(Unaudited)

													Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
	Three Months Ended March 31,						Six Months Ended June 30,
	2020			2019			2020			2019
	($ in millions)						($ in millions)
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for reorganization items, net							$	55		$	—
Interest paid, net of capitalized interest	$	113		$	145		$	177		$	296
Income taxes paid, net of refunds received	$	—		$	(5	)	$	(2	)	$	(5	)

SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Common stock issued for business combination	$	—		$	2,037		$	—		$	2,037
Change in senior notes exchanged							$	—		$	35
Change in accrued drilling and completion costs	$	(29	)	$	39		$	(223	)	$	17

TABLE OF CONTENTS

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Unaudited)


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
	($ in millions)						($ in millions)
PREFERRED STOCK:
Balance, beginning and end of period	$	1,631		$	1,671		$	1,631		$	1,671		$	1,631		$	1,671
COMMON STOCK:^(a)
Balance, beginning of period	—			—			—			—			—			—
Common shares issued for WildHorse Merger	—			—			—			—			—			—
Balance, end of period	—			—			—			—			—			—
ADDITIONAL PAID-IN CAPITAL:^(a)
Balance, beginning of period	16,973			14,387			16,920			16,408			16,973			14,387
Common shares issued for WildHorse Merger	—			2,037			—			—			—			2,037
Stock-based compensation	(31		)	7			4			11			(27		)	18
Dividends on preferred stock	(22		)	(23		)	—			(23		)	(22		)	(46		)
Balance, end of period	16,920			16,408			16,924			16,396			16,924			16,396
ACCUMULATED DEFICIT:
Balance, beginning of period	(14,220		)	(13,912		)	(22,517		)	(13,933		)	(14,220		)	(13,912		)
Net loss attributable to Chesapeake	(8,297		)	(21		)
Net income (loss) attributable to Chesapeake							(276		)	98			(8,573		)	77
Balance, end of period	(22,517		)	(13,933		)	(22,793		)	(13,835		)	(22,793		)	(13,835		)
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS):
Balance, beginning of period	12			(23		)	21			(13		)	12			(23		)
Hedging activity	9			10			8			8			17			18
Balance, end of period	21			(13		)	29			(5		)	29			(5		)
TREASURY STOCK – COMMON:^(a)
Balance, beginning of period	(32		)	(31		)	—			(36		)	(32		)	(31		)
Purchase of 17,901 and 12,697 shares for company benefit plans	(2		)	(6		)
Release of 44,126 and 553 shares from company benefit plans	34			1
Purchase of 0, 405, 17,901 and 13,102 shares for company benefit plans							—			(1		)	(2		)	(7		)
Release of 0, 744, 44,126 and 1,297 shares from company benefit plans							—			1			34			2
Balance, end of period	—			(36		)	—			(36		)	—			(36		)
TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY (DEFICIT)	(3,945		)	4,097			(4,209		)	4,191			(4,209		)	4,191
NONCONTROLLING INTERESTS:
Balance, beginning of period	37			41			21			41			37			41
Net loss attributable to noncontrolling interests	(16		)	—			—			—			(16		)	—
Distributions to noncontrolling interest owners							—			(2		)	—			(2		)
Balance, end of period	21			41			21			39			21			39
TOTAL EQUITY (DEFICIT)	$	(3,924	)	$	4,138		$	(4,188	)	$	4,230		$	(4,188	)	$	4,230


(a)	Amounts and shares have been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 179 for additional information.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)


1.	Chapter 11 Proceedings

Unless the context otherwise requires, references to “Chesapeake”, the “Company”, “us”, “we” and “our” in this report are to Chesapeake Energy Corporation together with its subsidiaries. On June 28, 2020, (the “Petition Date”) we and certain of our subsidiaries (collectively, the “Debtors”) filed voluntary petitions (the “Chapter 11 Cases”) for relief (the “Bankruptcy Filing”) under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”). On June 29, 2020, the Bankruptcy Court entered an order authorizing the joint administration of the Chapter 11 Cases under the caption In re Chesapeake Energy Corporation, Case No. 20-33233 (DRJ). Subsidiaries with noncontrolling interests, consolidated variable interest entities and certain de minimis subsidiaries (collectively, the “Non-Filing Entities”) were not part of the Bankruptcy Filing. The Non-Filing Entities will continue to operate in the ordinary course of business.

Debtor-In-Possession

We are currently operating as debtors in possession in accordance with the applicable provisions of the Bankruptcy Code. The Bankruptcy Court granted the first day relief we requested that was designed primarily to mitigate the impact of the Chapter 11 Cases on our operations, customers and employees. As a result, we are able to conduct normal business activities and pay all associated obligations for the period following the Bankruptcy Filing and are also authorized to pay owner royalties, employee wages and benefits, and certain vendors and suppliers in the ordinary course for goods and services provided prior to the Bankruptcy Filing. During the pendency of the Chapter 11 Cases, all transactions outside the ordinary course of business require the prior approval of the Bankruptcy Court.

Automatic Stay

Subject to certain specific exceptions under the Bankruptcy Code, the filing of the Chapter 11 Cases automatically stayed all judicial or administrative actions against us and efforts by creditors to collect on or otherwise exercise rights or remedies with respect to pre-petition claims. Absent an order from the Bankruptcy Court, substantially all of the Debtors’ pre-petition liabilities are subject to settlement under the Bankruptcy Code.

Restructuring Support Agreement

On June 28, 2020, the Debtors entered into a restructuring support agreement (the "RSA") with certain holders (collectively, the "Consenting Stakeholders") of (i) obligations under that certain Amended and Restated Credit Agreement, dated as of September 12, 2018, by and among Chesapeake, as borrower, the Debtor guarantors party thereto, MUFG Union Bank, N.A., as administrative agent, and the other lender, issuer, and agent parties thereto (the "pre-petition revolving credit facility"); (ii) obligations under that certain Term Loan Agreement, dated as of December 19, 2019, by and among Chesapeake, as borrower, the Debtor guarantors party thereto, GLAS USA LLC., as administrative agent, and the lender parties thereto (the "FLLO Term Loan"); and (iii) obligations under the 11.5% Senior Secured Second Lien Notes due 2025 (the "Second Lien Notes") issued pursuant to that certain indenture, dated as of December 19, 2019, by and among Chesapeake, as issuer, certain guarantors party thereto, and Deutsche Bank Trust Company Americas, as trustee and collateral trustee to support a restructuring (the "Restructuring") on the terms set forth in the RSA and the term sheet annexed to the RSA (the "Restructuring Term Sheet"). Certain Consenting Stakeholders also hold Unsecured Notes (as defined in the Restructuring Term Sheet) and their Unsecured Notes are also subject to the terms and obligations under the RSA. The RSA contemplates that the Company will implement the Restructuring through the Chapter 11 Cases pursuant to a consensual plan of reorganization (the "Plan") and the various related transactions set forth in or contemplated by the RSA and the Restructuring Term Sheet.

The RSA contains certain covenants on the part of each of the Company and the Consenting Stakeholders, including limitations on the parties’ ability to pursue alternative transactions (subject to customary provisions regarding the ability of the Company’s Board of Directors to satisfy its fiduciary duties), commitments by the Consenting Stakeholders to vote in favor of the Plan and commitments of the Company and the Consenting Stakeholders to negotiate in good faith to finalize the documents and agreements contemplated by and required to implement the Plan. The RSA also provides for certain conditions to the obligations of the parties and for termination upon the occurrence of certain events, including, without limitation, the failure to achieve certain milestones and certain breaches by the parties under the RSA. One such condition is the requirement to obtain sufficient savings on certain midstream obligations (as determined by the required plan sponsors, defined in the RSA) through rejection of such contracts and/or renegotiation of terms.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)

The RSA includes a hedging order that authorizes the Debtors to enter into post-petition hedge agreements with the lenders under the DIP Credit Facility (as defined below). Beginning 30 days after the Petition Date, the Debtors are required to, at a minimum, hedge 50% of the anticipated projected monthly production from proved developed producing oil and natural gas reserves (in each case, calculated separately for (i) crude oil and (ii) natural gas and natural gas liquids, taken together) for a rolling 24-month period. The Debtors notional hedge volumes shall not exceed (a) for the 24-month period from the date such commodity hedge transaction is executed, 90% of the anticipated projected monthly production from proved developed producing oil and natural gas reserves and (b) for the 24-month period thereafter, 80% of the anticipated projected monthly production from proved developed producing oil and natural gas reserves.

Although the Company intends to pursue the Restructuring in accordance with the terms set forth in the RSA, there can be no assurance that the Company will be successful in completing the Restructuring or any other similar transaction on the terms set forth in the RSA, on different terms, or at all.

Pursuant to the terms of the RSA and the Restructuring Term Sheet, below is a summary of the treatment that the stakeholders of the Company would receive under the Plan:

•

Holders of Other Secured Claims. Each holder of Other Secured Claims (as defined in the RSA) would receive, at the Company's option and in consultation with a requisite number of holders of claims who are backstopping a rights offering pursuant to the Plan: (a) payment in full in cash; (b) the collateral securing its secured claim; (c) reinstatement of its secured claim; or (d) such other treatment rendering its secured claim unimpaired in accordance with Section 1124 of the Bankruptcy Code.


•	Holders of Other Priority Claims. Each holder of Other Priority Claims (as defined in the RSA) would receive treatment in a manner consistent with Section 1129(a)(9) of the Bankruptcy Code.

•

Holders of Pre-Petition Revolving Credit Facility Claims. On the effective date of the Plan (the "Plan Effective Date"), each holder of obligations under the pre-petition revolving credit facility would receive, at such holder's option, its pro rata share of either Tranche A RBL Exit Facility Loans or Tranche B RBL Exit Facility Loans (each as defined in the Exit Facilities Term Sheet, defined below), each on a dollar for dollar basis.

Holders of FLLO Term Loan Facility Claims. On the Plan Effective Date, each holder of obligations under the FLLO Term Loan Facility would receive its pro rata share of (i) 76% of the reorganized Company's new common equity interests (the "New Common Stock"), subject to the terms set forth in the Restructuring Term Sheet and (ii) the right to participate in a rights offering on the terms set forth in the Restructuring Term Sheet.

•

Holders of Second Lien Notes Claims. On the Plan Effective Date, each holder of the Second Lien Notes would receive its pro rata share of (i) 12% of the New Common Stock, subject to the terms set forth in the Restructuring Term Sheet, (ii) the right to participate in a rights offering on the terms set forth in the Restructuring Term Sheet, and (iii) warrants to purchase 10% of the New Common Stock on certain terms set forth in the Restructuring Term Sheet, warrants to purchase another 10% of the New Common Stock on certain other terms set forth in the Restructuring Term Sheet, and 50% of warrants to purchase another 10% of the New Common Stock on certain other terms set forth in the Restructuring Term Sheet (the "New Class C Warrants").


•	Holders of Unsecured Notes Claims. On the Plan Effective Date, each holder of the Unsecured Notes (as defined in the RSA) would receive its pro rata share of (i) 12% of the New Common Stock, subject to the terms set forth in the Restructuring Term Sheet (the "Unsecured Claims Recovery"), and (ii) 50% of the New Class C Warrants.


•	Holders of General Unsecured Claims. On the Plan Effective Date, each holder of allowed general unsecured claims would receive its pro rata share of the Unsecured Claims Recovery.


•	Equity Holders. Each holder of an equity interest in Chesapeake, including our common and preferred stock, would have such interest canceled, released, and extinguished without any distribution.

DIP Credit Facility

On June 28, 2020, prior to the commencement of the Chapter 11 Cases, the Company entered into a commitment letter (the “Commitment Letter”) with certain of the lenders under the pre-petition revolving credit facility and/or their

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(Unaudited)

affiliates (collectively, the “Commitment Parties”), pursuant to which, and subject to the satisfaction of certain customary conditions, including the approval of the Bankruptcy Court, the Commitment Parties agreed to provide the Debtors with a post-petition senior secured super-priority debtor-in-possession revolving credit facility in an aggregate principal amount of up to approximately $2.104 billion (the “DIP Credit Facility”), consisting of a revolving loan facility of new money in an aggregate principal amount of up to $925 million, which includes a sub-facility of up to $200 million for the issuance of letters of credit, and an up to approximately $1.179 billion term loan that reflects the roll-up of a portion of outstanding borrowings under the pre-petition revolving credit facility. Pursuant to the Commitment Letter, the Commitment parties have also committed to provide, subject to certain conditions, an up to $2.5 billion exit credit facility, consisting of an up to $1.75 billion revolving credit facility (the “Exit Revolving Facility”) and an up to $750 million senior secured term loan facility (the “Exit Term Loan Facility” and, together with the Exit Revolving Facility, the “Exit Credit Facilities”). The terms and conditions of the DIP Credit Facility are set forth in the DIP Credit Agreement (the “DIP Credit Agreement”) attached to the Commitment Letter. The proceeds of the DIP Credit Facility may be used for, among other things, post-petition working capital, permitted capital investments, general corporate purposes, letters of credit, administrative costs, premiums, expenses and fees for the transactions contemplated by the Chapter 11 Cases, payment of court approved adequate protection obligations, and other such purposes consistent with the DIP Credit Facility. The terms and conditions of the Exit Credit Facilities are reflected in an exit facilities term sheet attached as an exhibit to the Restructuring Term Sheet (the “Exit Facilities Term Sheet”). The Exit Credit Facilities are subject to satisfaction of certain conditions set forth in the Exit Facilities Term Sheet, including compliance with (i) a minimum liquidity of $500 million, (ii) a 2.25:1.00 leverage ratio test and (iii) asset coverage of credit facilities to PV-10 of at least 1.50:1.00. See Note 4 for additional information.

Executory Contracts

Subject to certain exceptions, under the Bankruptcy Code, we may assume, assign, or reject certain executory contracts and unexpired leases subject to the approval of the Bankruptcy Court and certain other conditions. Generally, the rejection of an executory contract or unexpired lease is treated as a pre-petition breach of such executory contract or unexpired lease and, subject to certain exceptions, relieves us from performing our future obligations under such executory contract or unexpired lease but entitles the contract counterparty or lessor to a pre-petition general unsecured claim for damages caused by such deemed breach. Counterparties to rejected contracts or leases may assert unsecured claims in the Bankruptcy Court against our estate for such damages. Generally, the assumption of an executory contract or unexpired lease requires us to cure existing monetary defaults under such executory contract or unexpired lease and provide adequate assurance of future performance. Accordingly, any description of an executory contract or unexpired lease with us, including where applicable a quantification of our obligations under any such executory contract or unexpired lease of us, is qualified by any overriding rejection rights we have under the Bankruptcy Code.

Potential Claims

We have filed with the Bankruptcy Court schedules and statements setting forth, among other things, the assets and liabilities of us and each of our subsidiaries, subject to the assumptions filed in connection therewith. These schedules and statements may be subject to further amendment or modification after filing. Certain holders of pre-petition claims that are not governmental units are required to file proofs of claim by the deadline for general claims, (the “bar date”), which was set by the Bankruptcy Court as September 25, 2020.

As of August 5, 2020, the Debtors have received approximately 250 proofs of claim, not including proofs of claim related to the Healthcare of Ontario Pension Plan (HOOPP) disclosed in Note 5, primarily representing general unsecured claims, for an aggregate amount of approximately $75 million. Differences between amounts scheduled by us and claims by creditors are being investigated and will be reconciled and resolved to within an immaterial amount in connection with the claims resolution process. In light of the expected number of creditors, the claims resolution process may take considerable time to complete and likely will continue after we emerge from bankruptcy.

Financial Statement Classification of Liabilities Subject to Compromise

The accompanying unaudited condensed consolidated balance sheet as of June 30, 2020, includes amounts classified as liabilities subject to compromise, which represent liabilities we anticipate will be allowed as claims in the Chapter 11 Cases. These amounts represent our current estimate of known or potential obligations to be resolved in connection with the Chapter 11 Cases, and may differ from actual future settlement amounts paid. Differences between liabilities estimated and claims filed, or to be filed, will be investigated and resolved in connection with the claims resolution process. We will continue to evaluate these liabilities throughout the Chapter 11 process and adjust amounts as necessary. Such adjustments may be material.

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(Unaudited)

Liabilities subject to compromise includes amounts related to the rejection of various executory contracts and unexpired leases. Additional amounts may be included in liabilities subject to compromise in future periods if additional executory contracts and unexpired leases are rejected. The nature of many of the potential claims arising under our executory contracts and unexpired leases has not been determined at this time, and therefore, such claims are not reasonably estimable at this time and may be material.

The following table summarizes the components of liabilities subject to compromise included on our unaudited condensed consolidated balance sheet as of June 30, 2020:



	June 30, 2020
	($ in millions)
Debt	$	7,166
Accounts payable	250
Accrued interest	235
Other liabilities	484
Liabilities subject to compromise	$	8,135

Reorganization Items, Net

We have incurred and will continue to incur significant expenses, gains and losses associated with the reorganization, primarily the write-off of unamortized debt issuance costs and related unamortized premiums and discounts and legal and professional fees incurred subsequent to the Chapter 11 filings for the restructuring process. The amount of these items, which are being incurred in reorganization items, net within our accompanying unaudited condensed consolidated statements of operations, are expected to significantly affect our results of operations. In future periods, we may also incur adjustments for allowable claims related to our legal proceedings and executory contracts approved for rejections by the Bankruptcy Court.

The following table summarizes the components included in reorganization items for the three and six months ended June 30, 2020:



	Three and Six Months Ended June 30, 2020
	($ in millions)
Write off of unamortized debt premiums (discounts)	$	518
Write off of unamortized debt issuance costs	(61		)
DIP credit facility financing costs	(63		)
Reorganization items, net	$	394

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


2.	Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

The accompanying condensed consolidated financial statements of Chesapeake were prepared in accordance with accounting principles generally accepted in the United States of America and the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures have been condensed or omitted.

This Quarterly Report on Form 10-Q (this “Form 10-Q”) relates to the three and six months ended ~~March 31,~~June 30, 2020 (the “Current Quarter”) and the “Current Period”, respectively) and the three and six months ended ~~March 31,~~June 30, 2019 (the “Prior Quarter”) and the “Prior Period”, respectively). Our annual report on Form 10-K for the year ended December 31, 2019 (“2019 Form 10-K”) should be read in conjunction with this Form 10-Q. The accompanying condensed consolidated financial statements reflect all normal recurring adjustments which, in the opinion of management, are necessary for a fair statement of our condensed consolidated financial statements and accompanying notes and include the accounts of our direct and indirect wholly owned subsidiaries and entities in which we have a controlling financial interest. Intercompany accounts and balances have been eliminated.

Going Concern

The accompanying condensed consolidated financial statements have been prepared assuming we will continue as a going concern and contemplate the realization of assets and satisfaction of liabilities in the normal course of business. Our ability to continue as a going concern is contingent on our ability to comply with the financial and other covenants contained in our DIP Credit Facility, the Bankruptcy Court’s approval of the Plan and our ability to successfully implement the Plan and obtain exit financing, among other factors. As a result of the Bankruptcy Filing, the realization of assets and the satisfaction of liabilities are subject to uncertainty. While operating as debtors-in-possession under Chapter 11, we may sell or otherwise dispose of or liquidate assets or settle liabilities, subject to the approval of the Bankruptcy Court or as otherwise permitted in the ordinary course of business (and subject to restrictions contained in the DIP Credit Facility), for amounts other than those reflected in the accompanying condensed consolidated financial statements. Further, the Plan could materially change the amounts and classifications of assets and liabilities reported in the condensed consolidated financial statements. The factors noted above raise substantial doubt about our ability to continue as a going concern. The accompanying condensed consolidated financial statements do not include any adjustments related to the recoverability and classification of assets or the amounts and classification of liabilities or any other adjustments that might be necessary should we be unable to continue as a going concern or as a consequence of the Bankruptcy Filing.

Accounting During Bankruptcy

We have applied Accounting Standards Codification (ASC) 852 Reorganizations in preparing the unaudited condensed consolidated financial statements. ASC 852 requires that the financial statements, for periods subsequent to the Chapter 11 Cases, distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Accordingly, certain revenues, expenses, realized gains and losses and provisions for losses that are realized or incurred during the bankruptcy proceedings, including losses related to executory contracts that have been approved for rejection by the Bankruptcy Court, and unamortized deferred financing costs, premiums and discounts associated with debt classified as liabilities subject to compromise, are recorded as reorganization items. In addition, pre-petition obligations that may be impacted by the Chapter 11 process have been classified on the unaudited condensed consolidated balance sheet as of June 30, 2020 as liabilities subject to compromise. These liabilities are reported at the amounts we anticipate will be allowed by the Bankruptcy Court, even if they may be settled for lesser amounts. See Note 1 for more information regarding reorganization items.

Risks and Uncertainties

~~On March 11, 2020,~~The global spread of COVID-19 created significant volatility, uncertainty, and economic disruption during the ~~World Health Organization declared the ongoing coronavirus (COVID-19) outbreak a pandemic and recommended containment and mitigation measures worldwide.~~first six months of 2020. The pandemic has reached more than 200 countries and territories and has resulted in widespread adverse impacts on the global economy and on our customers and other parties with whom we have business relations. State and local authorities have also implemented multi-step policies with the goal of re-opening. However, certain jurisdictions began re-opening only to return to restrictions in the face of increases in new COVID-19 cases. To date, we have experienced limited operational impacts as a result of the restrictions from working remotely or COVID-19 directly. As an essential business under the guidelines issued by each of the states in which we operate, we have been allowed to continue ~~operations, although for the health and safety of our employees we chose to have our non-essential personnel work remotely.~~operations. As a result, since mid-March, we have restricted access to all of our offices and ~~have~~for a

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(Unaudited)

period of time directed employees to work remotely to the extent possible. ~~Those employees who are unable~~We began to ~~work remotely are being closely monitored~~re-open our offices in phases beginning mid-May and ~~are taking safety~~special precautions have been implemented to minimize the risk of exposure. These ~~restrictions~~actions have allowed us to maintain the engagement and connectivity of our ~~personnel, as well as minimize the number of employees required in the office and field.~~personnel. However, due to severe impacts from the global COVID-19 pandemic on the global demand for oil and natural gas, financial results may not be necessarily indicative of operating results for the ~~three months ended March 31, 2020 are not necessarily indicative of financial results for the~~ entire ~~year as only one month of the Current Quarter was impacted by COVID-19 and the related economic volatility.~~year. Moreover, future operations could be negatively affected if a significant number of our employees are quarantined as a result of exposure to the virus.

There is considerable uncertainty regarding the extent to which COVID-19 will continue to spread and the extent and duration of governmental and other measures implemented to try to slow the spread of the virus, such as large-scale travel bans and restrictions, border closures, quarantines, shelter-in-place orders and business and government shutdowns. One of the largest impacts of the pandemic has been a significant reduction in global demand for oil and, to a lesser extent, natural gas. This significant decline in demand has been met with a sharp decline in oil prices following the announcement of price reductions and production increases in March 2020 by members of the Organization of Petroleum Exporting Countries (OPEC+) and other foreign, oil-exporting countries. Further, in April 2020, OPEC+ finalized an agreement to cut oil production by 9.7 million barrels per day during May and June 2020. On June 6, 2020, OPEC+ agreed to extend such production cuts until the end of July 2020. However, prices in the oil and gas market have remained depressed, as the oversupply and lack of demand in the market persist. Oil and natural gas prices are expected to continue to be volatile as a result of the near-term production instability and the ongoing COVID-19 outbreaks and as changes in oil and natural gas inventories, industry demand and global and national economic performance are reported. The resulting supply/demand imbalance is having disruptive impacts on the oil and natural gas exploration and production industry and on other industries that serve exploration and production companies. ~~These industry conditions, coupled with those resulting from the COVID-19 pandemic, are expected to lead to significant global economic contraction generally and in our industry in particular.~~

Oil and natural gas prices have historically been volatile; however, the volatility in the prices for these commodities has substantially increased as a result of COVID-19 and the OPEC+ decisions mentioned above. While an agreement to cut production has since been announced by OPEC+ and its allies, the situation, coupled with the impact of COVID-19, has continued to result in a significant downturn in the oil and gas industry. Oil prices declined sharply in April 2020 and remain volatile. Strip pricing for natural gas has increased as a result of the oil price war; however, the impact of these recent developments and our business are unpredictable. We expect to see continued volatility in oil and natural gas prices for the foreseeable future, and such volatility, combined with the current depressed prices, has impacted and is expected to continue to adversely impact our business. AThe continued low level of demand orand prices for oil and natural gas or otherwise ~~would~~has had and will continue to have a ~~continued~~ material adverse effect on our business, cash flows, liquidity, financial condition and results of operations.

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~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

We cannot predict the full impact that COVID-19 or the significant disruption and volatility currently being experienced in the oil and natural gas markets will have on our business, cash flows, liquidity, financial condition and results of operations at this time due to numerous uncertainties. The ultimate impacts will depend on future developments, including the ultimate geographic spread of the virus, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, the duration of the outbreak, actions taken by members of OPEC+ and other foreign, oil-exporting countries, governmental authorities, customers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume.

~~Reverse Stock Split~~

On April 13, 2020, our Board of Directors and our shareholders approved a 1-for-200 (1:200) reverse stock split of our common stock and a reduction in the total number of authorized shares of our common stock as determined by a formula based on two-thirds of the reverse stock split ratio. The reverse stock split became effective as of the close of business on April 14, 2020. Our common stock began trading on a split-adjusted basis on the New York Stock Exchange (NYSE) at the market open on April 15, 2020. The par value of the common stock was not adjusted as a result of the reverse stock split. All share and per share data have been retroactively adjusted to reflect this reverse stock split, including reclassifying an amount equal to the reduction in par value of our common stock to additional paid-in capital. See ~~Note 17~~ ~~for additional information.~~


2.	~~Going Concern~~

Fluctuations in oil and natural gas prices have a material impact on our financial position, results of operations, cash flows and quantities of oil, natural gas and NGL reserves that may be economically produced. Historically, oil and natural gas prices have been volatile; however, the volatility in the prices for these commodities has substantially increased as a result of COVID-19 and the OPEC+ decisions discussed in ~~Note 1~~. We expect to see continued volatility in oil and natural gas prices for the foreseeable future, and such volatility, combined with the current depressed prices has impacted and is expected to continue to adversely impact our business. If the current depressed prices persist, combined with the scheduled reductions in the leverage ratio covenant and an expected significant reduction in our borrowing base in our scheduled determination, then our liquidity and our ability to comply with our financial covenants during the next 12 months will be adversely affected. Based on our current forecast, we do not expect to be in compliance with our financial covenants beginning in the fourth quarter of 2020. Failure to comply with these covenants, if not waived, would result in an event of default under our revolving credit facility, the potential acceleration of outstanding debt thereunder and the potential foreclosure on the collateral securing such debt, and could cause a cross-default under our other outstanding indebtedness.

As a result of the impacts to the Company’s financial position resulting from declining industry conditions and in consideration of the substantial amount of long-term debt outstanding, the Company has engaged advisors to assist with the evaluation of strategic alternatives, which may include, but not be limited to, seeking a restructuring, amendment or refinancing of existing debt through a private restructuring or reorganization under Chapter 11 of the Bankruptcy Code. However, there can be no assurances that the Company will be able to successfully restructure its indebtedness, improve its financial position or complete any strategic transactions. As a result of these uncertainties and the likelihood of a restructuring or reorganization, management has concluded that there is substantial doubt about the Company’s ability to continue as a going concern. The condensed consolidated financial statements (i) have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities and other commitments in the normal course of business and (ii) do not include any adjustments to reflect the possible future effects of the uncertainty on the recoverability or classification of recorded asset amounts or the amounts or classifications of liabilities.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)

3. Earnings Per Share

Basic earnings per share (EPS) is calculated using the weighted average number of common shares outstanding during the period and includes the effect of any participating securities as appropriate. Participating securities consist of unvested restricted stock issued to our employees and non-employee directors that provide dividend rights.

Diluted EPS is calculated assuming the issuance of common shares for all potentially dilutive securities, provided the effect is not antidilutive. For all periods presented, our convertible senior notes did not have a dilutive effect and, therefore, were excluded from the calculation of diluted EPS.

Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive:


	Three Months Ended March 31,		Three Months Ended June 30,		Six Months Ended June 30,
	2020	2019	2020	2019	2020	2019
	(in thousands)		(in thousands)
Common stock equivalent of our preferred stock outstanding^(a)	290	298	290	298	290	298
Common stock equivalent of our convertible senior notes outstanding^(a)	621	729	621	729	621	729
Participating securities^(a)	4	2	—	3	—	5


(a)	Amount has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 179 for additional information.

As a result of the Company’s reverse stock split effective on April 14, 2020, proportionate adjustments were made to the conversion price of Chesapeake’s outstanding 5.5% Convertible Senior Notes due 2026, 4.5% Cumulative Convertible Preferred Stock, 5.00% Cumulative Convertible Preferred Stock (Series 2005B), 5.75% Cumulative Convertible Non-Voting Preferred Stock (Series A) and 5.75% Cumulative Non-Voting Convertible Preferred Stock and to the outstanding awards and number of shares issued and issuable under the Company's equity compensation plans. See Note 179 for additional information.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


4.	Debt

Our long-term debt consisted of the following as of ~~March 31,~~June 30, 2020 and December 31, 2019:


	March 31, 2020						December 31, 2019						June 30, 2020						December 31, 2019
	Principal Amount			Carrying Amount			Principal Amount			Carrying Amount			Principal Amount			Carrying Amount			Principal Amount			Carrying Amount
	($ in millions)												($ in millions)
Revolving credit facility	$	1,900		$	1,900		$	1,590		$	1,590
Pre-petition revolving credit facility													$	1,929		$	1,929		$	1,590		$	1,590
Term loan due 2024	1,500			1,472			1,500			1,470			1,500			1,500			1,500			1,470
11.5% senior secured second lien notes due 2025	2,330			3,205			2,330			3,248			2,330			2,330			2,330			3,248
6.625% senior notes due 2020	177			177			208			208			176			176			208			208
6.875% senior notes due 2020	76			76			93			93			73			73			93			93
6.125% senior notes due 2021	167			167			167			167			167			167			167			167
5.375% senior notes due 2021	127			127			127			127			127			127			127			127
4.875% senior notes due 2022	272			272			338			338			272			272			338			338
5.75% senior notes due 2023	167			167			209			209			167			167			209			209
7.00% senior notes due 2024	624			624			624			624			624			624			624			624
6.875% senior notes due 2025	2			2			2			2			2			2			2			2
8.00% senior notes due 2025	246			245			246			245			246			246			246			245
5.5% convertible senior notes due 2026^(b)	1,064			773			1,064			765			1,064			1,064			1,064			765
7.5% senior notes due 2026	119			119			119			119			119			119			119			119
8.00% senior notes due 2026	46			44			46			44			46			46			46			44
8.00% senior notes due 2027	253			253			253			253			253			253			253			253
Debt issuance costs	—			(40		)	—			(44		)	—			—			—			(44		)
Total debt, net	9,070			9,583			8,916			9,458			9,095			9,095			8,916			9,458
Less current maturities of long-term debt, net^(c)	(420		)	(420		)	(385		)	(385		)
Less current maturities of long-term debt													(1,929		)	(1,929		)	(385		)	(385		)
Less amounts reclassified to liabilities subject to compromise													(7,166		)	(7,166		)	—			—
Total long-term debt, net	$	8,650		$	9,163		$	8,531		$	9,073		$	—		$	—		$	8,531		$	9,073

~~___________________________________________~~


~~(a)~~	We are required to account for the liability and equity components of our convertible debt instrument separately and to reflect interest expense through the first demand repurchase date, as applicable, at the interest rate of similar nonconvertible debt at the time of issuance. The applicable rate for our 5.5% Convertible Senior Notes due 2026 is 11.5%.


~~(b)~~	Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. During the Current Quarter, the price of our common stock was below the threshold level for conversion and, as a result, the holders do not have the option to convert their notes in the second quarter of 2020.


~~(c)~~	As of March 31, 2020, net current maturities of long-term debt includes our 6.625% Senior Notes due August 2020, our 6.875% Senior Notes due November 2020 and our 6.125% Senior Notes due February 2021. As of December 31, 2019, net current maturities of long-term debt includes our 6.625% Senior Notes due August 2020 and our 6.875% Senior Notes due November 2020.

Chapter 11 Proceedings

Filing of the Chapter 11 Cases constituted an event of default with respect to certain of our secured and unsecured debt obligations. As a result of the Chapter 11 Cases, the principal and interest due under these debt instruments became immediately due and payable. However, Section 362 of the Bankruptcy Code stays the creditors from taking any action as a result of the default.

The principal amounts outstanding under the FLLO Term Loan, Second Lien Notes and all of our other unsecured senior and convertible senior notes have been reclassified as liabilities subject to compromise on the accompanying unaudited condensed consolidated balance sheet at June 30, 2020. Additionally, non-cash adjustments were made to write off all of the related unamortized debt issuance costs and associated discounts and premiums of approximately $457 million are included in reorganization items, net in the accompanying unaudited condensed consolidated statements of operations for the three and six-month periods ended June 30, 2020, as discussed in Note 1.

Debtor-in-Possession Credit Agreement

On June 28, 2020, prior to the commencement of Chapter 11 Cases, the Company entered into a commitment letter with certain of the lenders (“New Money Lenders”) under the pre-petition revolving credit facility and/or their affiliates to provide the Debtors with a DIP Credit Facility in an aggregate principal amount of up to approximately $2.104 billion in commitments and loans from the New Money Lenders. The DIP Credit Facility consists of a revolving loan facility of new money in an aggregate principal amount of up to $925 million (the “New Money Facility”), which

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(Unaudited)

includes a sub-facility of up to $200 million for the issuance of letters of credit, and a $1.179 billion term loan that reflects the roll-up of a portion of outstanding borrowings under the pre-petition revolving credit facility: (i) a $925 million term loan reflecting the roll-up of a portion of outstanding existing borrowings made by the New Money Lenders under the existing revolving credit agreement (the “New Money Roll-Up Loans”) and (ii) an up to approximately $254 million term loan reflecting the roll-up or a portion of outstanding existing borrowings made by certain other lenders under the pre-petition revolving credit facility agreement (the “Incremental Roll-Up Loans”). The proceeds of the DIP Credit Facility may be used for, among other things, post-petition working capital, permitted capital investments, general corporate purposes, letters of credit, administrative costs, premiums, expenses and fees for the transactions contemplated by the Chapter 11 Cases, payment of court approved adequate protection obligations and other such purposes consistent with the DIP Credit Facility. The DIP Credit Facility was approved by the Bankruptcy Court on a final basis on July 31, 2020.

Borrowings under the DIP Credit Facility will mature, and the lending commitments thereunder will terminate, upon the earliest to occur of: (a) March 28, 2021 (the 9-month anniversary of the Petition Date); (b) the date of the termination of the commitments and/or the acceleration of all of obligations following the occurrence and continuance of an event of default defined the DIP Credit Facility; (c) the first business day on which the interim order, as defined in the DIP Credit Facility, expires or is terminated; (d) the conversion of any of Chapter 11 Cases to a case under Chapter 7 of the Bankruptcy Code; (e) the dismissal of any of the Chapter 11 Cases; (f) the closing of a sale of all or substantially all of the equity or assets of the Debtors; (g) the date of the payment in full in cash of all obligations and termination of all the commitments of the Debtors and; (h) the effective date of any of the Debtors’ approved plan of reorganization.

Borrowings under the DIP Credit Facility bear interest at an alternative base rate (ABR) or LIBOR, at our election, plus an applicable margin of 5.00% per annum for ABR loans and 6.00% per annum for LIBOR loans for the New Money Facility and bear interest at an ABR or LIBOR, at our election, plus an applicable margin of 4.50% per annum for ABR loans and 5.50% per annum for LIBOR loans for the New Money Roll-Up Loans and Incremental Roll-up Loans.

In addition to paying interest on outstanding principal under the DIP Credit Facility, we are required to pay a commitment fee of 0.50% per annum to the lenders of the DIP Credit Facility in respect of the unutilized revolving commitments thereunder and a letter of credit fee equal to 0.125% per annum.

The DIP Credit Facility includes negative covenants that, subject to significant exceptions, limit our ability and the ability of our restricted subsidiaries to, among other things, (i) incur additional indebtedness, (ii) create liens on assets, (iii) engage in mergers, consolidations, liquidations and dissolutions, (iv) sell assets, (v) make investments, loans or advances, except as described in the DIP Credit Facility, (vi) pay dividends and distributions or repurchase capital stock, (vii) engage in certain transactions with affiliates and (viii) change lines of business. The DIP Credit Facility includes certain customary representations and warranties, affirmative covenants and events of default, including but not limited to, payment defaults, breach of representations and warranties, covenant defaults, certain bankruptcy-related events, certain events under ERISA, material judgments and a change in control. If an event of default occurs, the lenders under the DIP Credit Facility will be entitled to take various actions, including the acceleration of all amounts due under the DIP Credit Facility and all actions permitted to be taken under the loan documents or application of law. In addition, the DIP Credit Facility is subject to various other financial covenants, including compliance with certain financial metrics to an approved budget and a required Asset Coverage Ratio (as defined in the DIP Credit Agreement) of not less than 1.25:1.00.

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(Unaudited)

Senior Notes

In the Current ~~Quarter,~~Period, we repurchased approximately $~~156~~160 million aggregate principal amount of the following senior notes for $9395 million and recorded an aggregate gain of approximately $6365 million.


	Notes Repurchased		Notes Repurchased
	($ in millions)		($ in millions)
6.625% senior notes due 2020	$	31	$	32
6.875% senior notes due 2020	17		20
4.875% senior notes due 2022	66		66
5.75% senior notes due 2023	42		42
Total	$	156	$	160

~~Revolving Credit Facility~~

Our revolving credit facility matures in September 2023 and the current aggregate commitment of the lenders and borrowing base under the facility is $3.0 billion. The revolving credit facility provides for an accordion feature, pursuant to which the aggregate commitments thereunder may be increased to up to $4.0 billion from time to time, subject to agreement of the participating lenders and certain other customary conditions. Scheduled borrowing base redeterminations will continue to occur semiannually. Our borrowing base was reaffirmed on November 1, 2019. As of March 31, 2020, we had outstanding borrowings of $1.900 billion under our revolving credit facility and had used $89 million for various letters of credit. Our next borrowing base redetermination, scheduled for the second quarter of 2020, is not complete. Although we believe we have adequate reserves value to support the reaffirmation of our full borrowing base, we believe it is likely the lending group will reduce our borrowing base due to our distressed financial position.

Borrowings under our revolving credit facility bear interest at an alternative base rate (ABR) or LIBOR, at our election, plus an applicable margin ranging from 1.50%-2.50% per annum for ABR loans and 2.50%-3.50% per annum for LIBOR loans, depending on the percentage of the borrowing base then being utilized.

Our revolving credit facility is subject to various financial and other covenants. The terms of the credit agreement include covenants limiting, among other things, our ability to incur additional indebtedness, make investments or loans, incur liens, consummate mergers and similar fundamental changes, make restricted payments, make investments in unrestricted subsidiaries and enter into transactions with affiliates.

On December 3, 2019, we entered into the second amendment to our credit agreement. Among other things, the amendment (i) permitted the issuance of certain secured indebtedness with a lien priority or proceeds recovery behind the obligations under the credit agreement without a corresponding 25% reduction in the borrowing base under the credit agreement, if issued by the next scheduled redetermination of the borrowing base, (ii) increased the amount of indebtedness that can be secured on a pari passu first-lien basis with (and with recovery proceeds behind) the obligations under the credit agreement from $1 billion to $1.5 billion, (iii) increased the applicable margin as defined in the credit agreement on borrowings under the credit agreement by 100 basis points, (iv) requires liquidity of at least $250 million at all times, (v) for each fiscal quarter commencing with the fiscal quarter ending December 31, 2019, replaced the secured leverage ratio financial covenant with a requirement that the first lien secured leverage ratio not exceed 2.50 to 1 as of the end of such fiscal quarter, (vi) increased the maximum permitted total leverage ratio as of the end of each fiscal quarter to 4.50 to1 through the fiscal quarter ending December 31, 2021, with step-downs to 4.25 to 1 for the fiscal quarter ending March 31, 2022 and to 4.00 to 1 for each fiscal quarter ending thereafter, and (vii) required that we use the aggregate net cash proceeds of certain asset sales in excess of $50 million to prepay certain indebtedness and/or reduce commitments under our credit agreement, until the retirement of all of our senior notes maturing before September 12, 2023. On December 26, 2019, we entered into the third amendment to our credit agreement, which, among other things, permitted the issuance of certain secured indebtedness with a lien priority behind the obligations under the credit agreement without a corresponding 25% reduction in the borrowing base under the credit agreement, if issued by December 31, 2019 and issued in exchange for, or the proceeds used to refinance, our senior notes.

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~~(Unaudited)~~

As of March 31, 2020, we were in compliance with all applicable financial covenants under the credit agreement and we were able to borrow up to the full availability under our revolving credit facility. If the current depressed prices persist, combined with the scheduled reductions in the leverage ratio covenant and an expected significant reduction in our borrowing base in our scheduled determination, then our liquidity and our ability to comply with our financial covenants during the next 12 months will be adversely affected. Based on our current forecast, we do not expect to be in compliance with our financial covenants beginning in the fourth quarter of 2020. Failure to comply with these covenants, if not waived, would result in an event of default under our revolving credit facility, the potential acceleration of outstanding debt thereunder and the potential foreclosure on the collateral securing such debt, and could cause a cross-default under our other outstanding indebtedness.

Phase-Out of LIBOR

In July 2017, the UK's Financial Conduct Authority, which regulates LIBOR, announced that it intends to phase out LIBOR as a benchmark by the end of 2021. At the present time, our pre-petition revolving credit facility and our term loan have terms that extend beyond 2021. Our pre-petition revolving credit facility and our term loan each provide for a mechanism to amend the underlying agreements to reflect the establishment of an alternate rate of interest upon the occurrence of certain events related to the phase-out of LIBOR. However, we have not yet pursued any technical amendment or other contractual alternative to our pre-petition revolving credit facility or term loan to address this matter. We are currently evaluating the potential impact of the eventual replacement of the LIBOR interest rate.

Fair Value of Debt

We estimate the fair value of our Level 1 debt based on the market value of our publicly traded debt as determined based on the yield of our senior notes. The fair value of our Level 2 debt is based on a market approach using estimates provided by an independent investment financial data services firm. ~~Fair~~Upon emergence from the Chapter 11 Cases, the pre-petition revolving credit facility will be paid in full with proceeds from our exit financing and, therefore, the estimated fair value ~~is compared to~~equals the carrying value inand is excluded from the table ~~below:~~below.


	March 31, 2020				December 31, 2019				June 30, 2020				December 31, 2019
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
			($ in millions)								($ in millions)
Short-term debt (Level 1)	$	420	$	103	$	385	$	360	$	—	$	—	$	385	$	360
Long-term debt (Level 1)	$	565	$	68	$	753	$	622	$	—	$	—	$	753	$	622
Long-term debt (Level 2)	$	8,598	$	3,042	$	8,320	$	6,085	$	—	$	—	$	8,320	$	6,085
Liabilities subject to compromise (Level 1)									$	982	$	28	$	—	$	—
Liabilities subject to compromise (Level 2)									$	6,184	$	1,191	$	—	$	—

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(Unaudited)


5.	Contingencies and Commitments

There have been no material developments in previously reported legal or environmental contingencies or commitments other than the items discussed below.

Contingencies

Chapter 11 Proceedings

Commencement of the Chapter 11 Cases automatically stayed the proceedings and actions against us that are described below, in addition to actions seeking to collect pre-petition indebtedness or to exercise control over the property of the Company’s bankruptcy estates. The plan contemplated by the RSA, if confirmed, will provide for the treatment of claims against the Company’s bankruptcy estates, including pre-petition liabilities that have not been satisfied or addressed during the Chapter 11 Cases. See Note 1 for additional information.

Litigation and Regulatory Proceedings

We are involved in a number of litigation and regulatory proceedings including those described below. Many of these proceedings are in early stages, and many of them seek or may seek damages and penalties, the amount of which is indeterminate. Our total accrued liability in respect of litigation and regulatory proceedings is determined on a case-by-case basis and represents an estimate of probable losses after considering, among other factors, the progress of each case or proceeding, our experience and the experience of others in similar cases or proceedings, and the opinions and views of legal counsel. Significant judgment is required in making these estimates and our final liabilities may ultimately be materially different.

Business Operations. We are involved in various lawsuits and disputes incidental to our business operations, including commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions.

We and other natural gas producers have been named in various lawsuits alleging underpayment of royalties and other shares of the proceeds of production. The lawsuits against us allege, among other things, that we used below-market prices, made improper deductions, utilized improper measurement techniques, entered into arrangements with affiliates that resulted in underpayment of amounts owed in connection with the production and sale of natural gas and NGL, or similar theories. These lawsuits include cases filed by individual royalty owners and putative class actions, some of which seek to certify a statewide class. The lawsuits seek compensatory, consequential, treble, and punitive damages, restitution and disgorgement of profits, declaratory and injunctive relief regarding our payment practices, pre-and post-judgment interest, and attorney’s fees and costs. Royalty plaintiffs have varying provisions in their respective leases, oil and gas law varies from state to state, and royalty owners and producers differ in their interpretation of the legal effect of lease provisions governing royalty calculations. We have resolved a number of these claims through negotiated settlements of past and future royalty obligations and have prevailed in various other lawsuits. We are currently defending numerous lawsuits seeking damages with respect to underpayment of royalties or other shares of the proceeds of production in multiple states where we have operated, including those discussed below.

On December 9, 2015, the Commonwealth of Pennsylvania, by the Office of Attorney General, filed a lawsuit in the Bradford County Court of Common Pleas related to royalty underpayment and lease acquisition and accounting practices with respect to properties in Pennsylvania. The lawsuit, which primarily relates to the Marcellus Shale and Utica Shale, alleges that we violated the Pennsylvania Unfair Trade Practices and Consumer Protection Law (UTPCPL) by making improper deductions and entering into arrangements with affiliates that resulted in underpayment of royalties. The lawsuit includes other UTPCPL claims and antitrust claims, including that a joint exploration agreement to which we are a party established unlawful market allocation for the acquisition of leases. The lawsuit seeks statutory restitution, civil penalties and costs, as well as a temporary injunction from exploration and drilling activities in Pennsylvania until restitution, penalties and costs have been paid, and a permanent injunction from further violations of the UTPCPL. We intend to vigorously defend these claims.

Putative statewide class actions in Pennsylvania and Ohio and purported class arbitrations in Pennsylvania have been filed on behalf of royalty owners asserting various claims for damages related to alleged underpayment of royalties as a result of the divestiture of substantially all of our midstream business and most of our gathering assets in 2012 and 2013. These cases include claims for violation of and conspiracy to violate the federal Racketeer Influenced and Corrupt Organizations Act and for an unlawful market allocation agreement for mineral rights, intentional interference with contractual relations, and violations of antitrust laws related to purported markets for gas mineral rights, operating rights and gas gathering sources. These lawsuits seek in aggregate compensatory, consequential, treble, and punitive damages, restitution and disgorgement of profits, declaratory and injunctive relief regarding our royalty payment practices, pre-and post-judgment interest, and attorney’s fees and costs. On December 20, 2017 and August 9, 2018, we reached tentative settlements to resolve substantially all Pennsylvania civil royalty cases for a total of approximately $36 million.

We believe losses are reasonably possible in certain of the pending royalty cases for which we have not accrued a loss contingency, but we are currently unable to estimate an amount or range of loss or the impact the actions could have on our future results of operations or cash flows. Uncertainties in pending royalty cases generally include the complex nature of the claims and defenses, the potential size of the class in class actions, the scope and types of the properties and agreements involved, and the applicable production years.

On July 24, 2018, ~~Healthcare of Ontario Pension Plan (HOOPP)~~HOOPP filed a demand for arbitration with the American Arbitration Association regarding HOOPP’s purchase of our interest in Chaparral Energy, Inc. stock for $215 million on January 5, 2014. HOOPP claims that we engaged in material misrepresentations and fraud, and that we violated the Securities Exchange Act of 1934 (the “Exchange Act”) and Oklahoma Uniform Securities Act. HOOPP seeks either rescission or $215 million in monetary damages, and in either case, interest, attorney’s fees, disgorgement and punitive damages. We intend to vigorously defend these claims.

In February 2019, a putative class action lawsuit was filed in the District Court of Dallas County, Texas against FTS International, Inc. (FTSI), certain investment banks, FTSI’s directors including certain of our officers and certain shareholders of FTSI including us. The lawsuit alleges various violations of Sections 11 (with respect to certain of our officers in their capacities as directors of FTSI) and 15 (with respect to such officers and us) of the Securities Act of 1933 in connection with public disclosure made during the initial public offering of FTSI. The suit seeks damages in excess of ~~$1,000,000~~$1 million and attorneys’ fees and other expenses. ~~We intend to vigorously defend these claims.~~On June 18, 2020, we were dismissed from the case without prejudice.

Environmental Contingencies

The nature of the oil and gas business carries with it certain environmental risks for us and our subsidiaries. We have implemented various policies, programs, procedures, training and audits to reduce and mitigate such environmental risks. We conduct periodic reviews, on a company-wide basis, to assess changes in our environmental risk profile. Environmental reserves are established for environmental liabilities for which economic losses are probable and reasonably estimable. We manage our exposure to environmental liabilities in acquisitions by using an evaluation process that seeks to identify pre-existing contamination or compliance concerns and address the potential liability. Depending on the extent of an identified environmental concern, we may, among other things, exclude a property from the transaction, require the seller to remediate the property to our satisfaction in an acquisition or agree to assume liability for the remediation of the property.

We are named as a defendant in numerous lawsuits in Oklahoma alleging that we and other companies have engaged in activities that have caused earthquakes. These lawsuits seek compensation for injury to real and personal property, diminution of property value, economic losses due to business interruption, interference with the use and enjoyment of property, annoyance and inconvenience, personal injury and emotional distress. In addition, they seek the reimbursement of insurance premiums and the award of punitive damages, attorneys’ fees, costs, expenses and interest. We intend to vigorously defend these claims.

Other Matters

Based on management’s current assessment, we are of the opinion that no pending or threatened lawsuit or dispute relating to our business operations is likely to have a material adverse effect on our future consolidated financial position, results of operations or cash flows. The final resolution of such matters could exceed amounts accrued, however, and actual results could differ materially from management’s estimates.

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(Unaudited)

Commitments

Gathering, Processing and Transportation Agreements

We have contractual commitments with midstream service companies and pipeline carriers for future gathering, processing and transportation of oil, natural gas and NGL to move certain of our production to market. Working interest owners and royalty interest owners, where appropriate, will be responsible for their proportionate share of these costs. Commitments related to gathering, processing and transportation agreements are not recorded as obligations in the accompanying condensed consolidated balance sheets; however, they are reflected in our estimates of proved reserves.

The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below:


	March 31, 2020		June 30, 2020
	($ in millions)		($ in millions)
Remainder of 2020	$	815	$	547
2021	986		988
2022	880		882
2023	752		754
2024	681		683
2025 – 2034	3,479		3,485
Total	$	7,593	$	7,339

In addition, we have entered into long-term agreements for certain natural gas gathering and related services within specified acreage dedication areas in exchange for cost-of-service based fees redetermined annually, or tiered fees based on volumes delivered relative to scheduled volumes. Future gathering fees may vary with the applicable agreement.

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6.	Other Liabilities

Other current liabilities as of ~~March 31,~~June 30, 2020 and December 31, 2019 are detailed below:


	March 31, 2020		December 31, 2019		June 30, 2020		December 31, 2019
	($ in millions)				($ in millions)
Revenues and royalties due others	$	396	$	516	$	138	$	516
Accrued drilling and production costs	260		326		24		326
Joint interest prepayments received	57		52		28		52
VPP deferred revenue^(a)	50		55		36		55
Accrued compensation and benefits^(b)	56		156		52		156
Other accrued taxes	132		150		114		150
Other	201		177		26		177
Total other current liabilities	$	1,152	$	1,432	$	418	$	1,432

Other long-term liabilities as of ~~March 31,~~June 30, 2020 and December 31, 2019 are detailed below:


	March 31, 2020		December 31, 2019		June 30, 2020		December 31, 2019
	($ in millions)				($ in millions)
VPP deferred revenue^(a)	$	—	$	9	$	—	$	9
Other	81		116		8		116
Total other long-term liabilities	$	81	$	125	$	8	$	125

(a)

At the inception of our volumetric production payment (VPP) agreements, we (i) removed the proved reserves associated with the VPP, (ii) recognized VPP proceeds as deferred revenue which are being amortized on a unit-of-production basis to other revenue over the term of the VPP, (iii) retained responsibility for the production costs and capital costs related to VPP interests and (iv) ceased recognizing production associated with the VPP volumes. The remaining deferred revenue balance will be recognized in other revenues in the consolidated statement of operations through 2021, assuming the related VPP production volumes are delivered as scheduled.


(b)	In the Current ~~Quarter,~~Period, we terminated our nonqualified deferred compensation plan. Accordingly, we derecognized the asset associated with the plan after the participants’ investments were liquidated. The cash was distributed to the participants, and we extinguished the corresponding $43 million accrued liability.

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7.	Revenue

The following table shows revenue disaggregated by operating area and product type, for the Current Quarter the Prior Quarter, the Current Period and the Prior ~~Quarter:~~Period:

Three Months Ended March 31, 2020
Oil Natural Gas NGL Total
($ in millions)
Marcellus $ —
$ 175
$ —
$ 175
Haynesville —
85
—
85
Eagle Ford 277
31
20
328
Brazos Valley 172
4
4
180
Powder River Basin 68
15
7
90
Mid-Continent 22
10
4
36
Revenue from contracts with customers 539
320
35
894
Gains on oil, natural gas and NGL derivatives 839
68
—
907
Oil, natural gas and NGL revenue $ 1,378
$ 388
$ 35
$ 1,801

Marketing revenue from contracts with customers $ 508
$ 124
$ 30
$ 662
Other marketing revenue 61
1
—
62
Marketing revenue $ 569
$ 125
$ 30
$ 724

Three Months Ended March 31, 2019
Oil Natural Gas NGL Total
($ in millions)
Marcellus $ —
$ 302
$ —
$ 302
Haynesville —
201
—
201
Eagle Ford 331
48
46
425
Brazos Valley 121
4
2
127
Powder River Basin 74
25
10
109
Mid-Continent 40
15
11
66
Revenue from contracts with customers 566
595
69
1,230
Losses on oil, natural gas and NGL derivatives (259 ) (42 ) —
(301 )
Oil, natural gas and NGL revenue $ 307
$ 553
$ 69
$ 929

Marketing revenue from contracts with customers $ 613
$ 413
$ 117
$ 1,143
Other marketing revenue 72
20
—
92
Losses on marketing derivatives —
(2 ) —
(2 )
Marketing revenue $ 685
$ 431
$ 117
$ 1,233



	Three Months Ended June 30, 2020
	Oil			Natural Gas			NGL		Total
	($ in millions)
Marcellus	$	—		$	131		$	—	$	131
Haynesville	—			67			—		67
Eagle Ford	73			21			14		108
Brazos Valley	76			3			1		80
Powder River Basin	29			7			3		39
Mid-Continent	8			5			2		15
Revenue from contracts with customers	186			234			20		440
Losses on oil, natural gas and NGL derivatives	(148		)	(25		)	—		(173		)
Oil, natural gas and NGL revenue	$	38		$	209		$	20	$	267

Marketing revenue from contracts with customers	$	121		$	96		$	15	$	232
Other marketing revenue	6			2			—		8
Marketing revenue	$	127		$	98		$	15	$	240

	Three Months Ended June 30, 2019
	Oil			Natural Gas			NGL		Total
	($ in millions)
Marcellus	$	—		$	198		$	—	$	198
Haynesville	—			164			—		164
Eagle Ford	349			37			20		406
Brazos Valley	199			9			5		213
Powder River Basin	102			18			8		128
Mid-Continent	50			10			10		70
Revenue from contracts with customers	700			436			43		1,179
Gains on oil, natural gas and NGL derivatives	86			189			—		275
Oil, natural gas and NGL revenue	$	786		$	625		$	43	$	1,454

Marketing revenue from contracts with customers	$	614		$	162		$	48	$	824
Other marketing revenue	78			15			—		93
Losses on marketing derivatives	—			(1		)	—		(1		)
Marketing revenue	$	692		$	176		$	48	$	916

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(Unaudited)



	Six Months Ended June 30, 2020
	Oil			Natural Gas			NGL		Total
	($ in millions)
Marcellus	$	—		$	306		$	—	$	306
Haynesville	—			151			—		151
Eagle Ford	350			52			34		436
Brazos Valley	248			7			5		260
Powder River Basin	97			23			10		130
Mid-Continent	30			15			6		51
Revenue from contracts with customers	725			554			55		1,334
Gains on oil, natural gas and NGL derivatives	691			43			—		734
Oil, natural gas and NGL revenue	$	1,416		$	597		$	55	$	2,068

Marketing revenue from contracts with customers	$	629		$	220		$	45	$	894
Other marketing revenue	67			3			—		70
Marketing revenue	$	696		$	223		$	45	$	964

	Six Months Ended June 30, 2019
	Oil			Natural Gas			NGL		Total
	($ in millions)
Marcellus	$	—		$	500		$	—	$	500
Haynesville	—			365			—		365
Eagle Ford	680			85			66		831
Brazos Valley	320			13			7		340
Powder River Basin	176			43			18		237
Mid-Continent	90			25			21		136
Revenue from contracts with customers	1,266			1,031			112		2,409
Gains (losses) on oil, natural gas and NGL derivatives	(173		)	147			—		(26		)
Oil, natural gas and NGL revenue	$	1,093		$	1,178		$	112	$	2,383

Marketing revenue from contracts with customers	$	1,227		$	575		$	165	$	1,967
Other marketing revenue	150			35			—		185
Losses on marketing derivatives	—			(3		)	—		(3		)
Marketing revenue	$	1,377		$	607		$	165	$	2,149

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)

Accounts Receivable

Our accounts receivable are primarily from purchasers of oil, natural gas and NGL and from exploration and production companies that own interests in properties we operate. This industry concentration could affect our overall exposure to credit risk, either positively or negatively, because our purchasers and joint working interest owners may be similarly affected by changes in economic, industry or other conditions. We monitor the creditworthiness of all our counterparties and we generally require letters of credit or parent guarantees for receivables from parties deemed to have sub-standard credit, unless the credit risk can otherwise be mitigated. We estimate expected credit losses using forecasts based on historical information and current information, in addition to specifically identifying receivables that may be uncollectible.

On January 1, 2020 we adopted ASU 2016-03, Financial Instruments-Credit Losses. The standard, as further amended, affects trade receivables, financial assets and certain other instruments that are not measured at fair value through net income. This ASU replaced the previously required incurred loss approach for estimating credit losses with an expected loss model. The adoption and implementation of this ASU did not have a material impact on our accounts receivable.

Accounts receivable as of ~~March 31,~~June 30, 2020 and December 31, 2019 are detailed below:


	March 31, 2020			December 31, 2019			June 30, 2020			December 31, 2019
	($ in millions)						($ in millions)
Oil, natural gas and NGL sales	$	458		$	737		$	385		$	737
Joint interest	178			200			102			200
Other	150			74			53			74
Allowance for doubtful accounts	(24		)	(21		)	(27		)	(21		)
Total accounts receivable, net	$	762		$	990		$	513		$	990


8.	Income Taxes

We estimate our annual effective tax rate (AETR) for continuing operations in recording our interim quarterly income tax provision for the various jurisdictions in which we operate. The tax effects of statutory rate changes, significant unusual or ~~infrequent~~infrequently occurring items, and certain changes in the assessment of the realizability of deferred tax assets are excluded from the determination of our estimated AETR as such items are recognized as discrete items in the quarter in which they occur.

Our estimated AETR for the Current Quarter is 0.1%. The impairments of long-lived assets recorded during the ~~Current Quarter (See~~first quarter of 2020 (see Note 13 for additional information on the impairments) resulted in the deferred tax position attributable to Texas reverting back to a net asset before valuation allowance. As ~~such,~~of December 31, 2019, we reported Texas as the only tax jurisdiction being in a net deferred tax liability position and recorded an associated income tax expense of $10 million. The $10 million of net deferred tax ~~expense recorded during the fourth quarter of 2019~~liability attributable to Texas is being reversed through the determination of the estimated AETR ~~and application of such to~~for the ~~year-to-date pre-tax book income.~~year ended December 31, 2020. The estimated AETR is otherwise low as a result of projecting a full valuation allowance for the year with only the $10 million going through the estimated AETR as a deferred tax benefit.

Based on all available positive and negative evidence, including projections of future taxable income, we believe it is more likely than not that our deferred tax assets will not be ~~realized.~~realized, including the deferred tax assets attributable to Texas. A significant piece of objectively verifiable negative evidence evaluated is the cumulative loss incurred over the rolling thirty-six-month period ended ~~March 31,~~June 30, 2020. Such evidence limits our ability to consider various forms of subjective positive evidence, such as any projections of future growth and earnings. However, should we return to a level of sustained profitability, consideration will need to be given to projections of future taxable income to determine whether such projections provide an adequate source of taxable income for the realization of our deferred tax assets, primarily federal and state net operating loss (NOL) carryforwards. A full valuation allowance was recorded against our net deferred tax asset position for federal and state purposes as of ~~March 31,~~June 30, 2020 and, with the exception of Texas which was in a net deferred tax liability position, as of December 31, 2019.

On February 1, 2019, we completed the acquisition of WildHorse Resource Development Corporation (“WildHorse”). For federal income tax purposes, the transaction (the “WildHorse Merger”) qualified as a tax-free merger

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)

under Section 368 of the Internal Revenue Code of 1986, as amended, (the “Code”) and, as a result, we acquired carryover tax basis in WildHorse’s assets and liabilities. We recorded a net deferred tax liability of $314 million as part of the business combination accounting for WildHorse. As a consequence of ~~maintaining~~having a full valuation allowance

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~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

against our net deferred tax asset, a partial release of the valuation allowance was recorded as a discrete income tax benefit of $314 million through the condensed consolidated statement of operations in the first quarter of 2019. The net deferred tax liability acquired includes deferred tax liabilities on plant, property and equipment and prepaid compensation totaling $401 million, partially offset by deferred tax assets totaling $87 million relating to federal NOL carryforwards, disallowed business interest carryforwards and certain other deferred tax assets. These carryforwards will be subject to an annual limitation under Section 382 of the Code of approximately $61 million. We determined that no separate valuation allowances were required to be established through business combination accounting against any of the individual deferred tax assets acquired.

We are subject to U.S. federal income tax as well as income and capital taxes in various state and local jurisdictions in which we operate. WeAs a result of having a full valuation allowance against our net deferred tax asset position, we did not record an income tax provision for the Current Quarter. However, we recorded an income tax benefit of $13 million for the Current ~~Quarter. The benefit for~~Period, which includes the ~~Current Quarter was primarily~~impact of Texas reverting back to a ~~result of reversing substantially all of the~~net deferred tax ~~liability associated with Texas through the estimated AETR and~~asset position as well as recording a receivable for amounts previously sequestered from refunds of corporate alternative minimum tax (AMT) credits.

Our ability to utilize NOL carryforwards and ~~possibly~~ other tax attributes to reduce future federal taxable income and federal income tax is subject to various limitations under Section 382 of the Code. The utilization of these attributes may be subject to an annual limitation under Section 382 of the Code should transactions involving our equity, including issuances of our stock or the sale or exchange of our stock by certain shareholders, result in a cumulative shift of more than 50% in the beneficial ownership of our stock during any three-year testing period (an “Ownership Change”). (For this purpose, “stock” includes certain preferred ~~stock).~~stock.) Some states impose similar limitations on tax attribute utilization upon experiencing an Ownership Change. On April 23, 2020, our Board of Directors approved the adoption of a rights plan that is intended to protect value by preserving our ability to use our tax attributes, such as NOLs, to offset potential future income taxes for federal income tax purposes. See ~~Note 17~~ ~~for additional information.~~

As of ~~March 31,~~June 30, 2020, we do not believe that an Ownership Change has occurred that would subject us to an annual limitation on the utilization of our NOL carryforwards and other tax ~~attributes. However, with~~attributes; however, our ~~cumulative~~current ownership shift ~~in excess~~remains at greater than 40%.

On April 23, 2020, our Board of ~~40%, future transactions involving our equity, including relatively small transactions and transactions beyond our control, could cause an Ownership Change and therefore an annual limitation on~~Directors approved the ~~utilization~~adoption of a rights plan that is designed to protect the availability of NOL carryforwards and ~~possibly~~ other tax attributes ~~(which~~by reducing the likelihood of an Ownership Change (see Note 9 for additional information on the rights plan). Further, as part of the Chapter 11 Cases, the Bankruptcy Court has granted a first day motion for entry of an order seeking relief that will enable the Company to closely monitor certain transfers of beneficial ownership of our stock so as to be in a position to prevent such transfers with the purpose of avoiding an Ownership Change, thereby preserving the value of our NOL carryforwards and other tax attributes.

Certain of the restructuring transactions contemplated by the RSA may have a material impact on the Company’s tax attributes, the full extent of which is currently unknown. Cancellation of indebtedness income resulting from such restructuring transactions may significantly reduce the Company’s tax attributes, including but not limited to NOL carryforwards. Further, the Company will experience an Ownership Change under Section 382 of the Code upon confirmation of the Plan by the Bankruptcy Court which will subject certain remaining tax attributes to an annual limitation ~~could potentially be very low).~~under Section 382 of the Code. Additionally, the Company will incur significant one-time costs associated with the Plan, a material amount of which are non-deductible for tax purposes under the Code.

On March 27, 2020, the President signed into law the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”). The CARES Act provides relief to corporate taxpayers by permitting a five year carryback of NOLs incurred from 2018 through 2020, ~~NOLs,~~ removing the 80% limitation on the utilization of certain NOLs carried forward to years beginning before January 1, 2021, increasing the 30% limitation on interest expense deductibility under Section 163(j) of the Code to 50% of adjusted taxable income for 2019 and 2020 and accelerating refunds for AMT credit carryforwards, along with a few other provisions. With respect to the Current Quarter and the Current Period, there was no impact on our income tax provision from the enactment of the CARES Act.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


9.	Equity

Common Stock

A summary of the changes in our common shares issued is detailed below.


	Three Months Ended March 31,		Six Months Ended June 30,
	2020	2019	2020	2019
	(in thousands)		(in thousands)
Beginning balance^(a)	9,773	4,568	9,773	4,568
Common shares issued for WildHorse Merger^(a)	—	3,587	—	3,587
Restricted stock issuances (net of forfeitures and cancellations)^(a)(b)	11	13	7	17
Ending balance^(a)	9,784	8,168	9,780	8,172


(a)	All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See ~~Note 17~~below for additional information.


(b)	See Note 10 for discussion of restricted stock.


~~10.~~	~~Share-Based Compensation~~

~~Equity-Classified Awards~~

~~Restricted Stock.~~ ~~We grant restricted stock units to employees and non-employee directors. A summary of the changes in unvested restricted stock during the Current Quarter is presented below:~~

Shares of
Unvested
Restricted Stock^(a)

Weighted Average
Grant Date
Fair Value Per Share^(a)
(in thousands)
Unvested restricted stock as of January 1, 2020 52
$ 710
Granted 68
$ 60
Vested (18 ) $ 828
Forfeited —
$ 1,042
Unvested restricted stock as of March 31, 2020 102
$ 256


~~(a)~~	~~All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See~~ ~~Note 17~~ ~~for additional information.~~

~~The aggregate intrinsic value of restricted stock that vested during the Current Quarter was approximately $1 million based on the stock price at the time of vesting.~~

~~As of~~ ~~March 31, 2020~~, there was approximately $18 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 2.15 years.

~~Stock Options.~~ In the Prior Quarter, we granted members of management stock options that vest ratably over a three-year period. Each stock option award has an exercise price equal to the closing price of our common stock on the grant date. Outstanding options expire seven years to ten years from the date of grant.

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

We utilize the Black-Scholes option pricing model to measure the fair value of stock options. The expected life of an option is determined using the simplified method. Volatility assumptions are estimated based on the average historical volatility of Chesapeake stock over the expected life of an option. The risk-free interest rate is based on the U.S. Treasury rate in effect at the time of the grant over the expected life of the option. The dividend yield is based on an annual dividend yield, taking into account our dividend policy, over the expected life of the option.

~~The following table provides information related to stock option activity in the Current Quarter:~~

Number of
Shares
Underlying
Options^(a)

Weighted
Average
Exercise Price Per Share^(a)

Weighted
Average
Contract Life in Years

Aggregate
Intrinsic
Value^(b)
(in thousands) ($ in millions)
Outstanding as of January 1, 2020 90
$ 1,420
5.70 $ —
Granted —
$ —

Exercised —
$ —
$ —
Expired (1 ) $ 1,090

Forfeited —
$ —

Outstanding as of March 31, 2020 89
$ 1,424
5.47 $ —
Exercisable as of March 31, 2020 80
$ 1,510
5.18 $ —


~~(a)~~	~~All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See~~ ~~Note 17~~ ~~for additional information.~~


~~(b)~~	~~The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option.~~

~~As of~~ ~~March 31, 2020~~, there was $3 million of total unrecognized compensation expense related to stock options. The expense is expected to be recognized over a weighted average period of approximately 1.35 years, net of actual forfeitures.

~~Restricted Stock and Stock Option Compensation.~~ ~~We recognized the following compensation costs, net of actual forfeitures, related to restricted stock and stock options for the Current Quarter and the Prior Quarter:~~

Three Months Ended
March 31,
2020 2019
($ in millions)
General and administrative expenses $ 4
$ 6
Oil and natural gas properties 1
1
Oil, natural gas and NGL production expenses 1
1
Total restricted stock and stock option compensation $ 6
$ 8

~~Liability-Classified Awards~~

~~Performance Share Units.~~ In the Prior Quarter, we granted PSUs to senior management that vest ratably over a three-year performance period and are settled in cash. The ultimate amount earned is based on achievement of performance metrics established by the Compensation Committee of the Board of Directors. Compensation expense associated with PSU awards is recognized over the service period based on the graded-vesting method. The value of the PSU awards at the end of each reporting period is dependent upon our estimates of the underlying performance measures.

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

For PSUs granted in 2017, performance metrics include a total shareholder return (TSR) component, which can range from 0% to 100% and an operational performance component based on finding and development costs, which can range from 0% to 100%, resulting in a maximum payout of 200%. The payout percentage for the 2017 PSU awards is capped at 100% if our absolute TSR is less than zero. The PSUs are settled in cash on the third anniversary of the awards. The performance period for the 2017 awards ended on December 31, 2019.

For PSUs granted in 2018 and 2019, performance metrics include an operational performance component based on a ratio of cumulative earnings before interest expense, income taxes, and depreciation, depletion and amortization expense (EBITDA) to capital expenditures, for which payout can range from 0% to 200%. For the 2019 award, EBITDA and capital expenditures will be adjusted for changes resulting from our conversion from the full cost method of accounting to the successful efforts method. The vested PSUs are settled in cash on each of the three annual vesting dates. We used the closing price of our common stock on the grant date to determine the grant date fair value of the PSUs. The PSU liability will be adjusted quarterly, based on changes in our stock price and expected satisfaction of performance metrics, through the end of the performance period.

~~Cash Restricted Stock Units~~. In 2018, we granted CRSUs to employees that vest straight-line over a three-year period and are settled in cash on each of the three annual vesting dates. The ultimate amount earned is based on the closing price of our common stock on each of the vesting dates. We used the closing price of our common stock on the grant date to determine the grant date fair value of the CRSUs. The CRSU liability will be adjusted quarterly, based on changes in our stock price, through the end of the vesting period.

~~The following table presents a summary of our liability-classified awards:~~

Grant Date
Fair Value
March 31, 2020

Units^(a)
Fair Value Vested Liability
($ in millions) ($ in millions)
2019 PSU Awards:
Payable 2021 and 2022 15,581
$ 9
$ 1
$ —
2018 PSU Awards:
Payable 2021 5,822
$ 4
$ —
$ —
2017 PSU Awards:
Payable 2020 428
$ 1
$ —
$ —
2018 CRSU Awards:
Payable 2021 19,928
$ 12
$ 1
$ —


~~(a)~~	~~All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See~~ ~~Note 17~~ ~~for additional information.~~

~~We recognized the following compensation costs (credits), net of actual forfeitures, related to our liability-classified awards for the Current Quarter and the Prior Quarter.~~

Three Months Ended
March 31,
2020 2019
($ in millions)
General and administrative expenses $ (3 ) $ 9
Oil and natural gas properties —
1
Oil, natural gas and NGL production expenses (1 ) 3
Exploration expenses —
1
Total liability-classified awards compensation $ (4 ) $ 14

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~


~~11.~~	~~Derivative and Hedging Activities~~

~~Oil, Natural Gas and NGL Derivatives~~

~~As of~~ ~~March 31, 2020~~ ~~and December 31, 2019, our oil, natural gas and NGL derivative instruments consisted of the following types of instruments:~~


•	~~Swaps~~: We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options and call swaptions.


•	~~Options~~: We sell, and occasionally buy, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess on sold call options and we receive the excess on bought call options. If the market price is lower than the fixed price of the call option, no payment is due from either party.


•	~~Call Swaptions~~: We sell call swaptions to counterparties in exchange for a premium. Swaptions allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time or to increase the notional volumes of an existing fixed-price swap.

•

~~Collars~~: These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price.


•	~~Basis Protection Swaps~~: These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity.

•

~~Put spreads:~~ These instruments contain a fixed floor price (bought put) and sub floor price (sold put). If the market price exceeds the bought put strike, we receive the market price. If the market price is between the bought put and sold put strike prices, we receive the bought put price. If the market price falls below the sub floor, we receive the market price plus the difference between the sold put and bought put.

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

~~The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of~~ ~~March 31, 2020~~ ~~and December 31, 2019 are provided below:~~

March 31, 2020 December 31, 2019
Notional Volume Fair Value Notional Volume Fair Value
($ in millions) ($ in millions)
Oil (mmbbl):
Fixed-price swaps 21
$ 640
24
$ (7 )
Call options (sold) 9
(9 ) —
—
Collars 1
48
2
14
Basis protection swaps 10
38
8
(2 )
Total oil 41
717
34
5
Natural gas (bcf):
Fixed-price swaps 199
152
265
125
Call options 113
(19 ) 22
—
Call swaptions 29
(4 ) 29
(2 )
Put spreads 94
15
—
—
Basis protection swaps 46
1
30
2
Total natural gas 481
145
346
125
Total estimated fair value $ 862
$ 130

We have terminated certain commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. See further discussion below under ~~Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss)~~.

~~Effect of Derivative Instruments – Condensed Consolidated Balance Sheets~~

~~The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of~~ ~~March 31, 2020~~ ~~and December 31, 2019 on a gross basis and after same-counterparty netting:~~

Balance Sheet Classification
Gross
Fair Value

Amounts Netted
in the
Consolidated
Balance Sheets

Net Fair Value
Presented in the
Consolidated
Balance Sheets
($ in millions)
As of March 31, 2020
Commodity Contracts:
Short-term derivative asset $ 889
$ (5 ) $ 884
Short-term derivative liability (5 ) 5
—
Long-term derivative liability (22 ) —
(22 )
Total derivatives $ 862
$ —
$ 862

As of December 31, 2019
Commodity Contracts:
Short-term derivative asset $ 174
$ (40 ) $ 134
Short-term derivative liability (42 ) 40
(2 )
Long-term derivative liability (2 ) —
(2 )
Total derivatives $ 130
$ —
$ 130

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

~~Effect of Derivative Instruments – Condensed Consolidated Statements of Operations~~

~~The components of oil, natural gas and NGL revenues for the Current Quarter and the Prior Quarter are presented below:~~

Three Months Ended
March 31,
2020 2019
($ in millions)
Oil, natural gas and NGL revenues $ 894
$ 1,230
Gains (losses) on undesignated oil, natural gas and NGL derivatives 916
(291 )
Losses on terminated cash flow hedges (9 ) (10 )
Total oil, natural gas and NGL revenues $ 1,801
$ 929

~~The components of marketing revenues for the Current Quarter and the Prior Quarter are presented below:~~

Three Months Ended
March 31,
2020 2019
($ in millions)
Marketing revenues $ 724
$ 1,235
Losses on undesignated marketing natural gas derivatives —
(2 )
Total marketing revenues $ 724
$ 1,233

~~Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss)~~

~~A reconciliation of the changes in accumulated other comprehensive income (loss) in our condensed consolidated statements of stockholders’ equity related to our cash flow hedges is presented below:~~

Three Months Ended March 31,
2020 2019
Before
Tax   After
Tax   Before
Tax   After
Tax
($ in millions)
Balance, beginning of period $ (45 ) $ 12
$ (80 ) $ (23 )
Losses reclassified to income 9
9
10
10
Balance, end of period $ (36 ) $ 21
$ (70 ) $ (13 )

~~The accumulated other comprehensive loss as of~~ ~~March 31, 2020~~ represents the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. Remaining deferred gain or loss amounts will be recognized in earnings in the month for which the original contract months are to occur. As of March 31, 2020, we expect to transfer approximately $29 million of net loss included in accumulated other comprehensive income (loss) to net income (loss) during the next 12 months. The remaining amounts will be transferred by December 31, 2022.

~~Credit Risk Considerations~~

Our derivative instruments expose us to our counterparties’ credit risk. To mitigate this risk, we enter into derivative contracts only with counterparties that have a high credit rating or are deemed by us to have acceptable credit strength, and are deemed by management to be competent and competitive market-makers, and we attempt to limit our exposure to non-performance by any single counterparty. As of March 31, 2020, our oil, natural gas and NGL derivative instruments were spread among 11 counterparties.

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

~~Hedging Arrangements~~

Certain of our hedging arrangements are with counterparties that are also lenders (or affiliates of lenders) under our revolving credit facility. The contracts entered into with these counterparties are secured by the same collateral that secures the revolving credit facility. In addition, we enter into bilateral hedging agreements with other counterparties. The counterparties’ and our obligations under the bilateral hedging agreements must be secured by cash or letters of credit to the extent that any mark-to-market amounts owed to us or by us exceed defined thresholds. As of March 31, 2020, we did not have any cash or letters of credit posted as collateral for our commodity derivatives.

~~Fair Value~~

The fair value of our derivatives is based on third-party pricing models, which utilize inputs that are either readily available in the public market, such as oil, natural gas and NGL forward curves and discount rates, or can be corroborated from active markets or broker quotes. These values are compared to the values given by our counterparties for reasonableness. Since oil, natural gas and NGL swaps do not include optionality and therefore generally have no unobservable inputs, they are classified as Level 2. All other derivatives have some level of unobservable input, such as volatility curves, and are therefore classified as Level 3. Derivatives are also subject to the risk that either party to a contract will be unable to meet its obligations. We factor non-performance risk into the valuation of our derivatives using current published credit default swap rates. To date, this has not had a material impact on the values of our derivatives.

~~The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of~~ ~~March 31, 2020~~ ~~and December 31, 2019:~~

Quoted
Prices in
Active
Markets
(Level 1)

Significant
Other
Observable
Inputs
(Level 2)

Significant
Unobservable
Inputs
(Level 3)

Total
Fair Value
($ in millions)
As of March 31, 2020
Derivative Assets (Liabilities):
Commodity assets $ —
$ 831
$ 46
$ 877
Commodity liabilities —
—
(15 ) (15 )
Total derivatives $ —
$ 831
$ 31
$ 862

As of December 31, 2019
Derivative Assets (Liabilities):
Commodity assets $ —
$ 160
$ 14
$ 174
Commodity liabilities —
(42 ) (2 ) (44 )
Total derivatives $ —
$ 118
$ 12
$ 130

~~TABLE OF CONTENTS~~

~~CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~

~~A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Quarter and the Prior Quarter is presented below:~~

Commodity
Derivatives
Utica Contingent Consideration
($ in millions)
Balance, as of January 1, 2020 $ 12
$ —
Total gains (losses) (realized/unrealized):
Included in earnings^(a)
28
—
Total purchases, issuances, sales and settlements:
Settlements (9 ) —
Balance, as of March 31, 2020 $ 31
$ —

Balance, as of January 1, 2019 $ 87
$ 7
Total gains (losses) (realized/unrealized):
Included in earnings^(a)
(88 ) —
Total purchases, issuances, sales and settlements:
Settlements 4
—
Balance, as of March 31, 2019 $ 3
$ 7

~~___________________________________________~~

(a) Commodity Derivatives

2020 2019
($ in millions)
Total gains (losses) included in earnings for the period $ 28
$ (88 )

Change in unrealized gains (losses) related to assets
still held at reporting date
$ 19
$ (84 )

~~Qualitative and Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements~~

The significant unobservable inputs for Level 3 derivative contracts include market volatility. Changes in market volatility impact the fair value measurement of our derivative contracts, which is based on an estimate derived from option models. For example, an increase or decrease in the forward prices and volatility of oil and natural gas prices decreases or increases the fair value of oil and natural gas derivatives. The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of March 31, 2020:

Instrument
Type

Unobservable
Input
Range
Weighted
Average^(a)
Fair Value
March 31, 2020
($ in millions)
Oil trades Oil price volatility curves 26.50% – 242.41% 42.97% $ 39
Natural gas trades Natural gas price volatility curves 20.56% – 141.43% 42.77% $ (8 )


~~(a)~~	~~Weighted average volatility is weighted by relative volume.~~

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~


~~12.~~	~~Exploration Expense~~

~~A summary of our exploration expense for the Current Quarter and the Prior Quarter is as follows:~~

Three Months Ended
March 31,
2020 2019
($ in millions)
Impairments of unproved properties $ 272
$ 18
Dry hole expense 7
—
Geological and geophysical expense and other 3
6
Exploration expense $ 282
$ 24

Unproved oil and natural gas properties are periodically assessed for impairment by considering future drilling and exploration plans, results of exploration activities, commodity price outlooks, planned future sales and expiration of all or a portion of the projects. The exploration expense charges during the Current Quarter are the result of non-cash impairment charges in unproved properties, primarily in our Brazos Valley, Powder River Basin, Haynesville and Mid-Continent operating areas.


~~13.~~	~~Impairments~~

During the Current Quarter, the decrease in demand for crude oil primarily due to COVID-19 and sharp decline in commodity prices related to the combined impact of falling demand and recent increases in production from OPEC+ resulted in decreases in current and expected long-term crude oil and NGL sale prices. These conditions resulted in reductions to the market capitalization of peer companies in the energy industry. We determined these adverse market conditions represent a triggering event to perform an impairment assessment of our long-lived assets used in, and in support of, our operations, including proved oil and gas properties, and our sand mine assets.

~~Proved Oil and Gas Properties~~

Our impairment test involved a Step 1 assessment to determine if the net book value of our proved oil and natural gas properties is expected to be recovered from the estimated undiscounted future cash flows.

We calculated the expected undiscounted future net cash flows of our long-lived assets using management’s assumptions and expectations of (i) commodity prices, which are based on the NYMEX strip pricing escalated by an inflationary rate after 2 years, (ii) pricing adjustments for differentials, (iii) operating costs, (iv) capital investment plans, (v) future production volumes, and (vi) estimated proved reserves.

~~Unprecedented volatility in the price of oil due to the decrease in demand has led us to rely on NYMEX strip pricing, which represents a Level 1 input.~~

Certain oil and gas properties in our Eagle Ford, Brazos Valley, Powder River Basin, and Mid-Continent and other non-core operating areas failed the Step 1 assessment. For these assets, we used a discounted cash flow analysis to estimate fair value. The expected future net cash flows were discounted using a rate of 11%, which we believe represents the estimated weighted average cost of capital of a theoretical market participant. Based on Step 2 of our long-lived assets impairment test, we recognized an $8.446 billion impairment because the carrying value exceeded estimated fair market value as of March 31, 2020.

Significant inputs associated with the calculation of discounted future net cash flows include estimates of (i) recoverable reserves, (ii) production rates, (iii) future operating and development costs, (iv) future commodity prices escalated by an inflationary rate after two years, adjusted for differentials, and (v) a market-based weighted average cost of capital. We utilized NYMEX strip pricing, adjusted for differentials, to value the reserves. The NYMEX strip pricing inputs used are classified as Level 1 fair value assumptions and all other inputs are classified as Level 3 fair value assumptions.

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~~(Unaudited)~~

~~Sand Mine~~

Our in-field sand mine assets predominately service the oil and gas properties in our Brazos Valley operating area. Based on management’s assumptions and expectations of (i) future commodity prices, (ii) capital investment plans in the Brazos Valley operating area, and (iii) future operating cost of the sand mine, management expects the market for sand to significantly decrease for the foreseeable future. As a result, we recognized a $76 million impairment related to our sand mine assets for the difference between fair value and the carrying value as of March 31, 2020. The inputs used are classified as Level 3 fair value assumptions.


~~14.~~	~~Capitalized Exploratory Well Costs~~

A summary of the changes in our capitalized well costs for the Current Quarter is detailed below. Additions pending the determination of proved reserves excludes amounts capitalized and subsequently charged to expense within the same year.

Three Months Ended March 31, 2020
($ in millions)
Balance as of January 1 $ 7
Charges to exploration expense (7 )
Balance as of March 31 $ —

~~As of March 31, 2020, there were 0 drilling and completion costs on exploratory wells pending determination of proved reserves capitalized for greater than one year.~~


~~15.~~	~~Investments~~

In the Current Quarter, the hydraulic fracturing industry experienced challenging operating conditions resulting in the current fair value of our investment in FTS International, Inc. (NYSE: FTSI) falling below book value of $23 million and remaining below that value as of the end of the Current Quarter. Based on FTSI’s operating results and FTSI’s share price of $0.22 per share as of March 31, 2020, we determined that the reduction in fair value is other-than-temporary, and recognized an impairment of our entire investment in FTSI of $23 million.


~~16.~~	~~Other Operating Expense~~

In the Current Quarter, we terminated certain gathering, processing and transportation contracts and recognized a non-recurring $79 million expense related to the contract terminations. The contract terminations removed approximately $169 million of future commitments related to gathering, processing and transportation agreements. See ~~Note 5~~ ~~for further discussion of contingencies and commitments.~~

In the Prior Quarter, we recorded approximately $23 million of costs related to our acquisition of WildHorse which consisted of consulting fees, financial advisory fees, legal fees and travel and lodging expenses. In addition, we recorded approximately $38 million of severance expense as a result of the acquisition of WildHorse. A majority of the WildHorse executives and employees were terminated. These executives and employees were entitled to severance benefits in accordance with existing employment agreements.

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~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)~~

~~(Unaudited)~~


~~17.~~	~~Subsequent Events~~

Reverse Stock Split

On April 13, 2020, our Board of Directors and our shareholders approved a 1-for-200 (1:200) reverse stock split of our common stock and a reduction of the total number of authorized shares of our common stock as determined by a formula based on two-thirds of the reverse stock split ratio. The reverse stock split became effective as of the close of business on April 14, 2020. Our common stock began trading on a split-adjusted basis on the NYSE at the market open on April 15, 2020. The par value of the common stock was not adjusted as a result of the reverse stock split.

The reverse stock split was intended to, among other things, increase the per share trading price of our common shares to satisfy the $1.00 minimum closing price requirement for continued listing on the NYSE. As a result of the reverse stock split, each 200 pre-split shares of common stock outstanding were automatically combined into one issued and outstanding share of common stock. The fractional shares that resulted from the reverse stock split were canceled by paying cash in lieu of the fair value. The number of outstanding shares of common stock were reduced from approximately 1.957 billion as of April 10, 2020 to approximately 9.784 million shares (without giving effect to the liquidation of fractional shares). The total number of shares of common stock that we are authorized to issue was reduced from 3,000,000,000 to 22,500,000 shares. All share and per share amounts in the accompanying condensed consolidated financial statements and notes thereto were retroactively adjusted for all periods presented to give effect to this reverse stock split, including reclassifying an amount equal to the reduction in par value of our common stock to additional paid-in capital.

Preferred Stock Dividend Suspension

On April 17, 2020, we announced that we were suspending payment of dividends on each series of our outstanding convertible preferred stock. Suspension of the dividends did not constitute an event of default under any of our debt instruments.

Adoption of Rights Plan

On April 23, 2020, the Board of Directors of the Company declared a dividend of one preferred share purchase right (a “Right”), payable on May 4, 2020, for each share of common stock, par value $0.01 per share, of the Company (the “Common Stock”) outstanding on May 4, 2020 to the stockholders of record on that date. In connection with the distribution of the Rights, the Company entered into a Section 382 Rights Agreement (the “Rights Agreement”), dated as of April 23, 2020, between the Company and Computershare Trust Company, N.A., as rights agent. Each Right entitles the registered holder to purchase from the Company one one-thousandth of a share of Series B Preferred Stock, par value $0.01 per share, of the Company at a price of $90.00 subject to adjustment.

The purpose of the Rights Agreement is to protect value by preserving the Company’s ability to use its tax attributes (e.g., federal NOLs) to offset potential future income taxes for federal income tax purposes. As of December 31, 2019,

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the Company had federal NOLs of approximately $7.6 billion available to offset future federal taxable income. The Company’s ability to use its federal NOLs as well as other tax attributes would be substantially limited if it experiences an Ownership Change. The Rights Agreement is intended to reduce the likelihood of an Ownership Change by deterring any person or group of affiliated or associated persons from acquiring beneficial ownership of 4.9% or more of the outstanding shares of Common Stock.

The Rights Agreement will expire on the close of business on the day following the certification of the voting results from the Company’s 2021 annual meeting, unless the Company’s shareholders ratify the Rights Agreement at or prior to such meeting, in which case it will continue in effect until April 22, 2023, unless terminated earlier in accordance with its terms.


10.	Share-Based Compensation

Our share-based compensation program consists of restricted stock, stock options, performance share units (PSUs) and cash restricted stock units (CRSUs) granted to employees and restricted stock granted to non-employee directors under our long-term incentive plans. The restricted stock and stock options are equity-classified awards and the PSUs and CRSUs are liability-classified awards. On May 5, 2020, all of the outstanding share-based compensation issued to executive officers and designated vice presidents was canceled and replaced with cash retention incentives. Refer to 2020 Compensation Adjustments below for more information.

Equity-Classified Awards

Restricted Stock. We grant restricted stock units to employees and non-employee directors. A summary of the changes in unvested restricted stock during the Current Period is presented below:



	Shares of Unvested Restricted Stock^(a)		Weighted Average Grant Date Fair Value Per Share^(a)
	(in thousands)
Unvested as of January 1, 2020	52		$	710
Granted	68		$	60
Vested	(21	)	$	793
Forfeited/canceled	(97	)	$	243
Unvested as of June 30, 2020	2		$	630


(a)	All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 9 for additional information.

The aggregate intrinsic value of restricted stock that vested during the Current Period was approximately $1 million based on the stock price at the time of vesting.

As of June 30, 2020, there was approximately $1 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 1.31 years.

Stock Options. In the Prior Period, we granted members of management stock options that vest ratably over a three-year period. Each stock option award has an exercise price equal to the closing price of our common stock on the grant date. Outstanding options expire seven years to ten years from the date of grant.

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(Unaudited)

The following table provides information related to stock option activity in the Current Period:



	Number of Shares Underlying Options^(a)		Weighted Average Exercise Price Per Share^(a)		Weighted Average Contract Life in Years	Aggregate Intrinsic Value^(b)
	(in thousands)					($ in millions)
Outstanding as of January 1, 2020	90		$	1,420	5.70	$	—
Granted	—		$	—
Exercised	—		$	—		$	—
Expired	(20	)	$	888
Forfeited/canceled	(47	)	$	1,666
Outstanding as of June 30, 2020	23		$	1,385	4.91	$	—
Exercisable as of June 30, 2020	22		$	1,397	4.99	$	—


(a)	All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 9 for additional information.


(b)	The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option.

As of June 30, 2020, there was 0 unrecognized compensation expense related to unvested stock options.

Restricted Stock and Stock Option Compensation. We recognized the following compensation costs, net of actual forfeitures, related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period:



	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	($ in millions)
General and administrative expenses	$	4	$	9	$	8	$	15
Oil and natural gas properties	—		—		1		1
Oil, natural gas and NGL production expenses	—		1		1		2
Total restricted stock and stock option compensation	$	4	$	10	$	10	$	18

Liability-Classified Awards

Performance Share Units. In the Prior Period, we granted PSUs to senior management that vest ratably over a three-year performance period and are settled in cash. The ultimate amount earned is based on achievement of performance metrics established by the Compensation Committee of the Board of Directors. Compensation expense associated with PSU awards is recognized over the service period based on the graded-vesting method. The value of the PSU awards at the end of each reporting period is dependent upon our estimates of the underlying performance measures.

Cash Restricted Stock Units. In 2018, we granted CRSUs to employees that vest straight-line over a three-year period and are settled in cash on each of the three annual vesting dates. The ultimate amount earned is based on the closing price of our common stock on each of the vesting dates. We used the closing price of our common stock on

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the grant date to determine the grant date fair value of the CRSUs. The CRSU liability will be adjusted quarterly, based on changes in our stock price, through the end of the vesting period.

The following table presents a summary of our liability-classified awards:



		Grant Date Fair Value		June 30, 2020
	Units^(a)	Grant Date Fair Value		Fair Value		Vested Liability
		($ in millions)		($ in millions)
2018 CRSU Awards:
Payable 2021	16,322	$	10	$	—	$	—


(a)	All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See Note 9 for additional information.

We recognized the following compensation costs (credits), net of actual forfeitures, related to our liability-classified awards for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period.



	Three Months Ended June 30,					Six Months Ended June 30,
	2020		2019			2020			2019
	($ in millions)
General and administrative expenses	$	—	$	(1	)	$	(3	)	$	8
Oil and natural gas properties	—		—			—			1
Oil, natural gas and NGL production expenses	—		1			(1		)	3
Exploration expenses	—		(1		)	—			—
Total liability-classified awards compensation	$	—	$	(1	)	$	(4	)	$	12

2020 Compensation Adjustments

On May 5, 2020, all of the outstanding share-based compensation, including restricted stock, stock options, PSUs and CRSUs, granted to our executive officers and designated vice presidents was canceled and replaced with cash retention incentives. The cash retention incentives granted to executive officers are equally weighted between achievement of certain specified performance metrics and a service period. The cash retention incentives may be clawed back if an executive officer or vice president terminates employment for any reason other than a qualifying termination prior to the earlier of (i) the effective date of a plan of reorganization under Chapter 11 of the Bankruptcy Code or (ii) May 8, 2021. The transactions were considered a modification to the previously issued equity-classified awards. As such, the remaining unrecognized expense related to restricted stock and stock options will result in $18 million of share-based compensation expense to be amortized over the relevant service period of the new cash retention incentives. The $15 million after-tax fair value of the cash retention incentives was capitalized to other current assets in the condensed consolidated balance sheets in the Current Quarter and will be amortized over the relevant service period. The difference between the cash and after-tax value of the cash retention incentives of approximately $10 million, which is not subject to the claw back provisions contained within the agreements, was expensed to general and administrative expenses in the condensed consolidated statements of operations for the Current Quarter.

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(Unaudited)


11.	Derivative and Hedging Activities

We use derivative instruments to reduce our exposure to fluctuations in future commodity prices and to protect our expected operating cash flow against significant market movements or volatility. All of our oil, natural gas and NGL derivative instruments are net settled based on the difference between the fixed-price payment and the floating-price payment, resulting in a net amount due to or from the counterparty. NaN of our oil, natural gas or NGL derivative instruments were designated for hedge accounting as of December 31, 2019. As of June 30, 2020, we had 0 open derivative contracts. All of our existing contracts were settled in the Current Quarter prior to the Bankruptcy Filing. Pursuant to the RSA associated with our Chapter 11 Cases, we are required to hedge a certain amount of our production with our DIP Credit Facility lenders. See Note 1 for additional details regarding these hedging requirements and see Note 19 for details regarding hedges entered into subsequent to June 30, 2020.

Oil, Natural Gas and NGL Derivatives

Our oil, natural gas and NGL derivative instruments consist of the following types of instruments:


•	Swaps: We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options and call swaptions.


•	Options: We sell, and occasionally buy, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess on sold call options and we receive the excess on bought call options. If the market price is lower than the fixed price of the call option, no payment is due from either party.


•	Call Swaptions: We sell call swaptions to counterparties in exchange for a premium. Swaptions allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time or to increase the notional volumes of an existing fixed-price swap.

•

Collars: These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price.


•	Basis Protection Swaps: These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity.

•

Put spreads: These instruments contain a fixed floor price (bought put) and sub floor price (sold put). If the market price exceeds the bought put strike, we receive the market price. If the market price is between the bought put and sold put strike prices, we receive the bought put price. If the market price falls below the sub floor, we receive the market price plus the difference between the sold put and bought put.

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(Unaudited)

The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of June 30, 2020 and December 31, 2019 are provided below:



	June 30, 2020			December 31, 2019
	Notional Volume	Fair Value		Notional Volume	Fair Value
		($ in millions)			($ in millions)
Oil (mmbbl):
Fixed-price swaps	—	$	—	24	$	(7	)
Call options (sold)	—	—		—	—
Collars	—	—		2	14
Basis protection swaps	—	—		8	(2		)
Total oil	—	—		34	5
Natural gas (bcf):
Fixed-price swaps	—	—		265	125
Call options (sold)	—	—		22	—
Call swaptions	—	—		29	(2		)
Put spreads	—	—		—	—
Basis protection swaps	—	—		30	2
Total natural gas	—	—		346	125
Total estimated fair value		$	—		$	130

We have terminated certain commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. See further discussion below under Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss).

Effect of Derivative Instruments – Condensed Consolidated Balance Sheets

As of June 30, 2020, we had 0 open derivative contracts. The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of December 31, 2019 on a gross basis and after same-counterparty netting:



	December 31, 2019
Balance Sheet Classification	Gross Fair Value			Amounts Netted in the Consolidated Balance Sheets			Net Fair Value Presented in the Consolidated Balance Sheets
	($ in millions)
Commodity Contracts:
Short-term derivative asset	$	174		$	(40	)	$	134
Short-term derivative liability	(42		)	40			(2		)
Long-term derivative liability	(2		)	—			(2		)
Total derivatives	$	130		$	—		$	130

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(Unaudited)

Effect of Derivative Instruments – Condensed Consolidated Statements of Operations

The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below:



	Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019
	($ in millions)
Oil, natural gas and NGL revenues	$	440		$	1,179		$	1,334		$	2,409
Gains (losses) on undesignated oil, natural gas and NGL derivatives	(165		)	283			751			(8		)
Losses on terminated cash flow hedges	(8		)	(8		)	(17		)	(18		)
Total oil, natural gas and NGL revenues	$	267		$	1,454		$	2,068		$	2,383

The components of marketing revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below:



	Three Months Ended June 30,					Six Months Ended June 30,
	2020		2019			2020		2019
	($ in millions)
Marketing revenues	$	240	$	917		$	964	$	2,152
Losses on undesignated marketing natural gas derivatives	—		(1		)	—		(3		)
Total marketing revenues	$	240	$	916		$	964	$	2,149

Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss)

A reconciliation of the changes in accumulated other comprehensive income (loss) in our condensed consolidated statements of stockholders’ equity related to our cash flow hedges is presented below:



	Three Months Ended June 30,
	2020					2019
	Before Tax			After Tax		Before Tax			After Tax
	($ in millions)
Balance, beginning of period	$	(36	)	$	21	$	(70	)	$	(13	)
Losses reclassified to income	8			8		8			8
Balance, end of period	$	(28	)	$	29	$	(62	)	$	(5	)



	Six Months Ended June 30,
	2020					2019
	Before Tax			After Tax		Before Tax			After Tax
	($ in millions)
Balance, beginning of period	$	(45	)	$	12	$	(80	)	$	(23	)
Losses reclassified to income	17			17		18			18
Balance, end of period	$	(28	)	$	29	$	(62	)	$	(5	)

The accumulated other comprehensive loss as of June 30, 2020 represents the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. Remaining deferred gain or loss amounts will be recognized in earnings in the month for which

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the original contract months are to occur. As of June 30, 2020, we expect to transfer approximately $22 million of net loss included in accumulated other comprehensive income (loss) to net income (loss) during the next 12 months. The remaining amounts will be transferred by December 31, 2022.

Credit Risk Considerations

Hedging Arrangements

Certain of our hedging arrangements are with counterparties that are also lenders (or affiliates of lenders) under our pre-petition revolving credit facility. The contracts entered into with these counterparties are secured by the same collateral that secures the pre-petition revolving credit facility. In addition, we enter into bilateral hedging agreements with other counterparties. The counterparties’ and our obligations under the bilateral hedging agreements must be secured by cash or letters of credit to the extent that any mark-to-market amounts owed to us or by us exceed defined thresholds. As of June 30, 2020, we did not have any cash or letters of credit posted as collateral for our commodity derivatives.

Fair Value

As of June 30, 2020, we had 0 open derivative contracts. The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of December 31, 2019:



	December 31, 2019
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total Fair Value
Derivative Assets (Liabilities):			($ in millions)
Commodity assets	$	—	$	160		$	14		$	174
Commodity liabilities	—		(42		)	(2		)	(44		)
Total derivatives	$	—	$	118		$	12		$	130

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(Unaudited)

A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below:



	Commodity Derivatives			Utica Contingent Consideration
	($ in millions)
Balance, as of January 1, 2020	$	12		$	—
Total gains (losses) (realized/unrealized):
Included in earnings^(a)	3			—
Total purchases, issuances, sales and settlements:
Settlements	(15		)	—
Balance, as of June 30, 2020	$	—		$	—

Balance, as of January 1, 2019	$	87		$	7
Total gains (losses) (realized/unrealized):
Included in earnings^(a)	(64		)	(7		)
Total purchases, issuances, sales and settlements:
Settlements	(1		)	—
Balance, as of June 30, 2019	$	22		$	—

___________________________________________



(a)		Commodity Derivatives					Utica Contingent Consideration
		Commodity Derivatives					Utica Contingent Consideration
		2020		2019			2020		2019
		($ in millions)
	Total gains (losses) included in earnings for the period	$	3	$	(64	)	$	—	$	(7	)
	Change in unrealized gains (losses) related to assets still held at reporting date	$	—	$	(66	)	$	—	$	7


12.	Exploration Expense

A summary of our exploration expense for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period is as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	($ in millions)
Impairments of unproved properties	$	127	$	7	$	399	$	25
Dry hole expense	—		—		7		—
Geological and geophysical expense and other	3		8		6		14
Exploration expense	$	130	$	15	$	412	$	39

Unproved oil and natural gas properties are periodically assessed for impairment by considering future drilling and exploration plans, results of exploration activities, commodity price outlooks, planned future sales and expiration of all or a portion of the projects. The exploration expense charges during the Current Quarter are the result of non-cash impairment charges in unproved properties, primarily in our Haynesville operating area. The exploration expense charges during the Current Period are the result of non-cash impairment charges in unproved properties, primarily in our Brazos Valley, Powder River Basin, Haynesville and Mid-Continent operating areas.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


13.	Impairments

During the Current Period, the decrease in demand for crude oil primarily due to COVID-19 and sharp decline in commodity prices related to the combined impact of falling demand and increases in production from OPEC+ resulted in decreases in current and expected long-term crude oil and NGL sale prices. These conditions resulted in reductions to the market capitalization of peer companies in the energy industry. We determined these adverse market conditions represent a triggering event to perform an impairment assessment of our long-lived assets used in, and in support of, our operations, including proved oil and gas properties, and our sand mine assets.

Proved Oil and Gas Properties

Unprecedented volatility in the price of oil due to the decrease in demand has led us to rely on NYMEX strip pricing, which represents a Level 1 input.

Sand Mine

Our in-field sand mine assets predominately service the oil and gas properties in our Brazos Valley operating area. Based on management’s assumptions and expectations of (i) future commodity prices, (ii) capital investment plans in the Brazos Valley operating area, and (iii) future operating cost of the sand mine, management expects the market for sand to significantly decrease for the foreseeable future. As a result, we recognized a $76 million impairment related to our sand mine assets for the difference between fair value and the carrying value in the Current Period. The inputs used are classified as Level 3 fair value assumptions.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


14.	Capitalized Exploratory Well Costs

A summary of the changes in our capitalized well costs for the Current Period is detailed below.



	Six Months Ended June 30, 2020
	($ in millions)
Balance as of January 1	$	7
Charges to exploration expense	(7		)
Balance as of June 30	$	—

As of June 30, 2020, there were 0 drilling and completion costs on exploratory wells pending determination of proved reserves capitalized for greater than one year.


15.	Investments

In the Current Period, the hydraulic fracturing industry experienced challenging operating conditions resulting in the current fair value of our investment in FTS International, Inc. (NYSE: FTSI) falling below book value of $23 million and remaining below that value as of the end of the Current Period. Based on FTSI’s operating results, we determined that the reduction in fair value is other-than-temporary, and recognized an impairment of our entire investment in FTSI of $23 million.

In the Prior Period, in connection with the acquisition of WildHorse, we obtained a 50% membership interest in JWH Midstream LLC (JWH). The carrying value of our investment in JWH, which was being accounted for as an equity method investment, was approximately $17 million as of March 31, 2019. In the Prior Quarter, we paid approximately $7 million to terminate our involvement in the partnership. This removed us from any future obligations related to this joint venture and, therefore, we impaired the full value of the investment and recognized an approximate $23 million expense in the Prior Quarter.


16.	Other Operating Expense

In the Current Period, we terminated certain gathering, processing and transportation contracts and recognized a non-recurring $80 million expense related to the contract terminations. The contract terminations removed approximately $169 million of future commitments related to gathering, processing and transportation agreements. See Note 5 for further discussion of contingencies and commitments.

In the Prior Period, we recorded approximately $26 million of costs related to our acquisition of WildHorse which consisted of consulting fees, financial advisory fees, legal fees and travel and lodging expenses. In addition, we recorded approximately $38 million of severance expense as a result of the acquisition of WildHorse. A majority of the WildHorse executives and employees were terminated. These executives and employees were entitled to severance benefits in accordance with existing employment agreements.


17.	Separation and Other Termination Costs

In the Current Quarter and the Current Period, we incurred charges of approximately $22 million and $27 million, respectively, related to one-time termination benefits for certain employees.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


18.	Condensed Combined Debtor-in-Possession Financial Information

The financial statements below represent the condensed combined financial statements of the Debtors as of June 30, 2020 and December 31, 2019 and for the three and six months ended June 30, 2020 and 2019.

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)



	June 30, 2020			December 31, 2019
ASSETS	($ in millions)
CURRENT ASSETS:
Cash and cash equivalents	$	80		$	4
Other current assets	608			1,244
Total Current Assets	688			1,248
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, based on successful efforts accounting, net	4,671			13,586
Other property and equipment, net	1,014			1,118
Property and equipment held for sale, net	10			10
Total Property and Equipment, Net	5,695			14,714
Other long-term assets	161			187
Investments in subsidiaries and intercompany advances	(12		)	6
TOTAL ASSETS	$	6,532		$	16,155
LIABILITIES AND EQUITY (DEFICIT)
CURRENT LIABILITIES:
Current liabilities	$	2,389		$	2,391
Total Current Liabilities	2,389			2,391
Long-term debt, net	—			9,073
Deferred income tax liabilities	—			10
Other long-term liabilities	217			317
Liabilities subject to compromise	8,135			—
Total Liabilities	10,741			11,791
EQUITY (DEFICIT):
Chesapeake Stockholders’ Equity (Deficit)	(4,209		)	4,364
Total Equity (Deficit)	(4,209		)	4,364
TOTAL LIABILITIES AND EQUITY (DEFICIT)	$	6,532		$	16,155

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019
	($ in millions)
REVENUES AND OTHER:
Oil, natural gas and NGL	$	265		$	1,451		$	2,064		$	2,376
Marketing	240			916			964			2,149
Total Revenues	505			2,367			3,028			4,525
Other	14			15			30			30
Gains on sales of assets	—			1			—			20
Total Revenues and Other	519			2,383			3,058			4,575
OPERATING EXPENSES:
Oil, natural gas and NGL production	91			144			213			259
Oil, natural gas and NGL gathering, processing and transportation	269			270			553			542
Severance and ad valorem taxes	25			62			79			113
Exploration	130			15			412			39
Marketing	242			940			988			2,170
General and administrative	111			88			176			191
Separation and other termination costs	22			—			27			—
Provision for legal contingencies, net	7			3			8			3
Depreciation, depletion and amortization	157			578			759			1,096
Impairments	—			1			8,489			2
Other operating expense	5			3			88			64
Total Operating Expenses	1,059			2,104			11,792			4,479
INCOME (LOSS) FROM OPERATIONS	(540		)	279			(8,734		)	96
OTHER INCOME (EXPENSE):
Interest expense	(137		)	(175		)	(282		)	(336		)
Losses on investments	—			(23		)	(23		)	(24		)
Gains on purchases or exchanges of debt	2			—			65			—
Other income	6			18			12			27
Reorganization items, net	394			—			394			—
Equity in net earnings (losses) of subsidiary	(1		)	(1		)	(18		)	—
Total Other Income (Expense)	264			(181		)	148			(333		)
INCOME (LOSS) BEFORE INCOME TAXES	(276		)	98			(8,586		)	(237		)
Income tax benefit	—			—			(13		)	(314		)
NET INCOME (LOSS)	(276		)	98			(8,573		)	77
Other comprehensive income	8			8			17			18
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	$	(268	)	$	106		$	(8,556	)	$	95

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)

CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)



	Six Months Ended June 30,
	2020			2019
	($ in millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	$	771		$	850
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(843		)	(1,070		)
Business combination, net	—			(353		)
Acquisitions of proved and unproved properties	(9		)	(17		)
Proceeds from divestitures of proved and unproved properties	7			82
Additions to other property and equipment	(15		)	(18		)
Proceeds from sales of other property and equipment	4			4
Net Cash Used In Investing Activities	(856		)	(1,372		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from pre-petition revolving credit facility borrowings	3,806			6,416
Payments on pre-petition revolving credit facility borrowings	(3,467		)	(5,452		)
Cash paid to purchase debt	(95		)	(381		)
DIP credit facility financing costs	(55		)	—
Cash paid for preferred stock dividends	(22		)	(46		)
Other financing activities	(6		)	(16		)
Net Cash Provided By Financing Activities	161			521
Net increase (decrease) in cash and cash equivalents	76			(1		)
Cash and cash equivalents, beginning of period	4			3
Cash and cash equivalents, end of period	$	80		$	2

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

(Unaudited)


19.	Subsequent Events

On July 1, 2020, the Company, as borrower, entered into the DIP Credit Agreement, which was approved by the Bankruptcy Court on July 31, 2020.

Subsequent to June 30, 2020, pursuant to requirements of the RSA associated with our Chapter 11 Cases, we were required to enter into hedge agreements with certain of our DIP Credit Facility lenders, within 30 days of the Petition Date, for at least 50% of the projected monthly production from proved developed producing oil and natural gas reserves for a forward 24-month period. These hedge agreements provide downside price protection through swaps on 23 mmbbls of oil at an average price of $41.74 per bbl and 532 bcf of natural gas at an average price of $2.45 per mcf.

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CHESAPEAKE ENERGY CORPORATION AND SUBSIDIARIES

SUPPLEMENTARY INFORMATION

Oil, Natural Gas and NGL Reserve Quantities

Presented below is a summary of changes in estimated reserves ~~for the Current Quarter:~~through March 31, 2020:



	Oil		Natural Gas		NGL		Total
	(mmbbl)		(bcf)		(mmbbl)		(mmboe)
March 31, 2020
Proved reserves, beginning of period	358		6,566		120		1,572
Extensions, discoveries and other additions	3		91		1		19
Revisions of previous estimates	(136	)	(2,298	)	(40	)	(560	)
Production	(12	)	(173	)	(3	)	(43	)
Proved reserves, end of period	213		4,186		78		988
Proved developed reserves:
Beginning of period	201		3,377		82		846
End of period	198		3,371		73		832
Proved undeveloped reserves:
Beginning of period	157		3,189		38		726
End of period	15		815		5		156

Reflected above represents material changes to estimated reserves from December 31, 2019 through March 31, 2020. There were no material changes to estimated reserves in the Current Quarter. During the ~~Current Quarter,~~quarter ended March 31, 2020, revisions of previous estimates decreased primarily due to updates to our five-year development plan in contemplation of ongoing market conditions and uncertainty regarding our ability to finance the development of our proved reserves over a five-year period.

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ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations

Introduction

The following discussion should be read together with the condensed consolidated financial statements included in Item 1 of Part I of this report and in Item 8 of our 2019 Form 10-K.

We are an independent exploration and production company engaged in the acquisition, exploration and development of properties to produce oil, natural gas and NGL from underground reservoirs. We own a large and geographically diverse portfolio of onshore U.S. unconventional natural gas and liquids assets, including interests in approximately ~~13,700~~13,600 oil and natural gas wells. We have significant positions in the liquids-rich resource plays of the Eagle Ford Shale in South Texas, the stacked pay in the Powder River Basin in Wyoming and the Anadarko Basin in northwestern Oklahoma. Our natural gas resource plays are the Marcellus Shale in the northern Appalachian Basin in Pennsylvania and the Haynesville/Bossier Shales in northwestern Louisiana.

Our strategy is to ~~create shareholder value through the development of~~develop our significant resource ~~plays.~~plays in a manner that generates cash flow from operating activities and improves margins through financial discipline and operating efficiencies, while maintaining exceptional environmental and safety performance. Current market conditions make it difficult to execute on this ~~strategy;~~strategy, as evidenced by our voluntary filing for Chapter 11 protection on June 28, 2020; however, we continue to focus on ~~reducing debt,~~ increasing cash provided by operating activities, improving margins through financial discipline and operating efficiencies and maintaining exceptional environmental and safety performance. To accomplish these goals, we intend to allocate our capital expenditures to projects we believe offer the highest return and value, ~~regardless of the commodity price environment,~~ to deploy leading drilling and completion technology throughout our portfolio, and to take advantage of acquisition and divestiture opportunities to strengthen our cost structure and our portfolio. We continue to seek opportunities to reduce cash costs per barrel of oil equivalent production (production, gathering, processing and transportation and general and administrative) through operational efficiencies, including but not limited to improving our production volumes from existing wells. In response to current market conditions, we have reduced our workforce, curtailed production and reduced capital, which will further reduce future production.

Recent Developments

Voluntary Reorganization Under Chapter 11

On June 28, 2020 (the “Petition Date”), we and certain of our subsidiaries (collectively, the “Debtors”) filed voluntary petitions (the “Chapter 11 Cases”) for relief (the “Bankruptcy Filing”) under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”). On June 29, 2020, the Bankruptcy Court entered an order authorizing the joint administration of the Chapter 11 Cases under the caption In re Chesapeake Energy Corporation, Case No. 20-33233 (DRJ). Subsidiaries with noncontrolling interests, consolidated variable interest entities and certain de minimis subsidiaries (collectively, the “Non-Filing Entities”) were not part of the Bankruptcy Filing. The Non-Filing Entities will continue to operate in the ordinary course of business.

We are currently operating as debtors-in-possession in accordance with the applicable provisions of the Bankruptcy Code. The Bankruptcy Court has granted first day motions filed by us that were designed primarily to mitigate the impact of the Chapter 11 Cases on our operations, customers and employees. As a result, we are able to conduct normal business activities and pay all associated obligations for the period following the Bankruptcy Filing and are authorized to pay owner royalties, employee wages and benefits, and certain vendors and suppliers in the ordinary course for goods and services provided. During the pendency of the Chapter 11 Cases, all transactions outside the ordinary course of business require the prior approval of the Bankruptcy Court.

For the duration of the Chapter 11 Cases, our operations and ability to develop and execute our business plan are subject to the risks and uncertainties associated with the Chapter 11 process as described in Item 1A. “Risk Factors.” As a result of these risks and uncertainties, the number of our shares of common stock and stockholders, assets, liabilities, officers and/or directors could be significantly different following the outcome of the Chapter 11 Cases, and the description of our operations, properties and capital plans included in this Form 10-Q may not accurately reflect our operations, properties and capital plans following the Chapter 11 Cases.

During the Chapter 11 Cases, we expect our financial results to continue to be volatile as Restructuring activities and expenses, contract terminations and rejections, and claims assessments significantly impact our consolidated financial statements. As a result, our historical financial performance is likely not indicative of our financial performance after the date of the Bankruptcy Filing. In addition, we have incurred significant professional fees and other costs in

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connection with preparation for the Chapter 11 Cases and expect that we will continue to incur significant professional fees and costs throughout our Chapter 11 Cases.

See Note 1 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for a complete discussion of the Chapter 11 Cases.

Delisting of our Common Stock from the New York Stock Exchange

Our common stock was previously listed on the New York Stock Exchange (the “NYSE”) under the symbol “CHK.” As a result of our failure to satisfy the continued listing requirements of the NYSE, on June 29, 2020, our common stock ceased to trade on the NYSE. Since June 30, 2020, our common stock has been quoted on the OTC Pink Marketplace maintained by the OTC Markets Group, Inc. under the symbol “CHKAQ.” On July 20, 2020, the NYSE filed a Form 25 with the SEC to delist our common stock, senior notes and cumulative convertible preferred stock from the NYSE. The delisting was effective 10 days after the Form 25 was filed. The deregistration of our common stock, senior notes and cumulative convertible preferred stock under Section 12(b) of the Exchange Act will become effective 90 days after the filing date of the Form 25.

COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas

~~On March 11,~~The global spread of COVID-19 created significant volatility, uncertainty, and economic disruption during the first six months of 2020 ~~the World Health Organization declared the ongoing coronavirus (COVID-19) outbreak a pandemic and recommended containment and mitigation measures worldwide.~~. The pandemic has reached more than 200 countries and territories and has resulted in widespread adverse impacts on the global economy and on our customers and other parties with whom we have business relations. State and local authorities have also implemented multi-step policies with the goal of re-opening. However, certain jurisdictions began re-opening only to return to restrictions in the face of increases in new COVID-19 cases. To date, we have experienced limited operational impacts as a result of the restrictions from working remotely or COVID-19 directly. As an essential business under the guidelines issued by each of the states in which we operate, we have been allowed to continue ~~operations, although for the health and safety of our employees we chose to have our non-essential personnel work remotely.~~operations. As a result, since mid-March, we have restricted access to all of our offices and ~~have~~for a period of time directed employees to work remotely to the extent possible. ~~Those employees who are unable to work remotely are being closely monitored and are taking precautions to minimize the risk of exposure.~~ We ~~will begin~~began to re-open our offices in phases beginning ~~mid-May.~~mid-May and special precautions have been implemented to minimize the risk of exposure. These actions ~~since mid-March~~ have allowed us to maintain the engagement and connectivity of our ~~personnel, as well as minimize the number of employees required in the office and field.~~personnel. However, due to severe impacts from the global COVID-19 pandemic on the global demand for oil and natural gas, financial results ~~for the three months ended March 31, 2020 are~~may not necessarily be indicative of operating results for the entire ~~year as only one month of the Current Quarter was impacted by COVID-19 and the related economic volatility.~~year. Moreover, future operations could be negatively affected if a significant number of our employees are quarantined as a result of exposure to the virus.

Our first priority in our response to this crisis has been the health and safety of our employees and those of our other business counterparties. We have implemented preventative measures and developed corporate and regional response plans to minimize unnecessary risk of exposure and prevent infection, while supporting our employees, contractors and vendors to the best of our ability in the circumstances. We have a business continuity team for health, safety and environmental matters and personnel issues, and we have activated this business continuity team to address various impacts of the situation, as they develop. We also have modified certain business practices (including those related to employee travel, employee work locations, and cancellation of physical participation in meetings, events and conferences) to protect the health and safety of our employees, contractors and communities in which we operate by conforming to government restrictions and best practices encouraged by the Centers for Disease Control and Prevention, the World Health Organization and other governmental and regulatory authorities.

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with the current depressed prices, has impacted and is expected to continue to adversely impact our business. AThe continued low level of demand orand prices for oil and natural gas or otherwise ~~would~~has had and will continue to have a ~~continued~~ material adverse effect on our business, cash flows, liquidity, financial condition and results of operations.

As of the date of this Form 10-Q, our efforts to respond to the challenges presented by the conditions described above and minimize the impacts to our business have yielded results. We have moved quickly to implement strategies to reduce costs, increase operational efficiencies and lower our capital spending. In April, we underwent a reduction in workforce impacting approximately 13% of our employees. In connection with the reduction, we ~~expect to record~~recorded a non-recurring charge of approximately $22 million in the ~~second quarter of 2020~~Current Quarter and we anticipate an estimated annualized savings of approximately $36 million. Due to ~~current~~the significant drop in oil prices and midstream constraints in the Current Quarter, we ~~have~~ shut-in wells and delayed turn-in-lines, which ~~will reduce~~reduced our ~~projected~~ oil production by approximately 50% and ~~37%~~25% in May and June, respectively. As market conditions improve, we ~~will return~~have returned most wells to production and intend to complete most of our drilled but uncompleted wells. We anticipate our capital expenditures for the remainder of the year ~~will range between $500 and $700 million and~~ will be focused primarily on our gas assets. We have not received any funding under the CARES Act or other federal programs to support our operations and do not anticipate that we will. We are continuing to address concerns to protect the health and safety of our employees and those of our customers and other business counterparties, and this includes changes to comply with health-related guidelines as they are modified and supplemented.

We cannot predict the full impact that COVID-19 or the significant disruption and volatility currently being experienced in the oil and natural gas markets will have on our business, cash flows, liquidity, financial condition and results of operations at this time due to numerous uncertainties. The ultimate impacts will depend on future developments, including, among others, the ultimate geographic spread of the virus, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, the duration of the outbreak, actions taken by members of OPEC+ and other foreign, oil-exporting countries, governmental authorities, customers and other thirds parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume. For additional discussion regarding risks associated with the COVID-19 pandemic, see Item 1A “Risk Factors” in this report.

Reverse Stock Split

The reverse stock split was intended to, among other things, increase the per share trading price of our common shares to satisfy the $1.00 minimum closing price requirement for continued listing on the NYSE. The price condition will be deemed cured if on the last trading day of any calendar month within six months following the receipt from the NYSE of the notice of non-compliance, we have a closing share price of at least $1.00 and an average closing share

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price of at least $1.00 over the 30 trading-day period ending on the last trading day of that month. On April 1, 2020, the NYSE tolled the compliance period through June 30, 2020. As a result of the reverse stock split, each 200 pre-split shares of common stock outstanding were automatically combined into one issued and outstanding share of common stock. The fractional shares that resulted from the reverse stock split were canceled by paying cash in lieu of the fair value. The number of outstanding shares of common stock were reduced from approximately 1.957 billion as of April 10, 2020 to approximately 9.784 million shares (without giving effect to the liquidation of fractional shares). The total number of shares of common stock that we are authorized to issue was reduced from 3,000,000,000 to 22,500,000 shares. All share and per share amounts in the accompanying condensed consolidated financial statements and notes thereto were retroactively adjusted for all periods presented to give effect to this reverse stock split, including reclassifying an amount equal to the reduction in par value of our common stock to additional paid-in capital.

Adoption of Rights Plan

On April 23, 2020, our Board of Directors declared a dividend of one Right payable on May 4, 2020 for each share of our common stock outstanding on May 4, 2020 to the shareholders of record on that date. In connection with the distribution of the Rights, we entered into a Rights Agreement with Computershare Trust Company, N.A., as rights agent. Each Right entitles the registered holder to purchase from us Preferred Shares.

The Rights Agreement is intended to protect value by preserving our ability to use our tax attributes to offset potential future income taxes for federal income tax purposes. Our ability to use our tax attributes would be substantially

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limited if we experience an “ownership change,” as such term is defined in Section 382 of the Code. A company generally experiences an ownership change if the percentage of its shares of stock owned by its “5-percent shareholders,” as such term is defined in Section 382 of the Code, increases by more than 50 percentage points over a rolling three-year period. The Rights Agreement is intended to reduce the likelihood of an ownership change under Section 382 of the Code by deterring any person or group of affiliated or associated persons from acquiring 4.9% or more of our outstanding shares of common stock.

The Rights Agreement will expire on the close of business on the day following the certification of the voting results from our 2021 annual meeting of shareholders, unless our shareholders ratify the Rights Agreement at or prior to such meeting, in which case it will continue in effect until April 22, 2023, unless terminated earlier in accordance with its terms. This summary description of the rights plan does not purport to be complete and is qualified in its entirety by reference to the Rights Agreement, which was filed as an exhibit to our current report on Form 8-K filed on April 23, 2020.

Liquidity and Capital Resources

Liquidity Overview

Our primary sources of capital resources and liquidity have historically consisted of internally generated cash flows from operations, borrowings under certain credit agreements, dispositions of non-core assets and the capital markets when conditions are favorable. Our ability to ~~grow, make~~issue additional indebtedness, dispose of assets or access the capital expenditures and service our debt depends primarily upon the prices we receive for the oil, natural gas and NGL we sell. Substantial expenditures are required to replace reserves, sustain production and fund our business plans. Historically, oil and natural gas prices have been volatile; however, the volatility in the prices for these commodities hasmarkets may be substantially increased as a result of COVID-19 and the OPEC+ decisions discussed in this Form 10-Q. Oil prices in particular have plummeted in the past few weeks. We expect to see continued volatility in oil and natural gas prices for the foreseeable future, and such volatility, combined with the current depressed prices, has impacted and is expected to continue to adversely impact our business. A continued low level of oil, natural gas and NGL prices has affected and could continue to negatively affect the amount of cash we generate and have available for capital expenditures and debt service and has had and could continue to have a material impact on our financial position, results of operations, cash flows and on the quantities of reserves that we can economically producelimited or provide as collateral to our secured lenders and creditors. If the current depressed prices persist or decline throughout 2020, our ability to comply with financial covenants under our revolving credit facilitynonexistent during the ~~next 12 months~~Chapter 11 Cases and will ~~be adversely affected. Based~~require court approval in most instances. Accordingly, our liquidity will depend mainly on ~~our current forecast, we do not expect to be in compliance with our financial covenants beginning in~~cash generated from operating activities and available funds under the ~~fourth quarter~~DIP Credit Facility discussed below.

Filing of ~~2020. Failure to comply with these covenants, if not waived, would result in~~the Chapter 11 Cases constituted an event of default ~~under~~with respect to certain of our ~~revolving credit facility, the potential acceleration of outstanding~~secured and unsecured debt thereunder and the potential foreclosure on the collateral securing such debt, and could cause a cross-default under our other outstanding indebtedness. Other risks and uncertainties that could affect our liquidity include, but are not limited to, counterparty credit risk for our receivables, access to capital markets, regulatory risks and our ability to meet financial covenants in our financing agreements.

obligations. As a result of the ~~impacts to~~Chapter 11 Cases, the ~~Company’s financial position resulting~~principal and interest due under these debt instruments became immediately due and payable. However, the creditors are stayed from ~~declining industry conditions and in consideration~~taking any action as a result of the ~~substantial amount of long-term debt outstanding, the Company has engaged advisors to assist~~

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with the evaluation of strategic alternatives, which may include, but not be limited to, seeking a restructuring, amendment or refinancing of existing debt through a private restructuring or reorganizationdefault under ~~Chapter 11~~Section 362 of the Bankruptcy Code. ~~However, there can be no assurances that~~

Recent Events Affecting Liquidity

On June 28, 2020, prior to the commencement of the Chapter 11 Cases, the Company ~~will be able to successfully restructure its indebtedness, improve its financial position or complete any strategic transactions. As~~entered into a ~~result~~commitment letter (the “Commitment Letter”) with certain of ~~these uncertainties and~~ the ~~likelihood of a restructuring or reorganization, management has concluded that there is substantial doubt about~~lenders under the ~~Company’s ability to continue as a going concern.~~

As of March 31, 2020 and December 31, 2019, we had a cash balance of $82 million and $6 million, respectively. As of March 31, 2020 and December 31, 2019, we had a net working capital deficit of $442 million and $1.141 billion, respectively. As of March 31, 2020 and December 31, 2019, our working capital deficit included $420 million and $385 million, respectively, of debt due in the next 12 months. As of March 31, 2020, we had $1.011 billion of borrowing capacity available under ourpre-petition revolving credit facility and/or their affiliates (collectively, the “Commitment Parties”), pursuant to which, and subject to the satisfaction of certain customary conditions, including the approval of the Bankruptcy Court, the Commitment Parties agreed to provide the Debtors with a post-petition senior secured super-priority debtor-in-possession revolving credit facility in an aggregate principal amount of up to approximately $2.104 billion (the “DIP Credit Facility”), consisting of a revolving loan facility of new money in an aggregate principal amount of up to $925 million, which includes a sub-facility of up to $200 million for the issuance of letters of credit, and an up to approximately $1.179 billion term loan that reflects the roll-up of a portion of outstanding borrowings under the pre-petition revolving credit facility. Pursuant to the Commitment Letter, the Commitment Parties also committed to provide, subject to certain conditions, an up to $2.5 billion exit credit facility, consisting of ~~$1.900~~an up to $1.75 billion revolving credit facility (the “Exit Revolving Facility”) and ~~$89~~an up to $750 million ~~utilized~~senior secured term loan facility (the “Exit Term Loan Facility” and, together with the Exit Revolving Facility, the “Exit Credit Facilities��). The terms and conditions of the DIP Credit Facility are set forth in the DIP Credit Agreement (the “DIP Credit Agreement”) attached to the Commitment Letter. The financing package provides us the capital necessary to fund our operations during the Court-supervised Chapter 11 reorganization proceedings. The proceeds of the DIP Credit Facility may be used for, ~~various~~among other things, post-petition working capital, permitted capital investments, general corporate purposes, letters of ~~credit.~~credit, administrative costs, premiums, expenses and fees for the transactions contemplated by the Chapter 11 Cases, payment of court approved adequate protection obligations, and other such purposes consistent with the DIP Credit Facility. On July 1, 2020, the Company, as borrower, entered into the DIP Credit Agreement along with the Debtor guarantors party thereto, MUFG Union Bank, N.A., as agent, and the other lender, issuer, and agent parties thereto with the other Debtors party thereto. See Note 4 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for further discussion of our ~~debt obligations,~~DIP Credit Facility.

As of June 30, 2020 and December 31, 2019, we had a cash balance of $82 million and $6 million, respectively. As of June 30, 2020 and December 31, 2019, we had a net working capital deficit of $1.699 billion and $1.141 billion, respectively. Additionally, our DIP Credit Facility was approved by the Bankruptcy Court on a final basis on July 31, 2020 which allows us up to $925 million of borrowing capacity.

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We believe our cash flow from operations, borrowing capacity under the DIP Credit Facility and cash on hand will provide sufficient liquidity during the bankruptcy process. We expect to incur significant costs associated with the bankruptcy process, including ~~principal~~fees for legal, financial and ~~carrying amounts~~restructuring advisors to the Company, certain of our ~~notes.~~creditors and royalty interest owners. Therefore, our ability to obtain confirmation of the Plan in a timely manner is critical to ensuring our liquidity is sufficient during the bankruptcy process.

~~We closely monitor~~Our ability to continue as a going concern is contingent on our ability to comply with the financial and other covenants contained in our DIP Credit Facility, the Bankruptcy Court’s approval of the Plan and our ability to successfully implement the Plan and obtain exit financing, among other factors. As a result of the Bankruptcy Filing, the realization of assets and the satisfaction of liabilities are subject to uncertainty. While operating as debtors-in-possession under Chapter 11, we may sell or otherwise dispose of or liquidate assets or settle liabilities, subject to the approval of the Bankruptcy Court or as otherwise permitted in the ordinary course of business (and subject to restrictions contained in the DIP Credit Facility), for amounts other than those reflected in the accompanying condensed consolidated financial statements. Further, the Plan could materially change the amounts and ~~timing~~classifications of ~~our sources~~assets and ~~uses of funds, particularly as they affect~~liabilities reported in the condensed consolidated financial statements. The factors noted above raise substantial doubt about our ability to maintain compliance with the financial covenants of our revolving credit facility. Furthermore, our ability to generate operating cash flow in the current commodity price environment, sell assets, access capital markets or take any other action to improve our liquidity and manage our debt is subject to the risks discussed above and the other risks and uncertainties that exist in our industry, some of which we may not be able to anticipate at this time or control.continue as a going concern.

We currently have no access to capital and other financial markets. In response to the lack of new capital and funding, we are considering strategic alternatives, which may include but are not limited to additional expense reductions; seeking a restructuring, amendment or refinancing of existing debt through a private restructuring; and reorganization under Chapter 11 of the Bankruptcy Code. Additionally, ourCredit Risk

Our customers and counterparties are experiencing uncertain economic conditions which may impact their ability to make payments to us, which could adversely affect our business, cash flows, liquidity, financial condition and results of operations. We monitor the creditworthiness of all our counterparties and we generally require letters of credit or parent guarantees for receivables from parties deemed to have sub-standard credit, unless the credit risk can otherwise be mitigated

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Derivative and Hedging Activities

Our results of operations and cash flows are impacted by changes in market prices for oil, natural gas and NGL. To mitigate a portion of our exposure to adverse market price changes, we enter into various derivative instruments. Our oil, natural gas and NGL derivative activities, when combined with our sales of oil, natural gas and NGL, allow us to better predict the total revenue we expect to receive. Pursuant to the RSA associated with our Chapter 11 Cases, we are required to hedge a certain amount of our production with our DIP Credit Facility lenders. See Note 1 for additional details regarding these hedging requirements and see Note 19 for details regarding hedges entered into subsequent to June 30, 2020.

As of ~~May 8,~~August 7, 2020, including ~~April~~July and ~~May~~August derivative contracts that have settled, we had 2020 downside oil price protection through swaps ~~and collars~~ at an average price of ~~$59.95~~$41.69 per bbl. We had 2020 downside gas price protection through swaps at ~~$2.76 per mcf and under put spread arrangements based on an average bought put NYMEX price of $2.06 per mcf and exposure below an average sold put NYMEX price of $1.80~~$2.45 per mcf.

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Oil Derivatives^(a)	Oil Derivatives^(a)				Oil Derivatives^(a)
Year		Type of Derivative Instrument	Notional Volume	Average NYMEX Price		Type of Derivative Instrument	Notional Volume	Average NYMEX Price
			(mmbbls)				(mmbbls)
2020		Swaps	21	$59.63
2020		Two-way collars	1	$65.00/$83.25
2020		Basis protection swaps	10	$2.58		Swaps	6	$41.69
2021		Calls	5	$61.58		Swaps	12	$41.90
2022		Calls	4	$61.58		Swaps	5	$41.41
Natural Gas Derivatives^(a)	Natural Gas Derivatives^(a)				Natural Gas Derivatives^(a)
Year		Type of Derivative Instrument	Notional Volume	Average NYMEX Price		Type of Derivative Instrument	Notional Volume	Average NYMEX Price
			(bcf)				(bcf)
2020		Swaps	199	$2.76		Swaps	164	$2.45
2020		Calls	17	$12.00
2020		Basis protection swaps	46	($0.28)
2020		Put spread	94	$2.06/$1.80
2021		Calls	96	$2.75
2021		Call swaptions	14	$2.80		Swaps	235	$2.44
2022		Call swaptions	15	$2.80		Swaps	133	$2.46


(a)	Includes amounts settled in ~~April~~July and ~~May~~August 2020.

See Note 11 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for further discussion of derivatives and hedging activities.

~~Debt~~

We are committed to reducing total leverage to achieve long-term net debt/EBITDAX of 2x. To accomplish this goal, we intend to allocate our capital expenditures to projects we believe offer the highest return and value regardless of the commodity price environment, to deploy leading drilling and completion technology throughout our portfolio, and to take advantage of acquisition and divestiture opportunities to strengthen our cost structure and our portfolio. Increasing our margins means not only increasing our absolute level of cash flows from operations, but also increasing our cash flows from operations generated per barrel of oil equivalent production. We continue to seek opportunities to reduce cash costs (production, gathering, processing and transportation and general and administrative), improve our production volumes from existing wells, and achieve additional operating and capital efficiencies with a focus on growing our oil volumes.

We may continue to use a combination of cash and borrowings and the proceeds from asset sales to retire our outstanding debt or preferred stock through privately negotiated transactions, open market repurchases, redemptions, exchanges, tender offers or otherwise, but we are under no obligation to do so.

~~Revolving Credit Facility~~

Our revolving credit facility matures in September 2023 and the current aggregate commitment of the lenders and borrowing base under the facility is $3.0 billion. The revolving credit facility provides for an accordion feature, pursuant to which the aggregate commitments thereunder may be increased to up to $4.0 billion from time to time, subject to agreement of the participating lenders and certain other customary conditions. Scheduled borrowing base redeterminations will continue to occur semiannually. Our borrowing base was reaffirmed on November 1, 2019. Borrowings under the facility bear interest at a variable rate. As of March 31, 2020, we had outstanding borrowings of $1.900 billion under our revolving credit facility and had used $89 million of our revolving credit facility for various letters of credit. Our next borrowing base redetermination, scheduled for the second quarter of 2020, is not complete. Although we believe we have adequate reserves value to support the reaffirmation of our full borrowing base, we believe it is likely the lending group will reduce our borrowing base due to our distressed financial position. See ~~Note 4~~ ~~of the notes to our condensed consolidated financial statements included in Item 1 of this report for further discussion of the terms~~

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of our revolving credit facility. As of March 31, 2020, we were in compliance with all applicable financial covenants under the credit agreement. As of March 31, 2020, our total leverage ratio was approximately 3.70 to 1.00, our first lien leverage ratio was approximately 1.44 to 1 and our fixed charge coverage ratio was approximately 3.55 to 1.

Contractual Obligations and Off-Balance Sheet Arrangements

From time to time, we enter into arrangements and transactions that can give rise to contractual obligations and off-balance sheet commitments. As of ~~March 31,~~June 30, 2020, these arrangements and transactions included (i) certain operating lease agreements, (ii) open purchase commitments, (iii) open delivery commitments, (iv) open drilling commitments, (v) undrawn letters of credit, (vi) open gathering and transportation commitments, and (vii) various other commitments we enter into in the ordinary course of business that could result in future cash obligations.

Capital Expenditures

We have significant control and flexibility over the timing and execution of our development plan, enabling us to reduce our capital spending as needed. As a result of the impact to global oil demand primarily caused by the COVID-19 pandemic, we are significantly reducing our forecasted 2020 capital expenditures to a range of $1.0 billion –- $1.2 billion compared to our 2019 capital spending level of $2.2 billion. This reduction in spending will reduce our future production levels. Management continues to review operational plans for 2020 and beyond, which could result in changes to projected capital expenditures and projected revenues from sales of oil, natural gas and NGL.

~~Credit Risk~~

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Some of our counterparties have requested or required us to post collateral as financial assurance of our performance under certain contractual arrangements, such as gathering, processing, transportation and hedging agreements. As of May 7, 2020, we have received requests and posted approximately $95 million of collateral related to certain of our marketing and other contracts. We may be requested or required by other counterparties to post additional collateral in an aggregate amount of approximately $172 million, which may be in the form of additional letters of credit, cash or other acceptable collateral. However, we have substantial long-term business relationships with each of these counterparties, and we may be able to mitigate any collateral requests through ongoing business arrangements and by offsetting amounts that the counterparty owes us. Any posting of collateral consisting of cash or letters of credit reduces availability under our revolving credit facility and negatively impacts our liquidity.

Sources of Funds

The following table presents the sources of our cash and cash equivalents for the Current ~~Quarter~~Period and the Prior ~~Quarter.~~Period.

Three Months Ended
March 31,
2020 2019
($ in millions)
Cash provided by operating activities $ 397
$ 456
Proceeds from divestitures of proved and unproved properties, net 7
26
Proceeds from revolving credit facility borrowings, net 310
436
Proceeds from sales of other property and equipment, net —
1
Total sources of cash and cash equivalents $ 714
$ 919

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	Six Months Ended June 30,
	2020		2019
	($ in millions)
Cash provided by operating activities	$	773	$	853
Proceeds from divestitures of proved and unproved properties, net	7		82
Proceeds from revolving pre-petition credit facility borrowings, net	339		964
Proceeds from sales of other property and equipment, net	4		4
Total sources of cash and cash equivalents	$	1,123	$	1,903

Cash Flows from Operating Activities

Cash provided by operating activities was ~~$397~~$773 million in the Current ~~Quarter~~Period compared to ~~$456~~$853 million in the Prior ~~Quarter.~~Period. The decrease in the Current ~~Quarter~~Period is primarily due to the ~~result of~~ lower prices for the oil, natural gas and NGL we sold and lower volumes of oil, natural gas and NGL ~~sold offset by higher oil volumes~~ sold. Cash flows from operations are largely affected by the same factors that affect our net income, excluding various non-cash items, such as depreciation, depletion and amortization, certain impairments, gains or losses on sales of assets, deferred income taxes and mark-to-market changes in our open derivative instruments. ~~Only one month of the~~The Current ~~Quarter~~Period was impacted by COVID-19 and the related economic volatility and a continued low level of demand or depressed prices for oil and natural gas ~~or otherwise would have~~has had a continued material adverse effect on our cash flows. See further discussion below under Results of Operations.

Uses of Funds

The following table presents the uses of our cash and cash equivalents for the Current ~~Quarter~~Period and the Prior ~~Quarter:~~Period:


	Three Months Ended March 31,				Six Months Ended June 30,
	2020		2019		2020		2019
	($ in millions)				($ in millions)
Oil and Natural Gas Expenditures:
Drilling and completion costs	$	501	$	515	$	843	$	1,070
Acquisitions of proved and unproved properties	6		6		9		17
Total oil and natural gas expenditures	507		521		852		1,087
Other Uses of Cash and Cash Equivalents:
Cash paid to purchase debt	93		1		95		381
DIP credit facility financing costs					55		—
Business combination, net	—		353		—		353
Additions to other property and equipment	11		9		15		18
Dividends paid	22		23		22		46
Other	5		8		8		18
Total other uses of cash and cash equivalents	131		394		195		816
Total uses of cash and cash equivalents	$	638	$	915	$	1,047	$	1,903

Drilling and Completion Costs

Our drilling and completion costs decreased in the Current ~~Quarter~~Period compared to the Prior ~~Quarter~~Period primarily as a result of decreased drilling and completion activity. Our average operated rig count was 14 rigs and spud wells were 71 in the Current Quarter compared to an average operated rig count of 20 rigs and 79 spud wells in the Prior Quarter. We completed 74 operated wells in the Current Quarter compared to 83 in the Prior Quarter.

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Cash Paid to Purchase Debt

In the Current ~~Quarter,~~Period, we repurchased approximately $~~156~~160 million aggregate principal amount of our senior notes for $9395 million. See Note 4 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for further discussion of the notes repurchased.

DIP Credit Facility Financing Costs

In the Current Period, we paid $55 million of one-time fees to lenders to establish our DIP Credit Facility.

Business Combination - Acquisition of WildHorse

In the Prior ~~Quarter,~~Period, we acquired WildHorse for approximately 717.4 million shares of our common stock and $381 million less $28 million of cash held by WildHorse as of the acquisition date.

Dividends

We paid dividends of $22 million and ~~$23~~$46 million on our preferred stock in the Current ~~Quarter~~Period and the Prior ~~Quarter,~~Period, respectively. On April 17, 2020, we announced that we were suspending payment of dividends on each series of our outstanding convertible preferred stock. ~~Suspension~~Pursuant to the RSA associated with our Chapter 11 Cases, each holder of an equity interest in Chesapeake would have such interest canceled, released, and extinguished without any distribution. See Note 1 of the ~~dividends did not constitute an event~~notes to our condensed consolidated financial statements included in Item 1 of ~~default under any~~Part I of ~~our debt instruments. We eliminated common stock dividends in~~this report for additional information about the ~~2015 third quarter and do not anticipate paying any common stock dividends in the foreseeable future.~~Chapter 11 Cases.

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Results of Operations

Oil, Natural Gas and NGL Production and Average Sales Prices


	Three Months Ended March 31, 2020										Three Months Ended June 30, 2020
	Oil		Natural Gas		NGL		Total				Oil		Natural Gas			NGL		Total
	mbbl per day	$/bbl	mmcf per day	$/mcf	mbbl per day	$/bbl	mboe per day	%		$/boe	mbbl per day	$/bbl	mmcf per day		$/mcf	mbbl per day	$/bbl	mboe per day	%		$/boe
Marcellus	—	—	976	1.97	—	—	163	34		11.85	—	—	1,051		1.38	—	—	175	41		8.26
Haynesville	—	—	556	1.68	—	—	93	19		10.10	—	—	502		1.46	—	—	84	20		8.75
Eagle Ford	63	48.53	159	2.18	19	11.71	108	23		33.38	40	20.15	117		1.95	16	9.68	75	18		15.76
Brazos Valley	41	46.30	69	0.60	9	5.26	61	13		32.55	36	23.42	49		0.69	6	1.93	50	12		17.58
Powder River Basin	17	43.23	89	1.84	6	13.30	38	8		26.01	13	23.80	52		1.44	3	10.59	25	6		16.96
Mid-Continent	5	44.75	49	2.24	3	14.06	16	3		23.38	4	24.41	36		1.50	3	8.03	12	3		13.39
Retained assets^(a)	126	46.93	1,898	1.86	37	10.71	479	100		20.53	93	22.06	1,807		1.42	28	7.86	421	100		11.46
Divested assets	—	—	—	—	—	—	—	—		—	—	—	(1	)	2.92	—	—	—	—		.
Total	126	46.93	1,898	1.86	37	10.71	479	100	%	20.53	93	22.06	1,806		1.42	28	7.86	421	100	%	11.46

	Three Months Ended March 31, 2019										Three Months Ended June 30, 2019
	Oil		Natural Gas		NGL		Total				Oil		Natural Gas			NGL		Total
	mbbl per day	$/bbl	mmcf per day	$/mcf	mbbl per day	$/bbl	mboe per day	%		$/boe	mbbl per day	$/bbl	mmcf per day		$/mcf	mbbl per day	$/bbl	mboe per day	%		$/boe
Marcellus	—	—	948	3.54	—	—	158	33		21.23	—	—	929		2.33	—	—	155	31		13.99
Haynesville	—	—	759	2.94	—	—	126	26		17.63	—	—	751		2.39	—	—	125	25		14.36
Eagle Ford	61	59.78	148	3.58	24	21.70	109	23		43.01	58	65.82	152		2.69	19	12.78	102	21		43.89
Brazos Valley^(b)	23	59.32	23	2.04	3	8.25	30	6		47.55	35	63.34	55		1.81	5	9.33	49	10		47.57
Powder River Basin	16	50.93	82	3.38	6	18.57	36	7		33.70	20	57.05	89		2.26	5	16.30	40	8		35.58
Mid-Continent	8	52.93	58	2.82	6	21.64	23	5		30.77	9	58.12	59		2.03	6	16.97	25	5		30.53
Retained assets^(a)	108	57.85	2,018	3.27	39	20.03	482	100		28.23	122	63.09	2,035		2.35	35	13.50	496	100		26.13
Divested assets	1	48.05	5	2.48	—	—	2	—		25.59	—	—	(1	)	4.66	—	—	—	—		—
Total	109	57.80	2,023	3.27	39	20.03	484	100	%	28.22	122	63.04	2,034		2.35	35	13.43	496	100	%	26.12

											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
Marcellus											—	—	1,013		1.66	—	—	168	38		9.99
Haynesville											—	—	528		1.58	—	—	88	20		9.46
Eagle Ford											52	37.49	138		2.08	18	10.79	92	20		26.17
Brazos Valley											38	35.62	59		0.63	7	3.82	56	12		25.77
Powder River Basin											15	34.71	71		1.69	4	12.37	32	7		22.40
Mid-Continent											4	36.35	42		1.93	3	11.37	14	3		19.14
Retained assets^(a)											109	36.39	1,851		1.64	32	9.48	450	100		16.28
Divested assets											—	—	1		1.00	—	—	—	—		—
Total											109	36.39	1,852		1.64	32	9.48	450	100	%	16.28

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	Six Months Ended June 30, 2019
	Oil		Natural Gas		NGL		Total
	mbbl per day	$/bbl	mmcf per day	$/mcf	mbbl per day	$/bbl	mboe per day	%		$/boe
Marcellus	—	—	939	2.94	—	—	156	32		17.63
Haynesville	—	—	755	2.67	—	—	126	26		15.99
Eagle Ford	60	62.73	150	3.13	21	17.74	106	21		43.42
Brazos Valley^(b)	28	61.76	39	1.88	4	8.93	39	8		47.56
Powder River Basin	18	54.31	85	2.79	6	17.54	38	8		34.70
Mid-Continent	9	55.72	59	2.47	6	19.14	24	5		30.62
Retained assets^(a)	115	60.64	2,027	2.81	37	16.89	489	100		27.16
Divested assets	—	—	2	1.33	—	—	1	—		18.97
Total	115	60.59	2,029	2.81	37	16.86	490	100	%	27.15


(a)	Includes assets retained as of ~~March 31,~~June 30, 2020.

(b) Average production per day since the date of the WildHorse acquisition on February 1, 2019, 59150 days, was 3534 mbbl, 3547 mmcf and 5 mbbl for oil, natural gas and NGL, respectively.

Oil, Natural Gas and NGL Sales


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		Change		2020		2019		Change		2020		2019		Change
	($ in millions)						($ in millions)
Oil	$	539	$	566	(5	)%	$	186	$	700	(73	)%	$	725	$	1,266	(43	)%
Natural gas	320		595		(46	)%	234		436		(46	)%	554		1,031		(46	)%
NGL	35		69		(49	)%	20		43		(53	)%	55		112		(51	)%
Oil, natural gas and NGL sales	$	894	$	1,230	(27	)%	$	440	$	1,179	(63	)%	$	1,334	$	2,409	(45	)%

The net decrease in oil, natural gas and NGL sales in the Current Quarter of $739 million is primarily attributable to (i) $561 million decrease in revenues due to decreases in the average price received per boe ~~in the Current Quarter resulted in a $335~~and (ii) $178 million decrease in revenues ~~and~~due to decreased sales volumes ~~resulted~~from production curtailments, natural declines and shut-in wells.

The net decrease in ~~a $1~~oil, natural gas and NGL sales in the Current Period of $1.075 billion is primarily attributable to (i) $889 million decrease in revenues ~~for a total net~~due to decreases in the average price received per boe and (ii) $186 million decrease in revenues ~~of $336 million.~~due to decreased sales volumes from production curtailments, natural declines and shut-in wells.

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Oil and Natural Gas Derivatives


	Three Months Ended March 31,					Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019			2020			2019			2020			2019
	($ in millions)					($ in millions)
Oil derivatives – realized gains (losses)	$	127	$	10		$	569		$	(18	)	$	696		$	(8	)
Oil derivatives – unrealized gains (losses)	712		(269		)	(717		)	104			(5		)	(165		)
Total gains (losses) on oil derivatives	839		(259		)	(148		)	86			691			(173		)

Natural gas derivatives – realized gains (losses)	51		(36		)	123			24			174			(12		)
Natural gas derivatives – unrealized gains (losses)	17		(6		)	(148		)	165			(131		)	159
Total gains (losses) on natural gas derivatives	68		(42		)	(25		)	189			43			147
Total gains (losses) on oil and natural gas derivatives	$	907	$	(301	)	$	(173	)	$	275		$	734		$	(26	)

See Note 11 of the notes to our condensed consolidated financial statements included in Item 1 of this report for a discussion of our derivative activity.

Marketing Revenues and Expenses


	Three Months Ended March 31,							Three Months Ended June 30,								Six Months Ended June 30,
	2020			2019		Change		2020			2019			Change		2020			2019			Change
	($ in millions)							($ in millions)
Marketing revenues	$	724		$	1,233	(41	)%	$	240		$	916		(74	)%	$	964		$	2,149		(55	)%
Marketing expenses	746			1,230		(39	)%	242			940			(74	)%	988			2,170			(54	)%
Marketing margin	$	(22	)	$	3	833	%	$	(2	)	$	(24	)	(92	)%	$	(24	)	$	(21	)	(14	)%

Marketing revenues and expenses decreased in the Current Quarter and the Current Period primarily as a result of decreased oil, natural gas, and NGL prices received in our marketing ~~operations.~~operations and less volumes being marketed. Marketing margin ~~decreased~~increased in the Current Quarter primarily due to ~~loss on~~improved margins related to non-equity transactions. Marketing margin decreased in the Current Period primarily as a result of decreased inventory due to lower ~~prices.~~prices offset by improved margins related to non-equity transactions.

Other Revenue

Three Months Ended
March 31,
2020 2019 Change
($ in millions)
Other revenue $ 16
$ 15
7 %



	Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		Change		2020		2019		Change
	($ in millions)
Other revenue	$	14	$	15	(7	)%	$	30	$	30	—	%

Other revenue relates primarily to the amortization of deferred VPP revenue. Our remaining deferred revenue balance of ~~$50~~$36 million will be amortized on a straight-line basis through 2021. See Note 6 of the notes to our condensed consolidated financial statements included in Item 1 of this report for further discussion of our VPP.

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Oil, Natural Gas and NGL Production Expenses


	Three Months Ended March 31,							Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019			Change		2020		2019		Change		2020		2019			Change
	($ in millions, except per unit)							($ in millions, except per unit)
Marcellus	$	9	$	9		—	%	$	7	$	8	(13	)%	$	16	$	18		(11	)%
Haynesville	11		14			(21	)%	11		12		(8	)%	22		25			(12	)%
Eagle Ford	36		41			(12	)%	25		52		(52	)%	61		93			(34	)%
Brazos Valley	27		14			93	%	22		31		(29	)%	50		45			11	%
Powder River Basin	18		14			29	%	10		16		(38	)%	28		30			(7	)%
Mid-Continent	21		25			(16	)%	16		24		(33	)%	36		49			(27	)%
Retained Assets^(a)	122		117			4	%	91		143		(36	)%	213		260			(18	)%
Divested Assets	—		(2		)	(100	)%	—		1		(100	)%	—		(1		)	(100	)%
Total oil, natural gas and NGL production expenses	$	122	$	115		6	%	$	91	$	144	(37	)%	$	213	$	259		(18	)%

								($ per boe)
Marcellus	$	0.58	$	0.63		(8	)%	$	0.46	$	0.59	(22	)%	$	0.52	$	0.61		(15	)%
Haynesville	$	1.30	$	1.22		7	%	$	1.41	$	1.01	40	%	$	1.36	$	1.11		23	%
Eagle Ford	$	3.62	$	4.15		(13	)%	$	3.72	$	5.52	(33	)%	$	3.66	$	4.81		(24	)%
Brazos Valley	$	4.98	$	5.36		(7	)%	$	4.91	$	6.91	(29	)%	$	4.95	$	6.35		(22	)%
Powder River Basin	$	5.28	$	4.36		21	%	$	4.13	$	4.42	(7	)%	$	4.81	$	4.39		10	%
Mid-Continent	$	13.95	$	11.79		18	%	$	13.94	$	10.45	33	%	$	13.94	$	11.04		26	%
Retained Assets^(a)	$	2.80	$	2.69		4	%	$	2.37	$	3.14	(25	)%	$	2.60	$	2.92		(11	)%
Divested Assets	$	—	$	(10.24	)	(100	)%	$	—	$	—	—	%	$	—	$	—		—	%
Total oil, natural gas and NGL production expenses per boe	$	2.80	$	2.64		6	%	$	2.37	$	3.17	(25	)%	$	2.60	$	2.91		(11	)%

(a) Includes assets retained as of ~~March 31,~~June 30, 2020.

The absolute and per unit ~~increase~~decrease in the Current Quarter ~~was~~and the Current Period is primarily the result of ~~the acquisition of WildHorse~~production curtailments in ~~2019 and our higher production in~~the liquids-rich operating areas ~~which generally involve higher production expense per boe relative~~due to ~~our gas-rich operating areas.~~lower commodity prices.

Oil, Natural Gas, and NGL Gathering, Processing and Transportation Expenses


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		Change		2020		2019		Change		2020		2019		Change
	($ in millions, except per unit)						($ in millions, except per unit)
Oil, natural gas and NGL gathering, processing and transportation expenses	$	285	$	274	4	%	$	270	$	271	—	%	$	555	$	545	2	%
Oil ($ per bbl)	$	3.40	$	3.47	(2	)%	$	3.94	$	2.42	63	%	$	3.63	$	2.92	24	%
Natural gas ($ per mcf)	$	1.32	$	1.21	9	%	$	1.36	$	1.23	11	%	$	1.34	$	1.22	10	%
NGL ($ per bbl)	$	5.70	$	5.57	2	%	$	5.35	$	5.01	7	%	$	5.55	$	5.30	5	%
Total ($ per boe)	$	6.55	$	6.29	4	%	$	7.04	$	6.00	17	%	$	6.78	$	6.14	10	%

The ~~absolute and~~ per unit increase in oil, natural gas and NGL gathering, processing and transportation expenses was primarily due to the ~~acquisition of WildHorse in 2019 and an~~ increase in transportation expense related to oil ~~production.~~deficiency fees for our Eagle Ford operating area and production curtailments.

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Severance and Ad Valorem Taxes


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		Change		2020		2019		Change		2020		2019		Change
	($ in millions, except per unit)						($ in millions, except per unit)
Severance taxes	$	31	$	34	(9	)%	$	12	$	40	(70	)%	$	43	$	74	(42	)%
Ad valorem taxes	23		17		35	%	13		22		(41	)%	36		39		(8	)%
Severance and ad valorem taxes	$	54	$	51	6	%	$	25	$	62	(60	)%	$	79	$	113	(30	)%

Severance taxes per boe	$	0.71	$	0.78	(9	)%	$	0.31	$	0.88	(65	)%	$	0.52	$	0.83	(37	)%
Ad valorem taxes per boe	0.53		0.37		43	%	0.35		0.51		(31	)%	0.45		0.44		2	%
Severance and ad valorem taxes per boe	$	1.24	$	1.15	8	%	$	0.66	$	1.39	(53	)%	$	0.97	$	1.27	(24	)%

The ~~per unit~~ decrease in severance taxes was primarily due to the reduction in net revenue value ~~brought by~~as a result of decreased prices in areas where tax is calculated on net revenue instead of production. The decrease in ad valorem taxes is primarily due to lower assessed property values for 2020 compared to 2019. The lower valuations were achieved during the Current Quarter, resulting in the lower absolute and per unit ~~increase in ad valorem taxes was primarily due~~amounts for the Current Quarter as compared to the ~~addition of Texas assets through our acquisition of WildHorse, which increased the amount of oil and natural gas reserves that were subject to ad valorem taxes.~~Prior Quarter.

Exploration Expense


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		Change		2020		2019		Change		2020		2019		Change
	($ in millions)						($ in millions)
Impairments of unproved properties	$	272	$	18	1,411	%	$	127	$	7	1,714	%	$	399	$	25	1,496	%
Dry hole expense	7		—		n/a		—		—		—	%	7		—		n/a
Geological and geophysical expense and other	3		6		(50	)%	3		8		(63	)%	6		14		(57	)%
Exploration expense	$	282	$	24	1,075	%	$	130	$	15	767	%	$	412	$	39	956	%

The increase in exploration expense in the Current Quarter is the result of non-cash impairment charges in unproved properties, primarily in our Haynesville operating area. The increase in exploration expense in the Current Period is the result of non-cash impairment charges in unproved properties, primarily in our Brazos Valley, Powder River Basin, Haynesville and Mid-Continent operating areas. See Note 12 of the notes to our condensed consolidated financial statements included in Item 1 of this report for further discussion.

~~General and Administrative Expenses~~

Three Months Ended
March 31,
2020 2019 Change
($ in millions, except per unit)
Gross compensation and overhead $ 161
$ 195
(17 )%
Allocated to production expenses (30 ) (35 ) (14 )%
Allocated to marketing expenses (4 ) (4 ) — %
Allocated to exploration expenses —
(4 ) (100 )%
Allocated to sand mine expenses (2 ) —
n/a
Capitalized general and administrative expenses (21 ) (13 ) 62 %
Reimbursed from third parties (39 ) (36 ) 8 %
General and administrative expenses, net $ 65
$ 103
(37 )%

General and administrative expenses, net per boe $ 1.50
$ 2.34
(36 )%

~~The decrease in general and administrative expenses is primarily due to a reduction in compensation expense.~~

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~~Restructuring~~General and Administrative Expenses



	Three Months Ended June 30,								Six Months Ended June 30,
	2020			2019			Change		2020			2019			Change
	($ in millions, except per unit)
Gross compensation and overhead	$	189		$	185		2	%	$	350		$	380		(8	)%
Allocated to production expenses	(24		)	(37		)	(35	)%	(54		)	(72		)	(25	)%
Allocated to marketing expenses	(2		)	(4		)	(50	)%	(6		)	(8		)	(25	)%
Allocated to exploration expenses	—			(2		)	(100	)%	—			(6		)	(100	)%
Allocated to sand mine expenses	(1		)	(3		)	(67	)%	(3		)	(3		)	n/a
Capitalized general and administrative expenses	(16		)	(13		)	23	%	(37		)	(26		)	42	%
Reimbursed from third parties	(34		)	(37		)	(8	)%	(73		)	(73		)	—	%
General and administrative expenses, net	$	112		$	89		26	%	$	177		$	192		(8	)%

General and administrative expenses, net per boe	$	2.91		$	1.99		46	%	$	2.16		$	2.17		—	%

The $23 million increase in general and administrative expenses in the Current Quarter is primarily attributable to $42 million in fees for legal, financial and restructuring advisors in preparation for the Chapter 11 Cases and a decrease in allocated compensation expense of $18 million. These increases were partially offset by $37 million in cost reduction initiatives including decreases in salary and benefits resulting from reductions in workforce in the Current Quarter.

The $15 million decrease in general and administrative expenses in the Current Period is primarily attributable to $72 million in cost reduction initiatives including decreases in salary and benefits resulting from reduction in workforce in the Current Quarter and the fourth quarter of 2019. These decreases were partially offset by $42 million in fees for legal, financial and restructuring advisors in preparation for the Chapter 11 Cases and a decrease in allocated compensation expense of $15 million.

Separation and Other Termination Costs

In the Current Quarter and the Current Period, we incurred ~~a charge~~charges of approximately $5$22 million and $27 million, respectively, related to one-time termination benefits for certain employees.

Depreciation, Depletion and Amortization


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020		2019		Change		2020		2019		Change		2020		2019		Change
	($ in millions, except per unit)						($ in millions, except per unit)
Depreciation, depletion and amortization	$	603	$	519	16	%	$	158	$	580	(73	)%	$	761	$	1,099	(31	)%
Depreciation, depletion and amortization per boe	$	13.83	$	11.90	16	%	$	4.12	$	12.84	(68	)%	$	9.28	$	12.38	(25	)%

The absolute and per unit ~~increase~~decrease in the Current Quarter and the Current Period is primarily the result of a higher depletion rate. The increase in depletion rate per boe primarily reflects our higher concentration of capital deployment in liquids-rich operating areas, which generally involve higher finding costs per boe relative to our gas-rich operating areas, as we focus on expanding our margins through disciplined investingan $8.446 billion impairment recognized in the ~~highest-return projects.~~Current Period on our proved oil and natural gas properties due to lower forecasted commodity prices, which reduced the depletable carrying value.

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Impairments


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019		2020		2019
	($ in millions)				($ in millions)
Impairments of proved oil and natural gas properties	$	8,446	$	—	$	—	$	—	$	8,446	$	—
Impairments of other fixed assets and other	76		1		—		1		76		2
Total impairments	$	8,522	$	1	$	—	$	1	$	8,522	$	2

In the Current ~~Quarter,~~Period, we recorded impairments of proved oil and natural gas properties related to Eagle Ford, Brazos Valley, Powder River Basin, Mid-Continent and other non-core assets, all of which are due to lower forecasted commodity prices. Additionally, in the Current ~~Quarter~~Period we recorded a $76 million impairment of our sand mine assets that support our Brazos Valley operating area for the difference between fair value and the carrying value of the assets. See Note 13 of the notes to our condensed consolidated financial statements included in Item 1 of this report for further discussion.

Other Operating Expense

Three Months Ended
March 31,
2020 2019
($ in millions)
Other operating expense $ 83
$ 61



	Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019
	($ in millions)
Other operating expense	$	5	$	3	$	88	$	64

In the Current ~~Quarter,~~Period, we terminated certain gathering, processing and transportation contracts and recognized a non-recurring ~~$79~~$80 million expense related to the contract terminations. The contract terminations removed approximately $169 million of future commitments related to gathering, processing and transportation agreements.

In the Prior ~~Quarter,~~Period, we recorded ~~$23~~$26 million of costs related to our acquisition of WildHorse, which consisted of consulting fees, financial advisory fees, legal fees and travel and lodging expenses. Additionally, we recorded $38 million of severance expense as a result of our acquisition of WildHorse. A majority of the WildHorse executives and employees were terminated. These executives and employees were entitled to severance benefits in accordance with existing employment agreements.

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Interest Expense


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
	($ in millions, except per unit)						($ in millions, except per unit)
Interest expense on senior notes	$	129		$	144		$	117		$	142		$	239		$	281
Interest expense on term loan	38			—			33			—			71			—
Interest expense on pre-petition revolving credit facility							20			24			42			40
Amortization of discount, issuance costs and other	7			6			14			15			28			28
Amortization of premium	(44		)	—			(43		)	—			(87		)	—
Interest expense on revolving credit facility	22			17
Realized gains on interest rate derivatives	—			(1		)	—			(1		)	—			(1		)
Unrealized losses on interest rate derivatives	—			1			—			1			—			1
Capitalized interest	(7		)	(6		)	(4		)	(6		)	(11		)	(13		)
Total interest expense	$	145		$	161		$	137		$	175		$	282		$	336

Interest expense per boe	$	3.34		$	3.72		$	3.56		$	3.86		$	3.44		$	3.79

Average senior notes borrowings	$	5,783		$	8,207		$	5,666		$	8,161		$	5,725		$	8,183
Average credit facilities borrowings	$	1,648		$	1,021		$	2,043		$	2,032		$	1,845		$	1,627
Average term loan borrowings	$	1,500		$	—		$	1,500		$	—		$	1,500		$	—

The decrease in interest expense on senior notes is due to the decrease of the average outstanding balance on our senior notes. The increase in interest expense on the term loan is due to the issuance of our term loan in the fourth quarter of 2019. The increase in amortization of premium is due to the issuance of our senior secured second lien notes in the fourth quarter of 2019.

Losses on Investments

In the Current ~~Quarter,~~Period, the hydraulic fracturing industry experienced challenging operating conditions resulting in the current fair value of our investment in FTSI falling below book value of $23 million and remaining below that value as of the end of the Current ~~Quarter.~~Period. Based on FTSI’s operating results, ~~and FTSI’s share price of $0.22 per share as of March 31, 2020,~~ we determined that the reduction in fair value is other-than-temporary and recognized an impairment of our entire investment in FTSI of $23 million.

Gains on Purchases or Exchanges of Debt

In the Current ~~Quarter,~~Period, we repurchased approximately $~~156~~160 million aggregate principal amount of senior notes for $9395 million and recorded an aggregate gain of approximately $6365 million. See Note 4 of the notes to our condensed consolidated financial statements included in Item 1 of this report for further discussion.

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Reorganization Items, Net

In the Current Quarter, we recorded $394 million of reorganization items consisting of $518 million of income related to pre-petition premiums and discounts offset by $61 million of expense related to deferred charges on debt that is considered subject to compromise and $63 million of expense for debtor-in-possession financing fees to lenders for funding.

Income Tax Benefit

WeNo income tax provision was recorded in the Current Quarter and a $13 million income tax benefit was recorded in the Current Period. No income tax provision was recorded in the Prior Quarter ~~compared to~~and a $314 million income tax benefit was recorded in the Prior ~~Quarter.~~Period. Our effective income tax rate was ~~0.2%~~0.0% for the Current Quarter ~~compared to 93.7%~~and for the Prior Quarter. The rate for the Current Period was 0.2% whereas the effective income tax rate for the Prior ~~Quarter~~Period was 132.5%. The rate for the Prior Period was due to the partial release of the valuation allowance against our net deferred tax asset position as a result of the acquisition of WildHorse. Our effective tax rate can fluctuate as a result of the impact of discrete items, state income taxes and permanent differences. ~~For the Current Quarter, our estimated AETR remains nominal as a result of having a full valuation allowance against our net deferred tax asset position for federal and state purposes~~. See Note 8 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for a discussion of income taxes.

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~~Financial and Non-Financial Disclosures for Certain Securities Registered or Being Registered~~

Chesapeake Energy Corporation is a holding company, owns no operating assets and has no significant operations independent of its subsidiaries. Our obligations under our revolving credit facility, term loan, senior secured second lien notes and outstanding senior unsecured notes and convertible senior notes listed in ~~Note 4~~ of the notes to our condensed consolidated financial statements included in Item 1 are fully and unconditionally guaranteed, jointly and severally, by certain of our 100% owned subsidiaries. Our BVL subsidiaries are guarantors of our obligations under the revolving credit facility, term loan and senior secured second lien notes, but are not guarantors of our obligations under our outstanding senior unsecured notes or convertible senior notes as of March 31, 2020. Chesapeake has an obligation to add our BVL subsidiaries as guarantors of our obligations under such notes on or before June 20, 2020 in accordance with the various indentures governing the same. Subsidiaries with noncontrolling interests, consolidated variable interest entities and certain de minimis subsidiaries are non-guarantors.

The tables below are summarized financial information provided in conformity with the SEC’s Regulation S-X Rule 13-01 for Chesapeake Energy Corporation (parent) on a stand-alone, unconsolidated basis and its combined guarantor subsidiaries as of March 31, 2020 and December 31, 2019 and for the three months ended March 31, 2020. This financial information may not necessarily be indicative of our results of operations, cash flows or financial position had these subsidiaries operated as independent entities.

~~BALANCE SHEET~~

Obligors
March 31, 2020 December 31, 2020
($ in millions)
Current assets $ 1,761
$ 1,158
Total property and equipment, net $ 4,671
$ 10,480
Long-term assets $ 144
$ 166
Current liabilities $ 2,085
$ 2,231
Long-term liabilities $ 9,453
$ 9,380

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~~STATEMENT OF OPERATIONS~~

Obligors

Three Months Ended
March 31, 2020
$ in millions
REVENUES:
Oil, natural gas and NGL $ 1,619
Marketing 724
Total Revenues 2,343
Other 14
Total Revenues and Other 2,357
OPERATING EXPENSES:
Oil, natural gas and NGL production 95
Oil, natural gas and NGL gathering, processing and transportation 275
Production taxes 38
Exploration 120
Marketing 745
General and administrative 65
Restructuring and other termination costs 5
Provision for legal contingencies, net 1
Depreciation, depletion and amortization 430
Impairments 5,589
Other operating expense 82
Total Operating Expenses 7,445
LOSS FROM OPERATIONS (5,088 )
OTHER INCOME (EXPENSE):
Interest expense (148 )
Losses on investments (23 )
Gains on purchases or exchanges of debt 63
Other income 6
Total Other Expense (102 )
LOSS BEFORE INCOME TAXES (5,190 )
INCOME TAX BENEFIT (13 )
NET LOSS (5,177 )
Net loss attributable to noncontrolling interests —
NET LOSS ATTRIBUTABLE TO CHESAPEAKE (5,177 )
Other comprehensive income 9
COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE $ (5,168 )

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Forward-Looking Statements

This report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Exchange Act. Forward-looking statements include our current expectations or forecasts of future events, including matters relating to the continuing effects of the COVID-19 pandemic and the impact thereof on our business, financial condition, ~~and~~ results of operations and cash flows, the potential effects of the Chapter 11 Cases on our operations, management, and employees, our ability to consummate the Restructuring, actions by, or disputes among or between, members of OPEC+, market factors, market prices, our ability to meet debt service requirements, our ~~expectations regarding the borrowing base under our revolving credit facility, our~~ongoing evaluation and implementation of strategic alternatives, cost-cutting measures, reductions in capital expenditures, refinancing transactions, capital exchange transactions, asset divestitures, operational efficiencies and future ~~impairments, cost savings due to operational and capital efficiencies related to the WildHorse Merger and the other items discussed in the Introduction to Item 2 of this report.~~impairments. In this context, forward-looking statements often address our expected future business, financial performance and financial condition, and often contain words such as "expect," “could,” “may,” "anticipate," "intend," "plan," “ability,” "believe," "seek," "see," "will," "would," “estimate,” “forecast,” "target," “guidance,” “outlook,” “opportunity” or “strategy.”

Although we believe the expectations and forecasts reflected in our forward-looking statements are reasonable, they are inherently subject to numerous risks and uncertainties, most of which are difficult to predict and many of which are beyond our control. No assurance can be given that such forward-looking statements will be correct or achieved or that the assumptions are accurate or will not change over time. Particular uncertainties that could cause our actual results to be materially different than those expressed in our forward-looking statements include:

uncertainties relating to our Chapter 11 Cases, including but not limited to: our ability to obtain Bankruptcy Court approval with respect to motions in the Chapter 11 Cases; the effects of the Chapter 11 Cases on us and our various constituents; the impact of Bankruptcy Court rulings in the Chapter 11 Cases; our ability to develop and implement the Plan and whether that Plan will be approved by the Bankruptcy Court and the ultimate outcome of the Chapter 11 Cases in general; the length of time we will operate under the Chapter 11 Cases; attendant risks associated with restrictions on our ability to pursue our business strategies; risks associated with third-party motions in the Chapter 11 Cases; the potential adverse effects of the Chapter 11 Cases on our liquidity; the potential cancellation of our common and preferred stock in the Chapter 11 Cases; the potential material adverse effect of claims that are not discharged in the Chapter 11 Cases; uncertainty regarding our ability to retain key personnel; and uncertainty and continuing risks associated with our ability to achieve our stated goals and continue as a going concern;

the impact of the COVID-19 pandemic and its effect on our business, financial condition, employees, contractors, vendors and the global demand for oil and natural gas and U.S. and world financial markets;

our ability to comply with the covenants under our ~~revolving credit facility~~DIP Credit Facility and other indebtedness and the related impact on our ability to continue as a going concern;

the ~~impact~~significant changes in our stock price, the liquidity of ~~any strategic alternatives;~~the market for our common stock and the risk of future declines or fluctuations, including limitations caused by the delisting of our common stock from the New York Stock Exchange and the subsequent trading of our common stock in less established markets;

the volatility of oil, natural gas and NGL prices, which are affected by general economic and business conditions, as well as increased demand for (and availability of) alternative fuels and electric vehicles;

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 replace reserves and sustain production;

drilling and operating risks and resulting liabilities;

our ability to generate profits or achieve targeted results in drilling and well operations;

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 finance reserve replacement costs or satisfy our debt obligations;

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adverse developments or losses from pending or future litigation and regulatory proceedings, including royalty claims;

legislative and regulatory initiatives addressing environmental concerns, including initiatives addressing the impact of global climate change or further regulating hydraulic fracturing, methane emissions, flaring or water disposal;

terrorist activities and/or cyber-attacks adversely impacting our operations;

effects of acquisitions and dispositions, including our acquisition of WildHorse and our ability to realize related synergies and cost savings;

effects of purchase price adjustments and indemnity obligations; and


•	other factors that are described under Risk Factors in Item 1A of our 2019 Form 10-K and this Form 10-Q.

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

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Information About Us

Investors should note that we make available, free of charge on our website at chk.com, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. We also furnish quarterly, annual, and current reports for certain of our subsidiaries free of charge on our website at chk.com. We also post announcements, updates, events, investor information and presentations on our website in addition to copies of all recent news releases. We may use the Investors section of our website to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. Documents and information on our website are not incorporated by reference herein.

The SEC maintains a website at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers, including Chesapeake, that file electronically with the SEC.

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ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our exposure to market risk. The term market risk relates to our risk of loss arising from adverse changes in oil, natural gas, and NGL prices and interest rates. These disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses. The forward-looking information provides indicators of how we view and manage our ongoing market risk exposures.

Commodity Price Risk

Our results of operations and cash flows are impacted by changes in market prices for oil, natural gas and NGL, which have been historically volatile and are even more volatile as a result of COVID-19 and the OPEC+ decisions discussed in this Form 10-Q. To mitigate a portion of our exposure to adverse price changes, we enter into various derivative instruments. Our oil, natural gas and NGL derivative activities, when combined with our sales of oil, natural gas and NGL, allow us to predict with greater certainty the revenue we will receive. We believe our derivative instruments continue to be highly effective in achieving our risk management objectives.

We determine the fair value of our derivative instruments utilizing established index prices, volatility curves and discount factors. These estimates are compared to counterparty valuations for reasonableness. Derivative transactions are also subject to the risk that counterparties will be unable to meet their obligations. This non-performance risk is considered in the valuation of our derivative instruments, but to date has not had a material impact on the values of our derivatives. Future risk related to counterparties not being able to meet their obligations has been partially mitigated under our commodity hedging arrangements that require counterparties to post collateral if their obligations to us are in excess of defined thresholds. The values we report in our financial statements are as of a point in time and subsequently change as these estimates are revised to reflect actual results, changes in market conditions and other factors. See Note 11 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for further discussion of the fair value measurements associated with our derivatives.

For the ~~three~~six months ended ~~March 31,~~June 30, 2020, oil, natural gas, and NGL revenue, excluding any effect of our derivative instruments, were ~~$539~~$725 million, ~~$320~~$554 million and ~~$35~~$55 million, respectively. Based on production, oil, natural gas, and NGL revenue for the ~~three~~six months ended ~~March 31,~~June 30, 2020 would have increased or decreased by approximately ~~$54~~$73 million, ~~$32~~$55 million, and $4$6 million, respectively, for each 10% increase or decrease in prices. As of March 31, 2020, the fair values of our oil and natural gas derivatives were net assets of $717 million and $144 million, respectively. A 10% increase in forward oil prices would decrease the valuation of oil derivatives by $73 million while a 10% decrease would increase the valuation by $68 million. A 10% increase in forward gas prices would decrease the valuation of natural gas derivatives by approximately $52 million while a 10% decrease would increase the valuation by $48 million. This fair value change assumes volatility based on prevailing market parameters at ~~March 31,~~June 30, 2020. ~~See~~ ~~Note 11~~ ~~of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for further information on our open derivative positions.~~

Interest Rate Risk

~~The table below presents principal cash flows and related weighted average interest rates by expected maturity dates.~~

Years of Maturity
2020 2021 2022 2023 2024 Thereafter Total
($ in millions)
Liabilities:
Debt – fixed rate $ 253
$ 294
$ 272
$ 167
$ 624
$ 4,060
$ 5,670
Average interest rate 6.70 % 5.80 % 4.88 % 5.75 % 7.00 % 9.34 % 7.58 %
Debt – variable rate $ —
$ —
$ —
$ 1,900
$ 1,500
$ —
$ 3,400
Average interest rate — % — % — % 3.81 % 9.00 % — % 6.10 %

~~Changes in interest rates affect the amount of interest we earn on our cash, cash equivalents and short-term investments and the~~Our exposure to interest rate ~~we pay on~~changes relates primarily to borrowings under our pre-petition revolving credit facility, and DIP Credit Facility. Interest is payable on borrowings under the pre-petition revolving credit facility and DIP Credit Facility based on a floating rate. See Note 4 for additional information. As of June 30, 2020, we had $1.929 billion in borrowings outstanding under our ~~term loan facility. All~~pre-petition revolving credit facility and no outstanding borrowings under our DIP Credit Facility. A 1.0% increase in interest rates based on the variable borrowings as of June 30, 2020 would result in an increase in our ~~other indebtedness is fixed rate and, therefore, does not expose us to the risk~~interest expense of ~~fluctuations in earnings or cash flows due to changes in market interest rates. However, changes~~approximately $19 million per year. Changes in interest rates do affect the fair value of our fixed-rate debt.

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ITEM 4.	Controls and Procedures

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures designed to ensure that information required to be disclosed in reports we file or submit under the Exchange Act, is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to management, including our principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure.

As of the end of the period covered by this report, we carried out an evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Exchange Act Rule 13a-15(b). Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded as of ~~March 31,~~June 30, 2020 that our disclosure controls and procedures were effective.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting during the period covered by this ~~Quarterly Report on~~ Form 10-Q that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION


ITEM 1.	Legal Proceedings

~~There have been no material developments in previously reported legal or environmental proceedings.~~ For a description of ~~other~~our material pending legal proceedings as of June 30, 2020, see Note 5 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report.

For more information on the Chapter 11 Cases, see Note 1 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report and ~~regulatory proceedings affecting us, see~~Part I, Item ~~3 in our 2019 Form 10-K.~~2. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Recent Developments - Voluntary Reorganization Under Chapter 11.


ITEM 1A.	Risk Factors

Our business has many risks. Factors that could materially adversely affect our business, financial condition, operating results or liquidity and the trading price of our common stock, preferred stock or senior notes are described under “Risk Factors” in Item 1A of our 2019 Form 10-K, which risk factors could also be affected by the potential effects of the COVID-19 pandemic discussed herein, and in this Form 10-Q. This information should be considered carefully, together with other information in this report and other reports and materials we file with the SEC.

~~Restrictive covenants~~Risk Factors Relating to the Chapter 11 Cases

The Chapter 11 Cases may have a material adverse impact on our business, financial condition, results of operations and cash flows. In addition, the consummation of a plan of reorganization will result in ~~certain~~the cancellation and discharge of our ~~debt agreements~~equity securities, including our common stock.

The Chapter 11 Cases could ~~limit~~have a material adverse effect on our ~~growth~~business, financial condition, results of operations and cash flows. During the pendency of the Chapter 11 Cases, our management may be required to spend a significant amount of time and effort dealing with restructuring matters rather than focusing exclusively on our business operations. Bankruptcy Court protection and operating as debtors-in-possession also may make it more difficult to retain management and the key personnel necessary to the success of our business. In addition, during the pendency of the Chapter 11 Cases, our customers might lose confidence in our ability to ~~finance~~reorganize our ~~operations, fund our capital needs, respond~~business successfully and may seek to ~~changing conditions and engage in other business activities that may be in our best interests.~~

~~Our debt agreements impose operating and financial restrictions on us. These restrictions limit our ability and that~~establish alternative commercial relationships, renegotiate the terms of our ~~restricted subsidiaries to, among other things:~~

•~~incur additional indebtedness;~~

•~~make investments~~agreements, terminate their relationships with us or ~~loans;~~

•~~create liens;~~

•~~consummate mergers and similar fundamental changes;~~

•~~make restricted payments;~~

•~~make investments~~require financial assurances from us. Customers may lose confidence in ~~unrestricted subsidiaries;~~

•~~enter into transactions with affiliates; and~~

•~~use the proceeds of asset sales.~~

We may be prevented from taking advantage of business opportunities that arise because of the limitations imposed on us by the restrictive covenants under certain of our debt agreements. The restrictions contained in the covenants could:

~~limit~~ our ability to ~~plan for,~~provide them the level of service they expect, resulting in a significant decline in our revenues, profitability and cash flow.

Other significant risks include or ~~react~~relate to ~~market conditions,~~the following:

the effects of the filing of the Chapter 11 Cases on our business and the interests of various constituents, including our shareholders;

Bankruptcy Court rulings in the Chapter 11 Cases, including with respect to ~~meet capital needs or otherwise to restrict~~ our ~~activities or business plan;~~motions and third-party motions, as well as the outcome of other pending litigation;

~~adversely affect~~ our ability to ~~finance our operations, enter into acquisitions or divestitures to engage in other business activities that would be in our interest.~~

Also, our revolving credit facility requires us to maintain compliance with specified financial ratios and satisfy certain financial condition tests. Our ability to comply with these ratios and financial condition tests may be affected by events beyond our control and, as a result, we may be unable to meet these ratios and financial condition tests. These financial ratiooperate within the restrictions and ~~financial condition tests could limit~~ the liquidity limitations of the DIP Credit Agreement and any related orders entered by the Bankruptcy Court in connection with the Chapter 11 Cases;

our ability to ~~obtain future financings, make needed capital expenditures, withstand a continued downturn in our business, such~~maintain strategic control as debtors-in-possession during the ~~downturn in~~pendency of the ~~oil and gas industry as~~ Chapter 11 Cases;

the ~~result~~length of ~~COVID-19~~time that we will operate with Chapter 11 protection and the ~~OPEC+ decisions discussed in this Form 10-Q, or a downturn in~~continued availability of operating capital during the economy in general or otherwise conduct necessary corporate activities. Further declines in oil, NGL and natural gas prices, or a continued period of low oil, NGL and natural gas prices could eventually result in our failing to meet one or morependency of the ~~financial covenants under our revolving credit facility, which could require us to refinance or amend such obligations resulting in~~Chapter 11 Cases;

increased advisory costs during the ~~payment~~pendency of ~~consent fees or higher interest rates, or require us to raise additional capital at an inopportune time or~~the Chapter 11 Cases;

the risks associated with restrictions on terms not favorable to us. Specifically, the leverage ratio required by the covenants in our revolving credit facility began to decrease by 25 basis points each quarter beginning with the fiscal quarter ending December 31, 2019 until it reaches 4.00 to 1.00 for the fiscal quarter ending March 31, 2021 and each quarter thereafter. If depressed prices persist or decline even further throughout 2020, our ability to ~~comply with~~pursue some of our business strategies during the ~~leverage ratio under~~ pendency of the Chapter 11 Cases;

our ~~revolving~~ability to satisfy the conditions precedent to consummation of a plan of reorganization;

the potential adverse effects of the Chapter 11 Cases on our business, cash flows, liquidity, financial condition and results of operations;

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~~credit facility~~the ultimate outcome of the Chapter 11 Cases in general;

the cancellation of our existing equity securities, including our outstanding shares of common stock and preferred stock, in the Chapter 11 Cases;

the potential material adverse effects of claims that are not discharged in the Chapter 11 Cases;

uncertainties regarding the reactions of our customers, prospective customers and service providers to the Chapter 11 Cases;

uncertainties regarding our ability to retain and motivate key personnel; and

uncertainties and continuing risks associated with our ability to achieve our stated goals and continue as a going concern.

Further, under Chapter 11, transactions outside the ordinary course of business are subject to the prior approval of the Bankruptcy Court, which may limit our ability to respond in a timely manner to certain events, to take advantage of certain opportunities or adapt to changing market or industry conditions.

Because of the risks and uncertainties associated with the Chapter 11 Cases, we cannot predict or quantify the ultimate impact that events occurring during the ~~next 12 months~~Chapter 11 Cases may have on our business, cash flows, liquidity, financial condition and results of operations, nor can we provide any assurance as to our ability to continue as a going concern.

As a result of the Chapter 11 Cases, realization of assets and liquidation of liabilities are subject to uncertainty. While operating under the protection of the Bankruptcy Code, and subject to Bankruptcy Court approval or otherwise as permitted in the normal course of business, we may sell or otherwise dispose of assets and liquidate or settle liabilities for amounts other than those reflected in our consolidated financial statements.

Delays in the Chapter 11 Cases may increase the risk of us being unable to reorganize our business and emerge from bankruptcy and increase our costs associated with the bankruptcy process.

There can be no assurance that a plan of reorganization will become effective in accordance with its terms on the timeline we anticipate, or at all. Prolonged Chapter 11 proceedings could adversely affect our relationships with customers and employees, among other parties, which in turn could adversely affect our business, competitive position, financial condition, liquidity and results of operations and our ability to continue as a going concern. A weakening of our financial condition, liquidity and results of operations could adversely affect our ability to implement a plan of reorganization (or any other Chapter 11 plan). If we are unable to consummate a plan of reorganization, we may be forced to liquidate our assets.

We are subject to the risks and uncertainties associated with our exclusive right to file a plan of reorganization.

At the outset of the Chapter 11 Cases, the Bankruptcy Code provides debtors-in-possession the exclusive right to file and solicit acceptance of a plan of reorganization for the first 120 days of the bankruptcy case, subject to extension at the discretion of the court. All other parties are prohibited from filing or soliciting a plan of reorganization during this period. If the Bankruptcy Court terminates that right or the exclusivity period expires, there could be a material adverse effect on our ability to achieve confirmation of a plan in order to achieve our stated goals. The possible decision of creditors and/or other third parties, whose interest may be inconsistent with our own, to file alternative plans of reorganization could further protract the Chapter 11 Cases, leading us to continue to incur significant professional fees and costs. Because of these risks and uncertainties associated with the termination or expiration of our exclusivity rights, we cannot predict or quantify the ultimate impact that events occurring during the Chapter 11 Cases may have on our business, cash flows, liquidity, financial condition and results of operations, nor can we predict the ultimate impact that events occurring during the Chapter 11 Cases may have on our corporate or capital structure.

Adverse publicity in connection with the Chapter 11 Cases or otherwise could negatively affect our businesses.

Adverse publicity or news coverage relating to us, including, but not limited to, publicity or news coverage in connection with the Chapter 11 Cases, may negatively impact our efforts to establish and promote a positive image after emergence from the Chapter 11 Cases.

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Trading in our common stock and preferred stock during the pendency of the Chapter 11 Cases is highly speculative and poses substantial risks.

All of our indebtedness is senior to the existing common stock in our capital structure. The RSA contemplates that our existing equity interests will be canceled and discharged in connection with the Chapter 11 Cases and the holders of those equity interests, including the holders of our common and preferred stock, will be entitled to no recovery. Accordingly, any trading in our common and preferred stock during the pendency of the Chapter 11 Cases is highly speculative and poses substantial risks to purchasers of our common and preferred stock.

Risks of trading in an over-the-counter market.

Since June 30, 2020, our common stock has been trading on the OTC Pink Marketplace maintained by the OTC Markets Group, Inc. under the symbol “CHKAQ.” Securities traded in the over-the-counter market generally have significantly less liquidity than securities traded on a national securities exchange, due to factors such as a reduction in the number of investors that will consider investing in the securities, the number of market makers in the securities, reduction in securities analyst and news media coverage and lower market prices than might otherwise be obtained. In addition to those factors, the market for the outstanding shares of our common stock has been adversely affected by the provisions of the RSA that contemplate that our existing equity interests will be cancelled and discharged in connection with the Chapter 11 Cases and the holders of those equity interests, including the holders of our outstanding shares of common stock, will be entitled to no recovery relating to those equity interests. We can provide no assurance that our common stock will continue to trade on the OTC Pink Marketplace, whether broker-dealers will continue to provide public quotes of our common stock on that market, whether the trading volume of our common stock will be sufficient to provide for an efficient trading market or whether quotes for our common stock will continue to be provided on that market in the future.

The RSA is subject to significant conditions and milestones that may be difficult for us to satisfy.

There are certain material conditions we must satisfy under the RSA, including the timely satisfaction of milestones in the Chapter 11 Cases, which include the consummation of the financing contemplated by the Exit Credit Facilities and other transactions contemplated by a plan of reorganization. Our ability to timely complete such milestones is subject to risks and uncertainties, many of which are beyond our control.

A plan of reorganization may not become effective.

Even if a plan of reorganization is confirmed by the Bankruptcy Court, it may not become effective because it is subject to the satisfaction of certain conditions precedent (some of which are beyond our control). There can be no assurance that such conditions will be satisfied and, therefore, that a plan of reorganization will become effective and that the Debtors will emerge from the Chapter 11 Cases as contemplated by a plan of reorganization. If the effective date of a plan of reorganization is delayed, the Debtors may not have sufficient cash available to operate their businesses. In that case, the Debtors may need new or additional post-petition financing, which may increase the cost of consummating a plan of reorganization. There can be no assurance of the terms on which such financing may be available or if such financing will be available. If the transactions contemplated by a plan of reorganization are not completed, it may become necessary to amend the plan. The terms of any such amendment are uncertain and could result in material additional expense and result in material delays to the Chapter 11 Cases.

Even if a Chapter 11 plan of reorganization is consummated, we may not be able to achieve our stated goals.

Even if a Chapter 11 plan of reorganization is consummated, we may continue to face a number of risks, such as changes in economic conditions, changes in our industry, changes in demand for our services and increasing expenses. Some of these risks become more acute when a case under the Bankruptcy Code continues for a protracted period without indication of how or when the transactions under a Chapter 11 plan of reorganization will close. As a result of these and other risks, we cannot guarantee that a Chapter 11 plan of reorganization will achieve our stated goals. Furthermore, even if our debts are reduced or discharged through a plan of reorganization, we may need to raise additional funds through public or private debt or equity financing or other various means to fund our business after the completion of the Chapter 11 Cases. Our access to additional financing may be limited, if it is available at all. Therefore, adequate funds may not be available when needed or may not be available on favorable terms.

As a result, a plan of reorganization may not become effective and, thus, we cannot assure you of our ability to continue as a going concern.

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Our long-term liquidity requirements and the adequacy of our capital resources are difficult to predict at this time.

We face uncertainty regarding the adequacy of our liquidity and capital resources and have extremely limited, if any, access to additional financing. In addition to the cash requirements necessary to fund our ongoing operations, we have incurred significant professional fees and other costs in connection with preparation for the Chapter 11 Cases and expect that we will continue to incur significant professional fees and other costs throughout the Chapter 11 Cases. We cannot assure you that cash on hand and cash flow from operations will be sufficient to continue to fund our operations and allow us to satisfy our obligations related to the Chapter 11 Cases. Although we entered into the DIP Credit Agreement providing for new money in an aggregate principal amount of up to $925 million pursuant to the DIP Credit Facility in connection with the Chapter 11 Cases, we cannot assure you that such financing will be sufficient, that we will be able to secure additional interim financing or adequate exit financing sufficient to meet our liquidity needs (or if sufficient funds are available, that they will be offered to us on acceptable terms).

Our liquidity, including our ability to meet our ongoing operational obligations, depends on, among other things: (1) our ability to comply with the terms and conditions of any order governing the use of cash collateral that may be entered by the Bankruptcy Court in connection with the Chapter 11 Cases, (2) our ability to access credit under the DIP Credit Facility, (3) our ability to maintain adequate cash on hand, (4) our ability to generate cash flow from operations, (5) our ability to consummate a plan of reorganization or other alternative restructuring transaction, and (6) the cost, duration and outcome of the Chapter 11 Cases.

In certain limited instances, a Chapter 11 case may be converted to a case under Chapter 7 of the Bankruptcy Code.

Upon a showing of cause, the Bankruptcy Court may convert the Chapter 11 Cases to cases under Chapter 7 of the Bankruptcy Code. In such event, a Chapter 7 trustee would be appointed or elected to liquidate our assets for distribution in accordance with the priorities established by the Bankruptcy Code. We believe that liquidation under Chapter 7 would result in significantly smaller distributions being made to our creditors than those provided for in a plan of reorganization because of: (1) the likelihood that the assets would have to be sold or otherwise disposed of in a distressed fashion over a short period of time rather than in a controlled manner and as a going concern; (2) additional administrative expenses involved in the appointment of a Chapter 7 trustee; and (3) additional expenses and claims, some of which would be entitled to priority, that would be generated during the liquidation and from the rejection of executory contracts in connection with a cessation of operations.

The unaudited condensed consolidated financial statements included in this Form 10-Q for the period ended June 30, 2020 contain disclosures that express substantial doubt about our ability to continue as a going concern.

~~A breach~~The unaudited condensed consolidated financial statements included in this Form 10-Q for the period ended June 30, 2020 have been prepared on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities and other commitments in the normal course of business and does not include any ~~of these covenants or~~adjustments that might result from uncertainty about our ~~inability~~ability to ~~comply with the required financial ratios or financial condition tests could result in~~continue as a default under our revolving credit facility that, if not cured or waived, could result in acceleration of all indebtedness outstanding thereunder and cross-default rights under our other debt. If that should occur, we may be unable to pay all such debt or to borrow sufficient funds to refinance it. Even if new financing were then available, itgoing concern. Such assumption may not be justified. Our liquidity has been negatively impacted by the prolonged depressed prices we receive for the oil, natural gas and NGL we sell and our substantial indebtedness and associated debt-related expenses. As a result of these and other factors, we entered into the RSA and commenced the Chapter 11 Cases. The RSA contemplates that our equity investors, including the holders of our common and preferred stock, will lose the entire value of their investment in our business. The inclusion of disclosures that express substantial doubt about our ability to continue as a going concern may negatively impact the trading price of our common and preferred stock and have an adverse impact on ~~terms that are acceptable~~our relationships with third parties with whom we do business, including our customers, subcontractors, suppliers and employees, and could have a material adverse impact on our business, financial condition, results of operations and cash flows.

As a result of the Chapter 11 Cases, our historical financial information may not be indicative of our future performance, which may be volatile.

During the Chapter 11 Cases, we expect our financial results to ~~us.~~continue to be volatile as restructuring activities and expenses impact our consolidated financial statements. As a result, our historical financial performance is likely not indicative of our financial performance after the date of the filing of the Chapter 11 Cases. In addition, if we emerge from Chapter 11, the amounts reported in subsequent consolidated financial statements may materially change relative to our historical consolidated financial statements. We also will be required to adopt fresh start accounting, in which case our assets and liabilities will be recorded at fair value as of the fresh start reporting date, which may differ materially

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from the recorded values of assets and liabilities on our historical consolidated balance sheets. Our financial results after the application of fresh start accounting may be different from historical trends.

The actual results achieved during the periods covered by our recently issued projections will vary from those set forth in those projections, and such variations may be material.

In connection with the commencement of the Chapter 11 Cases, we were required to file with the SEC certain projections that we had previously provided to our lenders and others under confidentiality arrangements (the “Projections”). Although we believe the Projections were made on a reasonable basis, no representation was or can be made regarding, and there can be no assurance as to, their attainability. Our actual results achieved during the periods covered by the Projections will vary from those set forth in the Projections, and those variations may be material. The Projections are dependent upon numerous assumptions with respect to commodity prices, operating expenses, availability and cost of capital and performance. In addition, as disclosed elsewhere in this “Risk Factors” section, our business and operations are subject to substantial risks which increase the uncertainty inherent in the Projections. Many of the facts disclosed in this “Risk Factors” section could cause actual results to differ materially from those projected in the Projections. The Projections were not prepared with a view towards public disclosure or complying with the guidelines established by the American Institute of Certified Public Accountants or the SEC’s published guidelines regarding projections or forecasts. Our independent public accountants did not examine, compile, review or perform any procedures with respect to the Projections, and, accordingly, assumed no responsibility for the Projections. No independent expert reviewed the Projections on our behalf. The Projections have not been included or incorporated by reference in this Quarterly Report on Form 10-Q, and, except as may be required by applicable law, we do not intend to update or otherwise revise the Projections, even if any or all the underlying assumptions are not realized.

We may be subject to claims that will not be discharged in the Chapter 11 Cases, which could have a material adverse effect on our business, cash flows, liquidity, financial condition and results of operations.

The Bankruptcy Code provides that the confirmation of a plan of reorganization discharges a debtor from, among other things, substantially all debts arising prior to consummation of a plan of reorganization. With few exceptions, all claims against the Debtors that arose prior to June 28, 2020 or before consummation of a plan of reorganization (i) would be subject to compromise and/or treatment under a plan of reorganization and/or (ii) would be discharged in accordance with the Bankruptcy Code and the terms of a plan of reorganization. Subject to the terms of a plan of reorganization and orders of the Bankruptcy Court, any claims not ultimately discharged pursuant to a plan of reorganization could be asserted against the reorganized entities and may have an adverse effect on our business, cash flows, liquidity, financial condition and results of operations on a post-reorganization basis.

The Chapter 11 Cases limit the flexibility of our management team in running our business.

While we operate our businesses as debtor-in-possession under supervision by the Bankruptcy Court, we are required to obtain the approval of the Bankruptcy Court, and in some cases certain lenders, prior to engaging in activities or transactions outside the ordinary course of business. Bankruptcy Court approval of non-ordinary course activities entails preparation and filing of appropriate motions with the Bankruptcy Court, negotiation with the various creditors’ committees and other parties-in-interest and one or more hearings. The creditors’ committees and other parties-in-interest may be heard at any Bankruptcy Court hearing and may raise objections with respect to these motions. This process may delay major transactions and limit our ability to respond quickly to opportunities and events. Furthermore, in the event the Bankruptcy Court does not approve a proposed activity or transaction, we would be prevented from engaging in activities and transactions that we believe are beneficial to us.

We may experience employee attrition as a result of ~~an event~~the Chapter 11 Cases.

As a result of ~~default under~~the Chapter 11 Cases, we have experienced, and may continue to experience, employee attrition, and our ~~revolving credit facility,~~employees may face considerable distraction and uncertainty. A loss of key personnel or material erosion of employee morale could adversely affect our business and results of operations. Our ability to engage, motivate and retain key employees or take other measures intended to motivate and incentivize key employees to remain with us through the ~~affected lenders could foreclose~~pendency of the Chapter 11 Cases is limited by certain restrictions on the ~~collateral securing such revolving credit facility and require repayment~~implementation of ~~all borrowings outstanding thereunder. If~~incentive programs under the ~~amounts outstanding under our revolving credit facility or any~~Bankruptcy Code. The loss of services of members of our ~~other indebtedness were~~senior management team could impair our ability to ~~be accelerated,~~execute our ~~assets~~business strategies and implement operational initiatives, which may ~~not be sufficient~~have a material adverse effect on our business, cash flows, liquidity, financial condition and results of operations.

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Upon emergence from bankruptcy, the composition of our Board of Directors will change significantly.

The composition of our Board of Directors is expected to ~~repay in full~~change significantly following the ~~amounts owed to~~Chapter 11 Cases. Any new directors may have different backgrounds, experiences and perspectives from those individuals who currently serve on our Board of Directors and, thus, may have different views on the ~~lenders or to~~issues that will determine the future of our ~~other debt holders.~~company. As a result, our future strategy and plans may differ materially from those of the past.

Risk Factors Relating to the COVID-19 Pandemic

The ongoing coronavirus (COVID-19) pandemic and related economic turmoil have affected and could continue to adversely affect our business, financial condition, ~~and~~ results of ~~operations.~~operations and cash flows.

The global spread of COVID-19 created significant volatility, uncertainty, and economic disruption during the first six months of 2020. The ongoing COVID-19 outbreak ~~which the World Health Organization declared as a pandemic on March 11, 2020,~~ has reached more than 200 countries and has continued to be a rapidly evolving economic and public health situation. The pandemic has resulted in widespread adverse impacts on the global economy, and there is considerable uncertainty regarding the extent to which COVID-19 will continue to spread and the extent and duration of governmental and other measures implemented to try to slow the spread of the virus, such as quarantines, shelter-in-place orders and business and government shutdowns. State and local authorities have also implemented multi-step policies with the goal of re-opening. However, certain jurisdictions began re-opening only to return to restrictions in the face of increases in new COVID-19 cases. We have taken certain precautionary measures intended to help minimize the risk to our employees, our business and the communities in which we operate, and we are actively assessing and planning for various operational contingencies in the event one or more of our operational employees experiences any symptoms consistent with COVID-19. However, we cannot guarantee that any actions taken by us will be effective in preventing future disruptions to our business. Moreover, future operations could be negatively affected if a significant number of our employees are quarantined as a result of exposure to the virus.

We regularly monitor the credit worthiness of our customers and derivative contract counterparties. Although we have not received notices from our customers or counterparties regarding non-performance issues or delays resulting from the pandemic, ~~to the extent there is an outbreak of COVID-19 in the communities in which we operate,~~ we may have to temporarily shut down or further reduce production, which could result in significant downtime and have significant adverse consequences for our business, financial condition, ~~and~~ results of ~~operations.~~operations, and cash flows. In addition, most of our non-operational employees are now working remotely, which could increase the risk of security breaches or other cyber-incidents or attacks, loss of data, fraud and other disruptions.

Furthermore, the impact of the pandemic, including a resulting reduction in demand for oil and natural gas, coupled with the sharp decline in commodity prices following the announcement of price reductions and production increases in March 2020 by members of OPEC+ has led to significant global economic contraction generally and in our industry in particular. While an agreement to cut production has since been announced by OPEC+ and its allies, the situation, coupled with the impact of COVID-19, has continued to result in a significant downturn in the oil and gas industry. ~~Oil prices declined sharply~~Although OPEC+ finalized an agreement in April 2020 to cut oil production by 9.7 million barrels per day during May and June 2020, and OPEC+ agreed in June 2020 to extend such production cuts until the end of July 2020, crude oil prices have remain ~~low.~~depressed as a result of an increasingly utilized global storage network and the decrease in crude oil demand due to COVID-19. Oil and natural gas prices are expected to continue to be volatile as a result of the near term production increases and the ongoing COVID-19 outbreak and as changes in oil and natural gas inventories, industry demand and national and economic performance are reported, and we cannot predict when prices will improve and stabilize. We cannot predict the full impact that COVID-19 or the significant disruption and volatility currently being experienced in the oil and natural gas markets will have on our business, financial condition and results of operations at this time due to numerous uncertainties.

The ultimate impact of COVID-19 will depend on future developments, including, among others, the ultimate geographic spread and severity of the virus, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, the duration of the outbreak, further actions taken by members of OPEC+, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume.

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ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds

~~The following table presents information about~~There were no repurchases of our common stock during the quarter ended ~~March 31, 2020:~~June 30, 2020.

Period
Total
Number
of Shares
Purchased^(a)

Average
Price
Paid
Per
Share^(a)

Total Number
of Shares
Purchased as
Part of
Publicly
Announced
Plans or
Programs

Maximum
Approximate
Dollar Value
of Shares
That May Yet
Be Purchased
Under
the Plans
or Programs
($ in millions)
January 1, 2020 through January 31, 2020 131
$ 158.00
—
$ —
February 1, 2020 through February 29, 2020 17,770
$ 90.00
—
$ —
March 1, 2020 through March 31, 2020 —
$ —
—
$ —
Total 17,901
$ 90.50
—


~~(a)~~	Includes shares of common stock purchased on behalf of our deferred compensation plan, which we terminated in January 2020 in accordance with its terms. All share information has been retroactively adjusted to reflect a 1-for-200 (1:200) reverse stock split effective April 14, 2020. See ~~Note 6~~ ~~and~~ ~~Note 17~~ ~~for additional information.~~


ITEM 3.	Defaults Upon Senior Securities

~~None.~~Our Bankruptcy Filing described above constitutes an event of default that accelerated our obligations under our senior credit facility, our senior secured notes and our unsecured notes. Under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against us as a result of an event of default. See Note 4 and Note 1 to the unaudited condensed consolidated financial statements included in Part I, Item 1 of this Form 10-Q for additional details about the principal and interest amounts of debt included in liabilities subject to compromise on the accompanying unaudited condensed consolidated balance sheet at June 30, 2020 and our Bankruptcy Filing and the Chapter 11 Cases.

Under the terms of our 5.75% Cumulative Convertible Preferred Stock, 5.75% Cumulative Convertible Preferred Stock (Series A), 4.50% Cumulative Convertible Preferred Stock and 5.00% (Series 2005B) Cumulative Convertible Preferred Stock, we may suspend payments of our cumulative quarterly dividends. We have exercised our contractual right to suspend regularly scheduled quarterly payments of dividends on each series of our preferred stock beginning with the quarterly dividend payment for the second quarter of 2020, and are therefore currently in arrears with the dividend payments. No dividends have been accrued on our convertible preferred stock subsequent to the Petition Date. Pursuant to the RSA associated with our Chapter 11 Cases, each holder of an equity interest in Chesapeake would have such interest canceled, released, and extinguished without any distribution. See Note 1 of the notes to our condensed consolidated financial statements included in Item 1 of Part I of this report for additional information about the Chapter 11 Cases.


ITEM 4.	Mine Safety Disclosures

The information concerning mine safety violations and other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17CFR 229.104) is included in Exhibit 95.1 to this ~~Quarterly Report on~~ Form 10-Q.


ITEM 5.	Other Information

Not applicable.

TABLE OF CONTENTS


ITEM 6.	Exhibits

The exhibits listed below in the Index of Exhibits are filed, furnished or incorporated by reference pursuant to the requirements of Item 601 of Regulation S-K.

INDEX OF EXHIBITS

Incorporated by Reference
Exhibit
Number
Exhibit Description Form
SEC File
Number
Exhibit Filing Date
Filed or
Furnished
Herewith
3.1.1
Restated Certificate of Incorporation.
10-K 001-13726 3.1.1 2/27/2019

3.1.2
Amendment to Restated Certificate of Incorporation, dated April 13, 2020.
8-K 001-13726 3.1 4/13/2020

3.1.3
Certificate of Designation of 5% Cumulative Convertible Preferred Stock (Series 2005B), as amended.
10-Q 001-13726 3.1.4 11/10/2008

3.1.4
Certificate of Designation of 4.5% Cumulative Convertible Preferred Stock, as amended.
10-Q 001-13726 3.1.6 8/11/2008

3.1.5
Certificate of Designation of 5.75% Cumulative Non-Voting Convertible Preferred Stock (Series A).
8-K 001-13726 3.2 5/20/2010

3.1.6
Certificate of Designation of 5.75% Cumulative Non-Voting Convertible Preferred Stock, as amended.
10-Q 001-13726 3.1.5 8/9/2010

3.1.7
Certificate of Designations of Series B preferred Stock, dated April 23, 2020.
8-K 001-13726 3.1 4/13/2020

3.2
Chesapeake’s Amended and Restated Bylaws.
8-K 001-13726 3.2 6/19/2014

4.1
Section 382 Rights Agreement, dated April 23, 2020, between Chesapeake Energy Corporation and Computershare Trust Company, N.A., as rights agent.
8-K 001-13726 4.1 4/23/2020

22.1
List of Guarantor Subsidiaries
X

31.1
Robert D. Lawler, President and Chief Executive Officer, Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
X

31.2
Domenic J. Dell’Osso, Jr., Executive Vice President and Chief Financial Officer, Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
X

32.1
Robert D. Lawler, President and Chief Executive Officer, Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
X

32.2
Domenic J. Dell’Osso, Jr., Executive Vice President and Chief Financial Officer, Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
X

95.1
Mine Safety Disclosure
X

101 INS Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. X

101 SCH Inline XBRL Taxonomy Extension Schema Document. X

101 CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document. X

101 DEF Inline XBRL Taxonomy Extension Definition Linkbase Document. X

101 LAB Inline XBRL Taxonomy Extension Labels Linkbase Document. X

101 PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document. X

104 Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). X

† Management contract or compensatory plan or arrangement



		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File Number	Exhibit	Filing Date	Filed or Furnished Herewith
3.1.1	Restated Certificate of Incorporation.	10-K	001-13726	3.1.1	2/27/2019

3.1.2	Amendment to Restated Certificate of Incorporation, dated April 13, 2020.	8-K	001-13726	3.1	4/13/2020

3.1.3	Certificate of Designation of 5% Cumulative Convertible Preferred Stock (Series 2005B), as amended.	10-Q	001-13726	3.1.4	11/10/2008

3.1.4	Certificate of Designation of 4.5% Cumulative Convertible Preferred Stock, as amended.	10-Q	001-13726	3.1.6	8/11/2008

3.1.5	Certificate of Designation of 5.75% Cumulative Non-Voting Convertible Preferred Stock (Series A).	8-K	001-13726	3.2	5/20/2010

3.1.6	Certificate of Designation of 5.75% Cumulative Non-Voting Convertible Preferred Stock, as amended.	10-Q	001-13726	3.1.5	8/9/2010

3.1.7	Certificate of Designations of Series B preferred Stock, dated April 23, 2020.	8-K	001-13726	3.1	4/13/2020

3.2	Chesapeake’s Amended and Restated Bylaws.	8-K	001-13726	3.2	6/19/2014

4.1	Section 382 Rights Agreement, dated April 23, 2020, between Chesapeake Energy Corporation and Computershare Trust Company, N.A., as rights agent.	8-K	001-13726	4.1	4/23/2020

10.1	Fourth Amendment and Waiver to Amended and Restated Credit Agreement, dated as of June 12, 2020, among Chesapeake Energy Corporation and MUFG Union Bank, N.A., as administrative agent and the Lenders party thereto.	8-K	001-13726	10.1	6/18/2020

10.2	Restructuring Support Agreement, dated June 28, 2020.	8-K	001-13726	10.1	6/29/2020

10.3	Commitment Letter, dated June 28, 2020.	8-K	001-13726	10.2	6/29/2020

22.1	List of Guarantor Subsidiaries	10-Q	001-13726	22.1	5/11/2020

31.1	Robert D. Lawler, President and Chief Executive Officer, Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X

31.2	Domenic J. Dell’Osso, Jr., Executive Vice President and Chief Financial Officer, Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X

32.1	Robert D. Lawler, President and Chief Executive Officer, Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.					X

32.2	Domenic J. Dell’Osso, Jr., Executive Vice President and Chief Financial Officer, Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.					X

95.1	Mine Safety Disclosure					X

TABLE OF CONTENTS

Incorporated by Reference

Exhibit

Number

Exhibit Description

Form

SEC File

Number

Exhibit

Filing Date

Filed or

Furnished

Herewith

101 INS

Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101 SCH

Inline XBRL Taxonomy Extension Schema Document.

101 CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document.

101 DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document.

101 LAB

Inline XBRL Taxonomy Extension Labels Linkbase Document.

101 PRE

Inline XBRL Taxonomy Extension Presentation Linkbase Document.

104

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

†

Management contract or compensatory plan or arrangement

TABLE OF CONTENTS

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

Date: ~~May 11,~~August 10, 2020	By:	/s/ ROBERT D. LAWLER
		Robert D. Lawler President and Chief Executive Officer




Date: ~~May 11,~~August 10, 2020	By:	/s/ DOMENIC J. DELL’OSSO, JR.
		Domenic J. Dell’Osso, Jr. Executive Vice President and Chief Financial Officer

5574



Instrument Type	Unobservable Input	Range	Weighted Average^(a)	Fair Value March 31, 2020
				($ in millions)
Oil trades	Oil price volatility curves	26.50% – 242.41%	42.97%	$	39
Natural gas trades	Natural gas price volatility curves	20.56% – 141.43%	42.77%	$	(8	)



	Obligors
	March 31, 2020		December 31, 2020
	($ in millions)
Current assets	$	1,761	$	1,158
Total property and equipment, net	$	4,671	$	10,480
Long-term assets	$	144	$	166
Current liabilities	$	2,085	$	2,231
Long-term liabilities	$	9,453	$	9,380



	Obligors
	Three Months Ended March 31, 2020
	$ in millions
REVENUES:
Oil, natural gas and NGL	$	1,619
Marketing	724
Total Revenues	2,343
Other	14
Total Revenues and Other	2,357
OPERATING EXPENSES:
Oil, natural gas and NGL production	95
Oil, natural gas and NGL gathering, processing and transportation	275
Production taxes	38
Exploration	120
Marketing	745
General and administrative	65
Restructuring and other termination costs	5
Provision for legal contingencies, net	1
Depreciation, depletion and amortization	430
Impairments	5,589
Other operating expense	82
Total Operating Expenses	7,445
LOSS FROM OPERATIONS	(5,088		)
OTHER INCOME (EXPENSE):
Interest expense	(148		)
Losses on investments	(23		)
Gains on purchases or exchanges of debt	63
Other income	6
Total Other Expense	(102		)
LOSS BEFORE INCOME TAXES	(5,190		)
INCOME TAX BENEFIT	(13		)
NET LOSS	(5,177		)
Net loss attributable to noncontrolling interests	—
NET LOSS ATTRIBUTABLE TO CHESAPEAKE	(5,177		)
Other comprehensive income	9
COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE	$	(5,168	)



	Years of Maturity
	2020			2021			2022			2023			2024			Thereafter			Total
	($ in millions)
Liabilities:
Debt – fixed rate	$	253		$	294		$	272		$	167		$	624		$	4,060		$	5,670
Average interest rate	6.70		%	5.80		%	4.88		%	5.75		%	7.00		%	9.34		%	7.58		%
Debt – variable rate	$	—		$	—		$	—		$	1,900		$	1,500		$	—		$	3,400
Average interest rate	—		%	—		%	—		%	3.81		%	9.00		%	—		%	6.10		%



Period	Total Number of Shares Purchased^(a)	Average Price Paid Per Share^(a)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs
					($ in millions)
January 1, 2020 through January 31, 2020	131	$	158.00	—	$	—
February 1, 2020 through February 29, 2020	17,770	$	90.00	—	$	—
March 1, 2020 through March 31, 2020	—	$	—	—	$	—
Total	17,901	$	90.50	—