UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_________________________________________________________

FORM 10-Q

_________________________________________________________

(Mark One)


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

For the Quarterly Period Ended ~~June~~September 30, 2021


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

Commission File No. 001-35049

_________________________________________________________

EARTHSTONE ENERGY, INC.

(Exact name of registrant as specified in its charter)

_________________________________________________________


Delaware						84-0592823
(State or other jurisdiction						(I.R.S Employer
of incorporation or organization)						Identification No.)

1400 Woodloch Forest Drive, Suite 300

The Woodlands, Texas 77380

(Address of principal executive offices)

Registrant’s telephone number, including area code: (281) 298-4246

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Class A Common Stock, $0.001 par value per share	ESTE	New York Stock Exchange

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 the 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

☐

Table of Contents

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 ~~July 29,~~November 2, 2021, ~~50,493,800~~53,305,168 shares of Class A Common Stock, $0.001 par value per share, and ~~34,397,877~~34,351,995 shares of Class B Common Stock, $0.001 par value per share, were outstanding.

Table of Contents

TABLE OF CONTENTS

Page

PART I – FINANCIAL INFORMATION

Item 1.

Financial Statements (Unaudited)

Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2021 and December 31, 2020

Condensed Consolidated Statements of Operations for the Three and ~~Six~~Nine Months Ended ~~June~~September 30, 2021 and 2020

Condensed Consolidated Statements of Equity for the ~~Six~~Nine Months Ended ~~June~~September 3 0 ,30, 2021 and 2020

Condensed Consolidated Statements of Cash Flows for the ~~Six~~Nine Months Ended ~~June~~Septe mber 3 0 ,30, 2021 and 2020

Notes to Unaudited Condensed Consolidated Financial Statements

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

2526

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

3738

Item 4.

Controls and Procedures

3738

PART II – OTHER INFORMATION

Unregistered Sales of Equity Securities and Use of Proceeds

3839

Item 3.

Defaults Upon Senior Securities

3839

Item 4.

Mine Safety Disclosures

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

EARTHSTONE ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(In thousands, except share and per share amounts)


		June 30,		December 31,			September 30,		December 31,
ASSETS	ASSETS	2021		2020		ASSETS	2021		2020
Current assets:	Current assets:					Current assets:
Cash	Cash	$	478	$	1,494	Cash	$	441	$	1,494
Accounts receivable:	Accounts receivable:					Accounts receivable:
Oil, natural gas, and natural gas liquids revenues	Oil, natural gas, and natural gas liquids revenues	35,063		16,255		Oil, natural gas, and natural gas liquids revenues	45,076		16,255
Joint interest billings and other, net of allowance of $19 and $19 at June 30, 2021 and December 31, 2020, respectively		4,843		7,966
Joint interest billings and other, net of allowance of $19 and $19 at September 30, 2021 and December 31, 2020, respectively						Joint interest billings and other, net of allowance of $19 and $19 at September 30, 2021 and December 31, 2020, respectively	3,058		7,966
Derivative asset	Derivative asset	72		7,509		Derivative asset	17		7,509
Prepaid expenses and other current assets	Prepaid expenses and other current assets	2,109		1,509		Prepaid expenses and other current assets	1,565		1,509
Total current assets	Total current assets	42,565		34,733		Total current assets	50,157		34,733

Oil and gas properties, successful efforts method:	Oil and gas properties, successful efforts method:					Oil and gas properties, successful efforts method:
Proved properties	Proved properties	1,321,064		1,017,496		Proved properties	1,487,362		1,017,496
Unproved properties	Unproved properties	233,699		233,767		Unproved properties	235,232		233,767
Land	Land	5,382		5,382		Land	5,382		5,382
Total oil and gas properties	Total oil and gas properties	1,560,145		1,256,645		Total oil and gas properties	1,727,976		1,256,645

Accumulated depreciation, depletion and amortization	Accumulated depreciation, depletion and amortization	(340,091)		(291,213)		Accumulated depreciation, depletion and amortization	(367,000)		(291,213)
Net oil and gas properties	Net oil and gas properties	1,220,054		965,432		Net oil and gas properties	1,360,976		965,432

Other noncurrent assets:	Other noncurrent assets:					Other noncurrent assets:

Office and other equipment, net of accumulated depreciation and amortization of $4,286 and $3,675 at June 30, 2021 and December 31, 2020, respectively		1,364		931
Office and other equipment, net of accumulated depreciation and amortization of $4,323 and $3,675 at September 30, 2021 and December 31, 2020, respectively						Office and other equipment, net of accumulated depreciation and amortization of $4,323 and $3,675 at September 30, 2021 and December 31, 2020, respectively	1,730		931
Derivative asset	Derivative asset	694		396		Derivative asset	453		396
Operating lease right-of-use assets	Operating lease right-of-use assets	2,130		2,450		Operating lease right-of-use assets	1,963		2,450
Other noncurrent assets	Other noncurrent assets	10,854		1,315		Other noncurrent assets	9,694		1,315
TOTAL ASSETS	TOTAL ASSETS	$	1,277,661	$	1,005,257	TOTAL ASSETS	$	1,424,973	$	1,005,257
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	25,555	$	6,232	Accounts payable	$	33,602	$	6,232
Revenues and royalties payable	Revenues and royalties payable	29,398		27,492		Revenues and royalties payable	30,139		27,492
Accrued expenses	Accrued expenses	16,224		16,504		Accrued expenses	20,620		16,504
Asset retirement obligation	Asset retirement obligation	541		447		Asset retirement obligation	543		447
Derivative liability	Derivative liability	57,957		1,135		Derivative liability	67,575		1,135
Advances	Advances	330		2,277		Advances	1,325		2,277
Operating lease liabilities	Operating lease liabilities	782		773		Operating lease liabilities	732		773
Finance lease liabilities	Finance lease liabilities	4		69		Finance lease liabilities	—		69
Other current liabilities	Other current liabilities	498		565		Other current liabilities	634		565
Total current liabilities	Total current liabilities	131,289		55,494		Total current liabilities	155,170		55,494

Noncurrent liabilities:	Noncurrent liabilities:					Noncurrent liabilities:
Long-term debt	Long-term debt	241,360		115,000		Long-term debt	278,253		115,000
Deferred tax liability	Deferred tax liability	13,316		14,497		Deferred tax liability	13,764		14,497
Asset retirement obligation	Asset retirement obligation	14,016		2,580		Asset retirement obligation	14,965		2,580
Derivative liability	Derivative liability	5,401		173		Derivative liability	7,730		173

Table of Contents


Operating lease liabilities	Operating lease liabilities	1,510		1,840		Operating lease liabilities	1,394		1,840
Finance lease liabilities	Finance lease liabilities	0		5		Finance lease liabilities	—		5
Other noncurrent liabilities	Other noncurrent liabilities	3,089		132		Other noncurrent liabilities	3,803		132
Total noncurrent liabilities	Total noncurrent liabilities	278,692		134,227		Total noncurrent liabilities	319,909		134,227

Commitments and Contingencies (Note 13)	Commitments and Contingencies (Note 13)	0		0		Commitments and Contingencies (Note 13)	0		0

Equity:	Equity:					Equity:
Preferred stock, $0.001 par value, 20,000,000 shares authorized; NaN issued or outstanding		0		0
Preferred stock, $0.001 par value, 20,000,000 shares authorized; none issued or outstanding						Preferred stock, $0.001 par value, 20,000,000 shares authorized; none issued or outstanding	—		—

Class A Common Stock, $0.001 par value, 200,000,000 shares authorized; 44,293,062 and 30,343,421 issued and outstanding at June 30, 2021 and December 31, 2020, respectively		44		30
Class B Common Stock, $0.001 par value, 50,000,000 shares authorized; 34,397,877 and 35,009,371 issued and outstanding at June 30, 2021 and December 31, 2020, respectively		34		35
Class A Common Stock, $0.001 par value, 200,000,000 shares authorized; 50,692,057 and 30,343,421 issued and outstanding at September 30, 2021 and December 31, 2020, respectively						Class A Common Stock, $0.001 par value, 200,000,000 shares authorized; 50,692,057 and 30,343,421 issued and outstanding at September 30, 2021 and December 31, 2020, respectively	51		30
Class B Common Stock, $0.001 par value, 50,000,000 shares authorized; 34,353,995 and 35,009,371 issued and outstanding at September 30, 2021 and December 31, 2020, respectively						Class B Common Stock, $0.001 par value, 50,000,000 shares authorized; 34,353,995 and 35,009,371 issued and outstanding at September 30, 2021 and December 31, 2020, respectively	34		35
Additional paid-in capital	Additional paid-in capital	626,791		540,074		Additional paid-in capital	690,739		540,074
Accumulated deficit	Accumulated deficit	(209,962)		(195,258)		Accumulated deficit	(199,544)		(195,258)

Total Earthstone Energy, Inc. equity	Total Earthstone Energy, Inc. equity	416,907		344,881		Total Earthstone Energy, Inc. equity	491,280		344,881
Noncontrolling interest	Noncontrolling interest	450,773		470,655		Noncontrolling interest	458,614		470,655
Total equity	Total equity	867,680		815,536		Total equity	949,894		815,536

TOTAL LIABILITIES AND EQUITY	TOTAL LIABILITIES AND EQUITY	$	1,277,661	$	1,005,257	TOTAL LIABILITIES AND EQUITY	$	1,424,973	$	1,005,257

The accompanying notes are an integral part of these unaudited Condensed Consolidated Financial Statements.

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EARTHSTONE ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)

(In thousands, except share and per share amounts)


		Three Months Ended				Six Months Ended					Three Months Ended				Nine Months Ended
		June 30,				June 30,					September 30,				September 30,
		2021		2020		2021		2020			2021		2020		2021		2020
REVENUES	REVENUES									REVENUES
Oil	Oil	$	70,918	$	18,847	$	131,737	$	59,859	Oil	$	74,051	$	33,158	$	205,788	$	93,017
Natural gas	Natural gas	6,690		1,127		12,542		2,213		Natural gas	14,368		2,642		26,910		4,855
Natural gas liquids	Natural gas liquids	12,063		1,689		20,964		4,729		Natural gas liquids	21,965		5,247		42,929		9,976
Total revenues	Total revenues	89,671		21,663		165,243		66,801		Total revenues	110,384		41,047		275,627		107,848

OPERATING COSTS AND EXPENSES	OPERATING COSTS AND EXPENSES									OPERATING COSTS AND EXPENSES
Lease operating expense	Lease operating expense	11,747		5,588		22,596		14,927		Lease operating expense	12,983		7,044		35,579		21,971
Production and ad valorem taxes	Production and ad valorem taxes	5,176		1,479		10,203		4,502		Production and ad valorem taxes	7,225		2,696		17,428		7,198
Rig termination expense	Rig termination expense	0		426		0		426		Rig termination expense	—		—		—		426
Depreciation, depletion and amortization	Depreciation, depletion and amortization	26,027		22,902		50,434		47,558		Depreciation, depletion and amortization	27,059		28,538		77,493		76,096
Impairment expense	Impairment expense	0		62		0		60,433		Impairment expense	—		2,115		—		62,548
General and administrative expense	General and administrative expense	9,170		6,687		17,550		13,819		General and administrative expense	7,650		5,796		25,200		19,615
Transaction costs	Transaction costs	507		(463)		2,613		381		Transaction costs	293		(705)		2,906		(324)
Accretion of asset retirement obligation	Accretion of asset retirement obligation	303		46		593		90		Accretion of asset retirement obligation	323		47		916		137
Exploration expense	Exploration expense	30		(3)		30		298		Exploration expense	296		—		326		298
Total operating costs and expenses	Total operating costs and expenses	52,960		36,724		104,019		142,434		Total operating costs and expenses	55,829		45,531		159,848		187,965

Gain on sale of oil and gas properties	Gain on sale of oil and gas properties	348		(6)		348		198		Gain on sale of oil and gas properties	392		—		740		198

Income (loss) from operations	Income (loss) from operations	37,059		(15,067)		61,572		(75,435)		Income (loss) from operations	54,947		(4,484)		116,519		(79,919)

OTHER INCOME (EXPENSE)	OTHER INCOME (EXPENSE)									OTHER INCOME (EXPENSE)
Interest expense, net	Interest expense, net	(2,401)		(1,285)		(4,618)		(3,021)		Interest expense, net	(3,050)		(1,186)		(7,668)		(4,207)

(Loss) gain on derivative contracts, net	(Loss) gain on derivative contracts, net	(51,175)		(20,679)		(84,438)		79,105		(Loss) gain on derivative contracts, net	(33,128)		(6,040)		(117,566)		73,065

Other income, net	Other income, net	200		12		303		138		Other income, net	520		(18)		823		120
Total other (expense) income		(53,376)		(21,952)		(88,753)		76,222
Total other income (expense)										Total other income (expense)	(35,658)		(7,244)		(124,411)		68,978

(Loss) income before income taxes		(16,317)		(37,019)		(27,181)		787
Income tax benefit		486		1,110		794		18
Net (loss) income		(15,831)		(35,909)		(26,387)		805
Income (loss) before income taxes										Income (loss) before income taxes	19,289		(11,728)		(7,892)		(10,941)
Income tax (expense) benefit										Income tax (expense) benefit	(451)		(130)		343		(112)
Net income (loss)										Net income (loss)	18,838		(11,858)		(7,549)		(11,053)

Less: Net (loss) income attributable to noncontrolling interest		(6,960)		(19,570)		(11,683)		436
Less: Net income (loss) attributable to noncontrolling interest										Less: Net income (loss) attributable to noncontrolling interest	8,420		(6,413)		(3,263)		(5,977)

Net (loss) income attributable to Earthstone Energy, Inc.		$	(8,871)	$	(16,339)	$	(14,704)	$	369
Net income (loss) attributable to Earthstone Energy, Inc.										Net income (loss) attributable to Earthstone Energy, Inc.	$	10,418	$	(5,445)	$	(4,286)	$	(5,076)

Net (loss) income per common share attributable to Earthstone Energy, Inc.:
Net income (loss) per common share attributable to Earthstone Energy, Inc.:										Net income (loss) per common share attributable to Earthstone Energy, Inc.:
Basic	Basic	$	(0.20)	$	(0.55)	$	(0.34)	$	0.01	Basic	$	0.21	$	(0.18)	$	(0.09)	$	(0.17)
Diluted	Diluted	$	(0.20)	$	(0.55)	$	(0.34)	$	0.01	Diluted	$	0.20	$	(0.18)	$	(0.09)	$	(0.17)

Weighted average common shares outstanding:	Weighted average common shares outstanding:									Weighted average common shares outstanding:
Basic	Basic	44,127,718		29,858,162		43,457,043		29,677,795		Basic	49,243,185		30,073,635		45,406,952		29,810,705
Diluted	Diluted	44,127,718		29,858,162		43,457,043		29,677,795		Diluted	52,662,942		30,073,635		45,406,952		29,810,705

The accompanying notes are an integral part of these unaudited Condensed Consolidated Financial Statements.

Table of Contents

EARTHSTONE ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED)

(In thousands, except share amounts)


		Issued Shares																	Issued Shares
		Class A Common Stock	Class B Common Stock	Class A Common Stock		Class B Common Stock		Additional Paid-in Capital		Accumulated Deficit		Total Earthstone Energy, Inc. Equity		Noncontrolling Interest		Total Equity			Class A Common Stock	Class B Common Stock	Class A Common Stock		Class B Common Stock		Additional Paid-in Capital		Accumulated Deficit		Total Earthstone Energy, Inc. Equity		Noncontrolling Interest		Total Equity
At December 31, 2020	At December 31, 2020	30,343,421	35,009,371	$	30	$	35	$	540,074	$	(195,258)	$	344,881	$	470,655	$	815,536	At December 31, 2020	30,343,421	35,009,371	$	30	$	35	$	540,074	$	(195,258)	$	344,881	$	470,655	$	815,536
Stock-based compensation expense	Stock-based compensation expense	—	—	—		—		2,605		—		2,605				2,605		Stock-based compensation expense	—	—	—		—		2,605		—		2,605				2,605
Shares issued in connection with the IRM Acquisition	Shares issued in connection with the IRM Acquisition	12,719,594	—	13		—		76,559		—		76,572		—		76,572		Shares issued in connection with the IRM Acquisition	12,719,594	—	13		—		76,559		—		76,572		—		76,572
Vesting of restricted stock units and performance units, net of taxes paid	Vesting of restricted stock units and performance units, net of taxes paid	463,495	—	—		—		—		—		—		—		—		Vesting of restricted stock units and performance units, net of taxes paid	463,495	—	—		—		—		—		—		—		—
Vested restricted stock units and performance units retained by the Company in exchange for payment of recipient mandatory tax withholdings	Vested restricted stock units and performance units retained by the Company in exchange for payment of recipient mandatory tax withholdings	257,764	—	—		—		(2,080)		—		(2,080)		—		(2,080)		Vested restricted stock units and performance units retained by the Company in exchange for payment of recipient mandatory tax withholdings	257,764	—	—		—		(2,080)		—		(2,080)		—		(2,080)
Cancellation of treasury shares	Cancellation of treasury shares	(257,764)	—	—		—		—		—		—		—		—		Cancellation of treasury shares	(257,764)	—	—		—		—		—		—		—		—
Class B Common Stock converted to Class A Common Stock	Class B Common Stock converted to Class A Common Stock	578,031	(578,031)	1		(1)		7,758		—		7,758		(7,758)		0		Class B Common Stock converted to Class A Common Stock	578,031	(578,031)	1		(1)		7,758		—		7,758		(7,758)		—
Net loss	Net loss	—	—	—		—		—		(5,833)		(5,833)		(4,723)		(10,556)		Net loss	—	—	—		—		—		(5,833)		(5,833)		(4,723)		(10,556)
At March 31, 2021	At March 31, 2021	44,104,541	34,431,340	$	44	$	34	$	624,916	$	(201,091)	$	423,903	$	458,174	$	882,077	At March 31, 2021	44,104,541	34,431,340	$	44	$	34	$	624,916	$	(201,091)	$	423,903	$	458,174	$	882,077
Stock-based compensation expense	Stock-based compensation expense	—	—	—		—		2,175		—		2,175		—		2,175		Stock-based compensation expense	—	—	—		—		2,175		—		2,175		—		2,175
Vesting of restricted stock units, net of taxes paid	Vesting of restricted stock units, net of taxes paid	155,058	—	—		—		—		—		—		—		—		Vesting of restricted stock units, net of taxes paid	155,058	—	—		—		—		—		—		—		—
Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	66,343	—	—		—		(741)		—		(741)		—		(741)		Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	66,343	—	—		—		(741)		—		(741)		—		(741)
Cancellation of treasury shares	Cancellation of treasury shares	(66,343)	—	—		—		—		—		—		—		—		Cancellation of treasury shares	(66,343)	—	—		—		—		—		—		—		—
Class B Common Stock converted to Class A Common Stock	Class B Common Stock converted to Class A Common Stock	33,463	(33,463)	—		—		441		—		441		(441)		0		Class B Common Stock converted to Class A Common Stock	33,463	(33,463)	—		—		441		—		441		(441)		—
Net loss	Net loss	—	—	—		—		—		(8,871)		(8,871)		(6,960)		(15,831)		Net loss	—	—	—		—		—		(8,871)		(8,871)		(6,960)		(15,831)
At June 30, 2021	At June 30, 2021	44,293,062	34,397,877	$	44	$	34	$	626,791	$	(209,962)	$	416,907	$	450,773	$	867,680	At June 30, 2021	44,293,062	34,397,877	$	44	$	34	$	626,791	$	(209,962)	$	416,907	$	450,773	$	867,680

Stock-based compensation expense																		Stock-based compensation expense	—	—	—		—		2,161		—		2,161		—		2,161
Shares issued in connection with the Tracker/Sequel Acquisitions																		Shares issued in connection with the Tracker/Sequel Acquisitions	6,200,000	—	6		—		61,808		—		61,814		—		61,814
Vesting of restricted stock units, net of taxes paid																		Vesting of restricted stock units, net of taxes paid	155,113	—	1		—		(1)		—		—		—		—
Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings																		Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	65,106	—	—		—		(599)		—		(599)		—		(599)
Cancellation of treasury shares																		Cancellation of treasury shares	(65,106)	—	—		—		—		—		—		—		—
Class B Common Stock converted to Class A Common Stock																		Class B Common Stock converted to Class A Common Stock	43,882	(43,882)	—		—		579		—		579		(579)		—
Net loss																		Net loss	—	—	—		—		—		10,418		10,418		8,420		18,838
At September 30, 2021																		At September 30, 2021	50,692,057	34,353,995	$	51	$	34	$	690,739	$	(199,544)	$	491,280	$	458,614	$	949,894

Table of Contents


		Issued Shares																	Issued Shares
		Class A Common Stock	Class B Common Stock	Class A Common Stock		Class B Common Stock		Additional Paid-in Capital		Accumulated Deficit		Total Earthstone Energy, Inc. Equity		Noncontrolling Interest		Total Equity			Class A Common Stock	Class B Common Stock	Class A Common Stock		Class B Common Stock		Additional Paid-in Capital		Accumulated Deficit		Total Earthstone Energy, Inc. Equity		Noncontrolling Interest		Total Equity
At December 31, 2019	At December 31, 2019	29,421,131	35,260,680	$	29	$	35	$	527,246	$	(181,711)	$	345,599	$	490,152	$	835,751	At December 31, 2019	29,421,131	35,260,680	$	29	$	35	$	527,246	$	(181,711)	$	345,599	$	490,152	$	835,751
Stock-based compensation expense	Stock-based compensation expense	—	—	—		—		2,694		—		2,694				2,694		Stock-based compensation expense	—	—	—		—		2,694		—		2,694				2,694
Vesting of restricted stock units, net of taxes paid	Vesting of restricted stock units, net of taxes paid	231,834	—	1		—		—		—		1		—		1		Vesting of restricted stock units, net of taxes paid	231,834	—	1		—		—		—		1		—		1
Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	75,695	—	—		—		(214)		—		(214)		—		(214)		Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	75,695	—	—		—		(214)		—		(214)		—		(214)
Cancellation of treasury shares	Cancellation of treasury shares	(75,695)	—	—		—		—		—		—		—		—		Cancellation of treasury shares	(75,695)	—	—		—		—		—		—		—		—
Class B Common Stock converted to Class A Common Stock	Class B Common Stock converted to Class A Common Stock	199,993	(199,993)	—		—		2,897		—		2,897		(2,897)		0		Class B Common Stock converted to Class A Common Stock	199,993	(199,993)	—		—		2,897		—		2,897		(2,897)		—
Net income	Net income	—	—	—		—		—		16,708		16,708		20,006		36,714		Net income	—	—	—		—		—		16,708		16,708		20,006		36,714
At March 31, 2020	At March 31, 2020	29,852,958	35,060,687	$	30	$	35	$	532,623	$	(165,003)	$	367,685	$	507,261	$	874,946	At March 31, 2020	29,852,958	35,060,687	$	30	$	35	$	532,623	$	(165,003)	$	367,685	$	507,261	$	874,946
Stock-based compensation expense	Stock-based compensation expense	—	—	—		—		2,568		—		2,568		—		2,568		Stock-based compensation expense	—	—	—		—		2,568		—		2,568		—		2,568
Vesting of restricted stock units, net of taxes paid	Vesting of restricted stock units, net of taxes paid	165,399	—	—		—		—		—		—		—		0		Vesting of restricted stock units, net of taxes paid	165,399	—	—		—		—		—		—		—		—
Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	57,810	—	—		—		(170)		—		(170)		—		(170)		Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	57,810	—	—		—		(170)		—		(170)		—		(170)
Cancellation of treasury shares	Cancellation of treasury shares	(57,810)	—	—		—		—		—		—		—		—		Cancellation of treasury shares	(57,810)	—	—		—		—		—		—		—		—
Class B Common Stock converted to Class A Common Stock	Class B Common Stock converted to Class A Common Stock	2,000	(2,000)	—		—		28		—		28		(28)		0		Class B Common Stock converted to Class A Common Stock	2,000	(2,000)	—		—		28		—		28		(28)		—
Net loss	Net loss	—	—	—		—		—		(16,339)		(16,339)		(19,570)		(35,909)		Net loss	—	—	—		—		—		(16,339)		(16,339)		(19,570)		(35,909)
At June 30, 2020	At June 30, 2020	30,020,357	35,058,687	$	30	$	35	$	535,049	$	(181,342)	$	353,772	$	487,663	$	841,435	At June 30, 2020	30,020,357	35,058,687	$	30	$	35	$	535,049	$	(181,342)	$	353,772	$	487,663	$	841,435

Stock-based compensation expense																		Stock-based compensation expense	—	—	—		—		2,403		—		2,403		—		2,403
Vesting of restricted stock units, net of taxes paid																		Vesting of restricted stock units, net of taxes paid	141,076	—	—		—		—		—		—		—		—
Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings																		Vested restricted stock units retained by the Company in exchange for payment of recipient mandatory tax withholdings	54,268	—	—		—		(147)		—		(147)		—		(147)
Cancellation of treasury shares																		Cancellation of treasury shares	(54,268)	—	—		—		—		—		—		—		—
Class B Common Stock converted to Class A Common Stock																		Class B Common Stock converted to Class A Common Stock	49,316	(49,316)	—		—		685		—		685		(685)		—
Net loss																		Net loss	—	—	—		—		—		(5,445)		(5,445)		(6,413)		(11,858)
At September 30, 2020																		At September 30, 2020	30,210,749	35,009,371	$	30	$	35	$	537,990	$	(186,787)	$	351,268	$	480,565	$	831,833

The accompanying notes are an integral part of these unaudited Condensed Consolidated Financial Statements.

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EARTHSTONE ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(In thousands)


		For the Six Months Ended June 30,					For the Nine Months Ended September 30,
		2021		2020			2021		2020
Cash flows from operating activities:	Cash flows from operating activities:					Cash flows from operating activities:
Net (loss) income		$	(26,387)	$	805
Net loss						Net loss	$	(7,549)	$	(11,053)
Adjustments to reconcile net (loss) income to net cash provided by operating activities:	Adjustments to reconcile net (loss) income to net cash provided by operating activities:					Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	Depreciation, depletion and amortization	50,434		47,558		Depreciation, depletion and amortization	77,493		76,096
Impairment of proved and unproved oil and gas properties	Impairment of proved and unproved oil and gas properties	0		42,813		Impairment of proved and unproved oil and gas properties	—		44,928
Impairment of goodwill	Impairment of goodwill	0		17,620		Impairment of goodwill	—		17,620
Accretion of asset retirement obligations	Accretion of asset retirement obligations	593		90		Accretion of asset retirement obligations	916		137
Settlement of asset retirement obligations	Settlement of asset retirement obligations	(53)		0		Settlement of asset retirement obligations	(103)		—
(Gain) on sale of oil and gas properties	(Gain) on sale of oil and gas properties	(348)		(198)		(Gain) on sale of oil and gas properties	(740)		(198)
(Gain) on sale of office and other equipment	(Gain) on sale of office and other equipment	(114)		0		(Gain) on sale of office and other equipment	(114)		—

Total loss (gain) on derivative contracts, net	Total loss (gain) on derivative contracts, net	84,438		(79,105)		Total loss (gain) on derivative contracts, net	117,566		(73,065)
Operating portion of net cash (paid) received in settlement of derivative contracts	Operating portion of net cash (paid) received in settlement of derivative contracts	(25,427)		39,096		Operating portion of net cash (paid) received in settlement of derivative contracts	(46,311)		47,599
Stock-based compensation	Stock-based compensation	7,741		5,262		Stock-based compensation	10,621		7,665
Deferred income taxes	Deferred income taxes	(794)		(18)		Deferred income taxes	(343)		112

Amortization of deferred financing costs	Amortization of deferred financing costs	339		161		Amortization of deferred financing costs	581		241

Changes in assets and liabilities:	Changes in assets and liabilities:					Changes in assets and liabilities:
(Increase) decrease in accounts receivable	(Increase) decrease in accounts receivable	(4,181)		15,060		(Increase) decrease in accounts receivable	(12,238)		12,102
(Increase) decrease in prepaid expenses and other current assets	(Increase) decrease in prepaid expenses and other current assets	(114)		(747)		(Increase) decrease in prepaid expenses and other current assets	900		(264)
Increase (decrease) in accounts payable and accrued expenses	Increase (decrease) in accounts payable and accrued expenses	8,352		(3,410)		Increase (decrease) in accounts payable and accrued expenses	6,090		1,976
Increase (decrease) in revenues and royalties payable	Increase (decrease) in revenues and royalties payable	1,795		(16,491)		Increase (decrease) in revenues and royalties payable	2,556		(7,768)
Increase (decrease) in advances	Increase (decrease) in advances	(2,830)		(11,412)		Increase (decrease) in advances	(2,015)		(11,412)

Net cash provided by operating activities	Net cash provided by operating activities	93,444		57,084		Net cash provided by operating activities	147,310		104,716
Cash flows from investing activities:	Cash flows from investing activities:					Cash flows from investing activities:
Acquisition of oil and gas properties, net of cash acquired	Acquisition of oil and gas properties, net of cash acquired	(187,803)		0		Acquisition of oil and gas properties, net of cash acquired	(240,431)		—
Additions to oil and gas properties	Additions to oil and gas properties	(28,238)		(67,493)		Additions to oil and gas properties	(65,074)		(72,869)
Additions to office and other equipment	Additions to office and other equipment	(370)		(108)		Additions to office and other equipment	(886)		(111)
Proceeds from sales of oil and gas properties	Proceeds from sales of oil and gas properties	200		409		Proceeds from sales of oil and gas properties	975		409
Net cash used in investing activities	Net cash used in investing activities	(216,211)		(67,192)		Net cash used in investing activities	(305,416)		(72,571)
Cash flows from financing activities:	Cash flows from financing activities:					Cash flows from financing activities:
Proceeds from borrowings	Proceeds from borrowings	360,078		69,906		Proceeds from borrowings	503,734		93,923
Repayments of borrowings	Repayments of borrowings	(233,718)		(71,318)		Repayments of borrowings	(340,482)		(133,923)
Cash paid related to the exchange and cancellation of Class A Common Stock	Cash paid related to the exchange and cancellation of Class A Common Stock	(2,821)		(382)		Cash paid related to the exchange and cancellation of Class A Common Stock	(3,420)		(531)
Cash paid for finance leases	Cash paid for finance leases	(70)		(110)		Cash paid for finance leases	(70)		(125)
Deferred financing costs	Deferred financing costs	(1,718)		0		Deferred financing costs	(2,709)		—
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	121,751		(1,904)		Net cash provided by (used in) financing activities	157,053		(40,656)
Net decrease in cash	Net decrease in cash	(1,016)		(12,012)		Net decrease in cash	(1,053)		(8,511)
Cash at beginning of period	Cash at beginning of period	1,494		13,822		Cash at beginning of period	1,494		13,822
Cash at end of period	Cash at end of period	$	478	$	1,810	Cash at end of period	$	441	$	5,311
Supplemental disclosure of cash flow information	Supplemental disclosure of cash flow information					Supplemental disclosure of cash flow information
Cash paid for:	Cash paid for:					Cash paid for:
Interest	Interest	$	4,272	$	2,659	Interest	$	7,126	$	3,613
Income taxes	Income taxes	$	797	$	0	Income taxes	$	687	$	—
Non-cash investing and financing activities:	Non-cash investing and financing activities:					Non-cash investing and financing activities:
Class A Common Stock issued in IRM Acquisition	Class A Common Stock issued in IRM Acquisition	$	76,572	$	0	Class A Common Stock issued in IRM Acquisition	$	76,572	$	—
Class A Common Stock issued in Tracker/Sequel Acquisitions						Class A Common Stock issued in Tracker/Sequel Acquisitions	$	61,814	$	—
Accrued capital expenditures	Accrued capital expenditures	$	11,416	$	6,220	Accrued capital expenditures	$	18,971	$	2,213

Asset retirement obligations	Asset retirement obligations	$	161	$	43	Asset retirement obligations	$	242	$	44

The accompanying notes are an integral part of these unaudited Condensed Consolidated Financial Statements.

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 1. Basis of Presentation and Summary of Significant Accounting Policies

Earthstone Energy, Inc., a Delaware corporation (“Earthstone” and together with its consolidated subsidiaries, the “Company”), is a growth-oriented independent oil and natural gas development and production company. In addition, the Company is active in corporate mergers and the acquisition of oil and natural gas properties that have production and future development opportunities. The Company's operations are all in the upstream segment of the oil and natural gas industry and all its properties are onshore in ~~the United States.~~Texas.

Earthstone is the sole managing member of Earthstone Energy Holdings, LLC, a Delaware limited liability company (together with its wholly-owned consolidated subsidiaries, “EEH”), with a controlling interest in EEH. Earthstone, together with its wholly-owned subsidiary, Lynden Energy Corp., a corporation organized under the laws of British Columbia (“Lynden Corp”), and Lynden Corp’s wholly-owned consolidated subsidiary, Lynden USA Inc., a Utah corporation (“Lynden US”) and also a member of EEH, consolidates the financial results of EEH and records a noncontrolling interest in the Condensed Consolidated Financial Statements representing the economic interests of EEH's members other than Earthstone and Lynden US.

The accompanying unaudited Condensed Consolidated Financial Statements and notes thereto have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) applicable to interim financial statements. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been omitted. The accompanying unaudited Condensed Consolidated Financial Statements and notes should be read in conjunction with the financial statements and notes included in Earthstone’s 2020 Annual Report on Form 10-K.

The information furnished herein reflects all adjustments that are, in the opinion of management, necessary for the fair presentation of the Company's financial position, results of operations and cash flows for the periods presented. Any such adjustments are of a normal, recurring nature. The Company’s Condensed Consolidated Balance Sheet at December 31, 2020 is derived from the audited Consolidated Financial Statements at that date.

Recently Issued Accounting Standards

Income Taxes - In December 2019, the FASB issued an update that simplifies the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. The amendments also improve consistent application of and simplify GAAP for other areas of Topic 740 by clarifying and amending existing guidance. The amendments in this update are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020 and early adoption is permitted. The Company adopted the update effective January 1, 2021 and the impact was not material to the Consolidated Financial Statements.

Reference Rate Reform - In March 2020, the FASB issued an update that provides optional guidance for a limited period of time to ease the transition from LIBOR to an alternative reference rate. The ASU intends to address certain concerns relating to accounting for contract modifications and hedge accounting. These optional expedients and exceptions to applying GAAP, assuming certain criteria are met, are allowed through December 31, 2022. The Company is currently evaluating the provisions of this update and has not yet determined whether it will elect the optional expedients. The Company does not expect the transition to an alternative rate to have a material impact on its business, operations or liquidity.

Note 2. Fair Value Measurements

FASB Accounting Standards Codification (“ASC”) Topic 820, defines fair value as the price that would be received to sell an asset, or paid to transfer a liability, in an orderly transaction between market participants at the measurement date. ASC 820 provides a framework for measuring fair value, establishes a three-level hierarchy for fair value measurements based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date and requires consideration of the counterparty’s creditworthiness when valuing certain assets.

The three-level fair value hierarchy for disclosure of fair value measurements defined by ASC 820 is as follows:

Level 1 – Unadjusted, quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. An active market is defined as a market where transactions for the financial instrument occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 – Inputs, other than quoted prices within Level 1, that are either directly or indirectly observable for the asset or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Level 3 – Prices or valuations that require unobservable inputs that are both significant to the fair value measurement and unobservable. Valuation under Level 3 generally involves a significant degree of judgment from management.

A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, valuation models are applied. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the price transparency for the instruments or market and the instrument’s complexity. The Company reflects transfers between the three levels at the beginning of the reporting period in which the availability of observable inputs no longer justifies classification in the original level. There were no transfers between fair value hierarchy levels for the ~~six~~nine months ended ~~June~~September 30, 2021.

Fair Value on a Recurring Basis

Derivative Financial Instruments

Derivative financial instruments are carried at fair value and measured on a recurring basis. The derivative financial instruments consist of swaps and costless collars for crude oil and natural gas and interest rate swaps. The Company’s commodity price hedges and interest rate swaps are valued based on discounted future cash flow models that are primarily based on published forward commodity price curves and published LIBOR forward curves; thus, these inputs are designated as Level 2 within the valuation hierarchy.

The fair values of derivative instruments in asset positions include measures of counterparty nonperformance risk, and the fair values of derivative instruments in liability positions include measures of the Company’s nonperformance risk. These measurements were not material to the Condensed Consolidated Financial Statements.

Share-based Compensation Liability

Certain of our performance-based stock awards (“PSUs”) may be payable in cash. The Company classifies the awards that may be settled in cash as liability awards. These awards are valued quarterly utilizing the Monte Carlo Simulation pricing model, which calculates multiple potential outcomes for an award and establishes grant date fair value based on the most likely outcome. The inputs for the Monte Carlo model are designated as Level 2 within the valuation hierarchy. The share-based compensation liability related to the PSU liability awards is included in Other noncurrent liabilities in the Condensed Consolidated Balance Sheet as of September 30, 2021.

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The following table summarizes the fair value of the Company’s financial assets and liabilities, by level within the fair-value hierarchy (in thousands):


June 30, 2021		Level 1		Level 2		Level 3		Total
September 30, 2021										September 30, 2021	Level 1		Level 2		Level 3		Total
Financial assets	Financial assets									Financial assets
Derivative asset - current	Derivative asset - current	$	0	$	72	$	0	$	72	Derivative asset - current	$	—	$	17	$	—	$	17
Derivative asset - noncurrent	Derivative asset - noncurrent	0		694		0		694		Derivative asset - noncurrent	—		453		—		453
Total financial assets	Total financial assets	$	0	$	766	$	0	$	766	Total financial assets	$	—	$	470	$	—	$	470

Financial liabilities	Financial liabilities									Financial liabilities
Derivative liability - current	Derivative liability - current	$	0	$	57,957	$	0	$	57,957	Derivative liability - current	$	—	$	67,575	$	—	$	67,575
Derivative liability - noncurrent	Derivative liability - noncurrent	0		5,401		0		5,401		Derivative liability - noncurrent	—		7,730		—		7,730
Share-based compensation liability - noncurrent										Share-based compensation liability - noncurrent	—		3,680		—		3,680
Total financial liabilities	Total financial liabilities	$	0	$	63,358	$	0	$	63,358	Total financial liabilities	$	—	$	78,985	$	—	$	78,985

December 31, 2020	December 31, 2020									December 31, 2020
Financial assets	Financial assets									Financial assets
Derivative asset - current	Derivative asset - current	$	0	$	7,509	$	0	$	7,509	Derivative asset - current	$	—	$	7,509	$	—	$	7,509
Derivative asset - noncurrent	Derivative asset - noncurrent	0		396		0		396		Derivative asset - noncurrent	—		396		—		396
Total financial assets	Total financial assets	$	0	$	7,905	$	0	$	7,905	Total financial assets	$	—	$	7,905	$	—	$	7,905

Financial liabilities	Financial liabilities									Financial liabilities
Derivative liability - current	Derivative liability - current	$	0	$	1,135	$	0	$	1,135	Derivative liability - current	$	—	$	1,135	$	—	$	1,135
Derivative liability - noncurrent	Derivative liability - noncurrent	0		173		0		173		Derivative liability - noncurrent	—		173		—		173
Total financial liabilities	Total financial liabilities	$	0	$	1,308	$	0	$	1,308	Total financial liabilities	$	—	$	1,308	$	—	$	1,308

Other financial instruments include cash, accounts receivable and payable, and revenue royalties. The carrying amount of these instruments approximates fair value because of their short-term nature. The Company’s long-term debt obligation bears interest at floating market rates, therefore carrying amounts and fair value are approximately equal.

Fair Value on a Nonrecurring Basis

The Company applies the provisions of the fair value measurement standard on a non-recurring basis to its non-financial assets and liabilities, including oil and gas properties, goodwill, business combinations and asset retirement ~~obligations and performance~~

~~Table of Contents~~

~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~

~~units.~~obligations. These assets and liabilities are not measured at fair value on an ongoing basis but are subject to fair value adjustments if events or changes in certain circumstances indicate that adjustments may be necessary. Due to significant declines in commodity prices and global demand for oil and natural gas products resulting from the COVID-19 pandemic, the Company assessed the fair values of its oil and natural gas properties and goodwill resulting in non-cash impairment charges during the three months ended March 31, 2020. NoSince then, commodity prices have recovered and no other such triggering events that require further assessment were observed during the ~~six~~nine months ended ~~June~~September 30, 2021. See further discussion in Note 5. Oil and Natural Gas Properties.

Note 3. Derivative Financial Instruments

Commodity Derivative Instruments

The Company’s hedging activities primarily consist of derivative instruments entered into in order to hedge against changes in oil and natural gas prices through the use of fixed price swap ~~agreements.~~agreements and costless collars. Swaps exchange floating price risk in the future for a fixed price at the time of the hedge. Costless collars set both a maximum (sold ceiling) and a minimum (bought floor) future price. Consistent with its hedging policy, the Company has entered into a series of derivative instruments to hedge a significant portion of its expected oil and natural gas production through December 31, 2022. Typically, these derivative instruments require payments to (receipts from) counterparties based on specific indices as required by the derivative agreements. Although not risk free, the Company believes these instruments reduce its exposure to oil and natural gas price fluctuations and, thereby, allow the Company to achieve a more predictable cash flow. The Company does not enter into derivative instruments for trading or other speculative purposes.

Table of Contents

EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

These transactions are recorded in the Condensed Consolidated Financial Statements in accordance with FASB ASC Topic 815. The Company has accounted for these transactions using the mark-to-market accounting method. Generally, the Company incurs accounting losses on derivatives during periods where prices are rising and gains during periods where prices are falling which may cause significant fluctuations in the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Operations.

The Company nets its derivative instrument fair value amounts executed with each counterparty pursuant to an International Swap Dealers Association Master Agreement (“ISDA”), which provides for net settlement over the term of the contract. The ISDA is a standard contract that governs all derivative contracts entered into between the Company and the respective counterparty. The ISDA allows for offsetting of amounts payable or receivable between the Company and the counterparty, at the election of both parties, for transactions that occur on the same date and in the same currency.

The Company had the following open crude oil and natural gas derivative contracts as of ~~June~~September 30, 2021:


		Price Swaps					Price Swaps
Period	Period	Commodity	Volume (Bbls / MMBtu)	Weighted Average Price ($/Bbl / $/MMBtu)		Period	Commodity	Volume (Bbls / MMBtu)	Weighted Average Price ($/Bbl / $/MMBtu)
Q3 - Q4 2021		Crude Oil	1,693,400	$	49.10
Q4 2021						Q4 2021	Crude Oil	941,475	$	50.63
Q1 - Q4 2022	Q1 - Q4 2022	Crude Oil	1,732,250	$	53.64	Q1 - Q4 2022	Crude Oil	2,462,250	$	56.31
Q3 - Q4 2021		Crude Oil Basis Swap (1)	1,509,400	$	0.80
Q3 - Q4 2021		Crude Oil Roll Swap (2)	474,650	$	(0.26)
Q4 2021						Q4 2021	Crude Oil Basis Swap (1)	757,475	$	0.80
Q4 2021						Q4 2021	Crude Oil Roll Swap (2)	228,475	$	(0.27)
Q1 - Q4 2022	Q1 - Q4 2022	Crude Oil Basis Swap (1)	2,007,500	$	0.68	Q1 - Q4 2022	Crude Oil Basis Swap (1)	2,007,500	$	0.68
Q3 - Q4 2021		Natural Gas	4,904,000	$	2.87
Q4 2021						Q4 2021	Natural Gas	2,576,000	$	2.87
Q1 - Q4 2022	Q1 - Q4 2022	Natural Gas	4,295,000	$	2.92	Q1 - Q4 2022	Natural Gas	4,295,000	$	2.92
Q3 - Q4 2021		Natural Gas Basis Swap (3)	5,026,000	$	(0.30)
Q4 2021						Q4 2021	Natural Gas Basis Swap (3)	2,698,000	$	(0.29)
Q1 - Q4 2022	Q1 - Q4 2022	Natural Gas Basis Swap (3)	7,725,000	$	(0.24)	Q1 - Q4 2022	Natural Gas Basis Swap (3)	9,100,000	$	(0.26)

(1)The basis differential price is between WTI Midland Crude and the WTI NYMEX.

(2)The swap is between WTI Roll and the WTI NYMEX.

(3)The basis differential price is between W. Texas (WAHA) and the Henry Hub NYMEX.

~~Table of Contents~~

~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~


		Costless Collars							Costless Collars
Period	Period	Commodity	Volume (Bbls / MMBtu)	Sold Ceiling ($/Bbl / $/MMBtu)		Bought Floor ($/Bbl / $/MMBtu)		Period	Commodity	Volume (Bbls / MMBtu)	Sold Ceiling ($/Bbl / $/MMBtu)		Bought Floor ($/Bbl / $/MMBtu)
Q1 - Q4 2022	Q1 - Q4 2022	Crude Oil Costless Collar	365,000	$	68.75	$	55.00	Q1 - Q4 2022	Crude Oil Costless Collar	365,000	$	68.75	$	55.00
Q3 - Q4 2021		Natural Gas Costless Collar	122,000	$	4.10	$	3.50
Q1 2022		Natural Gas Costless Collar	1,080,000	$	3.75	$	3.17
Q4 2021								Q4 2021	Natural Gas Costless Collar	122,000	$	4.10	$	3.50
Q1 - Q4 2022								Q1 - Q4 2022	Natural Gas Costless Collar	2,905,000	$	4.00	$	3.06

Interest Rate Swaps

At times, the Company’s hedging activities include the use of interest rate swaps entered into in order to manage cash flow variability resulting from changes in interest rates. These derivative instruments are not accounted for under hedge accounting.

The Company had the following interest rate swaps as of ~~June~~September 30, 2021:


Effective Dates	Notional Amount	Fixed Rate
May 5, 2020 to May 5, 2022	$125,000,000	0.286	%
May 5, 2022 to May 5, 2023	$100,000,000	0.286	%
May 5, 2023 to May 7, 2024	$75,000,000	0.286	%

Table of Contents

EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The following table summarizes the location and fair value amounts of all derivative instruments in the Condensed Consolidated Balance Sheets as well as the gross recognized derivative assets, liabilities, and amounts offset in the Condensed Consolidated Balance Sheets (in thousands):

June 30, 2021 December 31, 2020
Derivatives not
designated as hedging
contracts under ASC
Topic 815 Balance Sheet Location Gross
Recognized
Assets /
Liabilities Gross
Amounts
Offset Net
Recognized
Assets /
Liabilities Gross
Recognized
Assets /
Liabilities Gross
Amounts
Offset Net
Recognized
Assets /
Liabilities
Commodity contracts Derivative asset - current $ 2,127 $ (2,055) $ 72 $ 11,071 $ (3,562) $ 7,509
Commodity contracts Derivative liability - current $ 59,820 $ (2,055) $ 57,765 $ 4,492 $ (3,562) $ 930
Interest rate swaps Derivative liability - current $ 192 $ 0 $ 192 $ 205 $ 0 $ 205
Commodity contracts Derivative asset - noncurrent $ 856 $ (617) $ 239 $ 396 $ 0 $ 396
Commodity contracts Derivative liability - noncurrent $ 6,018 $ (617) $ 5,401 $ 0 $ 0 $ 0
Interest rate swaps Derivative asset - noncurrent $ 455 0 455 $ 0 $ 0 $ 0
Interest rate swaps Derivative liability - noncurrent $ 0 $ 0 $ 0 $ 173 $ 0 $ 173

~~Table of Contents~~

~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~


		September 30, 2021						December 31, 2020
Derivatives not designated as hedging contracts under ASC Topic 815	Balance Sheet Location	Gross Recognized Assets / Liabilities		Gross Amounts Offset		Net Recognized Assets / Liabilities		Gross Recognized Assets / Liabilities		Gross Amounts Offset		Net Recognized Assets / Liabilities
Commodity contracts	Derivative asset - current	$	1,340	$	(1,323)	$	17	$	11,071	$	(3,562)	$	7,509
Commodity contracts	Derivative liability - current	$	68,707	$	(1,323)	$	67,384	$	4,492	$	(3,562)	$	930
Interest rate swaps	Derivative liability - current	$	191	$	—	$	191	$	205	$	—	$	205
Commodity contracts	Derivative asset - noncurrent	$	285	$	(277)	$	8	$	396	$	—	$	396
Commodity contracts	Derivative liability - noncurrent	$	8,007	$	(277)	$	7,730	$	—	$	—	$	—
Interest rate swaps	Derivative asset - noncurrent	$	445	—		445		$	—	$	—	$	—
Interest rate swaps	Derivative liability - noncurrent	$	—	$	—	$	—	$	173	$	—	$	173

The following table summarizes the location and amounts of the Company’s realized and unrealized gains and losses on derivatives instruments in the Condensed Consolidated Statements of Operations and Condensed Consolidated Statements of Cash Flows (in thousands):


Derivatives not designated as hedging contracts under ASC Topic 815	Derivatives not designated as hedging contracts under ASC Topic 815			Three Months Ended June 30,				Six Months Ended June 30,				Derivatives not designated as hedging contracts under ASC Topic 815			Three Months Ended September 30,				Nine Months Ended September 30,
		Statement of Cash Flows Location	Statement of Operations Location	2021		2020		2021		2020			Statement of Cash Flows Location	Statement of Operations Location	2021		2020		2021		2020
Unrealized (loss) gain	Unrealized (loss) gain	Not separately presented	Not separately presented	$	(36,653)	$	(50,036)	$	(59,011)	$	40,009	Unrealized (loss) gain	Not separately presented	Not separately presented	$	(12,244)	$	(14,543)	$	(71,255)	$	25,466
Realized (loss) gain	Realized (loss) gain	Operating portion of net cash (paid) received in settlement of derivative contracts	Not separately presented	(14,522)		29,357		(25,427)		39,096		Realized (loss) gain	Operating portion of net cash (paid) received in settlement of derivative contracts	Not separately presented	(20,884)		8,503		(46,311)		47,599
		Total (loss) gain on derivative contracts, net	(Loss) gain on derivative contracts, net	$	(51,175)	$	(20,679)	$	(84,438)	$	79,105		Total (loss) gain on derivative contracts, net	(Loss) gain on derivative contracts, net	$	(33,128)	$	(6,040)	$	(117,566)	$	73,065

Included in Accounts receivable under the subheading of Joint interest billings and other in the Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2021 and December 31, 2020 are ~~$0.03~~$0.01 million and $2.3 million, respectively, related to commodity hedge contracts settled as of that date for which the cash has not been received.

Note 4. Acquisitions

IRM Acquisition

As part of the execution of its growth strategy to further increase its scale, on January 7, 2021, the Company completed the acquisition (the “IRM Acquisition”) of all of the issued and outstanding limited liability company interests in Independence Resources Management, LLC (“IRM”) and certain wholly owned subsidiaries for consideration consisting of the following: (i) net cash of approximately ~~$134.3~~$140.4 million (the “Cash Consideration”) and (ii) 12,719,594 shares of the Company’s Class A common stock, $0.001 par value per share (“Class A Common Stock”). The fair value of each share of Class A Common Stock was determined using the closing price of $6.02 per share on January 7, 2021. The purchase agreement contains customary representations and warranties for transactions of this nature. The Company has obtained representation and warranty insurance to provide coverage in the event of certain breaches of representations and warranties of the seller contained in the purchase agreement, which will be subject to various exclusions, deductibles and other terms and conditions set forth therein.

Table of Contents

EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The IRM Acquisition has been accounted for as a business combination using the acquisition method of accounting, with Earthstone identified as the acquirer. The preliminary allocation of the total purchase price in the IRM Acquisition is based upon management’s estimates of and assumptions related to the fair value of assets acquired and liabilities assumed. Although the purchase price allocation is substantially complete as of the date of this filing, there may be further adjustments to the Company’s estimates of the acquired oil and ~~natural~~ gas ~~properties.~~properties resulting in changes to the purchase price allocation. These amounts will be finalized no later than one year from the acquisition date. The consideration transferred, fair value of assets acquired and liabilities assumed by Earthstone were recorded as follows (in thousands, except share amounts and stock price):

~~Table of Contents~~

~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~


Consideration:
Shares of Earthstone Class A Common Stock issued	12,719,594
Earthstone Class A Common Stock price as of January 7, 2021	$	6.02
Class A Common Stock consideration	76,572
Cash consideration (1)	~~137,302~~140,366

Total consideration transferred	$	~~213,874~~216,938

Fair value of assets acquired:
Cash	$	~~2,992~~4,763
Other current assets	~~10,925~~11,524
Oil and gas properties	~~226,148~~226,178
Other non-current assets	~~258~~252
Amount attributable to assets acquired	$	~~240,323~~242,717

Fair value of liabilities assumed:
Derivative liability ~~- current~~	$	10,177
Other current liabilities	~~5,985~~5,314
Asset retirement obligation - noncurrent	~~10,287~~10,288
Amount attributable to liabilities assumed	$	~~26,449~~25,779

Tracker/Sequel Acquisitions

On March 31, 2021, Earthstone, EEH, Tracker Resource Development III, LLC, a Delaware limited liability company (“Tracker”), and TRD III Royalty Holdings (TX), LP, a Delaware limited partnership (“RoyaltyCo” and collectively with Tracker, the “Seller”), entered into a purchase and sale agreement (the “Tracker Agreement”), which provided that EEH would acquire (the “Tracker Acquisition”) interests in oil and gas leases and related property of Tracker located in Irion County, Texas (the “Tracker Assets”). Also on March 31, 2021, Earthstone, EEH, SEG-TRD LLC, a Delaware limited liability company (“SEG-I”), and SEG-TRD II LLC, a Delaware limited liability company (“SEG-II” and collectively with SEG-I, “Sequel”) entered into a purchase and sale agreement (the “Sequel Agreement” and collectively with the Tracker Agreement, the “Tracker/Sequel Purchase Agreements”), which provided that EEH would acquire (the “Sequel Acquisition” and collectively with the Tracker Acquisition, the “Tracker/Sequel Acquisitions”) certain well-bore interests and related equipment (the “Sequel Assets”).

On July 20, 2021, Earthstone, EEH and the Seller consummated the transactions contemplated in the Tracker Agreement. At the closing of the Tracker Agreement, among other things, EEH acquired the Tracker Assets for aggregate consideration consisting of: (i) $22.5 million in cash, net of preliminary and customary purchase price adjustments that remains subject to final post-closing settlement between EEH and the Seller, and (ii) 4.7 million shares of Class A Common Stock. Also, on July 20, 2021, Earthstone, EEH and Sequel consummated the transactions contemplated in the Sequel Agreement. At the closing of the Sequel Agreement, among other things, EEH acquired the Sequel Assets for aggregate consideration consisting of: (i) $45.3 million in cash, net of preliminary and customary purchase price adjustments that remains subject to final post-closing settlement between EEH and the Seller, and (ii) 1.5 million shares of Class A Common Stock valued at $9.97 per share at the closing of the transaction. The Significant Shareholder, as described below, owned approximately 49% of Tracker as of the closing of the Tracker Acquisition. See Note 12. Related Party Transactions for further discussion.

Table of Contents

EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The Tracker/Sequel Acquisitions have been accounted for as asset acquisitions in accordance with ASC Topic 805, Business Combinations (referred to as “ASC 805”). The preliminary allocation of the total purchase price in the Tracker/Sequel Acquisitions is based upon management’s estimates of and assumptions related to the relative fair value of assets acquired and liabilities assumed. Although the purchase price allocation is substantially complete as of the date of this filing, there may be further adjustments to the Company’s oil and natural gas properties. These amounts will be finalized no later than one year from the acquisition date. The consideration transferred, fair value of assets acquired and liabilities assumed by Earthstone were recorded as follows (in thousands, except share amounts and stock price):


	Total
Consideration:
Shares of Earthstone Class A Common Stock issued	6,200,000
Earthstone Class A Common Stock price as of July 20, 2021	$	9.97
Class A Common Stock consideration	61,814
Cash consideration (1)	59,569
Direct transaction costs (2)	1,550
Total consideration transferred	$	122,933

Fair value of assets acquired:
Oil and gas properties	$	123,533
Amount attributable to assets acquired	$	123,533

Fair value of liabilities assumed:
Noncurrent liabilities - ARO	600
Amount attributable to liabilities assumed	$	600

(1)~~Net cash consideration of $134.3 million consists of $137.3 million gross cash remitted at closing less $3.0~~Includes customary purchase price adjustments.

(2)Represents $1.6 million of ~~cash acquired.~~transaction costs associated with the Tracker Acquisition and the Sequel Acquisition that have been capitalized in accordance with ASC 805-50.

The following unaudited supplemental pro forma condensed results of operations present consolidated information as though the IRM Acquisition and Tracker/Sequel Acquisitions had been completed as of January 1, 2020. The unaudited supplemental pro forma financial information was derived from the historical consolidated and combined statements of operations for IRM, Tracker, Sequel and Earthstone and adjusted to include depletion expense applied to the adjusted basis of the properties acquired. These unaudited supplemental pro forma results of operations are provided for illustrative purposes only and do not purport to be indicative of the actual results that would have been achieved by the combined company for the periods presented or that may be achieved by the combined company in the future. Future results may vary significantly from the results reflected in this unaudited pro forma financial information (in thousands, except per share amounts):

Three Months Ended Six Months Ended
June 30, June 30,
2020 2021 2020
Revenue $ 38,311 $ 166,939 $ 103,844
Loss before taxes (47,272) $ (28,823) 41,494
Net loss (46,083) $ (28,019) 41,178
Less: Net loss attributable to noncontrolling interest (20,853) $ (12,413) 18,556
Net loss attributable to Earthstone Energy, Inc. (25,230) $ (15,606) 22,622
Pro forma net (loss) income per common share attributable to Earthstone Energy, Inc.:
Basic and diluted $ (0.60) $ (0.34) $ 0.53


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
Revenue	$	115,331	$	79,345	$	316,932	$	215,504
Income (loss) before taxes	22,647		(2,656)		17,660		49,461
Net income (loss)	22,196		(2,840)		18,003		48,962
Less: Net income (loss) attributable to noncontrolling interest	9,921		(1,182)		7,782		20,372
Net income (loss) attributable to Earthstone Energy, Inc.	12,275		(1,658)		10,222		28,589
Pro forma net income (loss) per common share attributable to Earthstone Energy, Inc.:
Basic	$	0.25	$	(0.03)	$	0.23	$	0.59
Diluted	$	0.23	$	(0.03)	$	0.23	$	0.59

The Company has included in its Condensed Consolidated Statements of Operations, revenues of ~~$24.0~~$20.8 million and operating expenses of ~~$10.6~~$9.6 million for the three months ended ~~June~~September 30, 2021 and revenues of ~~$44.3~~$65.1 million and operating expenses of ~~$24.1~~$33.7 million for the period January 7, 2021 to ~~June~~September 30, 2021 related to the IRM Acquisition. During the three and ~~six months ended June 30, 2021, the Company recorded $0.5 million and $3.8 million, respectively, of legal and professional fees, and~~nine

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

months ended September 30, 2021, the Company recorded $0.1 million and $3.9 million, respectively, of legal and professional fees, and employee severance costs related to the IRM Acquisition which are included in Transaction costs in the Condensed Consolidated Statements of Operations.

Additionally, the Company has included in its Condensed Consolidated Statements of Operations, revenues of $16.6 million and operating expenses of $5.6 million for the period July 20, 2021 to September 30, 2021 related to the Tracker/Sequel Acquisitions.

The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair value of oil and gas properties and asset retirement obligations were measured using the discounted cash flow technique of valuation.

Significant inputs to the valuation of oil and gas properties include estimates of: (i) reserves, (ii) future operating and development costs, (iii) future commodity prices, (iv) future plugging and abandonment costs, (v) estimated future cash flows, and (vi) a market-based weighted average cost of capital rate. These inputs require significant judgments and estimates and are the most sensitive and subject to change.

Eagle Ford Acquisitions

In May and June 2021, the Company completed acquisitions of working interests in certain assets it operates located in southern Gonzales County, Texas (collectively, the “Eagle Ford Acquisitions”) from 4 separate sellers. The aggregate purchase price of the Eagle Ford Acquisitions was approximately $48.0 million. One of the 4 separate sellers was a related party. See Note 12. Related Party Transactions for further discussion. The Eagle Ford Acquisitions have been accounted for as asset acquisitions in accordance with ASC 805. The preliminary allocation of each purchase was based upon management’s estimates of and assumptions related to the relative fair value of assets acquired and liabilities assumed. Although the purchase price allocation is substantially complete as of the date of this filing, there may be further adjustments to the Company’s oil and natural gas properties. These amounts will be finalized no later than one year from the acquisition date.

~~Tracker/Sequel Acquisitions~~Foreland Acquisition

On ~~March 31,~~September 30, 2021, Earthstone and EEH, ~~Tracker Resource Development III,~~as buyer, and Foreland Investments LP, a Delaware limited partnership (“Foreland”), as seller, entered into a Purchase and Sale Agreement (the “Foreland Purchase Agreement”). Also, on September 30, 2021, Earthstone and EEH, as buyer, and BCC-Foreland LLC, a Delaware limited liability company (“~~Tracker”~~BCC”), ~~and TRD III Royalty Holdings (TX), LP, a Delaware limited partnership (“RoyaltyCo” and collectively with Tracker, the “Seller”),~~as seller, entered into a ~~purchase~~Purchase and ~~sale agreement~~Sale Agreement (the ~~“Tracker~~“BCC Purchase Agreement”)(collectively the “Foreland Acquisition”), ~~which provided that~~subject to customary purchase price adjustments with an effective date of July 1, 2021.

A $6.1 million deposit related to the Foreland Acquisition became payable on September 30, 2021. As such, $6.1 million was recorded in both Other noncurrent assets and Accrued expenses in the Condensed Consolidated Balance Sheet as of September 30, 2021.

On November 2, 2021, the Foreland Acquisition was consummated. Among other things, EEH ~~would acquire (the “Tracker Acquisition”)~~acquired interests in oil and gas leases and related property ~~of Tracker~~ located in Irion County and Crockett County, Texas, (the “Tracker Assets”). Also on March 31, 2021, Earthstone, EEH, SEG-TRD LLC, a Delaware limited liability company (“SEG-I”), and SEG-TRD II LLC, a Delaware limited liability company (“SEG-II” and collectively with SEG-I, “Sequel”) entered into a purchase and sale agreement (the “Sequel Agreement” and collectively with the Tracker Agreement, the “Tracker/Sequel Purchase Agreements”), which provided that EEH would acquire (the “Sequel Acquisition” and collectively with the Tracker Acquisition, the “Acquisitions”)including certain well-bore interests and related equipment (the “Sequel Assets”). In April 2021, the Company paid approximately $8.2 million in earnest money deposits in connection with the Acquisitions. These deposits are included in Other noncurrent assets in the Condensed Consolidated Balance Sheets asheld under a joint development agreement, for a collective purchase price of June 30, 2021 and the cash outflows for these deposits are included in Acquisition of oil and gas properties, net of cash acquired in the Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2021.

On July 20, 2021, Earthstone, EEH and the Seller consummated the transactions contemplated in the Tracker Agreement. At the closing of the Tracker Agreement, among other things, EEH acquired the Tracker Assets for aggregate consideration consisting of the following: (i) $22.5$49.2 million in cash, net of preliminary and customary purchase price adjustments and remains subject to final post-closing settlement between EEH and ~~the Seller,~~Foreland or BCC, as applicable, and (ii) 4.7 million shares of Class A Common Stock. Also, on July 20, 2021, Earthstone, EEH and Sequel consummated the transactions contemplated in the Sequel Agreement. At the closing of the Sequel Agreement, among other things, EEH acquired the Sequel Assets for aggregate consideration consisting of the following: (i) $45.3 million in cash, net of preliminary and customary purchase price adjustments and remains subject to final post-closing settlement between EEH and the Seller, and (ii) 1.5 million2,611,111 shares of Class A Common Stock valued at ~~$9.97~~$10.77 per share at the closing of the transaction. ~~The Significant Shareholder, as described below, owned approximately 49% of Tracker as of the closing of the transaction. See Note 12. Related Party Transactions for further discussion.~~

The Acquisitions will be accounted for as asset acquisitions in accordance with ASC Topic 805, Business Combinations (referred to as “ASC 805”). The fair value of the consideration paid by the Company and allocation of that amount to the underlying Tracker Assets and Sequel Assets acquired, on a relative fair value basis, will be recorded as of July 20, 2021. Additionally, costs directly related to the Acquisitions will be capitalized as a component of the purchase price. The operating results of Tracker and Sequel will be incorporated into the Company's interim Condensed Consolidated Financial Statements for the three months ended September 30, 2021.

Note 5. Oil and Natural Gas Properties

The Company follows the successful efforts method of accounting for its oil and natural gas properties. Under this method, costs to acquire oil and natural gas properties, drill and equip exploratory wells that find proved reserves, and drill and equip development wells are capitalized. Exploration costs, including unsuccessful exploratory wells and geological and geophysical costs, are charged to operations as incurred. Upon sale or retirement of oil and natural gas properties, the costs and related accumulated depreciation, depletion and amortization are eliminated from the accounts and the resulting gain or loss is recognized.

~~Table of Contents~~

~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~

Costs incurred to maintain wells and related equipment, lease and well operating costs, and other exploration costs are charged to expense as incurred. Gains and losses arising from the sale of properties are included in Income from operations in the Condensed Consolidated Statements of Operations.

The Company’s lease acquisition costs and development costs of proved oil and natural gas properties are amortized using the units-of-production method, at the field level, based on total proved reserves and proved developed reserves, respectively. For

Table of Contents

EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

the three and ~~six~~nine months ended ~~June~~September 30, 2021, depletion expense for oil and gas producing property and related equipment was ~~$25.9~~$26.9 million and ~~$50.1~~$77.0 million, respectively. For the three and ~~six~~nine months ended ~~June~~September 30, 2020, depletion expense for oil and gas producing property and related equipment was ~~$22.8~~$28.4 million and ~~$47.3~~$75.7 million, respectively.

Our accrual basis capital expenditures for the three and nine months ended September 30, 2021 were as follows (in thousands):


	Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021
Drilling and completions	$	42,179	$	74,346
Leasehold costs	1,990		2,444
Total capital expenditures	$	44,169	$	76,790

Proved Properties

Proved oil and natural gas properties are reviewed for impairment on a nonrecurring basis. The impairment charge reduces the carrying values to their estimated fair values. These fair value measurements are classified as Level 3 measurements and include many unobservable inputs. Fair value is calculated as the estimated discounted future net cash flows attributable to the assets. The Company’s primary assumptions in preparing the estimated discounted future net cash flows to be recovered from oil and gas properties are based on (i) proved reserves, (ii) forward commodity prices and assumptions as to costs and expenses, and (iii) the estimated discount rate that would be used by potential purchasers to determine the fair value of the assets.

Unproved Properties

Unproved properties consist of costs incurred to acquire undeveloped leases. Unproved oil and gas leases are generally for a primary term of three to five years. In most cases, the term of the unproved leases can be extended by paying a lease renewal fee, meeting contractual drilling obligations, or by the presence of producing wells on the leases. Unproved costs related to successful drilling on unproved leases are reclassified to proved properties.

The Company reviews its unproved properties periodically for impairment. In determining whether an unproved property is impaired, the Company considers numerous factors including, but not limited to, current exploration and development plans, favorable or unfavorable exploration activity on the property being evaluated and/or adjacent properties, the Company’s geologists' evaluation of the property, and the remaining months in the lease term for the property.

Impairments to Oil and Natural Gas Properties

~~NaN~~No impairments were recorded to the Company's oil and natural gas properties during the three ~~or six~~and nine months ended ~~June~~September 30, 2021.

During the three months ended ~~June~~September 30, 2020, the Company recorded non-cash impairment charges of ~~$0.1~~$2.1 million to its oil and natural gas properties due to acreage expirations. During the ~~six~~nine months ended ~~June~~September 30, 2020, as a result of the decline in crude oil price futures at the time, the Company recorded the following non-cash impairment charges:


(In thousands)	(In thousands)	Eagle Ford Trend		Midland Basin		Corporate		Total		(In thousands)	Eagle Ford Trend		Midland Basin		Corporate		Total
Proved properties	Proved properties	$	25,252	$	0	$	0	$	25,252	Proved properties	$	25,252	$	—	$	—	$	25,252
Unproved properties	Unproved properties	11,311		0		0		11,311		Unproved properties	11,311		—		—		11,311
Acreage expirations (1)	Acreage expirations (1)	431		5,819		0		6,250		Acreage expirations (1)	450		7,915		—		8,365
Goodwill	Goodwill	0		0		17,620		17,620		Goodwill	—		—		17,620		17,620
		$	36,994	$	5,819	$	17,620	$	60,433		$	37,013	$	7,915	$	17,620	$	62,548

(1)Impairments in unproved properties resulting from acreage deemed expired (not planned to be renewed).

Note 6. Noncontrolling Interest

Earthstone consolidates the financial results of EEH and its subsidiaries and records a noncontrolling interest for the economic interest in Earthstone held by the members of EEH other than Earthstone and Lynden US. Net income (loss) ~~income~~ attributable to noncontrolling interest in the Condensed Consolidated Statements of Operations for the three and ~~six~~nine months ended ~~June~~September 30, 2021 and 2020 represents the portion of net income (loss) ~~income~~ attributable to the economic interest in the Company held by the members of EEH other than Earthstone and Lynden US. Noncontrolling interest in the Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2021 and December 31, 2020 represents the portion of net assets of the Company attributable to the members of EEH other than Earthstone and Lynden US.

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The following table presents the changes in noncontrolling interest for the ~~six~~nine months ended ~~June~~September 30, 2021:


		EEH Units Held By Earthstone and Lynden US	%		EEH Units Held By Others	%		Total EEH Units Outstanding		EEH Units Held By Earthstone and Lynden US	%		EEH Units Held By Others	%		Total EEH Units Outstanding
As of December 31, 2020	As of December 31, 2020	30,343,421	46.4	%	35,009,371	53.6	%	65,352,792	As of December 31, 2020	30,343,421	46.4	%	35,009,371	53.6	%	65,352,792
EEH Units issued in connection with the IRM Acquisition	EEH Units issued in connection with the IRM Acquisition	12,719,594			0			12,719,594	EEH Units issued in connection with the IRM Acquisition	12,719,594			—			12,719,594
EEH Units issued in connection with the Tracker/Sequel Acquisitions									EEH Units issued in connection with the Tracker/Sequel Acquisitions	6,200,000			—			6,200,000
EEH Units and Class B Common Stock converted to Class A Common Stock	EEH Units and Class B Common Stock converted to Class A Common Stock	611,494			(611,494)			0	EEH Units and Class B Common Stock converted to Class A Common Stock	655,376			(655,376)			—
EEH Units issued in connection with the vesting of restricted stock units and performance-based units	EEH Units issued in connection with the vesting of restricted stock units and performance-based units	618,553			0			618,553	EEH Units issued in connection with the vesting of restricted stock units and performance-based units	773,666			—			773,666
As of June 30, 2021		44,293,062	56.3	%	34,397,877	43.7	%	78,690,939
As of September 30, 2021									As of September 30, 2021	50,692,057	59.6	%	34,353,995	40.4	%	85,046,052

Note 7. Net Income (Loss) ~~Income~~ Per Common Share

Net income (loss) ~~income~~ per common share—basic is calculated by dividing Net income (loss) ~~income~~ by the weighted average number of shares of common stock outstanding during the period. Net income (loss) ~~income~~ per common share—diluted assumes the conversion of all potentially dilutive securities and is calculated by dividing Net income (loss) ~~income~~ by the sum of the weighted average number of shares of common stock, as defined above, outstanding plus potentially dilutive securities. Net income (loss) ~~income~~ per common share—diluted considers the impact of potentially dilutive securities except in periods in which there is a loss because the inclusion of the potential common shares, as defined above, would have an anti-dilutive effect.

A reconciliation of Net income (loss) ~~income~~ per common share is as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
(In thousands, except per share amounts)	(In thousands, except per share amounts)	2021		2020		2021		2020		(In thousands, except per share amounts)	2021		2020		2021		2020
Net (loss) income attributable to Earthstone Energy, Inc.		$	(8,871)	$	(16,339)	$	(14,704)	$	369
Net income (loss) attributable to Earthstone Energy, Inc.										Net income (loss) attributable to Earthstone Energy, Inc.	$	10,418	$	(5,445)	$	(4,286)	$	(5,076)

Net (loss) income per common share attributable to Earthstone Energy, Inc.:
Net income (loss) per common share attributable to Earthstone Energy, Inc.:										Net income (loss) per common share attributable to Earthstone Energy, Inc.:
Basic	Basic	$	(0.20)	$	(0.55)	$	(0.34)	$	0.01	Basic	$	0.21	$	(0.18)	$	(0.09)	$	(0.17)
Diluted	Diluted	$	(0.20)	$	(0.55)	$	(0.34)	$	0.01	Diluted	$	0.20	$	(0.18)	$	(0.09)	$	(0.17)

Weighted average common shares outstanding	Weighted average common shares outstanding									Weighted average common shares outstanding
Basic	Basic	44,127,718		29,858,162		43,457,043		29,677,795		Basic	49,243,185		30,073,635		45,406,952		29,810,705
Add potentially dilutive securities:	Add potentially dilutive securities:									Add potentially dilutive securities:
Unvested restricted stock units (1)	Unvested restricted stock units (1)	0		0		0		0		Unvested restricted stock units (1)	525,475		—		—		—
Unvested performance units (1)	Unvested performance units (1)	0		0		0		0		Unvested performance units (1)	2,894,282		—		—		—
Diluted weighted average common shares outstanding	Diluted weighted average common shares outstanding	44,127,718		29,858,162		43,457,043		29,677,795		Diluted weighted average common shares outstanding	52,662,942		30,073,635		45,406,952		29,810,705

(1)For the three ~~and six~~ months ended ~~June~~September 30, 2021, the ~~Company had~~1,099,800 performance units granted on January 27, 2021 were excluded due to an assumed settlement in cash and the liability treatment described in Note 9. Stock-Based Compensation. For the nine months ended September 30, 2021, there was no dilutive effect related to unvested restricted stock units or performance units due to the loss for the period. For the three and ~~six~~nine months ended ~~June~~September 30, 2020, ~~the Company had~~there was no dilutive effect related to unvested restricted stock units or performance units ~~as, under~~due to the ~~treasury stock method, the proceeds from the average unrecognized expense~~loss for the ~~period were in excess of the weighted average outstanding fair value for the unvested shares for the same~~ period.

The Class B common stock, $0.001 par value per share of Earthstone (the “Class B Common Stock”), has been excluded, as its conversion would eliminate noncontrolling interest and net ~~loss~~income attributable to noncontrolling interest of ~~$7.0~~$8.4 million for the three months ended ~~June~~September 30, 2021 and net loss attributable to noncontrolling interest of ~~$11.7~~$3.3 million for the ~~six~~nine months ended June 30, 2021 would be added back to Net (loss) income attributable to Earthstone Energy, Inc. for the periods then ended, having 0 dilutive effect on Net (loss) income per common share attributable to Earthstone Energy, Inc.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

ended September 30, 2021 would be added back to Net income (loss) attributable to Earthstone Energy, Inc. for the periods then ended, having no dilutive effect on Net income (loss) per common share attributable to Earthstone Energy, Inc.

The Class B Common Stock has been excluded, as its conversion would eliminate noncontrolling interest and net loss attributable to noncontrolling interest of ~~$19.6~~$6.4 million for the three months ended ~~June~~September 30, 2020 and net income attributable to noncontrolling interest of ~~$0.4~~$6.0 million for the ~~six~~nine months ended ~~June~~September 30, 2020 would be added back to Net (loss) income attributable to Earthstone Energy, Inc. for the periods then ended, having 0no dilutive effect on Net (loss) income per common share attributable to Earthstone Energy, Inc.

Note 8. Common Stock

Class A Common Stock

At ~~June~~September 30, 2021 and December 31, 2020, there were ~~44,293,062~~50,692,057 and 30,343,421 shares of Class A Common Stock issued and outstanding, respectively. In connection with the IRM Acquisition, on January 7, 2021, Earthstone issued 12,719,594 shares of Class A Common Stock valued at ~~approximated~~approximately $76.6 million on that date. ~~On March 18,~~Additionally, in connection with the Tracker/Sequel Acquisitions, on July 20, 2021, Earthstone issued 6,200,000 shares of Class A Common Stock valued at approximately $61.8 million on that date.

During the three and nine months ended September 30, 2021, as a result of the vesting and settlement of performance units and restricted stock units under the Earthstone Energy, Inc. Amended and Restated 2014 Long-Term Incentive Plan, as amended (the “2014 Plan”), Earthstone ~~issued 455,000 shares of Class A Common Stock, of which 178,453 shares of Class A Common Stock were retained as treasury stock~~220,219 and canceled to satisfy the related employee income tax liability. During the three and six months ended June 30, 2021, as a result of the vesting and settlement of restricted stock units and performance units under the 2014 Plan, Earthstone issued 221,401 and 487,6601,162,879 shares, respectively, of Class A Common Stock, of which ~~66,343~~65,106 and ~~145,654~~389,213 shares, respectively, of Class A Common Stock were retained as treasury stock and canceled to satisfy the related employee income tax liability. For further discussion, see Note 9. Stock-Based Compensation.

During the three and ~~six~~nine months ended ~~June~~September 30, 2020, as a result of the vesting and settlement of restricted stock units under the 2014 Plan, Earthstone issued ~~223,209~~195,344 and ~~530,738~~726,082 shares, respectively, of Class A Common Stock, of which ~~57,810~~54,268 and ~~133,505~~187,773 shares, respectively, of Class A Common Stock were retained as treasury stock and canceled to satisfy the related employee income tax liability. Additionally, as discussed below, shares of Class A Common Stock were issued as the result of conversions of Class B Common Stock.

Class B Common Stock

At ~~June~~September 30, 2021 and December 31, 2020, there were ~~34,397,877~~34,353,995 and 35,009,371 shares of Class B Common Stock issued and outstanding, respectively. Each share of Class B Common Stock, together with 1 EEH Unit, is convertible into 1 share of Class A Common Stock. During the three and ~~six~~nine months ended ~~June~~September 30, 2021, ~~33,463~~43,882 and ~~611,494~~655,376 shares, respectively, of Class B Common Stock and EEH Units were exchanged for an equal number of shares of Class A Common Stock. During the three and ~~six~~nine months ended ~~June~~September 30, 2020, ~~2,000~~49,316 and ~~201,993~~251,309 shares, respectively, of Class B Common Stock and EEH Units were exchanged for an equal number of shares of Class A Common Stock.

Note 9. Stock-Based Compensation

Restricted Stock Units

The 2014 Plan, allows, among other things, for the grant of restricted stock units (“RSUs”). As of ~~June~~September 30, 2021, the maximum number of shares of Class A Common Stock that may be issued under the 2014 Plan was 9.4 million shares. On July 20,2021, at Earthstone’s annual meeting of stockholders, Earthstone’s stockholders approved and adopted an amendment to the 2014 Plan which increased the maximum number of shares of Class A Common Stock that may be issued under the 2014 Plan to 12.0 million shares.

Each RSU represents the contingent right to receive 1 share of Class A Common Stock. The holders of outstanding RSUs do not receive dividends or have voting rights prior to vesting and settlement. The Company determines the fair value of granted RSUs based on the market price of the Class A Common Stock on the date of the grant. Compensation expense for granted RSUs is recognized on a straight-line basis over the vesting and is net of forfeitures, as incurred. Stock-based compensation is included in General and administrative expense in the Condensed Consolidated Statements of Operations and is recorded with a corresponding increase in Additional paid-in capital within the Condensed Consolidated Balance Sheets.

~~The table below summarizes RSU award activity for the six months ended June 30, 2021:~~

Shares Weighted-Average Grant Date Fair Value
Unvested RSUs at December 31, 2020 1,050,908 $ 5.55
Granted 548,100 $ 5.34
Vested (487,660) $ 5.81
Unvested RSUs at June 30, 2021 1,111,348 $ 5.34

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The table below summarizes RSU award activity for the nine months ended September 30, 2021:


	Shares	Weighted-Average Grant Date Fair Value
Unvested RSUs at December 31, 2020	1,050,908	$	5.55
Granted	553,100	$	5.38
Forfeited	(15,333)	$	5.13
Vested	(707,879)	$	5.75
Unvested RSUs at September 30, 2021	880,796	$	5.30

As of ~~June~~September 30, 2021, there was ~~$5.9~~$4.6 million of unrecognized compensation expense related to the RSU awards which will be recognized over a weighted average period of ~~0.92~~0.87 years.

For the three and ~~six~~nine months ended ~~June~~September 30, 2021, Stock-based compensation related to RSUs was $1.2 million and ~~$2.7~~$3.9 million, respectively. For the three and ~~six~~nine months ended ~~June~~September 30, 2020, Stock-based compensation related to RSUs was ~~$1.3~~$1.2 million and ~~$3.0~~$4.2 million, respectively.

Performance Units

The table below summarizes ~~performance unit (“PSU”)~~PSU activity for the ~~six~~nine months ended ~~June~~September 30, 2021:


		Shares	Weighted-Average Grant Date Fair Value			Shares	Weighted-Average Grant Date Fair Value
Unvested PSUs at December 31, 2020	Unvested PSUs at December 31, 2020	1,879,425	$	7.65	Unvested PSUs at December 31, 2020	1,879,425	$	7.65
Granted	Granted	1,099,800	$	10.85	Granted	1,099,800	$	10.85

Vested	Vested	(227,500)	$	13.75	Vested	(227,500)	$	13.75
Unvested PSUs at June 30, 2021		2,751,725	$	8.42
Unvested PSUs at September 30, 2021					Unvested PSUs at September 30, 2021	2,751,725	$	8.42

On January 27, 2021, the Board of Directors of Earthstone (the “Board”) granted 1,099,800 PSUs (the “2021 PSUs”) to certain officers pursuant to the 2014 Plan (the “2021 Grant”). The 2021 PSUs are payable in cash ~~based~~or shares of Class A Common Stock upon the achievement by the Company over a period commencing on January 1, 2021 and ending on December 31, 2023 (the “Performance Period”) of certain performance criteria established by the Board. The Company classifies these awards that will be settled in cash as liability awards. All previous PSU grants will be settled in shares and are classified as equity awards.

The 2021 PSUs are eligible to be earned based on the annualized Total Shareholder Return (“TSR”) of the Class A Common Stock during a three-year period beginning on February 1, 2021. Between 0x to 2.0x of the Performance Units are eligible to be earned based on Earthstone achieving an annualized TSR based on the following pre-established goals:


Earthstone’s Annualized TSR						TSR Multiplier
20.5% or greater						2
14.5%						1
7.7%						0.5
Less than 7.7%						0

The Company accounts for these awards as market-based awards which are valued quarterly utilizing the Monte Carlo Simulation pricing model, which calculates multiple potential outcomes for an award and establishes grant date fair value based on the most likely outcome. For the 2021 PSUs, assuming a risk-free rate of 0.3% and volatility of 86.0%, the Company calculated the weighted average grant date fair value per PSU to be $10.85. Based on the fair value of the 2021 PSUs, the Company recorded stock-based compensation expense of ~~$2.3~~$0.7 million and ~~$3.0~~$3.7 million during the three and ~~six~~nine months ended ~~June~~September 30, 2021, respectively. A corresponding liability of ~~$3.0~~$3.7 million related to the 2021 PSUs is included in Other noncurrent liabilities in the Condensed Consolidated Balance Sheet as of ~~June~~September 30, 2021.

On February 28, 2018, the Board granted 252,500 PSUs to certain named executive officers pursuant to the 2014 Plan. The PSUs were payable in shares of Class A Common Stock based upon the achievement by the Company over a period commencing on February 28, 2018 and ending on February 28, 2021 of performance criteria established by the Board. On March 18, 2021, the Company settled the remaining 227,500 PSUs, net of forfeitures, based on the achievement of the 200% target, resulting in the issuance of 455,000 shares of Class A Common Stock.

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

As of ~~June~~September 30, 2021, there was ~~$21.4~~$15.3 million of unrecognized compensation expense related to all PSU awards which will be amortized over a weighted average period of ~~1.18~~1.05 years.

For the three and ~~six~~nine months ended ~~June~~September 30, 2021, Stock-based compensation related to all PSUs was approximately ~~$3.2~~$1.7 million and ~~$5.0~~$6.7 million, respectively. For the three and ~~six~~nine months ended ~~June~~September 30, 2020, Stock-based compensation related to all PSUs was approximately ~~$1.3~~$1.2 million and ~~$2.3~~$3.5 million, respectively.

Note 10. Long-Term Debt

Credit Facility

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~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~

On November 21, 2019, Earthstone, EEH (the “Borrower”), Wells Fargo Bank, National Association, as Administrative Agent and Issuing Bank (“Wells Fargo”), Royal Bank of Canada, as Syndication Agent, BOKF, NA dba Bank of Texas (“BOKF”) as Issuing Bank with respect to Existing Letters of Credit, SunTrust Bank, as Documentation Agent, and the lenders party thereto (the “Lenders”) entered into a credit agreement (the “Credit Facility”), which replaced the prior credit facility, which was terminated on November 21, 2019.

On December 17, 2020, Earthstone, EEH, as Borrower, Wells Fargo, as Administrative Agent, the guarantors party thereto, and the lenders party thereto (the “Lenders”) entered into an amendment (the “Second Amendment”) to the credit agreement dated November 21, 2019, by and among EEH, as Borrower, Earthstone, as Parent, Wells Fargo, as Administrative Agent and Issuing Bank, BOKF, NA dba Bank of Texas, as Issuing Bank with respect to Existing Letters of Credit, Royal Bank of Canada, as Syndication Agent, Truist Bank, as successor by merger to SunTrust Bank, as Documentation Agent, and the Lenders party thereto (collectively, the “Parties”) to the Credit Agreement. The Second Amendment was effective upon the closing of the IRM Acquisition described in Note 4. Acquisitions. Among other things, the Second Amendment (i) joined certain financial institutions as additional lenders, increased the borrowing base from $240.0 million to $360.0 million, (ii) increased the interest rate on outstanding borrowings; and (iii) adjusted some of the financial covenants.

On April 20, 2021, the Parties entered into an amendment (the “Third Amendment”) to the Credit Agreement under which the borrowing base increased from $360 million to $475 million in connection with its regularly scheduled redetermination. Further, the Third Amendment provided for an increase in the borrowing base from $475 million to $550 million which became effective on July 20, 2021 upon closing of the Tracker/Sequel Purchase Agreements described in Note 4. Acquisitions.

On September 17, 2021, Earthstone, EEH, as Borrower, Wells Fargo as Administrative Agent and Issuing Bank, the lenders party thereto (the “Lenders”) and the guarantors party thereto entered into an amendment (the “Fourth Amendment”) to the Credit Agreement. Among other things, the Fourth Amendment increased the borrowing base from $550 million to $650 million in connection with its regularly scheduled semi-annual redetermination, added provisions to provide for the eventual replacement of LIBOR as a benchmark interest rate, made certain changes to the lenders under the Credit Agreement, and made certain other administrative changes to the Credit Agreement.

The next regularly scheduled redetermination of the borrowing base is expected to occur on or around ~~October~~May 1, ~~2021.~~2022. Subsequent redeterminations are expected to occur on or about each ~~May~~November 1st and ~~November~~May 1st thereafter. The amounts borrowed under the Credit Facility bear annual interest rates at either (a) the adjusted LIBO Rate (as customarily defined) (the “Adjusted LIBO Rate”) plus 2.50% to 3.75% or (b) the sum of (i) the greatest of (A) the prime rate of Wells Fargo, (B) the federal funds rate plus ½ of 1.0%, and (C) the Adjusted LIBO Rate for an interest rate period of one month plus 1.0%, (ii) plus 1.50% to 2.75%, depending on the amount borrowed under the Credit Facility. Principal amounts outstanding under the Credit Facility are due and payable in full at maturity on November 21, 2024. All of the obligations under the Credit Facility, and the guarantees of those obligations, are secured by substantially all of EEH’s assets. Additional payments due under the Credit Facility include paying a commitment fee of 0.375% to 0.50% per year, depending on the amount borrowed under the Credit Facility, to the Lenders in respect of the unutilized commitments thereunder. EEH is also required to pay customary letter of credit fees.

Effective May 2020, the Company entered into certain interest rate swaps, exchanging the LIBO Rate for a fixed rate of 0.286% (the “Swap”). The initial notional amount of the Swap is $125 million through May 2022 and decreases to $100 million through May 2023 and $75 million through May 2024.

The Credit Facility contains a number of covenants that, among other things, restrict, subject to certain exceptions, EEH’s ability to incur additional indebtedness, create liens on assets, make investments, pay dividends and distributions or repurchase its limited liability interests, engage in mergers or consolidations, sell certain assets, sell or discount any notes receivable or accounts receivable and engage in certain transactions with affiliates.

In addition, the Credit Facility requires EEH to maintain the following financial covenants: a current ratio, as(as such term is defined in the Credit Agreement) of not less than 1.0 to 1.0 and a consolidated leverage ratio of not greater than 3.5 to 1.0. Consolidated leverage ratio means the ratio of (i) the aggregate debt of EEH and its consolidated subsidiaries as at the last day

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

of the fiscal quarter to (ii) EBITDAX for the applicable period, which was calculated as EBITDAX for the four consecutive fiscal quarters ending on such date. The term “EBITDAX” means, for any period, the sum of consolidated net income (loss) for such period plus (a) the following expenses or charges to the extent deducted from consolidated net income (loss) in such period: (i) interest, (ii) taxes, (iii) depreciation, (iv) depletion, (v) amortization, (vi) certain distributions to employees related to the stock compensation, (vii) certain transaction related expenses, (viii) reimbursed indemnification expenses related to certain dispositions and investments, (ix) non-cash extraordinary, usual, or nonrecurring expenses or losses, (x) other non-cash charges and minus (b) to the extent included in consolidated net income (loss) in such period: (i) non-cash income, (ii) gains on asset dispositions, disposals and abandonments outside of the ordinary course of business and (iii) to the extent not otherwise deducted from consolidated net income (loss), the aggregate amount of any pass-through cash distributions received by Borrower during such period in an amount equal to the aggregate amount of pass-through cash distributions actually made by Borrower during such period.

The Credit Facility contains customary affirmative covenants and defines events of default to include failure to pay principal or interest, breach of covenants, breach of representations and warranties, insolvency, judgment default and a change in control. Upon the occurrence and continuance of an event of default, the Lenders have the right to accelerate repayment of the loans and exercise their remedies with respect to the collateral. As of ~~June~~September 30, 2021, EEH was in compliance with the covenants under the Credit Facility.

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~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~

For the ~~six~~nine months ended ~~June~~September 30, 2021, under the Credit Facility, the Company had borrowings of ~~$360.1~~$503.7 million and ~~$233.7~~$340.5 million in repayments of borrowings.

For the three and ~~six~~nine months ended ~~June~~September 30, 2021, interest on borrowings under the Credit Facility averaged ~~3.33%~~3.66% and ~~3.36%~~3.47% per annum, respectively, which excluded commitment fees of $0.2 million and ~~$0.4~~$0.6 million, respectively, and amortization of deferred financing costs of $0.2 million and ~~$0.3~~$0.6 million, respectively. For the three and ~~six~~nine months ended ~~June~~September 30, 2020, interest on borrowings under the Credit Facility averaged ~~2.55%~~2.48% and ~~3.07%~~2.89% per annum, respectively, which excluded commitment fees of ~~$0.1~~$0.2 million and ~~$0.3~~$0.5 million, respectively, and amortization of deferred financing costs of $0.1 million and $0.2 million, respectively.

The Company’s policy is to capitalize the financing costs associated with its debt and amortize those costs on a straight-line basis over the term of the associated debt. These capitalized costs are included in Other noncurrent assets in the Condensed Consolidated Balance Sheets. During the three and ~~six~~nine months ended ~~June~~September 30, 2021, the Company capitalized ~~$0.8~~$1.0 million and ~~$1.8~~$2.8 million, respectively, of costs associated with the Credit Facility. ~~NaN~~No costs associated with the Credit Facility were capitalized during the three and ~~six~~nine months ended ~~June~~September 30, 2020.

Note 11. Asset Retirement Obligations

The Company has asset retirement obligations associated with the future plugging and abandonment of oil and gas properties and related facilities. Revisions to the liability typically occur due to changes in the estimated abandonment costs, well economic lives, and the discount rate.

The following table summarizes the Company’s asset retirement obligation transactions recorded during the ~~six~~nine months ended ~~June~~September 30, (in thousands):

2021

Beginning asset retirement obligations

3,027

Liabilities incurred

57103

Liabilities settled

~~(53)~~(103)

Acquisitions

~~10,866~~11,466

Accretion expense

~~593~~916

Divestitures

~~(37)~~(41)

Revision of estimates

~~104~~140

Ending asset retirement obligations

~~14,557~~15,508

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Note 12. Related Party Transactions

FASB ASC Topic 850, Related Party Disclosures, requires that information about transactions with related parties that would make a difference in decision making shall be disclosed so that users of the financial statements can evaluate their significance. The Audit Committee of the Board of Directors of Earthstone independently reviews and approves all related party transactions.

~~Earthstone's~~Earthstone has two significant ~~shareholder consists~~shareholders that consist of various investment funds managed by aeach of the two private equity ~~firm~~firms who may manage other investments in entities with which the Company interacts in the normal course of ~~business (the “Significant Shareholder”).~~business. On February 12, 2020, the Company sold certain of its interests in oil and natural gas leases and wells in an arm’s length transaction to a portfolio company of one of the ~~Significant Shareholder~~aforementioned shareholder (not under common control) (the “Significant Shareholder”) for cash consideration of approximately $0.4 million.

In connection with the Olenik v. Lodzinski et al. lawsuit described below in Note 13. Commitments and Contingencies, the Significant Shareholder was also named in the lawsuit. As a result of a settlement agreement relating to the ~~Settlement Agreement (defined below),~~lawsuit, the Company ~~has concluded negotiations~~agreed with its insurance carrier regarding an allocation of defense costs and settlement contributions above its deductible for all the parties named in the lawsuit. In connection with the Court approved ~~Settlement,~~settlement, the Significant Shareholder was billed approximately $1.1 millionin fiscal 2020 and ~~this amount has~~all amounts have been ~~reimbursed as of June 30, 2021.~~received.

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~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~

As discussed in Note 4. Acquisitions, on March 31, 2021, the Company entered into the Tracker/Sequel Purchase Agreements. The ~~transactions contemplated by the~~ Tracker/Sequel ~~Purchase Agreements,~~Acquisitions were consummated on July 20, 2021, whereby the Company acquired the Tracker Assets for a purchase price of $22.5 million in cash and 4.7 million shares of ~~the Company’s~~Earthstone’s Class A Common Stock. The Significant Shareholder owned approximately 49% of Tracker as of the closing of the Tracker Acquisition. A majority of the non-affiliated stockholders of Earthstone approved the issuance of 6.2 million shares of Class A Common Stock in connection with the closing of the Tracker/Sequel Purchase Agreements at Earthstone’s Annual Meeting of Stockholders held on July 20, 2021.

As discussed in Note 4. Acquisitions, during the second quarter of 2021, the Company completed the Eagle Ford ~~Acquisitions. The aggregate~~Acquisitions for a purchase price of ~~the Eagle Ford Acquisitions was~~ approximately $48.0 million in cash. The Significant Shareholder controlled one of the 4 sellers. After participating in a competitive sales process, the Company acquired the aforementioned assets for $8.2 million in cash from that related party entity.

Note 13. Commitments and Contingencies

Legal

From time to time, Earthstone and its subsidiaries may be involved in various legal proceedings and claims in the ordinary course of business.

Olenik v. Lodzinski et al.: On June 2, 2017, ~~Nicholas Olenik filed~~ a purported shareholder class and derivative action in the Delaware Court of Chancery was filed against Earthstone’s Chief Executive Officer, along with other members of the Board, EnCap Investments L.P. (“EnCap”), Bold Energy Holdings, LLC (“Bold ~~Holdings~~Holdings”), and Bold Energy III LLC (“Bold”) and Oak Valley Resources, LLC. The complaint alleged that Earthstone’s directors breached their fiduciary duties in connection with the contribution agreement dated as of November 7, 2016 and as amended on March 21, 2017 (the “Bold Contribution Agreement”), by and among Earthstone, EEH, Lynden US, Lynden USA Operating, LLC, Bold Holdings and Bold. The Plaintiff asserted that the directors negotiated the business combination pursuant to the Bold Contribution Agreement (the “Bold Transaction”) to ~~benefit EnCap and its affiliates, failed to obtain adequate consideration for~~the detriment of the Earthstone ~~shareholders~~stockholders who were not affiliated with EnCap or Earthstone management, did not follow an adequate process in negotiating and approving the Bold Transaction and made materially misleading or incomplete proxy disclosures in connection with the Bold Transaction. The suit sought unspecified damages and purported to assert claims derivatively on behalf of Earthstone and as a class action on behalf of all persons who held common stock up to March 13, 2017, excluding defendants and their affiliates. On July 20, 2018, the Delaware Court of Chancery granted the defendants’ motion to dismiss and entered an order dismissing the action in its entirety with prejudice. The Plaintiff filed an appeal with the Delaware Supreme Court. On April 5, 2019, the Delaware Supreme Court affirmed the Delaware Court of Chancery’s dismissal of the proxy disclosure claims but reversed the Delaware Court of Chancery’s dismissal of the other claims, holding that the allegations with respect to those claims were sufficient for pleading purposes. After engaging in extensive pre-trial discovery, the parties ~~engaged in a mediation process that resulted in a non-binding settlement term sheet on September 21, 2020. The term sheet was translated~~entered into a ~~Stipulation and Agreement of Compromise, Settlement and Release Agreement (the “Settlement Agreement”) between the parties and~~settlement agreement that was ~~filed with~~approved by the Delaware Court of Chancery ~~for approval.~~on March 31, 2021. The principal terms of the ~~Settlement Agreement are as follows:~~settlement agreement are: (i) a $3.5 million all-in cash settlement payment (the “Fund”) to be funded by defendants and/or their insurers into an escrow account, (ii) a bi-lateral complete and full release of all claims against defendants and plaintiffs, and (iii) ~~that~~ 55% of the Fund (the derivative payment) be paid to Earthstone to be used as determined by management, ~~according to their fiduciary duties and business judgment,~~ 45% of the Fund (the class payment) be paid to members of the class or current stockholders of Earthstone. ~~On March 31, 2021, the Court approved the Settlement Agreement and the Company~~Earthstone paid the $3.5 million settlement ~~shortly thereafter. The~~in April 2021 and the insurance carriers ~~immediately~~ reimbursed their agreed upon allocation of the settlement totaling $2.8 ~~million and in~~million. In addition, ~~the Company~~Earthstone has received $1.3 million from the derivative portion of the settlement, which iswas included as a reduction of Transaction costs in the Condensed Consolidated Statement of Operations for the ~~six~~nine months ended ~~June~~September 30, 2021.

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EARTHSTONE ENERGY, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Environmental and Regulatory

As of ~~June~~September 30, 2021, there were no known environmental or other regulatory matters related to the Company’s operations that are reasonably expected to result in a material liability to the Company.

Note 14. Income Taxes

The Company’s corporate structure requires the filing of two separate consolidated U.S. Federal income tax returns and one Canadian income tax return which include Lynden US, Earthstone, and Lynden Corp. As such, taxable income of Earthstone cannot be offset by tax attributes, including net operating losses, of Lynden US, nor can taxable income of Lynden US be offset by tax attributes of Earthstone. Earthstone and Lynden US record a tax provision, respectively, for their share of the book income or loss of EEH, net of the non-controlling interest. As EEH is treated as a partnership for U.S. Federal income tax purposes, it is not subject to income tax at the federal level and only recognizes the Texas Margin Tax.

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~~EARTHSTONE ENERGY, INC.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)~~

As of ~~June~~September 30, 2021 and December 31, 2020, a current liability of ~~$0.5~~$0.6 million and $0.6 million, respectively, is included in Other current liabilities in the Condensed Consolidated Balance Sheets. The amounts represent current Texas Margin Tax payable.

During the ~~six~~nine months ended ~~June~~September 30, 2021, the Company recorded income tax benefit of approximately ~~$0.8~~$0.3 million which included (1) a deferred income tax benefit for Lynden US of ~~$0.4~~$0.1 million as a result of its share of the distributable loss from EEH, (2) no net income tax benefit for Earthstone as the ~~$2.6~~$0.8 million income tax benefit resulting from its share of the distributable loss from EEH had a full valuation allowance recorded against it as future realization of the net deferred tax asset cannot be assured and (3) deferred income tax benefit of $0.8 million related to the Texas Margin Tax, offset by (4) current income tax expense of ~~$0.4~~$0.6 million related to the Texas Margin Tax. Lynden Corp incurred no material income or loss, or related income tax expense or benefit, for the ~~six~~nine months ended ~~June~~September 30, 2021.

During the ~~six~~nine months ended ~~June~~September 30, 2020, the Company recorded income tax ~~benefit~~expense of approximately ~~$0.02~~$0.1 million which included (1) no income tax ~~benefit~~expense for Lynden US ~~of $0.1 million~~ as a result of its share of the distributable income from EEH, (2) a deferred income tax ~~expense~~benefit for Earthstone of ~~$0.06~~$0.8 million as a result of its share of the distributable income from EEH, which was used to reduce the valuation allowance recorded against its deferred tax asset which was previously recorded as future realization of the net deferred tax asset cannot be assured and (3) deferred income tax ~~benefit~~expense of ~~$0.01~~$0.1 million related to the Texas Margin Tax. Lynden Corp incurred no material income or loss, or related income tax expense or benefit, for the ~~six~~nine months ended ~~June~~September 30, 2020.

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

Statement Regarding Forward-Looking Information

This discussion and other items in this Quarterly Report on Form 10-Q contain forward-looking statements and information that are based on management’s beliefs, as well as assumptions made by, and information currently available to, management. When used in this document, the words “believe,” “anticipate,” “estimate,” “expect,” “intend,” “may,” “will,” “project,” “forecast,” “plan,” and similar expressions are intended to identify forward-looking statements. Although management believes that the expectations reflected in these forward-looking statements are reasonable, it can give no assurance that these expectations will prove to have been correct. These statements are subject to numerous risks, uncertainties and assumptions. Certain of these risks are summarized under “Item 1A. Risk Factors” in our 2020 Annual Report on Form 10-K filed with the Securities and Exchange Commission (“SEC”), which you should read carefully in connection with our forward-looking statements. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those anticipated. We undertake no obligation to release publicly any revisions to these forward-looking statements that may be made to reflect events or circumstances after the date hereof or to reflect the occurrence of unanticipated events.

You should read “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in conjunction with the corresponding sections and our audited consolidated financial statements for the year ended December 31, 2020, which are included in our 2020 Annual Report on Form 10-K.

Overview

Earthstone Energy, Inc., a Delaware corporation (“Earthstone” and together with our consolidated subsidiaries, the “Company,” “our,” “we,” “us,” or similar terms), is a growth-oriented independent oil and gas company engaged in the acquisition and development of oil and gas reserves through activities that include the acquisition, drilling and development of undeveloped leases, asset and corporate acquisitions and mergers. Our operations are all in the upstream segment of the oil and natural gas industry and all our properties are onshore in the United States. At present, our assets are located in the Midland Basin of west Texas and the Eagle Ford Trend of south Texas.

Our primary focus is concentrated in the Midland Basin of west Texas, a high oil and liquids rich resource basin which provides us with multiple horizontal targets with proven production results, long-lived reserves and historically high drilling success rates.

Recent Developments

~~IRM~~Foreland Acquisition

On ~~January 7,~~September 30, 2021, Earthstone Energy, Inc. (“Earthstone”), Earthstone Energy Holdings, LLC, a subsidiary of Earthstone (“EEH”), as buyer, and ~~collectively~~Foreland Investments LP, a Delaware limited partnership (“Foreland”), as seller, entered into a Purchase and Sale Agreement (the “Foreland Purchase Agreement”). Also, on September 30, 2021, Earthstone and EEH, as buyer, and BCC-Foreland LLC, a Delaware limited liability company (“BCC”), as seller, entered into a Purchase and Sale Agreement (the “BCC Purchase Agreement”).

On November 2, 2021, Earthstone, EEH and Foreland consummated the transactions contemplated by the Foreland Purchase Agreement, whereby EEH acquired (the “Foreland Acquisition”) interests in oil and gas leases and related property of Foreland located in Irion County and Crockett County, Texas, for a purchase price (the “Foreland Purchase Price”) of: (i) $23.5 million in cash, net of preliminary and customary purchase price adjustments that remains subject to final post-closing settlement between EEH and Foreland, and (ii) 2,611,111 shares (the “Foreland Shares”) of Class A common stock of Earthstone (the “Class A Common Stock”) valued at $10.77 per share at the closing of the transaction. The cash portion of the Foreland Purchase Price is subject to customary purchase price adjustments with an effective date of July 1, 2021.

On November 2, 2021, Earthstone, EEH and BCC consummated the transactions contemplated by the BCC Purchase Agreement, whereby EEH acquired (the “BCC Acquisition” and with the Foreland Acquisition, the “Foreland-BCC Acquisition”) certain well-bore interests and related equipment held by BCC that are part of a joint development agreement between Foreland, Foreland Operating, LLC, and BCC involving portions of the acreage covered by the Foreland Purchase Agreement for a purchase price (the “BCC Purchase Price”) of $25.7 million in cash, net of preliminary and customary purchase price adjustments that remains subject to final post-closing settlement between EEH and BCC, with an effective date of July 1, 2021.

In connection with the closing of the Foreland Purchase Agreement, Earthstone entered into a customary registration rights agreement with Foreland and their equity holders containing provisions under which Earthstone will, among other things, file a

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registration statement on Form S-3 with the Securities and Exchange Commission (“SEC”) providing for the registration of the Foreland Shares and cooperate in certain as yet undetermined underwritten offerings thereof.

In connection with the closing of the Foreland Purchase Agreement, Earthstone entered into a customary lock-up agreement with Foreland and its equity holders providing that such holders will not transfer a portion of the Foreland Shares for 60 days after the closing of the Foreland Acquisition (25% of the Foreland Shares), a portion of the Foreland Shares for 90 days after the closing of the Foreland Acquisition (25% of the Foreland Shares), and a portion of the Foreland Shares for 120 days after the closing of the Foreland Acquisition (50% of the Foreland Shares).

Fourth Amendment to Credit Agreement

On September 17, 2021, Earthstone and EEH (collectively the “Borrower”), Wells Fargo Bank, National Association (“Wells Fargo”) as Administrative Agent and Issuing Bank, the lenders party thereto (the “Lenders”) and the guarantors party thereto entered into an amendment (the “Fourth Amendment”) to the Credit Agreement dated November 21, 2019, by and among EEH, as Borrower, Earthstone, as Parent, Wells Fargo as Administrative Agent and Issuing Bank, Royal Bank of Canada, as Syndication Agent, Truist Bank, as successor by merger to SunTrust Bank, as Documentation Agent, and the Lenders party thereto (together with all amendments or other modifications, the “Credit Agreement”). Among other things, the Fourth Amendment increased the borrowing base from $550 million to $650 million, added provisions to provide for the eventual replacement of LIBOR as a benchmark interest rate, made certain changes to the lenders under the Credit Agreement, and made certain other administrative changes to the Credit Agreement.

IRM Acquisition

On January 7, 2021, Earthstone and EEH (collectively with Earthstone, the “Buyer”), Independence Resources Holdings, LLC (“Independence”), and Independence Resources Manager, LLC (“Independence Manager” and collectively with Independence, the “Seller”) consummated the transactions contemplated in the Purchase and Sale Agreement dated December 17, 2020 (the “IRM Purchase Agreement”) that was previously reported in our Current Report on Form 8-K filed with the SEC on December 22, 2020. The Seller was unaffiliated with the Company. At the closing of the IRM Purchase Agreement, ~~among other things,~~ EEH acquired (the “IRM Acquisition”) all of the issued and outstanding limited liability company interests in certain wholly owned subsidiaries of Independence and Independence Manager ~~(collectively, the “Acquired Entities”)~~ for aggregate consideration consisting of: (i) cash of ~~the following: (i) an aggregate amount of cash from EEH equal to~~ approximately ~~$134.3~~$140.4 million (the “Cash Consideration”) and (ii) 12,719,594 shares of Class A Common Stock (such shares, the “Acquisition Shares,” and such issuance, the “Stock Issuance”). As a result of the Stock Issuance, Earthstone is no longer considered a controlled company within the meaning of the listing standards of the NYSE.

In order to fund the cash consideration for the IRM Acquisition, on December 17, 2020, Earthstone, EEH, as Borrower, Wells Fargo Bank, National Association (“Wells Fargo”), as Administrative Agent, the guarantors party thereto, and the lenders party thereto (the “Lenders”) entered into an amendment (the “Second Amendment”) to the credit agreement dated November 21, 2019, by and among EEH, as Borrower, Earthstone, as Parent, Wells Fargo, as Administrative Agent and Issuing Bank, BOKF, NA dba Bank of Texas, as Issuing Bank with respect to Existing Letters of Credit Royal Bank of Canada, as Syndication Agent, Truist Bank, as successor by merger to SunTrust Bank, as Documentation Agent, and the Lenders party thereto (collectively, the “Parties”) (together with all amendments or other modifications, the “Credit Agreement”).Agreement. The Second Amendment was effective upon the closing of the IRM Acquisition. Among other things, the Second Amendment (i) joined certain financial institutions as additional lenders, increased the borrowing base from $240.0 million to $360.0 million, (ii) increased the interest rate on outstanding borrowings; and (iii) adjusted some of the financial covenants.

Eagle Ford Acquisitions

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During the second quarter of 2021, we acquired working interests in certain assets we operate ~~located~~ in southern Gonzales County, Texas (the “Eagle Ford Acquisitions”) from four separate ~~sellers. The aggregate purchase price of the Eagle Ford Acquisitions was~~sellers for approximately $48.0 million in cash. We funded the Eagle Ford Acquisitions with cash on hand and borrowings under our senior secured revolving credit facility. The effective date of the Eagle Ford Acquisitions was April 1, ~~2021 and the closings occurred on May 14, May 24 and June 2,~~ 2021. ~~The largest of the acquisition components, comprised of working interests owned by two affiliates of Titanium Exploration Partners, LLC, constituted the majority of the total consideration.~~ One of the four sellers ~~was~~is a related party ~~entity at the time of the acquisition.~~entity. See further discussion in Note 4. Acquisitions and Note 12. Related Party Transactions in the Notes to Unaudited Condensed Consolidated Financial ~~Statements.~~Statements.

Tracker/Sequel Acquisitions

On July 20, 2021, Earthstone, EEH, Tracker Resource Development III, LLC (“Tracker”), and TRD III Royalty Holdings (TX), LP (“RoyaltyCo” and collectively with Tracker, the “Seller”) consummated the transactions contemplated in the Purchase and Sale Agreement dated March 31, 2021 by and among Earthstone, EEH and Seller (the “Tracker Agreement”) that was previously reported on Form 8-K filed on April 5, 2021. At the closing of the Tracker Agreement, ~~among other things,~~ EEH acquired (the “Tracker Acquisition”) interests in oil and gas leases and related property of Tracker located in Irion County, Texas (the “Tracker Assets”) for aggregate consideration consisting ~~of the following (the “Tracker Purchase Price”):~~of: (i) $22.5 million in cash, ~~net of preliminary and customary purchase price adjustments and remains subject to final post-closing settlement between the Buyer and the Seller,~~ and (ii) 4.7 million shares ~~(the “Tracker Shares”)~~ of Class A ~~common stock, $0.001 par value per share of Earthstone (the “Class A~~ Common ~~Stock”).~~Stock. Also, on July 20, 2021, Earthstone, EEH, SEG-TRD LLC (“SEG-I”), and SEG-TRD II LLC (“SEG-II” and collectively with SEG-I, “Sequel”), consummated the transactions contemplated in the Purchase and Sale Agreement dated March 31, 2021 by and among Earthstone, EEH and Sequel ~~(the “Sequel Agreement” and collectively with the Tracker Agreement, the “Purchase Agreements”)~~ that was previously reported on Form 8-K filed on April 5, 2021. At the closing of the Sequel Agreement, ~~among other things,~~ EEH acquired ~~(the “Sequel Acquisition” and with the Tracker Acquisition, the “Transaction”)~~ certain well-bore interests and related equipment held by Sequel that were part of a joint development agreement between Tracker and Sequel involving portions of the acreage covered by the Tracker Agreement ~~(the “Sequel Assets” and collectively with the Tracker Assets, the “Assets”)~~ for

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aggregate consideration consisting ~~of the following:~~of: (i) $45.3 million in cash, ~~net of preliminary and customary purchase price adjustments and remains subject to final post-closing settlement between the Buyer and Sequel,~~ and (ii) 1.5 million shares of Class A Common ~~Stock (the “Sequel Shares” and collectively with the Tracker Shares, the “Transaction Shares”).~~Stock. See further discussion in Note 4. Acquisitions and Note 12. Related Party Transactions in the Notes to Unaudited Condensed Consolidated Financial ~~Statements.~~Statements.

Cash consideration for the Tracker/Sequel Acquisitions was funded by borrowings under our senior secured revolving credit facility ~~which~~whose borrowing base was increased from $475 million to $550 million on July 20, 2021.

Tracker Registration Rights Agreements – On July 20, 2021, in connection with the closing of the Tracker Agreement, Earthstone and the members of Tracker entered into a registration rights agreement (the “Tracker Registration Rights Agreement”) relating to the Tracker Shares. The Tracker Registration Rights Agreement provides that, within sixty days after the closing date of the Tracker Acquisition, Earthstone will prepare and file a registration statement to permit the public resale of the Tracker Shares. Earthstone shall cause the registration statement to be continuously effective from and after the date it is first declared or becomes effective until the earlier of (i) all such shares of Class A Common Stock have been disposed of in the manner set forth in the registration statement or under Rule 144 of the Securities Act of 1933, as amended (the “Securities Act”), until the distribution of the Class A Common Stock does not require registration under the Securities Act, or until there are no longer any such registrable shares of Class A Common Stock issued in connection with the Tracker Acquisition outstanding or (ii) four years after the closing of the Tracker Acquisition.

Sequel Registration Rights Agreements – On July 20, 2021, in connection with the closing of the Sequel Agreement, Earthstone and Sequel entered into a registration rights agreement (the “Sequel Registration Rights Agreement”) relating to the Sequel Shares. The Sequel Registration Rights Agreement provides that, within thirty days after the closing date of the Sequel Acquisition, Earthstone will prepare and file a registration statement to permit the public resale of the Sequel Shares. Earthstone shall cause the registration statement to be continuously effective from and after the date it is first declared or becomes effective until the earlier of (i) all such shares of Class A Common Stock have been disposed of in the manner set forth in the registration statement or under Rule 144 of the Securities Act, until the distribution of the Class A Common Stock does not require registration under the Securities Act, or until there are no longer any such registrable shares of Class A Common Stock issued in connection with the Sequel Acquisition outstanding or (ii) four years after the closing of the Sequel Acquisition.

Lock-Up Agreement – In connection with the closing of the Tracker Agreement, on July 20, 2021, Earthstone and EnCap Energy Capital Fund VIII, L.P. (“EnCap Fund VIII”), a member of Tracker, entered into a lock-up agreement (the “EnCap Lock-up Agreement”) providing that EnCap Fund VIII will not transfer any of the shares of Class A Common Stock that it received at the closing of the Tracker Acquisition for a period of 120 days after the closing of the Tracker Acquisition. Also, on

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July 20, 2021, in connection with the closing of the Tracker Agreement, Earthstone and ZIP Ventures I, L.L.C. (“ZIP”), a member of Tracker, entered in a lock-up agreement (the “ZIP Lock-up Agreement”) providing that ZIP will not transfer any of the shares of Class A Common Stock that it received at the closing of the Tracker Acquisition for a period of 120 days after the closing of the Tracker Acquisition.

COVID-19

Despite the recoveries in commodity prices, recent surges from COVID-19 variants continue to negatively impact the global economy, disrupt global supply chains and create significant volatility and disruption of financial and commodity markets. The extent of the impact of the COVID-19 pandemic on our operational and financial performance, including our ability to execute our business strategies and initiatives in the expected time frame, is uncertain and depends on various factors, including how the pandemic and measures taken in response to its impact on demand for oil and natural gas, the availability of personnel, equipment and services critical to our ability to operate our properties and the impact of potential governmental restrictions on travel, transports and operations. There is uncertainty around the extent and duration of disruption, including any resurgence, and we expect that the longer the duration of any such disruption, the greater the adverse impact may be on our business.

Operational Status

As a producer of oil, natural gas and NGLs, we are recognized as an essential business under various federal, state and local regulations related to the COVID-19 pandemic. We have continued to operate as permitted under these regulations while taking mitigation efforts and steps to protect the health and safety of our employees. The safety of our employees is paramount, and we have emphasized the respective guidelines to support our mitigation efforts. Our field personnel are performing their job responsibilities and practicing mitigation guidelines with no issues to date. Our non-field personnel have returned to the office but we remain flexible to working remotely, using information technology in which we previously invested if needed. We have managed and conducted both field and non-field functions effectively thus far, including our day-to-day operations, our accounting and financial reporting systems and our internal control over financial reporting. We will continue to focus on the health and safety of our employees in conformity with the applicable jurisdictional mitigation guidelines. We will continue to monitor CDC guidelines and respond appropriately.

Commodity Market Impacts and Response

During the course of 2020, commodity prices declined significantly, negatively impacting producers of oil, natural gas and NGLs. We significantly curtailed our capital expenditures in response and, in the spring of 2020, voluntarily curtailed up to 60% of total net production. In June 2020, we returned to operating at full production capacity as oil prices began to recover. Additionally, based on recovered commodity price levels in late 2020, we resumed our operated well completions activities in the fourth quarter of 2020 and commenced a drilling program late in the first quarter of 2021. As commodity prices have continued to increase in 2021, we have enhanced our drilling program in the third quarter of 2021 to include a second drilling rig.

Operational/Financial Challenges

It is difficult to model and predict how our operations and financial status may change as a result of COVID-19. In our industry, any forecast, plans and changes to operations and financial status are a function of commodity prices. If oil prices decline due to a resurgence of COVID-19, we believe we can continue to operate and produce our properties at a minimum in a cash flow neutral position for the next 12 months. A significant driver in the future may be the financial institutions’ view on commodity prices with respect to borrowing base redeterminations. If a resurgence of COVID-19 triggers additional volatility in our business or global economies, our borrowing base, recently increased to ~~$550~~$650 million ~~with the closing of the Tracker Acquisition,~~in September 2021, could be reduced. Significant reductions in the borrowing base under our Credit Agreement could create a borrowing base deficiency depending on our loans then outstanding which may lead to a default. We believe global, as well as national, mitigation efforts currently being implemented to fight COVID-19 have had, and may continue to have, a material impact on commodity prices and may continue to present significant challenges to our industry.

The effects of COVID-19, including a substantial decrease in economic activity, have contributed to significant credit, debt and equity market volatility. Similar to other producers in our business, we experienced volatility in the price of our Class A Common Stock.

Consolidation Focus

We believe that the current industry environment will move to more consolidations; however, execution may be hampered by producers with high debt ~~levels and sellers unwilling to acknowledge persistent low commodity prices.~~levels. We continue to pursue value-accretive and scale-enhancing consolidation opportunities, as we

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believe we are in a position to operate effectively despite the COVID-19 induced volatility in oil price. We are focusing our attention on acquisition and corporate merger opportunities that would increase the scale of our operations. In addition, we believe the current industry environment presents unique opportunities ~~with distressed assets or corporations that will be distressed in the near future~~ which ~~would~~could provide us the

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potential for further consolidation because of our financial strength. At the same time, we will seek to block up acreage that would allow for longer horizontal laterals that would provide for higher economic returns. In short, we believe we are well qualified to continue to be a consolidator which could increase the scale of our operations and add value to our shareholders.

Areas of Operation

Our primary focus is concentrated in the Midland Basin of west Texas, a high oil and liquids rich resource which provides us with multiple horizontal targets with proven production results, long-lived reserves and historically high drilling success rates.

During the first quarter of 2021, we completed and turned to sales five gross (3.7 net) wells on the Hamman 30 pad in Upton County and commenced drilling three gross (2.1 net) wells on the Hamman 45 pad in Midland County. During the second quarter, we completed the ~~aforementioned~~ wells on the Hamman 45 pad in Midland County and drilled ~~a four-well~~four gross (3.8 net) wells on the Pearl Jam pad ~~(95% working interest)~~ on the recently acquired IRM Spanish Pearl ~~project which~~project. During the third quarter, we ~~expect to complete and turn to sales in late third quarter. After drilling~~completed the wells on the four-well Pearl Jam pad and moved the rig ~~was moved~~ to western Reagan County ~~in early July to drill a four-well~~where we drilled four gross (3.5 net) wells on the Hartgrove West pad ~~then is expected to move~~before moving to Upton County to drill afive gross (5.0 net) wells on the Nickel Saloon pad. Completions are currently underway on the four-well Hartgrove West pad ~~before being moved~~and we expect to Midland County late in 2021. We plan to deploy a second rig in early August, beginning in Upton County. Based on our revised capital budget, we anticipate spudding 30 gross / 26.2 net operated wells and bringing 20 gross / 16.1 net operated wells and 0.7 net non-operatedhave these wells online in ~~2021.~~November. Additionally, we expect to be in the process of completing the five-well Nickel Saloon pad around year-end and expect those wells to be online early in the first quarter of 2022.

We have operated one drilling rig in the Midland Basin since the first quarter of 2021 and added a second drilling rig in the third quarter. Currently both rigs are drilling in Upton County, Texas. One rig is on our Nickel Saloon five-well pad where we have 100% working interest and will average approximately 10,000-foot laterals. The other rig is on our Benedum six-well pad where we hold 100% working interest and will average 7,500-foot laterals. We expect to spud one additional pad before year-end with one of these rigs which will bring our operated program spudding to 29 gross (25.4 net) wells for the year. We expect to bring our final pad online near year-end which will be three gross (2.3 net) wells from our Hamman 30 pad in Upton County bringing our total completed wells brought online for the year to 19 gross (15.4 net).

Despite the ~~disruption in the oil markets resulting from the COVID-19 pandemic,~~commodity price volatility, we continue to seek acreage trades and acquisition opportunities in the Midland Basin which would allow for longer laterals, increased operated inventory and greater operating efficiency.

Critical Accounting Policies

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires us to use our judgment to make estimates and assumptions that affect certain amounts reported in our financial statements. As additional information becomes available, these estimates and assumptions are subject to change and thus impact amounts reported in the future. Critical accounting policies are those accounting policies that involve judgment and uncertainties affecting the application of those policies and the likelihood that materially different amounts would be reported under different conditions or using differing assumptions. We periodically update our estimates used in the preparation of the financial statements based on our latest assessment of the current and projected business and general economic environment. There have been no significant changes to our critical accounting policies during the ~~six~~nine months ended ~~June~~September 30, 2021.

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Results of Operations

Three Months Ended ~~June~~September 30, 2021, compared to the Three Months Ended ~~June~~September 30, 2020


		Three Months Ended June 30,							Three Months Ended September 30,
		2021		2020		Change			2021		2020		Change
Sales volumes:	Sales volumes:							Sales volumes:
Oil (MBbl)	Oil (MBbl)	1,083		800		35	%	Oil (MBbl)	1,055		839		26	%
Natural gas (MMcf)	Natural gas (MMcf)	2,927		1,351		117	%	Natural gas (MMcf)	4,119		2,010		105	%
Natural gas liquids (MBbl)	Natural gas liquids (MBbl)	496		208		138	%	Natural gas liquids (MBbl)	636		386		65	%
Barrels of oil equivalent (MBOE)		2,067		1,233		68	%
Barrels of oil equivalent (MBoe)								Barrels of oil equivalent (MBoe)	2,377		1,560		52	%
Average Daily Production (Boepd)	Average Daily Production (Boepd)	22,716		13,555		68	%	Average Daily Production (Boepd)	25,836		16,959		52	%

Average prices:	Average prices:							Average prices:
Oil (per Bbl)	Oil (per Bbl)	$	65.47	$	23.56	178	%	Oil (per Bbl)	$	70.20	$	39.50	78	%
Natural gas (per Mcf)	Natural gas (per Mcf)	$	2.29	$	0.83	176	%	Natural gas (per Mcf)	$	3.49	$	1.31	166	%
Natural gas liquids (per Bbl)	Natural gas liquids (per Bbl)	$	24.31	$	8.10	200	%	Natural gas liquids (per Bbl)	$	34.56	$	13.60	154	%

Average prices adjusted for realized derivatives settlements:	Average prices adjusted for realized derivatives settlements:							Average prices adjusted for realized derivatives settlements:
Oil ($/Bbl)	Oil ($/Bbl)	$	52.39	$	59.61	(12)	%	Oil ($/Bbl)	$	52.94	$	49.34	7	%
Natural gas ($/Mcf)	Natural gas ($/Mcf)	$	2.19	$	1.23	78	%	Natural gas ($/Mcf)	$	2.85	$	1.45	97	%
Natural gas liquids ($/Bbl)	Natural gas liquids ($/Bbl)	$	24.31	$	8.10	200	%	Natural gas liquids ($/Bbl)	$	34.56	$	13.60	154	%

(In thousands)	(In thousands)							(In thousands)
Oil revenues	Oil revenues	$	70,918	$	18,847	276	%	Oil revenues	$	74,051	$	33,158	123	%
Natural gas revenues	Natural gas revenues	$	6,690	$	1,127	494	%	Natural gas revenues	$	14,368	$	2,642	444	%
Natural gas liquids revenues	Natural gas liquids revenues	$	12,063	$	1,689	614	%	Natural gas liquids revenues	$	21,965	$	5,247	319	%

Lease operating expense	Lease operating expense	$	11,747	$	5,588	110	%	Lease operating expense	$	12,983	$	7,044	84	%
Production and ad valorem taxes	Production and ad valorem taxes	$	5,176	$	1,479	250	%	Production and ad valorem taxes	$	7,225	$	2,696	168	%

Depreciation, depletion and amortization	Depreciation, depletion and amortization	$	26,027	$	22,902	14	%	Depreciation, depletion and amortization	$	27,059	$	28,538	(5)	%

General and administrative expense (excluding stock-based compensation)	General and administrative expense (excluding stock-based compensation)	$	4,758	$	4,119	16	%	General and administrative expense (excluding stock-based compensation)	$	4,770	$	3,393	41	%
Stock-based compensation	Stock-based compensation	$	4,412	$	2,568	72	%	Stock-based compensation	$	2,880	$	2,403	20	%
General and administrative expense	General and administrative expense	$	9,170	$	6,687	37	%	General and administrative expense	$	7,650	$	5,796	32	%

Transaction costs	Transaction costs	$	507	$	(463)	NM		Transaction costs	$	293	$	(705)	NM

Interest expense, net	Interest expense, net	$	(2,401)	$	(1,285)	87	%	Interest expense, net	$	(3,050)	$	(1,186)	157	%

Unrealized loss on derivative contracts	Unrealized loss on derivative contracts	$	(36,653)	$	(50,036)	(27)	%	Unrealized loss on derivative contracts	$	(12,244)	$	(14,543)	(16)	%
Realized (loss) gain on derivative contracts	Realized (loss) gain on derivative contracts	$	(14,522)	$	29,357	(149)	%	Realized (loss) gain on derivative contracts	$	(20,884)	$	8,503	(346)	%
Loss on derivative contracts, net	Loss on derivative contracts, net	$	(51,175)	$	(20,679)	147	%	Loss on derivative contracts, net	$	(33,128)	$	(6,040)	448	%

Income tax benefit		$	486	$	1,110	(56)	%
Income tax expense								Income tax expense	$	(451)	$	(130)	247	%

NM – Not Meaningful

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Results of Operations Highlights

The IRM Acquisition, ~~and~~the Eagle Ford Acquisitions and the Tracker/Sequel Acquisitions (collectively, the “Acquisitions”) have had a significant and pervasive impact on our results of operations when compared to the prior year corresponding periods and, as ~~well as~~it relates to the nine months ended September 30, 2020, diminished operating results ~~in the corresponding prior year periods~~ due to voluntary production shut-ins resulting from low ~~and sometimes negative~~ commodity prices. In addition, commodity prices have improved compared to the prior corresponding periods further impacting our results of operations. Below is a detailed discussion further highlighting the impact of our recent acquisitions.

Oil revenues

For the three months ended ~~June~~September 30, 2021, oil revenues increased by ~~$52.1~~$40.9 million or ~~276%~~123% relative to the comparable period in 2020. Of the increase, ~~$33.5~~$25.8 million was attributable to an increase in our realized price and ~~$18.6~~$15.1 million was attributable to an increase in sales volume. Our average realized price per Bbl increased from ~~$23.56~~$39.50 for the three months ended ~~June~~September 30, 2020 to ~~$65.47~~$70.20 or ~~178%~~78% for the three months ended ~~June~~September 30, 2021. Additionally, we had a net increase in the volume of oil sold of ~~283~~216 MBbls or ~~35%~~26%, which included an increase of ~~304~~397 MBbls related to the wells acquired in the ~~IRM Acquisition and an increase of 34 MBbls related to the Eagle Ford~~ Acquisitions, offset by a decrease of 55181 MBbls in our other wells primarily resulting from natural ~~decline.~~declines, partially offset by new wells coming online related to our 2021 drilling program.

Natural gas revenues

For the three months ended ~~June~~September 30, 2021, natural gas revenues increased by ~~$5.6~~$11.7 million or ~~494%~~444% relative to the comparable period in 2020. Of the increase, ~~$3.6~~$7.3 million was due to increased sales volume and ~~$2.0~~$4.4 million was attributable to an increase in realized price. Our average realized price per Mcf increased ~~176%~~166% from ~~$0.83~~$1.31 for the three months ended ~~June~~September 30, 2020 to ~~$2.29~~$3.49 for the three months ended ~~June~~September 30, 2021. The total volume of natural gas produced and sold increased ~~1,576~~2,108 MMcf or ~~117%~~105% which included an increase of ~~600~~1,852 MMcf related to the wells acquired in the ~~IRM Acquisition, an increase of 10 MMcf related to the Eagle Ford~~ Acquisitions and an increase of ~~966~~256 MMcf in our other wells primarily resulting from a higher mix of natural gas from existing wells and ~~the impact of voluntary production shut-ins in the prior year period.~~new wells coming online related to our 2021 drilling program.

Natural gas liquids revenues

For the three months ended ~~June~~September 30, 2021, natural gas liquids revenues increased by ~~$10.4~~$16.7 million or ~~614%~~319% relative to the comparable period in 2020. Of the increase, ~~$3.4~~$8.1 million was attributable to an increase in our realized price and ~~$7.0~~$8.6 million was attributable to increased volume. The volume of natural gas liquids produced and sold increased by ~~288~~250 MBbls or ~~138%~~65%, which included an increase of ~~112~~263 MMcf related to the wells acquired in the ~~IRM Acquisition, an increase~~Acquisitions, offset by a decrease of ~~2 MBbls related to the Eagle Ford Acquisitions and an increase of 174~~13 MBbls in our other wells primarily resulting from ~~voluntary production shut-ins in the prior year period.~~natural declines, partially offset by new wells coming online related to our 2021 drilling program.

Lease operating expense (“LOE”)

LOE increased by ~~$6.2~~$5.9 million or ~~110%~~84% for the three months ended ~~June~~September 30, 2021 relative to the comparable period in 2020, due to a ~~$2.8~~$5.7 million increase resulting from the LOE of the properties acquired in the ~~IRM Acquisition, an increase of $0.3 million related to the Eagle Ford~~ Acquisitions and a ~~$3.1~~$0.2 million increase primarily resulting from ~~higher production volumes when compared to the prior year period as the prior year period was impacted by voluntary production shut-ins.~~workovers.

Production and ad valorem taxes

Production and ad valorem taxes for the three months ended ~~June~~September 30, 2021 increased by ~~$3.7~~$4.5 million or ~~250%~~168% relative to the comparable period in 2020 due to a ~~$1.3~~$3.0 million increase resulting from the properties acquired in the ~~IRM Acquisition, an increase of $0.1 million related to the Eagle Ford~~ Acquisitions and a ~~$2.3~~$1.5 million increase related to our other wells resulting from to improved commodity ~~prices, as well as voluntary production shut-ins in the prior year period.~~prices.

Depreciation, depletion and amortization (“DD&A”)

DD&A for the three months ended ~~June~~September 30, 2021 ~~increased~~decreased by ~~$3.1~~$1.5 million, or ~~14%~~5% relative to the comparable period in 2020, primarily due to ~~$5.8~~a $7.6 million increase in DD&A related to the assets acquired in the ~~IRM Acquisition, partially~~Acquisitions, offset by a ~~$2.7~~$9.1 million decrease in DD&A related to our other wells primarily resulting from ~~lower volumes from voluntary production shut-ins in the prior year period, as well as~~ additional volumes added to the depletable base of our properties resulting from the impact of improved commodity prices on our estimated proved reserves.

General and administrative expense (“G&A”)

G&A for the three months ended ~~June~~September 30, 2021 increased by ~~$2.5~~$1.9 million, or ~~37%~~32% relative to the comparable period in 2020, primarily due to an increase of ~~$1.8~~$0.5 million in non-cash performance-based stock-based compensation expense resulting from increases

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in the market value of our Class A Common Stock, ~~as well as~~an increase of $0.7 million resulting from the reinstatement

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of certain cash-based compensation expenses which were suspended in the prior year ~~period.~~period and an increase of $0.2 million related to professional fees and lower administrative overhead reimbursements.

Transaction costs

For the three months ended ~~June~~September 30, 2021, there were no material transaction costs. For the three months ended September 30, 2020, transaction costs ~~increased by $1.0 million primarily due to~~were a benefit resulting from reimbursements associated with the ~~impact~~anticipated settlement of ~~prior year reimbursements related to~~ the Olenik litigation.

Interest expense, net

Interest expense increased from ~~$1.3~~$1.2 million for the three months ended ~~June~~September 30, 2020 to ~~$2.4~~$3.1 million for the three months ended ~~June~~September 30, 2021, due to higher average borrowings outstanding compared to the prior year period primarily resulting from borrowings related to the ~~IRM Acquisition.~~Acquisitions. See Note 10. Long-Term Debt in the Notes to Unaudited Condensed Consolidated Financial ~~Statements.~~Statements.

Loss on derivative contracts, net

For the three months ended ~~June~~September 30, 2021, we recorded a net loss on derivative contracts of ~~$51.2~~$33.1 million, consisting of unrealized mark-to-market losses of ~~$36.6~~$12.2 million related to our commodity hedges along with net realized losses on settlements of our commodity hedges of ~~$14.5~~$20.8 million and net realized losses on our interest rate swap of $0.1 million. For the three months ended ~~June~~September 30, 2020, we recorded a net loss on derivative contracts of ~~$20.7~~$6.0 million, consisting of unrealized mark-to-market losses of ~~$49.6~~$14.6 million related to our commodity hedges and ~~$0.5~~unrealized gains of $0.1 million related to our interest rate ~~swaps,~~swap, partially offset by net realized gains on settlements of our commodity hedges of ~~$29.4~~$8.5 million.

Income tax ~~benefit~~expense

For the three months ended ~~June~~September 30, 2021, we recorded income tax ~~benefit~~expense of approximately $0.5 million which included (1) a deferred income tax ~~benefit~~expense for one of our subsidiaries, Lynden USA Inc.~~, a Utah corporation and wholly-owned subsidiary of Lynden Corp~~ (“Lynden US”), of ~~$0.2~~$0.3 million as a result of its share of the distributable loss from EEH, (2) no net income tax ~~benefit~~expense for Earthstone as the ~~$1.4~~$1.8 million income tax ~~benefit~~expense resulting from its share of the distributable ~~loss~~income from EEH had a full valuation allowance recorded against it as future realization of the net deferred tax asset cannot be assured and (3) a ~~deferred income tax benefit of $0.7 million related to the Texas Margin Tax, offset by (4)~~ current income tax expense of ~~$0.4~~$0.2 million related to the Texas Margin Tax. One of our subsidiaries, Lynden Energy Corp.~~, a corporation organized under the laws of British Columbia and wholly-owned subsidiary of Earthstone~~ (“Lynden Corp”), incurred no material income or loss, or related income tax expense or benefit, for the three months ended ~~June~~September 30, 2021.

~~During~~For the three months ended ~~June~~September 30, 2020, we recorded an income tax expense of approximately ~~$1.1~~$0.1 million which included (1) no income tax expense for Lynden US ~~of $0.7 million~~ as a result of its share of the distributable income from EEH, (2) deferred income tax ~~expense~~benefit for Earthstone of ~~$2.8~~$0.9 million as a result of its share of the distributable income from EEH, which was used to reduce the valuation allowance recorded against its deferred tax asset which was previously recorded as future realization of the net deferred tax asset cannot be assured and (3) deferred income tax expense of ~~$0.4~~$0.1 million related to the Texas Margin Tax. Lynden Corp incurred no material income or loss, or related income tax expense or benefit, for the three months ended ~~June~~September 30, 2020.

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~~Six~~Nine Months Ended ~~June~~September 30, 2021, compared to the ~~Six~~Nine Months Ended ~~June~~September 30, 2020


		Six Months Ended June 30,							Nine Months Ended September 30,
		2021		2020		Change			2021		2020		Change
Sales volumes:	Sales volumes:							Sales volumes:
Oil (MBbl)	Oil (MBbl)	2,140		1,680		27	%	Oil (MBbl)	3,195		2,520		27	%
Natural gas (MMcf)	Natural gas (MMcf)	5,372		3,021		78	%	Natural gas (MMcf)	9,490		5,031		89	%
Natural gas liquids (MBbl)	Natural gas liquids (MBbl)	861		485		78	%	Natural gas liquids (MBbl)	1,497		870		72	%
Barrels of oil equivalent (MBOE)		3,896		2,668		46	%
Barrels of oil equivalent (MBoe)								Barrels of oil equivalent (MBoe)	6,273		4,229		48	%
Average Daily Production (Boepd)	Average Daily Production (Boepd)	21,525		14,661		47	%	Average Daily Production (Boepd)	22,978		15,433		49	%

Average prices:	Average prices:							Average prices:
Oil (per Bbl)	Oil (per Bbl)	$	61.56	$	35.63	73	%	Oil (per Bbl)	$	64.42	$	36.92	74	%
Natural gas (per Mcf)	Natural gas (per Mcf)	$	2.33	$	0.73	219	%	Natural gas (per Mcf)	$	2.84	$	0.96	196	%
Natural gas liquids (per Bbl)	Natural gas liquids (per Bbl)	$	24.35	$	9.76	149	%	Natural gas liquids (per Bbl)	$	28.69	$	11.46	150	%

Average prices adjusted for realized derivatives settlements:	Average prices adjusted for realized derivatives settlements:							Average prices adjusted for realized derivatives settlements:
Oil ($/Bbl)	Oil ($/Bbl)	$	50.06	$	58.04	(14)	%	Oil ($/Bbl)	$	51.01	$	55.14	(7)	%
Natural gas ($/Mcf)	Natural gas ($/Mcf)	$	2.20	$	1.21	82	%	Natural gas ($/Mcf)	$	2.49	$	1.31	90	%
Natural gas liquids ($/Bbl)	Natural gas liquids ($/Bbl)	$	24.35	$	9.76	149	%	Natural gas liquids ($/Bbl)	$	28.69	$	11.46	150	%

(In thousands)	(In thousands)							(In thousands)
Oil revenues	Oil revenues	$	131,737	$	59,859	120	%	Oil revenues	$	205,788	$	93,017	121	%
Natural gas revenues	Natural gas revenues	$	12,542	$	2,213	467	%	Natural gas revenues	$	26,910	$	4,855	454	%
Natural gas liquids revenues	Natural gas liquids revenues	$	20,964	$	4,729	343	%	Natural gas liquids revenues	$	42,929	$	9,976	330	%

Lease operating expense	Lease operating expense	$	22,596	$	14,927	51	%	Lease operating expense	$	35,579	$	21,971	62	%
Production and ad valorem taxes	Production and ad valorem taxes	$	10,203	$	4,502	127	%	Production and ad valorem taxes	$	17,428	$	7,198	142	%

Impairment expense	Impairment expense	$	—	$	60,433	NM		Impairment expense	$	—	$	62,548	NM
Depreciation, depletion and amortization	Depreciation, depletion and amortization	$	50,434	$	47,558	6	%	Depreciation, depletion and amortization	$	77,493	$	76,096	2	%

General and administrative expense (excluding stock-based compensation)	General and administrative expense (excluding stock-based compensation)	$	9,809	$	8,557	15	%	General and administrative expense (excluding stock-based compensation)	$	14,579	$	11,950	22	%
Stock-based compensation	Stock-based compensation	$	7,741	$	5,262	47	%	Stock-based compensation	$	10,621	$	7,665	39	%
General and administrative expense	General and administrative expense	$	17,550	$	13,819	27	%	General and administrative expense	$	25,200	$	19,615	28	%

Transaction costs	Transaction costs	$	2,613	$	381	NM		Transaction costs	$	2,906	$	(324)	NM

Interest expense, net	Interest expense, net	$	(4,618)	$	(3,021)	53	%	Interest expense, net	$	(7,668)	$	(4,207)	82	%

Unrealized (loss) gain on derivative contracts	Unrealized (loss) gain on derivative contracts	$	(59,011)	$	40,009	(247)	%	Unrealized (loss) gain on derivative contracts	$	(71,255)	$	25,466	(380)	%
Realized (loss) gain on derivative contracts	Realized (loss) gain on derivative contracts	$	(25,427)	$	39,096	(165)	%	Realized (loss) gain on derivative contracts	$	(46,311)	$	47,599	(197)	%
(Loss) gain on derivative contracts, net	(Loss) gain on derivative contracts, net	$	(84,438)	$	79,105	(207)	%	(Loss) gain on derivative contracts, net	$	(117,566)	$	73,065	(261)	%

Income tax benefit (expense)	Income tax benefit (expense)	$	794	$	18	NM		Income tax benefit (expense)	$	343	$	(112)	NM

NM – Not Meaningful

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Oil revenues

For the ~~six~~nine months ended ~~June~~September 30, 2021, oil revenues increased by ~~$71.9~~$112.8 million or ~~120%~~121% relative to the comparable period in 2020. Of the increase, ~~$43.6~~$69.3 million was attributable to an increase in our realized price and ~~$28.3~~$43.5 million was attributable to an increase in volume. Our average realized price per Bbl increased from ~~$35.63~~$36.92 for the ~~six~~nine months ended ~~June~~September 30, 2020 to ~~$61.56~~$64.42 or ~~73%~~74% for the ~~six~~nine months ended ~~June~~September 30, 2021. Additionally, we had a net increase in the volume of oil sold of ~~460~~675 MBbls or 27%, which included an increase of ~~598~~1,029 MBbls related to the wells acquired in the ~~IRM Acquisition and an increase of 34 MBbls related to the Eagle Ford~~ Acquisitions, offset by a decrease of ~~172~~354 MBbls in our other wells primarily resulting from natural ~~decline.~~declines, partially offset by new wells coming online related to our 2021 drilling program.

Natural gas revenues

For the ~~six~~nine months ended ~~June~~September 30, 2021, natural gas revenues increased by ~~$10.3~~$22.1 million or ~~467%~~454% relative to the comparable period in 2020. Of the increase, ~~$5.5~~$12.6 million was due to increased sales volume and ~~$4.8~~$9.4 million was attributable to an increase in realized price. Our average realized price per Mcf increased ~~219%~~196% from ~~$0.73~~$0.96 for the ~~six~~nine months ended ~~June~~September 30, 2020 to ~~$2.33~~$2.84 for the ~~six~~nine months ended ~~June~~September 30, 2021. The total volume of natural gas produced and sold increased ~~2,351~~4,459 MMcf or ~~78%~~89% which included an increase of ~~1,160~~3,022 MMcf related to the wells acquired in the ~~IRM Acquisition, an increase of 10 MMcf related to the Eagle Ford~~ Acquisitions and an increase of ~~1,181~~1,437 MMcf in our other wells primarily resulting from a higher mix of natural gas in the wells brought on in the current year, as well as prior year period volumes being impacted by voluntary production ~~shut-ins in the prior year period.~~shut-ins.

Natural gas liquids revenues

For the ~~six~~nine months ended ~~June~~September 30, 2021, natural gas liquids revenues increased by ~~$16.2~~$33.0 million or ~~343%~~330% relative to the comparable period in 2020. Of the increase, ~~$7.1~~$15.0 million was attributable to an increase in our realized price and ~~$9.1~~$18.0 million was attributable to increased volume. The volume of natural gas liquids produced and sold increased by ~~376~~626 MBbls or ~~78%~~72%, which included an increase of ~~212~~477 MMcf related to the wells acquired in the ~~IRM Acquisition, an increase of 2 MBbls related to the Eagle Ford~~ Acquisitions and an increase of ~~162~~149 MBbls in our other wells primarily resulting from new wells coming online related to our 2021 drilling program, as well as prior year period volumes being impacted by voluntary production ~~shut-ins in the prior year period.~~shut-ins.

Lease operating expense (“LOE”)

LOE increased by ~~$7.7~~$13.6 million or ~~51%~~62% for the ~~six~~nine months ended ~~June~~September 30, 2021 relative to the comparable period in 2020, due to a ~~$6.7~~$12.5 million increase resulting from the LOE of the properties acquired in the ~~IRM Acquisition, an increase of $0.3 million related to the Eagle Ford~~ Acquisitions and a ~~$0.7~~$1.1 million increase resulting from higher production volumes ~~when compared~~from new wells coming online related to ~~the~~our 2021 drilling program, as well as prior year period ~~as the prior year period was~~volumes being impacted by voluntary production shut-ins.

Production and ad valorem taxes

Production and ad valorem taxes for the ~~six~~nine months ended ~~June~~September 30, 2021 increased by ~~$5.7~~$10.2 million or ~~127%~~142% relative to the comparable period in 2020 due to a ~~$2.8~~$5.9 million increase resulting from the properties acquired in the ~~IRM Acquisition, an increase of $0.1 million related to the Eagle Ford~~ Acquisitions and a ~~$2.8~~$4.3 million increase related to our other wells resulting from to improved commodity prices, as well as prior year period volumes being impacted by voluntary production ~~shut-ins in the prior year period.~~shut-ins.

Impairment expense

During the prior year period, we recorded non-cash impairments totaling ~~$60.4~~$62.5 million, which consisted of $25.3 million to proved oil and natural gas properties, ~~$17.6~~$19.7 million to unproved oil and natural gas properties and $17.6 million to goodwill. No such impairments were recorded during the ~~three~~nine months ended ~~June~~September 30, 2021.

Depreciation, depletion and amortization (“DD&A”)

DD&A for the ~~six~~nine months ended ~~June~~September 30, 2021 increased by ~~$2.9~~$1.4 million, or 6%2% relative to the comparable period in 2020 primarily due to ~~an $11.6~~a $19.2 million increase in DD&A related to the assets acquired in the ~~IRM Acquisition,~~Acquisitions, offset by a ~~$8.7~~$17.8 million decrease in DD&A related to our other wells primarily resulting from lower prior year period volumes ~~from~~due to the impact of voluntary production shut-ins, ~~in the prior year period,~~ as well as additional volumes added to the depletable base of our properties resulting from the impact of improved commodity prices on our estimated proved reserves.

General and administrative expense (“G&A”)

G&A for the ~~six~~nine months ended ~~June~~September 30, 2021 increased by ~~$3.7~~$5.6 million, or ~~27%~~28% relative to the comparable period in 2020, primarily due to an increase of ~~$2.5~~$3.0 million in non-cash performance-based stock-based compensation expense resulting from increases in the market value of our Class A Common Stock, ~~as well as $1.4~~an increase of $2.1 million resulting from the reinstatement ~~of certain cash-based~~

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of certain cash-based compensation expenses which were suspended in the prior year period ~~offset by $0.2~~and an increase of $0.5 million ~~decrease in employee-related costs resulting from efficiencies gained over the prior year period.~~related to professional fees and lower administrative overhead reimbursements.

Transaction costs

For the ~~six~~nine months ended ~~June~~September 30, 2021, transaction costs increased by ~~$2.2~~$3.2 million primarily due to a ~~$3.8~~$3.9 million increase in legal and professional fees, and severance costs primarily associated with the ~~IRM Acquisition,~~Acquisitions, partially offset by a decrease of ~~$1.6~~$1.2 million primarily due to reimbursements received related to the Olenik litigation.

Interest expense, net

Interest expense increased from ~~$3.0~~$4.2 million for the ~~six~~nine months ended ~~June~~September 30, 2020 to ~~$4.6~~$7.7 million for the ~~six~~nine months ended ~~June~~September 30, 2021, due to higher average borrowings outstanding compared to the prior year period primarily resulting from borrowings related to the ~~IRM Acquisition.~~Acquisitions. See Note 10. Long-Term Debt in the Notes to Unaudited Condensed Consolidated Financial ~~Statements.~~Statements.

(Loss) gain on derivative contracts, net

For the ~~six~~nine months ended ~~June~~September 30, 2021, we recorded a net loss on derivative contracts of ~~$84.4~~$117.6 million, consisting of unrealized mark-to-market losses of ~~$59.6~~$71.9 million related to our commodity hedges, partially offset by unrealized mark-to-market gains of $0.6 million related to our interest rate swap, along with net realized losses on settlements of our commodity hedges of ~~$25.3~~$46.1 million and net realized losses on our interest rate swap of ~~$0.1~~$0.2 million. For the ~~six~~nine months ended ~~June~~September 30, 2020, we recorded a net gain on derivative contracts of ~~$79.1~~$73.1 million, consisting of unrealized mark-to-market gains of ~~$40.5~~$25.9 million related to our commodity hedges, unrealized mark-to-market losses of ~~$0.5~~$0.4 million related to our interest rate swap and net realized gains on settlements of our commodity hedges of ~~$39.1~~$47.6 million.

Income tax benefit (expense)

For the ~~six~~nine months ended ~~June~~September 30, 2021, we recorded income tax benefit of approximately ~~$0.8~~$0.3 million which included (1) a deferred income tax benefit for Lynden US of ~~$0.4~~$0.1 million as a result of its share of the distributable loss from EEH, (2) no net income tax benefit for Earthstone as the ~~$2.6~~$0.8 million income tax benefit resulting from its share of the distributable loss from EEH had a full valuation allowance recorded against it as future realization of the net deferred tax asset cannot be assured and (3) a deferred income tax benefit of $0.8 million related to the Texas Margin Tax, offset by (4) current income tax expense of ~~$0.4~~$0.6 million related to the Texas Margin Tax. Lynden Corp incurred no material income or loss, or related income tax expense or benefit, for the ~~six~~nine months ended ~~June~~September 30, 2021.

~~During~~For the ~~six~~nine months ended ~~June~~September 30, 2020, we recorded income tax ~~benefit~~expense of approximately ~~$0.02~~$0.1 million which included (1) no income tax expense for Lynden US ~~of $0.1 million~~ as a result of its share of the distributable income from EEH, (2) a deferred income tax ~~expense~~benefit for Earthstone of ~~$0.06~~$0.8 million as a result of its share of the distributable income from EEH, which was used to reduce the valuation allowance recorded against its deferred tax asset which was previously recorded as future realization of the net deferred tax asset cannot be assured and (3) deferred income tax expense of ~~$0.01~~$0.1 million related to the Texas Margin Tax. Lynden Corp incurred no material income or loss, or related income tax expense or benefit, for the ~~six~~nine months ended ~~June~~September 30, 2020.

Liquidity and Capital Resources

We have significant undeveloped acreage and future drilling locations. Drilling horizontal wells in the Midland Basin, generally consisting of 7,500 to 12,000-foot lateral lengths, ~~in the Midland Basin~~ is capital intensive. As of ~~June~~September 30, 2021, we had ~~$0.5~~$0.4 million in cash and ~~$241.4~~$278.3 million of long-term debt outstanding under our Credit Agreement with a borrowing base of ~~$475.0~~$650.0 million. With the ~~$233.6~~$371.7 million of undrawn borrowing base capacity and ~~$0.5~~$0.4 million in cash, we had total liquidity of approximately ~~$234.1~~$372.2 million. Adjusted for the closing of the Tracker Acquisition on July 20, 2021, we had an estimated $0.5 million in cash and $301.0 million of long-term debt outstanding under our credit facility with a borrowing base of $550 million. With the $249.0 million of undrawn borrowing base capacity and $0.5 million in cash, we had total liquidity of approximately $249.5 million on a combined basis.

With improvement in oil prices during 2021, we ~~have~~ resumed drilling operations with the deployment of a drilling rig in the first quarter of 2021 while adding a second drilling rig in ~~August and we~~August. We expect to spend $130-$140 million based on our current 2021 drilling plan. We believe we will have sufficient liquidity with cash flows from operations and available borrowings under the Credit Agreement to meet our cash requirements for the next 12 months.

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Working Capital

Working capital (presented below) was a deficit of ~~$88.7~~$105.0 million as of ~~June~~September 30, 2021, compared to a working capital deficit of $20.8 million as of December 31, 2020, representing an increase in the deficit of ~~$68.0~~$84.3 million. ~~The $68.0~~Of the $84.3 million increase in the working capital deficit ~~was primarily the result of~~$73.9 million resulted from a ~~$64.3 million~~ decrease in the net fair value of our derivative contracts expected to settle in the 12 months subsequent to ~~June~~September 30, 2021 resulting from increased oil price futures as of ~~June~~September 30, 2021.

The remaining decrease of $10.4 million primarily resulted from increased drilling in the current year. The components of working capital are presented below:


		June 30,		December 31,			September 30,		December 31,
(In thousands)	(In thousands)	2021		2020		(In thousands)	2021		2020
Current assets:	Current assets:					Current assets:
Cash	Cash	$	478	$	1,494	Cash	$	441	$	1,494
Accounts receivable:	Accounts receivable:					Accounts receivable:
Oil, natural gas, and natural gas liquids revenues	Oil, natural gas, and natural gas liquids revenues	35,063		16,255		Oil, natural gas, and natural gas liquids revenues	45,076		16,255
Joint interest billings and other, net of allowance of $19 and $19 at June 30, 2021 and December 31, 2020, respectively		4,843		7,966
Joint interest billings and other, net of allowance of $19 and $19 at September 30, 2021 and December 31, 2020, respectively						Joint interest billings and other, net of allowance of $19 and $19 at September 30, 2021 and December 31, 2020, respectively	3,058		7,966
Derivative asset	Derivative asset	72		7,509		Derivative asset	17		7,509
Prepaid expenses and other current assets	Prepaid expenses and other current assets	2,109		1,509		Prepaid expenses and other current assets	1,565		1,509
Total current assets	Total current assets	42,565		34,733		Total current assets	50,157		34,733

Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	25,555	$	6,232	Accounts payable	$	33,602	$	6,232
Revenues and royalties payable	Revenues and royalties payable	29,398		27,492		Revenues and royalties payable	30,139		27,492
Accrued expenses	Accrued expenses	16,224		16,504		Accrued expenses	20,620		16,504
Asset retirement obligation	Asset retirement obligation	541		447		Asset retirement obligation	543		447
Derivative liability	Derivative liability	57,957		1,135		Derivative liability	67,575		1,135
Advances	Advances	330		2,277		Advances	1,325		2,277
Operating lease liabilities	Operating lease liabilities	782		773		Operating lease liabilities	732		773
Finance lease liabilities	Finance lease liabilities	4		69		Finance lease liabilities	—		69
Other current liabilities	Other current liabilities	498		565		Other current liabilities	634		565
Total current liabilities	Total current liabilities	131,289		55,494		Total current liabilities	155,170		55,494

Working Capital	Working Capital	$	(88,724)	$	(20,761)	Working Capital	$	(105,013)	$	(20,761)

Cash Flows from Operating Activities

Cash flows provided by operating activities for the ~~six~~nine months ended ~~June~~September 30, 2021 increased to ~~$93.4~~$147.3 million compared to ~~$57.1~~$104.7 million for the ~~six~~nine months ended ~~June~~September 30, 2020, primarily due to the impact of oil and natural gas property acquisitions and the timing of payments and receipts partially offset by the cash settlement of derivative contracts as compared to the prior year period.

Cash Flows from Investing Activities

Cash flows used in investing activities for the ~~six~~nine months ended ~~June~~September 30, 2021 increased to ~~$216.2~~$305.4 million from ~~$67.2~~$72.6 million for the ~~six~~nine months ended ~~June~~September 30, 2020, primarily due to acquisitions of oil and gas ~~properties partially offset by limited drilling activity in the period.~~properties.

Cash Flows from Financing Activities

Cash flows provided by financing activities were ~~$121.8~~$157.1 million for the ~~six~~nine months ended ~~June~~September 30, 2021 as compared to cash flows used in financing activities of ~~$1.9~~$40.7 million for the ~~six~~nine months ended ~~June~~September 30, 2020, primarily due to borrowings required to fund acquisitions of oil and gas ~~properties, partially offset by limited drilling activity in the period.~~properties.

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Capital Expenditures

Our accrual basis capital expenditures for the three and ~~six~~nine months ended ~~June~~September 30, 2021 were as follows (in thousands):


		Three Months Ended June 30, 2021		Six Months Ended June 30, 2021			Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021
Drilling and completions	Drilling and completions	$	22,820	$	32,167	Drilling and completions	$	42,179	$	74,346
Leasehold costs	Leasehold costs	—		454		Leasehold costs	1,990		2,444
Total capital expenditures	Total capital expenditures	$	22,820	$	32,621	Total capital expenditures	$	44,169	$	76,790

Credit Facility

On ~~April 20,~~September 17, 2021, the ~~Parties~~parties entered into an amendment (the ~~“Third~~“Fourth Amendment”) to the Credit ~~Agreement under which~~Agreement. Among other things, the Fourth Amendment increased the borrowing base ~~increased~~ from ~~$360~~$550 million to ~~$475~~$650 million in connection with its regularly scheduled ~~redetermination. Further,~~semi-annual redetermination, added provisions to provide for the ~~Third Amendment provided for an~~eventual replacement of LIBOR as a benchmark interest rate, made certain changes to the lenders, and made certain other administrative changes to the Credit Agreement. The increase in ~~the~~our borrowing base ~~from $475 million to $550 million which became effective on July 20, 2021 upon closing~~is primarily the result of the ~~Tracker/Sequel Purchase Agreements described above.~~previously discussed Acquisitions and improved commodity prices.

The next regularly scheduled redetermination of ~~the~~our borrowing base is expected to occur on or around ~~October~~May 1, ~~2021.~~2022.

As of ~~June~~September 30, 2021, ~~$241.4~~$278.3 million of borrowings were outstanding, bearing annual interest of ~~3.347%~~3.153%, resulting in an additional ~~$233.6~~$371.7 million of borrowing base availability under the Credit Facility. As of December 31, 2020, the Company had a $240.0 million borrowing base under the Credit Agreement, of which $115.0 million was outstanding, bearing annual interest of 2.400%, resulting in an additional $125.0 million of borrowing base availability under the Credit Agreement. The increase in our borrowing base is a result of acquisitions, our drilling program in 2021 and an improvement in commodity prices.

Commodity Prices

There has been continued improvement in commodity prices compared to 2020, mostly resulting from improvements in oil demand as COVID-19 began to abate and actions taken by OPEC to reduce the worldwide supply of oil through production cuts. We can provide no assurances as to when or to what extent economic disruptions resulting from COVID-19 and the corresponding decrease in oil demand may continue to improve. Prices for natural gas and NGLs have also improved compared to 2020.

Hedging Activities

The following table sets forth our outstanding derivative contracts at ~~June~~September 30, 2021. When aggregating multiple contracts, the weighted average contract price is disclosed.


		Price Swaps					Price Swaps
Period	Period	Commodity	Volume (Bbls / MMBtu)	Weighted Average Price ($/Bbl / $/MMBtu)		Period	Commodity	Volume (Bbls / MMBtu)	Weighted Average Price ($/Bbl / $/MMBtu)
Q3 - Q4 2021		Crude Oil	1,693,400	$	49.10
Q4 2021						Q4 2021	Crude Oil	941,475	$	50.63
Q1 - Q4 2022	Q1 - Q4 2022	Crude Oil	1,732,250	$	53.64	Q1 - Q4 2022	Crude Oil	2,462,250	$	56.31
Q3 - Q4 2021		Crude Oil Basis Swap (1)	1,509,400	$	0.80
Q3 - Q4 2021		Crude Oil Roll Swap (2)	474,650	$	(0.26)
Q4 2021						Q4 2021	Crude Oil Basis Swap (1)	757,475	$	0.80
Q4 2021						Q4 2021	Crude Oil Roll Swap (2)	228,475	$	(0.27)
Q1 - Q4 2022	Q1 - Q4 2022	Crude Oil Basis Swap (1)	2,007,500	$	0.68	Q1 - Q4 2022	Crude Oil Basis Swap (1)	2,007,500	$	0.68
Q3 - Q4 2021		Natural Gas	4,904,000	$	2.87
Q4 2021						Q4 2021	Natural Gas	2,576,000	$	2.87
Q1 - Q4 2022	Q1 - Q4 2022	Natural Gas	4,295,000	$	2.92	Q1 - Q4 2022	Natural Gas	4,295,000	$	2.92
Q3 - Q4 2021		Natural Gas Basis Swap (3)	5,026,000	$	(0.30)
Q4 2021						Q4 2021	Natural Gas Basis Swap (3)	2,698,000	$	(0.29)
Q1 - Q4 2022	Q1 - Q4 2022	Natural Gas Basis Swap (3)	7,725,000	$	(0.24)	Q1 - Q4 2022	Natural Gas Basis Swap (3)	9,100,000	$	(0.26)

(1)The basis differential price is between WTI Midland Crude and the WTI NYMEX.

(2)The swap is between WTI Roll and the WTI NYMEX.

(3)The basis differential price is between W. Texas (WAHA) and the Henry Hub NYMEX.

Costless Collars
Period Commodity Volume
(Bbls / MMBtu) Sold Ceiling
($/Bbl / $/MMBtu) Bought Floor
($/Bbl / $/MMBtu)
Q1 - Q4 2022 Crude Oil Costless Collar 365,000 $ 68.75 $ 55.00
Q3 - Q4 2021 Natural Gas Costless Collar 122,000 $ 4.10 $ 3.50
Q1 2022 Natural Gas Costless Collar 1,080,000 $ 3.75 $ 3.17

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	Costless Collars
Period	Commodity	Volume (Bbls / MMBtu)	Sold Ceiling ($/Bbl / $/MMBtu)		Bought Floor ($/Bbl / $/MMBtu)
Q1 - Q4 2022	Crude Oil Costless Collar	365,000	$	68.75	$	55.00
Q4 2021	Natural Gas Costless Collar	122,000	$	4.10	$	3.50
Q1 - Q4 2022	Natural Gas Costless Collar	2,905,000	$	4.00	$	3.06

Obligations and Commitments

There have been no material changes from the obligations and commitments disclosed in the Obligations and Commitments section of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2020 Annual Report on Form 10-K other than those described in Note 13. Commitments and Contingencies in the Notes to the Unaudited Condensed Consolidated Financial Statements.

Environmental Regulations

~~Table of Contents~~

Our operations are subject to risks normally associated with the drilling for and the production of oil and natural gas, including blowouts, fires, and environmental risks such as oil spills or natural gas leaks that could expose us to liabilities associated with these risks.

In our acquisition of existing or previously drilled well bores, we may not be aware of prior environmental safeguards, if any, that were taken at the time such wells were drilled or during such time the wells were operated. We maintain comprehensive insurance coverage that we believe is adequate to mitigate the risk of any adverse financial effects associated with these risks.

However, should it be determined that a liability exists with respect to any environmental cleanup or restoration, the liability to cure such a violation could still accrue to us. No claim has been made, nor are we aware of any liability which we may have, as it relates to any environmental cleanup, restoration, or the violation of any rules or regulations relating thereto.

Recently Issued Accounting Standards

See Note 1. Basis of Presentation and Summary of Significant Accounting Policies in the Notes to Unaudited Condensed Consolidated Financial Statements in this report for discussion of recently issued and adopted accounting standards affecting us.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

We are a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and therefore are not required to provide the information required under this item.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

In accordance with Securities Exchange Act of 1934, as amended (the “Exchange Act”), Rules 13a-15(e) and 15d-15(e), we carried out an evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and our Principal Accounting Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer and Principal Accounting Officer concluded that our disclosure controls and procedures were effective as of ~~June~~September 30, 2021 to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Our disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Principal Accounting Officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during the most recent fiscal quarter that have 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

From time to time, we may be involved in various legal proceedings and claims in the ordinary course of business. As of ~~June~~September 30, 2021, and through the filing date of this report, we do not believe the ultimate resolution of any such actions or potential actions of which we are currently aware will have a material effect on our consolidated financial position or results of operations.

See Note 13. Commitments and Contingencies in the Notes to Unaudited Condensed Consolidated Financial Statements under Part I, Item 1 of this report, ~~which is incorporated herein by reference,~~ for material matters that have occurred since the filing of our Annual Report on Form 10-K for the year ended December 31, 2020.

Item 1A. Risk Factors

In addition to the other information set forth in this report, you should carefully consider the risk factors and other cautionary statements described in the “Risk Factors” section of our Annual Report on Form 10-K for the year ended December 31, 2020.

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

Unregistered Sale of Equity Securities

~~There were no unregistered~~Unregistered sales of equity securities during the three months ended ~~June~~September 30, ~~2021.~~2021 were reported in our Current Report on Form 8-K filed with the SEC on July 23, 2021, which report is incorporated herein by reference.

Repurchase of Equity Securities

The following table sets forth information regarding our acquisition of shares of Class A Common Stock for the periods presented:

Total Number of Shares Purchased (1)
Average Price Paid Per Share Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plan or Programs
April 2021 — $ — — —
May 2021 — — — —
June 2021 66,343 $ 11.17 — —


	Total Number of Shares Purchased (1)	Average Price Paid Per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plan or Programs
July 2021	—	$	—	—	—
August 2021	—	—		—	—
September 2021	65,106	$	9.19	—	—

(1)All of the shares were surrendered by employees (via net settlement) in satisfaction of tax obligations upon the vesting of restricted stock unit awards and performance unit awards. The acquisition of the surrendered shares was not part of a publicly announced program to repurchase shares of our Class A Common Stock.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information.

None.

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Item 6. Exhibits

Exhibit No.

Description

Filed Herewith

Furnished Herewith

31.1

Certification of the Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act

31.2

Certification of the Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act

32.1

Certification of the Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act

32.2

Certification of the Executive Vice President - Accounting and Administration pursuant to Section 906 of the Sarbanes-Oxley Act

101

Interactive Data Files (formatted as Inline XBRL).

104

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

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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.

EARTHSTONE ENERGY, INC.

Date:

~~August 4,~~November 3, 2021

By:

/s/ Tony Oviedo

Tony Oviedo

Executive Vice President – Accounting and Administration

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