~~UNITED STATES~~

~~SECURITIES AND EXCHANGE COMMISSION~~

United States

Securities and Exchange Commission

Washington, D.C. 20549

~~FORM~~

Form 10-Q

☒
~~QUARTERLY REPORT PURSUANT TO SECTION~~

xQuarterly Report Pursuant to Section 13 ORor 15(d) ~~OF THE SECURITIES EXCHANGE ACT OF~~of the Securities Exchange Act of 1934

For the quarterly period ~~ended:~~ ended September 30, ~~2022~~

2023

☐
~~TRANSITION REPORT PURSUANT TO SECTION~~

oTransition Report pursuant to Section 13 ORor 15(d) ~~OF THE SECURITIES EXCHANGE ACT OF~~of the Securities Exchange Act of 1934

For the transition period from ______ to ______

Commission ~~File Number:~~ file number 001-36057

~~RING ENERGY, INC.~~

Ring Energy, Inc.

(Exact ~~Name~~name of registrant as specified in its charter)

~~Nevada~~	~~90-0406406~~
Nevada		90-0406406
(State or other jurisdiction of incorporation or organization)		(~~IRS~~I.R.S. Employer Identification No.)


1725 Hughes Landing Blvd., Suite 900 The Woodlands,TX			77380
(Address of principal executive offices)			(Zip Code)

(281) 397-3699
(Registrant’s telephone number, including area code)

~~(281)~~~~397-3699~~

~~(Registrant’s telephone number, including area code)~~

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

Exchange Act:


Title of ~~each~~Each Class	Trading Symbol	Name of ~~each exchange~~Each Exchange on ~~which registered~~ Which Registered
Common Stock, ~~$0.001~~ par value $0.001	REI	NYSE American

Indicate by check mark whether the ~~registrant~~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~~Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

☒ Yes ☐x 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 ☐x 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”,~~filer,” “accelerated filer,” “smaller reporting company,” and ~~emerging~~"emerging growth ~~company”~~company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer☐

Accelerated filer

☒x

Non-accelerated filer☐

(Do not check if a smaller reporting company)

Smaller reporting company

☐o

Emerging growth company☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐o

Indicate by check mark whether the registrant is a shell company (as defined in Rule ~~12-b-2~~12b-2 of the ~~Exchange~~ Act).

☐ Yes ☒o No

~~The~~

As of November 2, 2023, the registrant ~~has one class~~had outstanding 195,630,301 shares of common stock ~~of which 174,411,333 shares were outstanding at November 9, 2022.~~

($0.001 par value).

Table of Contents

~~INDEX~~

~~Ring Energy, Inc.~~

~~For the Quarter Ended September 30, 2022~~

TABLE OF CONTENTS

PART I –— FINANCIAL INFORMATION

Item 1:

Condensed Financial Statements

~~Item 1.~~Notes to the Condensed Financial ~~Statements.~~Statements

Item 2. 2:

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

Item 3. 3:

Quantitative and Qualitative Disclosures About Market Risk

Item 4. 4:

Controls and Procedures

PART II — OTHER INFORMATION

~~PART II – OTHER INFORMATION~~

Item 1:

Legal Proceedings

Item 1A:

Risk Factors

Item ~~1. Legal Proceedings~~2:

~~Item 1A. Risk Factors~~

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

Item 3. 3:

Defaults Upon Senior Securities

Item 4:

Mine Safety Disclosures

Item ~~4. Mine Safety Disclosure~~5:

Other Information

Item 6:

Exhibits

~~Item 5. Other Information~~SIGNATURES

~~Item 6. Exhibits~~

~~SIGNATURES~~

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~~Forward-Looking~~Forward Looking Statements

This Quarterly Report on Form 10-Q (herein, “Quarterly Report”) contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). ~~The~~All statements, ~~contained~~other than statements of historical fact included in this ~~report that are not historical facts~~Quarterly Report regarding our strategy, future operations, financial position, estimated revenues and expenses, projected costs, prospects, plans and objectives of management are forward-looking ~~statements that represent management’s beliefs and assumptions based on currently available information. Forward-looking statements include information concerning our possible~~statements. When used in this Quarterly Report, the words “may,” “will,” “could,” “would,” “should,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “plan,” “pursue,” “target,” “continue,” “potential,” “guidance,” “project” or ~~assumed future results of operations, business strategies, need for financing, competitive position, and potential growth opportunities. Our~~other similar expressions are intended to identify forward-looking statements, doalthough not ~~consider~~all forward-looking statements contain such identifying words. All forward-looking statements speak only as of the ~~effects~~date of future legislation or regulations. Forward-looking statements include all statements that are not historical facts and can be identified by the use of forward-looking terminology such as the words “believes,” “intends,” “may,” “should,” “anticipates,” “expects,” “could,” “plans,” “estimates,” “projects,” “targets” or comparable terminology or by discussions of strategy or trends.this Quarterly Report. Although we believe that ~~the~~our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Quarterly Report are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved. We are making investors aware that such forward-looking statements, ~~are reasonable, we cannot give any assurances that these expectations will prove~~because they relate to ~~be correct. Such statements~~future events, are by their very nature ~~involve risks and uncertainties that could significantly affect expected results, and actual future results could differ materially from those described in such forward-looking statements.~~

~~Among the~~subject to many important factors that could cause actual ~~future~~ results to differ materially from those contemplated. Such factors include:

•declines or volatility in the prices we receive for our oil and natural gas;

•our ability to raise additional capital to fund future capital expenditures;

•our ability to generate sufficient cash flow from operations, borrowings or other sources to enable us to fully develop and produce our oil and natural gas properties;

•general economic conditions, whether internationally, nationally or in the regional and local market areas in which we do business;

•risks associated with drilling, including completion risks, cost overruns, mechanical failures and the drilling of non-economic wells or dry holes;

•uncertainties associated with estimates of proved oil and natural gas reserves;

•the presence or recoverability of estimated oil and natural gas reserves and the actual future production rates and associated costs;

•the effects of inflation on our cost structure;

•substantial declines in the estimated values of our proved oil and natural gas reserves;

•our ability to replace our oil and natural gas reserves;

•the effects of rising interest rates on our cost of capital and the actions that central banks around the world undertake to control inflation, including the impacts such actions have on general economic conditions;

•unanticipated reductions in the borrowing base under the credit agreement we are party to;

•the potential for production decline rates and associated production costs for our wells to be greater than we forecast;

•risks and ~~uncertainties~~liabilities associated with acquired companies and properties;

•risks related to integration of acquired companies and properties;

•cost and availability of drilling rigs, equipment, supplies, personnel and oilfield services;

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•geological concentration of our reserves;

•the timing and extent of our success in acquiring, discovering, developing and producing oil and natural gas reserves;

•the possibility that acquisitions and divestitures may involve unexpected costs or delays, and that acquisitions may not achieve intended benefits;

•our dependence on the availability, use and disposal of water in our drilling, completion and production operations;

•significant competition for oil and natural gas acreage and acquisitions;

•environmental or other governmental regulations, including legislation related to hydraulic fracture stimulation and climate change measures;

•our ability to secure firm transportation for oil and natural gas we produce and to sell the oil and natural gas at market prices;

•future environmental, social and governance ("ESG") compliance developments and increased attention to such matters which could adversely affect our ability to raise equity and debt capital;

•management’s ability to execute our plans to meet our goals;

•the occurrence of cybersecurity incidents, attacks or other breaches to our information technology systems or on

systems and infrastructure used by the oil and gas industry;

•our ability to find and retain highly skilled personnel and our ability to retain key members of our management team on commercially reasonable terms;

•adverse weather conditions;

•costs and liabilities associated with environmental, health and safety laws;

•the effect of our oil and natural gas derivative activities;

•social unrest, political instability or armed conflict in major oil and natural gas producing regions outside the United States, including evolving geopolitical and military hostilities in the Middle East, Russia and Ukraine and acts of terrorism or sabotage;

•our insurance coverage may not adequately cover all losses that may be sustained in connection with our business activities;

•possible adverse results from litigation and the use of financial resources to defend ourselves; and

•the other factors discussed in ~~this report and~~Part I, Item 1A-- “Risk Factors” in our ~~annual report~~Annual Report on Form 10-K for the year ended December 31, ~~2021. While it is not possible~~2022, as well as in our condensed financial statements, related notes, and the other financial information appearing elsewhere in this Quarterly Report and our other reports filed from time to ~~identify all factors, we continue to face many risks~~time with the Securities and ~~uncertainties including, but not limited to:~~

Exchange Commission (the “SEC”).

●

~~risks and liabilities associated with acquired companies and properties;~~

●

~~risks related to integration of acquired companies and properties;~~

●

~~our ability to generate sufficient cash flows to service our significant indebtedness;~~

●

~~declines or volatility in the prices we receive for our oil and natural gas;~~

●

~~our ability to raise additional capital to fund future capital expenditures;~~

●

~~our ability to generate sufficient cash flow from operations, borrowings or other sources to enable us to fully develop and produce our oil and natural gas properties;~~

●

~~general economic conditions, whether internationally, nationally or in the regional and local market areas in which we do business;~~

●

~~risks associated with drilling, including completion risks, cost overruns and the drilling of non-economic wells or dry holes;~~

●

~~uncertainties associated with estimates of proved oil and natural gas reserves;~~

●

~~the presence or recoverability of estimated oil and natural gas reserves and the actual future production rates and associated costs;~~

●

~~potential defects in title to our properties;~~

●

~~cost and availability of drilling rigs, equipment, supplies, personnel and oilfield services;~~

●

~~geological concentration of our reserves;~~

●

~~environmental or other governmental regulations, including legislation of hydraulic fracture stimulation;~~

●

~~our ability to secure firm transportation for oil and natural gas we produce and to sell the oil and natural gas at market prices;~~

●

~~exploration and development risks;~~

●

~~management’s ability to execute our plans to meet our goals;~~

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●

~~our ability to retain key members of our management team on commercially reasonable terms;~~

●

~~the occurrence of cybersecurity incidents, attacks or other breaches to our information technology systems or on systems and infrastructure used by the oil and gas industry;~~

●

~~weather conditions;~~

●

~~effectiveness of our internal control over financial reporting;~~

●

~~actions or inactions of third-party operators of our properties;~~

●

~~costs and liabilities associated with environmental, health and safety laws;~~

●

~~our ability to find and retain highly skilled personnel;~~

●

~~operating hazards attendant to the oil and natural gas business;~~

●

~~competition in the oil and natural gas industry;~~

●

~~evolving geopolitical and military hostilities in the Middle East, Russia and Ukraine, and other areas of the world;~~

●

the ongoing COVID-19 pandemic and its mutations and variants, including reactive or proactive measures taken by businesses, governments and by other organizations related thereto, and the direct and indirect effects of COVID-19 on the market for and price of oil; and

●

~~the other factors discussed under “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended December 31, 2021.~~

Should our underlying assumptions prove incorrect or the consequences of the aforementioned risks worsen, actual results could differ materially from those expected. There may also be other risks and uncertainties that weReaders are ~~unable~~cautioned not to ~~predict at this time or that we do not now expect to have a material adverse impact~~place undue reliance on ~~our business.~~

~~Forward-looking~~forward-looking statements, which speak only as toof the date ~~hereof. All~~that such statements are made. We undertake no obligation to publicly update or revise any forward-looking statements ~~and any subsequent written or oral forward-looking statements attributable to us or any person acting on our behalf~~after the date they are expressly qualified in their entirety by the statements contained herein or referred to in this section and any other cautionary statements that may accompany such forward-looking statements. Except as otherwise required by applicable law, we disclaim any intention or obligation to update publicly or revise such statementsmade, whether as a result of new information, future events or otherwise.

Unless the context otherwise requires, references in this Quarterly Report to “Ring,” “Ring Energy,” the “Company,” “we,” “us,” “our” or “ours” refer to Ring Energy, Inc.

Table of Contents

PART I –— FINANCIAL INFORMATION

Item 1. Condensed Financial Statements

The following (a) condensed balance sheet as of December 31, 2022 which has been derived from our audited financial statements, and (b) the unaudited condensed financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission ~~(“SEC”~~("SEC"). Accordingly, certain disclosures ~~required~~ by accounting principles generally accepted in the United States ("GAAP") and normally included in Annual Reports on Form 10-K have been omitted. Although management believes that our disclosures are adequate to make the information presented not misleading, these unaudited interim condensed financial statements should be read in conjunction with the ~~Company’s~~Company's audited financial statements and related ~~footnotes~~notes included in its most recent Annual Report on Form 10-K.

Table of Contents

RING ENERGY, INC.

CONDENSED BALANCE SHEETS

(Unaudited)

September 30, 2022

December 31, 2021
ASSETS

Current Assets




Cash and cash equivalents

$
890,567

$
2,408,316
Accounts receivable

45,864,400

24,026,807
Joint interest billing receivable

1,897,125

2,433,811
Derivative assets

13,322,013

—
Prepaid expenses and other assets

3,246,569

938,029
Total Current Assets

65,220,674

29,806,963
Properties and Equipment

Oil and natural gas properties, full cost method

1,418,931,111

883,844,745
Financing lease asset subject to depreciation

2,067,375

1,422,487
Fixed assets subject to depreciation

2,985,778

2,089,722
Total Properties and Equipment

1,423,984,264

887,356,954
Accumulated depreciation, depletion and amortization

(269,541,416)

(235,997,307)
Net Properties and Equipment

1,154,442,848

651,359,647
Operating lease asset

1,071,482

1,277,253
Derivative assets

11,545,982

—
Deferred financing costs

19,029,907

1,713,466
Total Assets

$
1,251,310,893

$
684,157,329

LIABILITIES, MEZZANINE EQUITY AND STOCKHOLDERS’ EQUITY

Current Liabilities

Accounts payable

$
86,822,997

$
46,233,452
Income tax liability

36,736

—
Financing lease liability

406,890

316,514
Operating lease liability

306,715

290,766
Derivative liabilities

23,767,689

29,241,588
Notes payable

877,631

586,410
Deferred cash payment

14,511,687

—
Total Current Liabilities

126,730,345

76,668,730

Noncurrent Liabilities

Deferred income taxes

5,920,300

90,292
Revolving line of credit

435,000,000

290,000,000
Financing lease liability, less current portion

564,205

343,727
Operating lease liability, less current portion

905,524

1,138,319
Derivative liabilities

8,734,388

—
Asset retirement obligations

29,426,737

15,292,054
Total Liabilities

607,281,499

383,533,122
Mezzanine Equity

Convertible preferred stock - $0.001 par value; 153,176 shares outstanding

137,858,446

—
Stockholders’ Equity

Preferred stock - $0.001 par value; 50,000,000 shares authorized; 153,176 shares issued or outstanding

—

—
Common stock - $0.001 par value; 225,000,000 shares authorized; 131,586,927 shares and 100,192,562 shares issued and outstanding, respectively

131,587

100,193
Additional paid-in capital

634,845,283

553,472,292
Accumulated deficit

(128,805,922)

(252,948,278)
Total Stockholders’ Equity

506,170,948

300,624,207
Total Liabilities, Mezannine Equity and Stockholders’ Equity

$
1,251,310,893

$
684,157,329


	September 30, 2023		December 31, 2022
ASSETS
Current Assets
Cash and cash equivalents	$	138,581	$	3,712,526
Accounts receivable	45,756,047		42,448,719
Joint interest billing receivables, net	3,306,125		983,802
Derivative assets	1,845,133		4,669,162
Inventory	5,548,835		9,250,717
Prepaid expenses and other assets	2,033,013		2,101,538
Total Current Assets	58,627,734		63,166,464
Properties and Equipment
Oil and natural gas properties, full cost method	1,628,230,243		1,463,838,595
Financing lease asset subject to depreciation	3,306,372		3,019,476
Fixed assets subject to depreciation	2,946,274		3,147,125
Total Properties and Equipment	1,634,482,889		1,470,005,196
Accumulated depreciation, depletion and amortization	(353,111,293)		(289,935,259)
Net Properties and Equipment	1,281,371,596		1,180,069,937
Operating lease asset	2,644,519		1,735,013
Derivative assets	6,465,355		6,129,410
Deferred financing costs	14,199,738		17,898,973
Total Assets	$	1,363,308,942	$	1,268,999,797

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts payable	$	110,392,713	$	111,398,268
Income tax liability	264,261		—
Financing lease liability	806,993		709,653
Operating lease liability	503,420		398,362
Derivative liabilities	23,906,800		13,345,619
Notes payable	950,068		499,880
Deferred cash payment	14,783,879		14,807,276
Asset retirement obligations	279,681		635,843
Total Current Liabilities	151,887,815		141,794,901

Non-current Liabilities

Deferred income taxes	497,067		8,499,016
Revolving line of credit	428,000,000		415,000,000
Financing lease liability, less current portion	690,456		1,052,479
Operating lease liability, less current portion	2,207,248		1,473,897
Derivative liabilities	18,089,847		10,485,650
Asset retirement obligations	28,482,982		29,590,463
Total Liabilities	629,855,415		607,896,406
Commitments and contingencies
Stockholders' Equity
Preferred stock - $0.001 par value; 50,000,000 shares authorized; no shares issued or outstanding	—		—
Common stock - $0.001 par value; 450,000,000 shares authorized; 195,380,527 shares and 175,530,212 shares issued and outstanding, respectively	195,380		175,530
Additional paid-in capital	793,603,238		775,241,114
Accumulated deficit	(60,345,091)		(114,313,253)
Total Stockholders’ Equity	733,453,527		661,103,391
Total Liabilities and Stockholders' Equity	$	1,363,308,942	$	1,268,999,797

The accompanying notes are an integral part of these unaudited condensed financial statements.

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RING ENERGY, INC.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

For the Three Months

For the Nine Months

Ended September 30,

Ended September 30,

2022

2021

2022

2021
Oil Natural Gas and Natural Gas Liquids Revenues

$
94,408,948

$
49,376,176

$
247,551,855

$
136,638,810

Costs and Operating Expenses








Lease operating expenses

13,029,098

6,983,196

30,283,706

22,634,259
Gathering, transportation and processing costs

—

1,051,163

1,846,247

2,883,348
Ad valorem taxes

1,199,385

703,774

3,100,578

2,144,800
Oil and natural gas production taxes

4,563,519

2,240,759

11,939,338

6,291,860
Depreciation, depletion and amortization

14,324,502

9,310,524

34,854,993

26,693,808
Asset retirement obligation accretion

243,140

182,905

617,685

560,662
Operating lease expense

83,590

83,589

250,770

439,896
General and administrative expense

7,393,848

4,433,251

18,748,427

11,103,394
Total Costs and Operating Expenses

40,837,082

24,989,161

101,641,744

72,752,027

Income from Operations

53,571,866

24,387,015

145,910,111

63,886,783

Other Income (Expense)

Interest income

4

—

4

1
Interest (expense)

(7,021,385)

(3,551,462)

(13,699,045)

(10,947,960)
Gain (loss) on derivative contracts

32,851,189

(6,720,320)

(2,201,970)

(73,586,199)
Net Other Income (Expense)

25,829,808

(10,271,782)

(15,901,011)

(84,534,158)

Income (Loss) Before Provision for Income Taxes

79,401,674

14,115,233

130,009,100

(20,647,375)

Benefit from (Provision for) Income Taxes

(4,315,783)

48,701

(5,866,744)

(141,943)
Net Income (Loss)

$
75,085,891

$
14,163,934

$
124,142,356

$
(20,789,318)

Basic Earnings (Loss) per share

$
0.65

$
0.14

$
1.16

$
(0.21)
Diluted Earnings (Loss) per share

$
0.49

$
0.12

$
0.92

$
(0.21)


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022

Oil, Natural Gas, and Natural Gas Liquids Revenues	$	93,681,798	$	94,408,948	$	261,113,283	$	247,551,855

Costs and Operating Expenses
Lease operating expenses	18,015,348		13,029,098		51,426,145		30,283,706
Gathering, transportation and processing costs	(4,530)		—		(6,985)		1,846,247
Ad valorem taxes	1,779,163		1,199,385		5,120,119		3,100,578
Oil and natural gas production taxes	4,753,289		4,563,519		13,173,568		11,939,338
Depreciation, depletion and amortization	21,989,034		14,324,502		64,053,637		34,854,993
Asset retirement obligation accretion	354,175		243,140		1,073,900		617,685
Operating lease expense	138,220		83,590		366,711		250,770
General and administrative expense	7,083,574		7,393,848		21,023,956		18,748,427

Total Costs and Operating Expenses	54,108,273		40,837,082		156,231,051		101,641,744

Income from Operations	39,573,525		53,571,866		104,882,232		145,910,111

Other Income (Expense)
Interest income	80,426		4		160,171		4
Interest (expense)	(11,381,754)		(7,021,385)		(32,322,840)		(13,699,045)
Gain (loss) on derivative contracts	(39,222,755)		32,851,189		(26,483,190)		(2,201,970)
Gain (loss) on disposal of assets	—		—		(132,109)		—
Other income	—		—		126,210		—
Net Other Income (Expense)	(50,524,083)		25,829,808		(58,651,758)		(15,901,011)

Income (Loss) Before Benefit from (Provision for) Income Taxes	(10,950,558)		79,401,674		46,230,474		130,009,100

Benefit from (Provision for) Income Taxes	3,411,336		(4,315,783)		7,737,688		(5,866,744)
Net Income (Loss)	$	(7,539,222)	$	75,085,891	$	53,968,162	$	124,142,356

Basic Earnings (Loss) per Share	$	(0.04)	$	0.65	$	0.29	$	1.16
Diluted Earnings (Loss) per Share	$	(0.04)	$	0.49	$	0.28	$	0.92

The accompanying notes are an integral part of these unaudited condensed financial statements.

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RING ENERGY, INC.

CONDENSED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Unaudited)

Additional

Retained Earnings

Total

Common Stock

Paid-in

(Accumulated

Stockholders’
For the Nine Months Ended September 30, 2022

Shares

Amount

Capital

Deficit)

Equity
Balance, December 31, 2021

100,192,562

$
100,193

$
553,472,292

$
(252,948,278)

$
300,624,207
Share-based compensation

—

—

1,521,910

—

1,521,910
Net income

—

—

—

7,112,043

7,112,043
Balance, March 31, 2022

100,192,562

$
100,193

$
554,994,202

$
(245,836,235)

$
309,258,160
Exercise of common warrants issued in offering

6,453,907

6,454

5,156,672

—

5,163,126
Options exercised

100,000

100

(100)

—

—
Shares elected to be withheld for options exercised

(47,506)

(48)

48

—

—
Restricted stock vested

610,195

610

(610)

—

—
Shares to cover tax withholdings for restricted stock vested

(73,047)

(73)

73

—

—
Payments to cover tax withholdings for restricted stock vested

—

—

(257,694)

—

(257,694)
Share-based compensation

—

—

1,899,245

—

1,899,245
Net income

—

—

—

41,944,422

41,944,422
Balance, June 30, 2022

107,236,111

$
107,236

$
561,791,836

$
(203,891,813)

$
358,007,259
Exercise of common warrants issued in offering

3,000,000

3,000

2,397,000

—

2,400,000
Restricted stock vested

13,504

14

(14)

—

—
Shares to cover tax withholdings for restricted stock vested

(2,674)

(3)

3

—

—
Payments to cover tax withholdings for restricted stock vested

—

—

(6,790)

—

(6,790)
Common stock issuance for Stronghold

21,339,986

21,340

69,120,215

—

69,141,555
Share-based compensation

—

—

1,543,033

—

1,543,033
Net income

—

—

—

75,085,891

75,085,891
Balance, September 30, 2022

131,586,927

$
131,587

$
634,845,283

$
(128,805,922)

$
506,170,948

For the Nine Months Ended September 30, 2021

Balance, December 31, 2020

85,568,287

$
85,568

$
550,951,415

$
(256,271,170)

$
294,765,813
Common stock and warrants issued for cash, net

—

—

(65,000)

—

(65,000)
Exercise of pre-funded warrants issued in offering

13,428,500

13,429

—

—

13,429
Exercise of common warrants issued in offering

184,800

185

147,655

—

147,840
Restricted stock vested

94,350

94

(94)

—

—
Share-based compensation

—

—

355,494

—

355,494
Net (loss)

—

—

—

(19,066,093)

(19,066,093)
Balance, March 31, 2021

99,275,937

$
99,276

$
551,389,470

$
(275,337,263)

$
276,151,483
Exercise of common warrants issued in offering

100,000

100

79,900

—

80,000
Restricted stock vested

3,480

3

(3)

—

—
Shares to cover tax withholdings for restricted stock vested

(28,272)

(28)

28

—

—
Share-based compensation

—

—

351,775

—

351,775
Net (loss)

—

—

—

(15,887,159)

(15,887,159)
Balance, June 30, 2021

99,351,145

$
99,351

$
551,821,170

$
(291,224,422)

$
260,696,099
Restricted stock vested

12,500

13

(13)

—

—
Shares to cover tax withholdings for restricted stock vested

(3,707)

(4)

4

—

—
Share-based compensation

—

777,461

—

777,461
Net income

—

—

14,163,934

14,163,934
Balance, September 30, 2021

99,359,938

$
99,360

$
552,598,622

$
(277,060,488)

$
275,637,494


	Common Stock			Additional Paid-in Capital		Retained Earnings (Accumulated Deficit)		Total Stockholders' Equity
For the Nine Months Ended September 30, 2023	Shares	Amount
Balance, December 31, 2022	175,530,212	$	175,530	$	775,241,114	$	(114,313,253)	$	661,103,391
Exercise of common warrants issued in offering	4,517,427	4,517		3,609,424		—		3,613,941


Restricted stock vested	659,479	659		(659)		—		—
Shares to cover tax withholdings for restricted stock vested	(79,634)	(79)		79		—		—
Payments to cover tax withholdings for restricted stock vested, net	—	—		(134,381)		—		(134,381)


Share-based compensation	—	—		1,943,696		—		1,943,696
Net income	—	—		—		32,715,779		32,715,779
Balance, March 31, 2023	180,627,484	$	180,627	$	780,659,273	$	(81,597,474)	$	699,242,426
Induced exercise of common warrants issued in offering	14,512,166	14,512		8,673,143		—		8,687,655


Restricted stock vested	288,709	289		(289)		—		—
Shares to cover tax withholdings for restricted stock vested	(77,687)	(78)		78		—		—
Payments to cover tax withholdings for restricted stock vested, net	—	—		(141,682)		—		(141,682)


Share-based compensation	—	—		2,260,312		—		2,260,312
Net income	—	—		—		28,791,605		28,791,605
Balance, June 30, 2023	195,350,672	$	195,350	$	791,450,835	$	(52,805,869)	$	738,840,316



Restricted stock vested	39,443	39		(39)		—		—
Shares to cover tax withholdings for restricted stock vested	(9,588)	(9)		9		—		—
Payments to cover tax withholdings for restricted stock vested, net	—	—		(18,302)		—		(18,302)


Share-based compensation	—	—		2,170,735		—		2,170,735
Net loss	—	—		—		(7,539,222)		(7,539,222)
Balance, September 30, 2023	195,380,527	$	195,380	$	793,603,238	$	(60,345,091)	$	733,453,527

For the Nine Months Ended September 30, 2022
Balance, December 31, 2021	100,192,562	$	100,193	$	553,472,292	$	(252,948,278)	$	300,624,207
Share-based compensation	—	—		1,521,910		—		1,521,910
Net income	—	—		—		7,112,043		7,112,043
Balance, March 31, 2022	100,192,562	$	100,193	$	554,994,202	$	(245,836,235)	$	309,258,160
Exercise of common warrants issued in offering	6,453,907	6,454		5,156,672		—		5,163,126
Options exercised	100,000	100		(100)		—		—
Shares elected to be withheld for options exercised	(47,506)	(48)		48		—		—
Restricted stock vested	610,195	610		(610)		—		—
Shares to cover tax withholdings for restricted stock vested	(73,047)	(73)		73		—		—
Payments to cover tax withholdings for restricted stock vested	—	—		(257,694)		—		(257,694)
Share-based compensation	—	—		1,899,245		—		1,899,245
Net income	—	—		—		41,944,422		41,944,422
Balance, June 30, 2022	107,236,111	$	107,236	$	561,791,836	$	(203,891,813)	$	358,007,259
Exercise of common warrants issued in offering	3,000,000	3,000		2,397,000		—		2,400,000
Restricted stock vested	13,504	14		(14)		—		—
Shares to cover tax withholdings for restricted stock vested	(2,674)	(3)		3		—		—
Payments to cover tax withholdings for restricted stock vested	—	—		(6,790)		—		(6,790)
Common stock issuance for Stronghold acquisition	21,339,986	21,340		69,120,215		—		69,141,555
Share-based compensation	—	—		1,543,033		—		1,543,033
Net income	—	—		—		75,085,891		75,085,891
Balance, September 30, 2022	131,586,927	$	131,587	$	634,845,283	$	(128,805,922)	$	506,170,948

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RING ENERGY, INC.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended
	September 30, 2023		September 30, 2022
Cash Flows From Operating Activities
Net income (loss)	$	53,968,162	$	124,142,356
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	64,053,637		34,854,993
Asset retirement obligation accretion	1,073,900		617,685
Amortization of deferred financing costs	3,699,235		1,483,621
Share-based compensation	6,374,743		4,964,188
Bad debt expense	41,865		—
Deferred income tax expense (benefit)	(8,160,712)		5,830,008
Excess tax expense (benefit) related to share-based compensation	158,763		—
(Gain) loss on derivative contracts	26,483,190		2,201,970
Cash received (paid) for derivative settlements, net	(5,829,728)		(48,593,882)
Changes in operating assets and liabilities:
Accounts receivable	(5,671,516)		(21,300,907)
Inventory	3,701,882		—
Prepaid expenses and other assets	68,525		(2,308,540)
Accounts payable	3,500,913		33,992,075
Settlement of asset retirement obligation	(1,025,607)		(2,548,344)
Net Cash Provided by Operating Activities	142,437,252		133,335,223
Cash Flows From Investing Activities
Payments for the Stronghold Acquisition	(18,511,170)		(183,359,626)
Payments for the Founders Acquisition	(49,902,757)		—
Payments to purchase oil and natural gas properties	(1,605,262)		(1,211,691)
Payments to develop oil and natural gas properties	(112,996,032)		(83,776,050)
Payments to acquire or improve fixed assets subject to depreciation	(209,798)		(158,598)
Sale of fixed assets subject to depreciation	332,230		134,600
Proceeds from divestiture of equipment for oil and natural gas properties	54,558		25,066
Proceeds from sale of Delaware properties	7,608,692		—
Proceeds from sale of New Mexico properties	4,312,502		—
Net Cash (Used in) Investing Activities	(170,917,037)		(268,346,299)
Cash Flows From Financing Activities
Proceeds from revolving line of credit	179,000,000		592,000,000
Payments on revolving line of credit	(166,000,000)		(447,000,000)
Proceeds from issuance of common stock from warrant exercises	12,301,596		7,563,126

Payments for taxes withheld on vested restricted shares, net	(294,365)		(264,484)
Proceeds from notes payable	1,565,071		1,245,303
Payments on notes payable	(1,114,883)		(954,082)
Payment of deferred financing costs	—		(18,762,502)
Reduction of financing lease liabilities	(551,579)		(334,034)
Net Cash Provided by (Used in) Financing Activities	24,905,840		133,493,327
Net Increase (Decrease) in Cash	(3,573,945)		(1,517,749)
Cash at Beginning of Period	3,712,526		2,408,316
Cash at End of Period	$	138,581	$	890,567

Table of Contents

For the Nine Months

Ended September 30,

2022

2021
Cash Flows From Operating Activities

Net income (loss)

$
124,142,356

$
(20,789,318)
Adjustments to reconcile net income to net cash provided by (used in) operating activities:

Depreciation, depletion and amortization

34,854,993

26,693,808
Asset retirement obligation accretion

617,685

560,662
Amortization of deferred financing costs

1,483,621

496,533
Share-based compensation

4,964,188

1,484,730
Deferred income tax expense (benefit)

5,830,008

141,943
Loss on derivative contracts

2,201,970

73,586,199
Cash (paid) for derivative settlements, net

(48,593,882)

(33,278,132)
Changes in assets and liabilities:

Accounts receivable

(21,300,907)

(5,017,078)
Prepaid expenses and other assets

(2,308,540)

(902,692)
Accounts payable

33,992,075

8,329,563
Settlement of asset retirement obligation

(2,548,344)

(1,782,779)
Net Cash Provided by (Used In) Operating Activities

133,335,223

49,523,439
Cash Flows From Investing Activities

Payments for the Stronghold Acquisition

(183,359,626)

—
Payments to purchase oil and natural gas properties

(1,211,691)

(579,156)
Payments to develop oil and natural gas properties

(83,776,050)

(34,680,935)
Purchase of fixed assets subject to depreciation

(158,598)

(609,633)
Sale of fixed assets subject to depreciation

134,600

—
Proceeds from divestiture of oil and natural gas properties

25,066

2,000,000
Net Cash Provided by (Used in) Investing Activities

(268,346,299)

(33,869,724)
Cash Flows From Financing Activities

Proceeds from revolving line of credit

592,000,000

34,400,000
Payments on revolving line of credit

(447,000,000)

(52,400,000)
Proceeds from issuance of common stock and warrants

7,563,126

241,269
Payments to cover tax withholdings for restricted stock vested

(264,484)

—
Proceeds from notes payable

1,245,303

1,233,138
Payments on notes payable

(954,082)

(375,987)
Payment of deferred financing costs

(18,762,502)

(76,887)
Reduction of financing lease liabilities

(334,034)

(206,936)
Net Cash Provided by (Used in) Financing Activities

133,493,327

(17,185,403)
Net Change in Cash

(1,517,749)

(1,531,688)
Cash at Beginning of Period

2,408,316

3,578,634
Cash at End of Period

$
890,567

$
2,046,946

RING ENERGY, INC.

STATEMENTS OF CASH FLOWS (CONTINUED)


	For the Nine Months Ended
	September 30, 2023		September 30, 2022
Supplemental Cash Flow Information
Cash paid for interest	$	27,804,707	$	12,371,753

Noncash Investing and Financing Activities
Asset retirement obligation incurred during development	$	261,786	$	218,082
Asset retirement obligation acquired	2,090,777		14,538,550
Asset retirement obligation revision of estimate	53,824		—
Asset retirement obligation sold	(4,717,507)		—
Operating lease assets obtained in exchange for new operating lease liability	1,713,677		—

Financing lease assets obtained in exchange for new financing lease liability	305,052		—

Capitalized expenditures attributable to drilling projects financed through current liabilities	(1,394,081)		13,233,975

Supplemental Schedule for Founders Acquisition
Investing Activities - Cash Paid
Escrow deposit released at closing	$	7,500,000	$	—
Closing amount paid to Founders	42,502,799		—
Interest from escrow deposit	1,747		—
Direct transaction costs	1,361,843		—
Post-close adjustments	(1,463,632)		—
Payments for the Founders Acquisition	$	49,902,757	$	—
Investing Activities - Noncash
Assumption of suspense liability	$	677,116	$	—
Assumption of asset retirement obligation	2,090,777		—
Assumption of ad valorem tax liability	234,051		—
Deferred cash payment at fair value	14,657,383		—

Supplemental Schedule for Stronghold Acquisition
Investing Activities - Cash Paid
Cash paid by bank to Stronghold on closing	$	—	$	121,392,455
Deposit in escrow	—		46,500,000
Direct transaction costs	—		9,162,143
Cash paid for realized August oil derivative losses	—		1,777,925
Cash paid for inventory and fixed assets acquired	—		4,527,103

Payment of deferred cash payment	15,000,000		—
Payment of post-close settlement	3,511,170		—
Payments for the Stronghold Acquisition	$	18,511,170	$	183,359,626
Investing Activities - Noncash
Assumption of suspense liability	$	—	$	1,651,596
Assumption of derivative liabilities	—		24,784,406
Assumption of asset retirement obligation	—		14,538,550
Deferred cash payment at fair value	—		14,511,688
Financing Activities - Noncash
Common stock issued for acquisition	$	—	$	69,141,555
Convertible preferred stock issued for acquisition	—		137,858,446

The accompanying notes are an integral part of these unaudited condensed financial statements.

Table of Contents

RING ENERGY, INC.

~~CONDENSED STATEMENTS OF CASH FLOWS~~

~~(Unaudited)~~

For the Nine Months

Ended September 30,

2022

2021
Supplemental Cash Flow Information

Cash paid for interest

$
12,371,753

$
10,622,077

Noncash Investing and Financing Activities

Asset retirement obligation incurred during development

$
218,082

$
160,285
Asset retirement obligation acquired

14,538,550

662,704
Asset retirement obligation revisions

—

153,475
Asset retirement obligation sold

—

(2,934,126)
Capitalized expenditures attributable to drilling projects financed through current liabilities

13,233,975

5,921,816
Operating lease assets obtained in exchange for new operating lease liability

—

839,536
Operating lease asset revision

—

(621,636)
Supplemental Schedule for Stronghold Acquisition

Investing Activities - Cash Paid

Cash paid by bank to Stronghold on closing

$
121,392,455

$
—
Deposit in escrow

46,500,000

—
Direct transaction costs

9,162,143

—
Cash paid for realized August oil derivative losses

1,777,925

—
Cash paid for inventory and fixed assets acquired

4,527,103

—
Payments for the Stronghold Acquisition

$
183,359,626

$
—

Investing Activities - Noncash

Assumption of suspense liability

1,651,596

—
Assumption of derivative liabilities

24,784,406

—
Assumption of asset retirement obligation

14,538,550

—
Deferred cash payment at fair value

14,511,688

—

Financing Activities - Noncash

Common stock issued for acquisition

69,141,555

—
Convertible preferred stock issued for acquisition

$
137,858,446

$
—

~~Table of Contents~~

~~The accompanying notes are an integral part of these unaudited condensed financial statements.~~

~~Table of Contents~~

~~RING ENERGY, INC.~~

NOTES TO CONDENSED FINANCIAL STATEMENTS

~~(UNAUDITED)~~

(UNAUDITED)

Index to the Notes to the Condensed Financial Statements


Note 1 — Basis of Presentation & Significant Accounting Policies			Note 8 — Revolving Line of Credit
Note 2 — Revenue Recognition			Note 9 — Asset Retirement Obligation
Note 3 — Leases			Note 10 — Stockholders' Equity
Note 4 — Earnings Per Share Information			Note 11 — Employee Stock Options and Restricted Stock Units
Note 5 — Acquisitions and Divestitures			Note 12 — Commitments and Contingencies
Note 6 — Derivative Financial Instruments			Note 13 — Subsequent Events
Note 7 — Fair Value Measurements

NOTE 1 –— BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Condensed Financial Statements – The accompanying condensed financial statements prepared by Ring Energy, Inc., a Nevada corporation (the ~~“Company”~~“Company,” "Ring Energy," “Ring,” "we," "us," or ~~“Ring”~~"our"), have not been audited by an independent registered public accounting firm. In the opinion of the Company’s management, the accompanying unaudited condensed ~~unaudited~~ financial statements contain all adjustments necessary for fair presentation of the results of operations for the periods presented, which adjustments were of a normal recurring nature, except as disclosed herein. The condensed results of operations for the three and nine months ended September 30, ~~2022,~~2023, are not necessarily indicative of the results to be expected for the full year ending December 31, ~~2022,~~2023, for various reasons, including the impact of fluctuations in prices received for oil and natural gas, natural production declines, the uncertainty of exploration and development drilling results, fluctuations in the fair value of derivative instruments, and other factors.

These unaudited condensed financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) applicable to interim financial information, and, accordingly, do not include all of the information and ~~footnotes~~notes required by GAAP for complete financial statements. Therefore, these condensed financial statements should be read in conjunction with the financial statements and notes included in the Company’s annual report on Form 10-K for the year ended December 31, ~~2021.~~

2022.

Organization and Nature of Operations – ~~The Company~~Ring Energy is a ~~Nevada corporation that owns interests~~growth oriented independent exploration and production company based in The Woodlands, Texas engaged in oil and natural gas ~~properties~~development, production, acquisition, and exploration activities currently focused in ~~Texas and New Mexico. The Company’s~~Texas. Our primary drilling operations target the oil and ~~natural gas sales, profitability and future growth are dependent upon prevailing and future prices for oil and natural gas~~liquids rich producing formations in the Northwest Shelf and the ~~successful acquisition, exploration and development~~Central Basin Platform, both of oil and natural gas properties. Oil and natural gas prices have historically been volatile and may be subject to wide fluctuations in the future. A substantial decline in oil and natural gas prices could have a material adverse effect on the Company’s financial position, results of operations, cash flows and quantities of oil and natural gas reserves that may be economically produced.

~~COVID-19 –~~ In March 2020, the World Health Organization classified the outbreak of COVID-19 as a pandemic. The nature of COVID-19 led to worldwide shutdowns, reductions in commercial and interpersonal activity and changes in consumer behavior. In attempting to control the spread of COVID-19, governments around the world imposed laws and regulations such as shelter-in-place orders, quarantines, executive orders and similar restrictions. As a result, the global economy was marked by significant slowdown and uncertainty, which ~~in turn led to a precipitous decline in oil prices in response to decreased demand, further exacerbated by global energy storage shortages and by the price war among members~~are part of the Organization of Petroleum Exporting Countries (“OPEC”) and other non-OPEC producer nations (collectively with OPEC members, “OPEC+”) during the first quarter 2020. Prices recovered to pre-pandemic levels in 2021 and have recently increased to levels not seen since 2014, due in part to the accessibility of vaccines, reopening of states and other regions around the world after lockdowns, and optimism about the economic recovery. The renewed spread of COVID-19, including vaccine-resistant strains or variants, or another deterioration in oil and natural gas prices could result in additional adverse impacts on the Company’s results of operations, cash flows and financial position, including asset impairments/charges.

Permian Basin.

Liquidity and Capital Considerations – The Company strives to maintain an adequate liquidity level to address volatility and risk. Sources of liquidity include the Company’s cash flow from operations, cash on hand, available borrowing capacity under its revolving ~~Credit Facility (defined below in Note 8),~~credit facility, and proceeds from sales of non-strategic assets.

While changes in oil and natural gas prices affect the Company’s liquidity, the Company has put in place hedges in seeking to protect ~~to some extent,~~a substantial portion of its cash flows from ~~such~~ price declines; however, if oil or natural gas prices rapidly deteriorate due to unanticipated economic conditions, this could still have a material adverse effect on the Company’s cash ~~flows in spite of our hedging activities.~~

flows.

The Company expects ongoing oil price volatility over ~~the short~~an indeterminate term. Extended depressed oil prices have historically had and could have a material adverse impact on the Company’s oil revenue, which ~~may be~~is mitigated to some extent by the Company’s hedge contracts. The Company is always mindful of oil price volatility and its impact on ~~the Company’s~~our liquidity.

The Company believes that it has the ability to continue to fund its operations and service its debt by using cash ~~on hand and cash~~ flows from operations.

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Use of Estimates – The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities and the reported amounts of revenues and expenses during the reporting period. The Company’s unaudited condensed financial statements are based on a number of significant estimates, including estimates of oil and natural gas reserve quantities, which are the basis for the calculation of depletion and impairment of oil and gas properties. Reserve estimates, by their nature, are inherently imprecise. Actual results could differ from those estimates. Changes in the future

Table of Contents

estimated oil and natural gas reserves or the estimated future cash flows attributable to the reserves that are utilized for impairment analysis could have a significant impact on the Company’s future results of operations.

Fair Value Measurements – - Fair value is 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 (exit price). The Financial Accounting Standards Board (“FASB”) has established a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. This hierarchy consists of three broad levels. Level 1 inputs are the highest priority and consist of unadjusted quoted prices in active markets for identical assets and liabilities. Level 2 are inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly. Level 3 are unobservable inputs for an asset or liability.

Fair Values of Financial Instruments – The carrying amounts reported for ~~the~~our revolving line of credit approximate their fair value because the underlying instruments are at interest rates which approximate current market rates. The carrying amounts of accounts receivables and accounts payable and other current assets and liabilities approximate fair value because of the short-term maturities and/or liquid nature of these assets and liabilities.

Fair Value of Non-financial Assets and Liabilities – The Company also applies fair value accounting guidance to initially, or as events dictate, measure non-financial assets and liabilities such as those obtained through business acquisitions, property and equipment and asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. Fair value may be estimated using comparable market data, a discounted cash flow method, or a combination of the two as considered appropriate based on the circumstances. Under the discounted cash flow method, estimated future cash flows are based on management’s expectations for the future and include estimates of future oil and natural gas production or other applicable sales estimates, operational costs and a risk-adjusted discount rate. The Company may use the present value of estimated future cash inflows and/or outflows or third-party offers or prices of comparable assets with consideration of current market conditions to value its non-financial assets and liabilities when circumstances dictate determining fair value is necessary. Given the significance of the unobservable nature of a number of the inputs, these are considered Level 3 on the fair value hierarchy.

Derivative Instruments and ~~Commodity Risk~~Hedging Activities – The Company ~~may~~ periodically ~~enter~~enters into derivative contracts to manage its exposure to commodity price risk. These derivative contracts, which are generally placed with major financial institutions, may take the form of forward contracts, futures contracts, swaps or options. The oil and gas reference prices upon which the commodity derivative contracts are based reflect various market indices that have a high degree of historical correlation with actual prices received by the Company for its oil and gas production.

~~Any~~

As the Company has not designated its derivative instruments as hedges for accounting purposes, any gains or losses resulting from changes in fair value of outstanding derivative financial instruments and from the settlement of derivative financial instruments are recognized in earnings and included as a component of ~~Other~~other income (expense) in the Condensed Statements of Operations.

When applicable, the Company records all derivative instruments, other than those that meet the normal purchases and sales exception, on the ~~Balance Sheets~~balance sheet as either an asset or liability measured at fair value. Changes in fair value are recognized currently in earnings unless specific hedge accounting criteria are met. ~~The change in fair value resulted in the recognition of an unrealized gain of $47,712,305~~See "NOTE 6 — DERIVATIVE FINANCIAL INSTRUMENTS" below for the three months ended September 30, 2022 and an unrealized gain of $46,391,912 for the nine months ended September 30, 2022. During the three and nine months ended September 30, 2021, the change in fair value resulted in the recognition of an unrealized gain of $8,200,688 and an unrealized loss of $40,308,067, respectively, on derivative contracts. During the three and nine months ended September 30, 2022, the Company had realized losses of $14,861,116 and $48,593,882, respectively, on derivatives. During the three and nine months ended September 30, 2021, the Company had realized losses of $14,921,008 and $33,278,132, respectively, on derivatives net of a realized gain of $581,424 in March 2021 from unwinding the Company’s then held gas swaps.

additional information.

Concentration of Credit Risk and ~~Major Customers~~Receivables – Financial instruments that potentially subject the Company to a concentration of credit risk consist principally of cash and receivables.

Cash and cash equivalents - The Company had ~~$640,522 of cash on deposit in excess of federally insured limits at September 30, 2022 and $1,936,805 of~~ cash in excess of federally insured limits atof $0 and $3,462,526 as of September 30, 2023 and December 31, ~~2021.~~2022, respectively. The Company places its cash with a high credit quality financial institution. The Company has not experienced any losses in such accounts and believes it is not exposed to significant credit risk in this area.

Accounts receivable - Substantially all of the Company’s accounts receivable is from purchasers of oil and natural gas. Oil and natural gas sales are generally unsecured. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectable. During the nine months ended September 30, ~~2022,~~2023, sales to ~~two customers~~three purchasers represented ~~69%~~67%, 12% and 4%10%, respectively, of ~~the Company’s~~total oil, natural gas, and natural gas ~~revenues. At~~liquids sales. As of September 30, ~~2022,~~2023, receivables outstanding from these ~~two customers made up 58%~~three purchasers represented 69%, 9% and ~~12%~~7%, respectively, of accounts receivable.

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Production imbalances- The Company accounts for natural gas production imbalances using the sales method, which recognizes revenue on all natural gas sold even though the natural gas volumes sold may be more or less than the Company's ownership entitles it to sell. Liabilities are recorded for imbalances greater than the Company’s ~~accounts receivable.~~

Atproportionate share of remaining estimated natural gas reserves.The Company recorded no imbalances as of September 30, ~~2022, approximately 94% of the Company’s accounts receivables and joint~~2023 or December 31, 2022.

Joint interest billing receivables, ~~are from purchasers of oil and gas. Oil and gas sales are generally unsecured.~~ net - The Company also has joint interest billing receivables. Joint interest billing receivables ~~which~~ are collateralized by the pro rata revenue attributable to the joint interest holders and further by the interest itself. Accounts receivable from joint interest owners or purchasers outstanding longer than the contractual payment terms are considered past ~~due.The Company has not had any significant credit losses in~~due. The following table indicates the ~~past and believes~~Company's provisions for bad debt expense associated with its ~~accounts and~~ joint interest billing receivables ~~are collectable. Accordingly, no material~~during the three and nine months ended September 30, 2023 and September 30, 2022.


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Bad debt expense	$	19,656	$	—	$	41,865	$	—

The following table reflects the Company's joint interest billing receivables and allowance for credit losses ~~has been provided at~~as of September 30, 2023 and December 31, 2022.


	September 30, 2023		December 31, 2022
Joint interest billing receivables	$	3,484,616	$	1,226,049
Allowance for credit losses	(178,491)		(242,247)
Joint interest billing receivables, net	$	3,306,125	$	983,802

The reduction of $63,756 in the allowance for credit losses during the nine months ended September 30, 2023 was primarily due to a clearing of $105,620 in allowances that were associated with the Delaware Basin asset sale, offset by new allowances booked (see NOTE 5 — ACQUISITIONS AND DIVESTITURES for more detail).

~~Table~~Cash and Cash Equivalents – The Company considers all highly liquid investments purchased with an original maturity of ~~Contents~~three months or less to be cash equivalents. At September 30, 2023 and December 31, 2022, the Company had no such investments.

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Inventory - The full balance of the Company's inventory consists of materials and supplies for its operations, with no work in process or finished goods inventory balances. Inventory is added to the books upon the purchase of supplies (inclusive of freight and sales tax costs) to use on well sites, and inventory is reduced by material transfers for inventory usage based on the initial invoiced value. The Company reports the balance of its inventory at the lower of cost or net realizable value. Inventory balances are excluded from the Company's calculation of depletion.

Oil and Natural Gas Properties – The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all costs (direct and indirect) associated with ~~the~~ acquisition, ~~leasing,~~ exploration, and development of oil and natural gas ~~reserves~~properties are capitalized. Costs capitalized include acquisition costs, ~~estimated future costs of abandonment and site restoration,~~ geological and geophysical expenditures, lease rentals on undeveloped properties and costs of drilling and equipping productive ~~wells~~ and ~~drilling costs for~~ non-productive wells. Drilling costs include directly related overhead costs. Capitalized costs are ~~generally~~ categorized either as being subject to amortization or not subject to amortization. All of the Company’s capitalized costs, excluding inventory, are subject to amortization.

All capitalized costs of oil and gas properties, plus estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves as determined by the Company’s independent petroleum engineers. The Company evaluates oil and gas properties for impairment quarterly. The Company did not incur a write down of oil and natural gas properties as a result of the ceiling test for the three and nine months ended September 30, 2022 or for the three and nine months ended September 30, 2021. Depreciation, depletion and amortization expense for the three and nine months ended September 30, 2022 was $14,324,502 and $34,854,993, respectively, based on depletion at the rate of $11.59 and $11.95, respectively, per barrel of oil equivalent compared to $9,310,524 and $26,693,808, respectively, based on depletion at the rate of $12.12 and $11.64 per barrel of oil equivalent for the three and nine months ended September 30, 2021. These amounts include $160,928 and $437,015, respectively, of depreciation and amortization for the three and nine months ended September 30, 2022, compared to $120,817 and $276,677, respectively, of depreciation and amortization for the three and nine months ended September 30, 2021.

~~Equipment, Vehicles and Leasehold Improvements~~ – Office equipment and vehicles are valued at historical cost adjusted for impairment loss less accumulated depreciation. Historical costs include all direct costs associated with the acquisition of office equipment and placing such equipment in service. Depreciation is calculated using the straight-line method based upon an estimated useful life of 3 to 10 years.

~~Asset Retirement Obligation~~ –

The Company records a liability in the period in which an asset retirement obligation (“ARO”) is incurred, in an amount equal to the discounted estimated fair value of the obligation that is capitalized. Thereafter this liability is accreted up to the final ~~estimated~~ retirement cost. An ARO is a future expenditure related to the disposal or other retirement of certain assets. The Company’s ARO relates to future plugging and abandonment expenses of its oil and natural gas properties and related facilities disposal.

Dispositions of oil and natural gas properties are accounted for as adjustments to capitalized costs.

All capitalized costs of oil and natural gas properties, including the estimated future costs to develop proved reserves and estimated future costs to plug and abandon wells and costs of site restoration, less the estimated salvage value of equipment associated with the oil and natural gas properties, are amortized on the unit-of-production method using estimates of proved reserves as determined by independent petroleum engineers. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is offset to the capitalized costs to be amortized. The following table shows total

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depletion and the depletion per barrel-of-oil-equivalent rate, for the three and nine months ended September 30, 2023 and 2022.


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Depletion	$	21,711,123	$	14,163,574	$	63,203,473	$	34,417,978
Depletion rate, per barrel-of-oil-equivalent (Boe)	$	13.48	$	11.59	$	13.09	$	11.95

In addition, capitalized costs less accumulated depreciation, depletion and amortization and related deferred income taxes are not allowed to exceed an amount (the full cost ceiling) equal to the sum of:

1)the present value of estimated future net revenues discounted at ten percent computed in compliance with SEC guidelines;

2)plus the cost of properties not being amortized;

3)plus the lower of cost or estimated fair value of unproven properties included in the costs being amortized;

4)less income tax effects related to differences between the book and tax basis of the properties.

Land, Buildings, Equipment, Software, Leasehold Improvements, and Automobiles – Land, buildings, equipment, software, leasehold improvements, and automobiles are carried at historical cost, adjusted for impairment loss and accumulated depreciation (except for land). Historical costs include all direct costs associated with the acquisition of land, buildings, equipment, software, leasehold improvements, and automobiles and placing them in service. Upon sale or abandonment, the cost of the fixed asset(s) and related accumulated depreciation are removed from the accounts and any gain or loss is recognized.

Depreciation of buildings, equipment, software, leasehold improvements, and automobiles is calculated using the straight-line method based upon the following estimated useful lives:


Leasehold improvements						3‑5 years
Office equipment and software						3‑7 years
Equipment						5‑10 years
Automobiles						4 years
Buildings and structures						7 years

The following table provides information on the Company's depreciation expense for the three and nine months ended September 30, 2023 and 2022.


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Depreciation	$	80,690	$	53,946	$	277,420	$	102,568

Notes Payable – At the end of May 2023, the Company renewed its control of well, general liability, pollution, umbrella, property, workers' compensation, auto, and D&O (directors and officers) insurance policies, and funded the premiums with a promissory note with a total face value after down payments of $1,565,071. The annual percentage rate (APR) for this note is 7.08%. As of September 30, 2023, the notes payable balance included in current liabilities on the Condensed Balance Sheet is $950,068. The following table shows interest paid related to notes payable for the three and nine months ended September 30, 2023 and 2022. This interest is included within "Interest (expense)" in the Condensed Statements of Operations.


	Three Months Ended				Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Interest paid for notes payable	$	22,286	$	7,917	$	35,211	$	17,201

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Revenue Recognition – In January 2018, the Company adopted Accounting Standards Update (“ASU”) 2014-09 Revenues from Contracts with Customers (Topic 606) (“ASU 2014-09”). The timing of recognizing revenue from the sale of produced crude oil and natural gas was not changed as a result of adopting ASU 2014-09. The Company predominantly derives its revenue from the sale of produced crude oil and natural gas. The contractual performance obligation is satisfied when the product is delivered to the purchaser. Revenue is recorded in the month the product is delivered to the purchaser. The Company receives payment from one to three months after delivery. The transaction price includes variable consideration as product pricing is based on published market prices and reduced for contract specified differentials (quality, transportation and other variables from benchmark prices). The guidance regarding ASU 2014-09 does not require that the transaction price be fixed or stated in the contract. Estimating the variable consideration does not require significant judgment and Ring engages third party sources to validate the estimates. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration the Company expects to receive in exchange for those products. See "NOTE 2 — REVENUE RECOGNITION" for additional information.

Income Taxes – Provisions for income taxes are based on taxes payable or refundable for the current year and deferred taxes. Deferred taxes are provided on differences between the tax basis of assets and liabilities and their reported amounts in the condensed financial statements, and tax carryforwards. Deferred tax assets and liabilities are included in the condensed financial statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the provision for income taxes.

Since December 31, 2020, the Company determined that a full valuation allowance was necessary due to the Company's assessment that it was more likely than not that it would be unable to obtain the benefits of its deferred tax assets due to the Company’s history of taxable losses. The Company determined that certain existing deferred tax assets would not be offset by existing deferred tax liabilities as a result of the 80% limitation on the utilization net operating losses incurred after 2017. Since 2021, commodity prices increased and the Company continues to project positive pre-tax book income. As of June 30, 2023, the Company was no longer in a cumulative loss position. As a result, future forecasted pre-tax book income was considered as positive evidence in assessing the valuation allowance. Based on the change in judgment on the realizability of the related federal deferred tax assets in future years, the Company released $10.5 million of valuation allowance as a discrete benefit in the first nine months ended September 30, 2023. Accordingly, the Company recorded the following federal and state income tax benefits (provisions) for the three and nine months ended September 30, 2023 and 2022.


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Deferred federal income tax benefit (provision)	$	3,381,104	$	(3,611,381)	$	8,492,595	$	(4,625,429)
Current state income tax benefit (provision)	(165,780)		(36,736)		(264,261)		(36,736)
Deferred state income tax benefit (provision)	196,012		(667,666)		(490,646)		(1,204,579)
Benefit from (Provision for) Income Taxes	$	3,411,336	$	(4,315,783)	$	7,737,688	$	(5,866,744)

The Company had immaterial operations in New Mexico which is in a net deferred tax asset position for which a full valuation allowance is still recorded.

For the three and nine months ended September 30, 2023, the Company’s overall effective tax rates (calculated as Benefit from (Provision for) Income Taxes divided by Income Before Benefit from (Provision for) Income Taxes) were 31.2% and 16.7%, respectively. These rates were primarily impacted by the release of valuation allowance on its federal net deferred tax asset. A tax benefit of $10.5 million was recorded as a discrete item in the nine months ended September 30, 2023.

Accounting for Uncertainty in Income Taxes – In accordance with GAAP, the Company has analyzed its filing positions in all jurisdictions where it is required to file income tax returns for the open tax years. The Company has identified its federal income tax return and its franchise tax return in Texas in which it operates as “major” tax jurisdictions. The Company’s federal income tax returns for the years ended December 31, 2018 and after remain subject to examination. The Company’s federal income tax returns for the years ended December 31, 2007 and after remain subject to examination to the extent of the net operating loss (NOL) carryforwards. The Company’s franchise tax returns in Texas remain subject to examination for 2017 and after. The Company currently believes that all significant filing positions are highly certain and that all of its significant income tax filing positions and deductions would be sustained upon audit. Therefore, the Company

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has no significant reserves for uncertain tax positions and no adjustments to such reserves were required by GAAP. No interest or penalties have been levied against the Company and none are anticipated; therefore, no interest or penalty has been included in our provision for income taxes in the Condensed Statements of Operations.

Three-Stream Reporting - Beginning July 1, 2022, the Company began reporting volumes and revenues on a three-stream basis, separately reporting crude oil, natural gas, and natural gas liquids ("NGLs") sales. For periods prior to July 1, 2022, sales and reserve volumes, prices, and revenues for NGLs were presented with natural gas. This represents a change in our accounting and reporting presentation necessitated by a change in the underlying facts and circumstances surrounding the Stronghold Acquisition, as Stronghold had historically reported its revenues on a three-stream basis. As clarified in the interpretive guidance of ASC 250, such changes should not be applied on a retrospective basis. Accordingly, we began reporting on a three-stream basis prospectively, beginning July 1, 2022. See NOTE 5 - ACQUISITIONS AND DIVESTITURES for a discussion of the Stronghold Acquisition.

Leases - The Company accounts for its leases in accordance with ASU 2016-02, Leases (Topic 842), effective January 1, 2019. The Company made accounting policy elections to not capitalize leases with a lease term of twelve months or less (i.e. short term leases) and to not separate lease and non-lease components for all asset classes. The Company also elected to adopt the package of practical expedients within ASU 2016-02 that allows an entity to not reassess prior to the effective date (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification for any expired or existing leases, or (iii) initial direct costs for any existing leases, and the practical expedient regarding land easements that exist prior to the adoption of ASU 2016-02. The Company did not elect the practical expedient of hindsight when determining the lease term of existing contracts at the effective date.

Earnings (Loss) Per Share – Basic earnings (loss) per share is computed by dividing net income (loss) by the weighted-average number of common shares outstanding during the applicable period. Diluted earnings (loss) per share are calculated to give effect to potentially issuable dilutive common shares.

Share-Based Employee Compensation – The Company has ~~common~~ outstanding stock option grants and restricted ~~common~~ stock unit awards to directors, officers and employees, which are described more fully below in ~~Note 11.~~"NOTE 11 — EMPLOYEE STOCK OPTIONS AND RESTRICTED STOCK UNITS". The Company recognizes the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award and recognizes the related compensation expense over the period during which an employee is required to provide service in exchange for the award, which is generally the vesting period.

Share-Based Compensation to Non-Employees – The Company accounts for share-based compensation issued to ~~directors and other~~ non-employees as either the fair value of the consideration received or the fair value of the equity instruments issued, whichever is more reliably measurable. The measurement date for these issuances is the earlier of (i) the date at which a commitment for performance by the recipient to earn the equity instruments is reached or (ii) the date at which the recipient’s performance is complete.

~~Income Taxes~~ ~~– Provisions for income taxes are based on taxes payable or refundable for~~

The following table summarizes the ~~current year~~Company's share-based compensation, included with General and ~~deferred taxes. Deferred taxes are based on differences between the tax bases~~administrative expense within our Condensed Statements of assets and liabilities and their reported amounts in the financial statements, and tax carry forwards. Deferred tax assets and liabilities are included in the financial statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the provision for income taxes.

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~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Since December 31, 2020, the Company has determined that a full valuation allowance is necessary due to the Company assessment that it is more likely than not that it will be unable to obtain the benefits of its deferred tax assets due to the Company’s history of taxable losses. During the nine months ended September 30, 2022, the Company determined that certain existing deferred tax assets will not be offset by existing deferred tax liabilities as a result of the 80% limitation on the utilization net operating lossesOperations, incurred ~~after 2017. Accordingly,~~ for the three and nine months ended September 30, ~~2022, the Company recorded federal income tax expense of $3,611,381~~2023 and ~~$4,625,429, respectively. The Company recorded state deferred income tax expense of $667,666 and $1,204,579, respectively, during the three and nine months ended September 30,~~ 2022. The Company recorded a state current income tax expense of $36,736 during the three and nine months ended September 30, 2022. The Company recorded a state deferred income tax benefit of $48,701 and expense of $141,943, respectively, for the three and nine months ended September 30, 2021. The Company has immaterial operations in New Mexico which is in a net deferred tax asset position for which a full valuation allowance is still recorded.

The shares issued for the Stronghold Acquisition (further discussed in Note 5) resulted in the Company having an ownership change under Section 382 of the Internal Revenue Code. Section 382 limits the availability of certain tax attributes, including net operating losses and disallowed interest carryforwards, to offset future taxable income of the Company. In evaluating its need for a valuation allowance against its deferred tax assets, the Company has estimated the amount of tax attributes related to the pre-ownership change period to be available under Section 382 in periods in which it expects deferred tax liabilities to be realized based on currently available information. Based on its current analysis, the Company does not anticipate any material tax attributes to expire unused as result of the section 382 ownership change; however, the ultimate timing in the amount of tax attributes available in future periods may be different than our current estimate and will be determined in each year as new information becomes available. Changes in expectation in the timing of the availability of our tax attributes could result in adjustments to the valuation allowance in future years as we update our analysis based on new information.

For the nine months ended September 30, 2022, the Company’s overall effective tax rate of 4.5% was primarily impacted by the valuation allowance on its federal net deferred tax asset and state income taxes.

~~Three-Stream Reporting~~ - Beginning July 1, 2022, the Company began reporting volumes and revenues on a three-stream basis, separately reporting crude oil, natural gas, and natural gas liquids (NGLs) sales. For periods prior to July 1, 2022, sales and reserve volumes, prices, and revenues for NGLs were presented with natural gas. This represents a change in our accounting and reporting presentation necessitated by a change in the underlying facts and circumstances surrounding the Stronghold Acquisition, as Stronghold has historically reported its revenues on a three-stream basis. As clarified in the interpretive guidance of ASC 250, such changes should not be applied on a retrospective basis. Accordingly, we began reporting on a three-stream basis prospectively, beginning July 1, 2022.


	Three Months Ended				Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Share-based compensation	$	2,170,735	$	1,543,033	$	6,374,743	$	4,964,188

Recently Adopted Accounting Pronouncements – In ~~December 2019, the FASB released Accounting Standards Update (ASU) No. 2019-12 (“ASU 2019-12”), “~~~~Income Taxes~~~~(Topic 740) – Simplifying the Accounting for Income Taxes~~,” which removes certain exceptions for recognizing deferred taxes for investments, performing intraperiod allocation and calculating income taxes in interim periods. The ASU also adds guidance to reduce complexity in certain areas, including recognizing deferred taxes for tax goodwill and allocating taxes to members of a consolidated group. The amended standard is effective for fiscal years beginning after December 15, 2020.The adoption of ASU 2019-12 did not have a material impact to the Company’s financial statements or disclosures.

~~In October 2020,~~July 2023, the FASB issued ASU 2023-03, Presentation of Financial Statements (Topic 205), Income Statement - Reporting Comprehensive Income (Topic 220), Distinguishing Liabilities from Equity (Topic 480), Equity (Topic 505), and Compensation - Stock Compensation (Topic 718): Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. ~~2020-10, “~~~~Codification Improvements~~~~” (“~~120, SEC Staff Announcement at the March 24, 2022 EITF Meeting, and Staff Accounting Bulletin Topic 6.B, Accounting Series Release 280 - General Revision of Regulation S-X: Income or Loss Applicable to Common Stock. The ASU ~~2020-10”), which clarifies~~provided updated views from the SEC Staff on employee and non-employee share-based payment accounting, including guidance related to spring-loaded awards. As the ASU did not provide any new ASC guidance, and there was no transition or ~~improves disclosure requirements for various topics to align with SEC regulations. This update was~~ effective ~~for~~date provided, the Company ~~beginning in~~adopted this standard upon issuance, and the ~~first quarter of 2021 and was applied retrospectively. The~~ adoption ~~and implementation of this ASU~~ did not have a material impact on ~~the Company’s~~our condensed financial statements.

~~In August 2020, the FASB issued ASU No. 2020-06, “~~~~Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40)”~~ (“ASU 2020-06”). ASU 2020-06 was issued to reduce the complexity associated with accounting for certain financial instruments with characteristics of liabilities and equity. The guidance may be applied using either a modified retrospective or a fully retrospective method. ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. The Company adopted ASU 2020-06 effective January 1, 2022. The adoption and implementation of this ASU did not have a material impact on the Company’s financial statements.

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~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Recent Accounting Pronouncements - – In March 2020, the FASB issued ASU ~~No.~~ 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial ~~Reporting”~~Reporting (“ASU 2020-04”), which ~~provides~~provided optional expedients and exceptions for applying GAAP to contract modifications and hedging relationships, subject to meeting certain criteria, that ~~reference~~referenced LIBOR or another ~~rate that is expected to be discontinued.~~rate. ASU 2020-04 ~~will be~~was in effect through December 31, 2022. In January 2021, the FASB issued ASU No. 2021-01, Reference Rate Reform (Topic 848): Scope (“ASU 2021-01”), to provide clarifying guidance regarding the scope of Topic 848. ASU 2020-04 was issued to provide optional guidance for a limited period of time to ease the potential burden in accounting for (or recognizing the effects of) reference rate reform on financial reporting. ~~The~~In December 2022, the FASB issued ASU 2022-06, "Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848" ("ASU 2022-06"), which defers the sunset date of Topic 848 from December 31, 2022 to December 31, 2024. Beginning August 31, 2022, under the Company's Second Amended and Restated Credit Agreement, the Company's interest rates were transitioned from the LIBOR to the SOFR (Standard Overnight Financing Rate) reference rate. At this time, the Company ~~is currently assessing the impact of adopting this new guidance.~~

does not plan to enter into additional contracts using LIBOR as a reference rate.

In October 2021, the FASB issued ASU ~~No.~~ 2021-08, “"Business Combinations (Topic 805) -– Accounting for Contract Assets and Contract Liabilities from Contracts with Customers” (“("ASU ~~2021-08”~~2021-08"). This update requires the acquirer in a business combination to record contract asset and liabilities following Topic 606 -– “Revenue from Contracts with Customers” at acquisition as if it had originated the contract, rather than at fair value. This update is effective for public business entities beginning after December 15, 2022, with early adoption permitted. The Company continues to evaluate the provisions of this update, but it does not believe the adoption will have a material impact on its financial position, results of operations or liquidity.

~~Basic~~On July 26, 2023, the SEC issued Final Rule Release No. 33-11216, Cybersecurity Risk Management, Strategy, Governance, and ~~Diluted Earnings per Share~~Incident Disclosure ~~– Basic earnings per share~~, which requires current disclosures (via Form 8-K, Item 1.05) about material cybersecurity incidents and requires periodic disclosures (via Form 10-K, Item 1C, "Cybersecurity") about a registrant’s processes to manage its material cybersecurity risks. The Company is ~~computed by dividing net income by~~currently considering the ~~weighted-average number~~impact of common shares outstanding during the period. Diluted earnings per share reflects the potential dilution that could occur if all contracts to issue common stock were converted into common stock, except for those that are anti-dilutive. The dilutive effect of stock options and other share-based compensation is calculated using the treasury method.

this rule on its disclosures.

NOTE 2 –— REVENUE RECOGNITION

The Company predominantly derives its revenue from the sale of produced crude oil, ~~and~~ natural ~~gas.~~gas, NGLs. The contractual performance obligation is satisfied when the product is delivered to the ~~customer.~~purchaser. Revenue is recorded in the month the product is delivered to the purchaser. The Company receives payment from one to three months after delivery. The Company has utilized the practical expedient in ~~ASC (“~~Accounting Standards ~~Codification”~~Codification ("ASC") 606-10-50-14, which states an entity is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under the Company’s sales contracts, each unit of production delivered to a ~~customer~~purchaser represents a separate performance obligation, therefore, future volumes to be delivered are wholly unsatisfied and disclosure of transaction price allocated to remaining performance obligation is not required. The transaction price includes variable consideration, as product pricing is based on published market prices and ~~reduced~~adjusted for contract specified differentials such as quality, energy content and transportation. The guidance does not require that the transaction price be fixed or stated in the contract. Estimating the variable consideration does not require significant judgment and the Company engages third party sources to validate the estimates. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration the Company expects to receive in exchange for those products.

Oil sales

Under the Company’s oil sales contracts, the Company sells oil production at the point of delivery and collects an agreed upon index price, net of pricing differentials. The Company recognizes revenue at the net price received when control transfers to the purchaser at the point of delivery and it is probable the Company will collect the consideration it is entitled to receive.

Natural gas and NGL sales

Under the Company’s natural gas sales processing contracts for its Central Basin Platform properties ~~Delaware Basin properties~~ and ~~part~~a portion of its Northwest Shelf assets, the Company delivers unprocessed natural gas to a midstream processing entity at the wellhead. The midstream processing entity obtains control of the natural gas and NGLs ~~(natural gas liquids)~~ at the wellhead. The midstream processing entity gathers and processes the natural gas and NGLs and remits proceeds to the Company for the resulting sale of natural gas and NGLs. Under these processing agreements, the Company recognizes revenue when control transfers to the

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purchaser at the point of delivery and it is probable the Company will collect the consideration it is entitled to receive. As such, the Company accounts for any fees and deductions as a reduction of the transaction price.

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~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Until April 30, 2022, under the ~~Company’s~~Company's natural gas sales processing contracts for the bulk of its Northwest Shelf assets, the Company delivered unprocessed natural gas to a midstream processing entity at the ~~well head.~~wellhead. However, the Company maintained ownership of the gas through processing and received proceeds from the marketing of the resulting products. Under this processing agreement, the Company recognized the fees associated with the processing as an expense rather than netting these costs against Oil, Natural Gas, and Natural Gas Liquids Revenues in the Condensed Statements of Operations. Beginning May 1, 2022, these contracts were combined into one contract, and it was modified so that the Company no longer maintained ownership of the gas through processing. Accordingly, the Company from that point on accounts for any such fees and deductions as a reduction of the transaction price.

Disaggregation of ~~revenue.~~Revenue. The following table presents revenues disaggregated by ~~product~~product:


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Oil, Natural Gas, and Natural Gas Liquids Revenues
Oil	$	90,392,004	$	86,413,665	$	252,020,403	$	229,532,827
Natural gas	562,374		4,655,002		526,161		14,678,747
Natural gas liquids (1)	2,727,420		3,340,281		8,566,719		3,340,281
Total oil, natural gas, and natural gas liquids revenues	$	93,681,798	$	94,408,948	$	261,113,283	$	247,551,855

(1) Beginning on July 1, 2022, the Company began reporting volumes and revenues on a three-stream basis, separately reporting crude oil, natural gas, and NGL sales. For periods prior to July 1, 2022, sales revenues for ~~the three and nine months ended September 30, 2022 and 2021:~~

For The Three Months

For The Nine Months

Ended September 30,

Ended September 30,


2022

2021

2022

2021
Operating Revenues








Oil

$
86,413,665

$
45,889,548

$
229,532,827

$
126,927,318
Natural gas

4,655,002

$
3,486,628

14,678,747

9,711,492
Natural gas liquids

3,340,281

—

3,340,281

—
Total operating revenues

$
94,408,948

$
49,376,176

$
247,551,855

$
136,638,810

~~All revenues are from production from the Permian Basin in Texas and New Mexico.~~

NGLs were presented with natural gas.

NOTE 3 –— LEASES

The Company has operating leases for its offices in Midland, Texas and The Woodlands, ~~Texas and~~Texas. The Midland ~~Texas.~~office is under a five-year lease which began January 1, 2021. The Midland office lease was amended effective October 1, 2022, with the revised five-year lease ending September 30, 2027. Beginning January 15, 2021, the Company entered into a five-and-a-half-year sub-lease for office space in The Woodlands, Texas; however, effective as of May 31, 2023, The Woodlands office sub-lease was terminated. On May 9, 2023, the Company entered into a 71-month (five years and 11-month) new lease for a larger amount of office space in The Woodlands, Texas. ~~Until September 2022,~~At the ~~Midland~~time of the new lease commencement, the additional office space that was added was under construction and until completed, the rental obligation for this space had not yet commenced, because the Company did not have control of the additional office space in accordance with ASC 842-40-55-5. On September 27, 2023, the Company provided a ~~five-year lease which began January 1, 2021. The~~certificate of acceptance of premises to the lessor of the additional office space, and accordingly, as of September 30, 2023, the future payments ~~associated~~for this space are included along with ~~these~~the other operating leases, ~~are~~ reflected in the future lease payments schedule below.

The Company ~~also~~ has month to month leases for office equipment and compressors used in its operations on which the Company has elected to apply ASU 2016-02 (i.e., to not capitalize). The office equipment and compressors are not subject to ASU 2016-02 based on the agreement and nature of use. These leases are for terms that are less than 12 months and the Company does not intend to continue to lease this equipment for more than 12 months. The lease costs associated with these leases is reflected in the short-term lease costs within Lease operating expenses, shown below.

The Company has financing leases for vehicles. These leases have a term of 36 months at the end of which the Company owns the vehicles. These vehicles are generally sold at the end of their term and the proceeds applied to a new ~~vehicles.~~

vehicle.

Table of Contents

Future lease payments ~~(undiscounted future cash flows)~~ associated with these operating and financing leases as of September 30, ~~2022~~2023 are as follows:

2022

2023

2024

2025

2026
Operating lease payments⁽¹⁾

$
87,282

$
356,991

$
376,855

$
384,719

$
110,096
Financing lease payments⁽²⁾

109,582

438,328

372,056

99,796

—

~~(1)~~

The weighted average discount rate as of September 30, 2022 for operating leases was 4.50%. Based on this rate, the future lease payments above include imputed interest of $103,704. The weighted average remaining term of operating leases was 3.55 years.

~~(2)~~

The weighted average discount rate as of September 30, 2022 for financing leases was 4.00%. Based on this rate, the future lease payments above include imputed interest of $48,667. The weighted average remaining term of financing leases was 2.38 years.


	2023		2024		2025		2026		2027		Other Future Years
Operating lease payments (1)	$	118,616	$	675,210	$	727,460	$	636,649	$	460,497	400,234
Financing lease payments (2)	223,492		832,238		493,290		49,763		—		—

~~Table~~(1)The weighted average annual discount rate as of ~~Contents~~September 30, 2023 for operating leases was 4.50%. Based on this rate, the future lease payments above include imputed interest of $307,998. The weighted average remaining term of operating leases was 4.51 years.

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

(2)The weighted average annual discount rate as of September 30, 2023 for financing leases was 6.25%. Based on this rate, the future lease payments above include imputed interest of $101,334. The weighted average remaining term of financing leases was 2.00 years.

The following table represents a reconciliation between the undiscounted future cash flows in the table above and the operating and financing lease liabilities disclosed in the Condensed Balance Sheets:

As of


September 30, 2022

December 31, 2021
Operating lease liability, current portion

$
306,715

$
290,766
Operating lease liability, non-current portion

905,524

1,138,319
Operating lease liability, total

$
1,212,239

$
1,429,085
Total undiscounted future cash flows

1,315,943

1,577,786
Imputed interest

103,704

148,701
Undiscounted future cash flows less imputed interest

$
1,212,239

$
1,429,085

Financing lease liability, current portion

$
406,890

$
316,514
Financing lease liability, non-current portion

564,205

343,727
Financing lease liability, total

$
971,095

$
660,241
Total undiscounted future cash flows

1,019,762

692,091
Imputed interest

48,667

31,850
Undiscounted future cash flows less imputed interest

$
971,095

$
660,241


	As of
	September 30, 2023		December 31, 2022
Operating lease liability, current portion	$	503,420	$	398,362
Operating lease liability, non-current portion	2,207,248		1,473,897
Operating lease liability, total	$	2,710,668	$	1,872,259
Total undiscounted future cash flows (sum of future operating lease payments)	3,018,666		2,065,580
Imputed interest	307,998		193,321
Undiscounted future cash flows less imputed interest	$	2,710,668	$	1,872,259

Financing lease liability, current portion	$	806,993	$	709,653
Financing lease liability, non-current portion	690,456		1,052,479
Financing lease liability, total	$	1,497,449	$	1,762,132
Total undiscounted future cash flows (sum of future financing lease payments)	1,598,783		1,900,595
Imputed interest	101,334		138,463
Undiscounted future cash flows less imputed interest	$	1,497,449	$	1,762,132

The following table provides supplemental information regarding ~~cash flows from operations~~lease costs in the Condensed Statements of Operations:


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Operating lease costs	$	138,220	$	83,590	$	366,711	$	250,770
Short-term lease costs (1)	1,012,525		639,708		4,042,160		1,937,310
Financing lease costs:
Amortization of financing lease assets (2)	197,221		106,982		572,744		334,447
Interest on financing lease liabilities (3)	23,416		10,391		73,115		24,184

(1)Amount included in Lease operating expenses

(2)Amount included in Depreciation, depletion and amortization

(3)Amount included in Interest (expense)

Table of Contents

NOTE 4 — EARNINGS (LOSS) PER SHARE INFORMATION

The following table presents the calculation of the Company's basic and diluted earnings (loss) per share for the three and nine months ~~ended:~~

Three months ended

Nine months ended

September 30,

September 30,


2022

2021

2022

2021
Operating lease costs

$
83,590

$
83,589

$
250,770

$
439,896
Short term lease costs ⁽¹⁾

639,708

964,873

1,937,310

2,903,387
Financing lease costs:

Amortization of financing lease assets ⁽²⁾

106,982

85,367

334,447

189,831
Interest on lease liabilities ⁽³⁾

10,391

5,160

24,184

14,166

~~(1)~~

~~Amount included in Lease operating expenses~~

~~(2)~~

~~Amount included in Depreciation, depletion and amortization~~

~~(3)~~

~~Amount included in Interest expense~~

~~NOTE 4 – EARNINGS (LOSS) PER SHARE INFORMATION~~

For the Three Months

For the Nine Months

Ended September 30,

Ended September 30,


2022

2021

2022

2021
Net Income (Loss)

$
75,085,891

$
14,163,934

$
124,142,356

$
(20,789,318)
Basic Weighted-Average Shares Outstanding

115,376,280

99,358,504

107,349,184

99,251,532
Effect of dilutive securities:

Stock options

52,110

135,536

93,688

—
Restricted stock units

1,908,662

1,463,690

2,135,675

—
Performance stock units

196,520

—

235,440

—
Common warrants

19,884,296

20,263,018

20,180,729

—
Convertible preferred stock

14,337,127

—

4,831,559

—
Diluted Weighted-Average Shares Outstanding

151,754,995

121,220,748

134,826,275

99,251,532
Basic Earnings (Loss) per Share

$
0.65

$
0.14

$
1.16

$
(0.21)
Diluted Earnings (Loss) per Share

$
0.49

$
0.12

$
0.92

$
(0.21)

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~For the three months~~ ended September 30, ~~2022, stock options to purchase 70,500 shares of common stock, 37,487 shares of unvested restricted stock units,~~2023 and ~~860,212 shares of unvested performance stock units~~2022.


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Net Income (Loss)	$	(7,539,222)	$	75,085,891	$	53,968,162	$	124,142,356
Basic Weighted-Average Shares Outstanding	195,361,476		115,376,280		188,865,752		107,349,184
Effect of dilutive securities:
Stock options	—		52,110		—		93,688
Restricted stock units	—		1,908,662		1,310,409		2,135,675
Performance stock units	—		196,520		361,406		235,440
Common warrants	—		19,884,296		4,045,648		20,180,729
Convertible preferred stock	—		14,337,127		—		4,831,559
Diluted Weighted-Average Shares Outstanding	195,361,476		151,754,995		194,583,215		134,826,275
Basic Earnings (Loss) per Share	$	(0.04)	$	0.65	$	0.29	$	1.16
Diluted Earnings (Loss) per Share	$	(0.04)	$	0.49	$	0.28	$	0.92

The following table presents the securities which were excluded from the Company's computation of diluted earnings per share for the three and nine months ended September 30, 2023 and 2022, as their effect would have been anti-dilutive. For the nine months ended September 30, 2022, stock options to purchase 70,500 shares of common stock, 11,312 shares of unvested restricted stock units, and 798,768 shares of unvested performance stock units were excluded from the computation of diluted earnings per share as their effect would have been anti-dilutive. For the three months ended September 30, 2021, stock options to purchase 70,500 shares of common stock and 14,709 shares of unvested restricted stock were excluded from the computation of diluted earnings per share as their effect would have been anti-dilutive. For the nine months ended September 30, 2021, 465,500 shares of common stock, 3,247,623 shares of unvested restricted stock, and unexercised common warrants of 29,519,500 were excluded from the computation of diluted earnings per share as their effect would have been anti-dilutive.


	For the Three Months Ended		For the Nine Months Ended
	September 30, 2023	September 30, 2022	September 30, 2023	September 30, 2022
Antidilutive securities:
Stock options to purchase common stock	265,500	70,500	265,500	70,500
Unvested restricted stock units	3,866,023	37,487	61,212	11,312
Unvested performance stock units	2,882,594	860,212	1,396,446	798,768

NOTE 5 –— ACQUISITIONS &AND DIVESTITURES

Stronghold Acquisition

On July 1, 2022, Ring, as buyer, and Stronghold Energy II Operating, LLC, a Delaware limited liability company (“Stronghold OpCo”) and Stronghold Energy II Royalties, LP, a Delaware limited partnership (“Stronghold RoyaltyCo”, together with Stronghold OpCo, collectively, “Stronghold”), as seller, entered into a purchase and sale agreement (the ~~“Purchase~~“Stronghold Purchase Agreement”). Pursuant to the Stronghold Purchase Agreement, Ring acquired (the “Stronghold Acquisition”) interests in oil and gas leases and related property of Stronghold consisting of approximately 37,000 net acres located in the Central Basin Platform of the Texas Permian Basin. On August 31, 2022, Ring completed the Stronghold ~~Acquisition pursuant to the Purchase Agreement.~~

Acquisition.

The fair value of consideration paid to Stronghold was approximately ~~$395.7~~$394.0 million, of which ~~$167.9~~$165.9 million, ~~subject to post-closing~~net of customary purchase price adjustments, was paid in cash at closing, ~~$15.0~~and $15.0 million ~~will be payable~~was paid in cash six months after the ~~six-month anniversary of the closing date of the Stronghold Acquisition, and~~closing. Also, shortly after closing, approximately $4.5 million was paid for inventory and vehicles and approximately $1.8 million was paid for August oil derivative settlements for ~~the~~certain novated hedges. The cash portion of the consideration was funded primarily from borrowings under ~~a new fully committed~~our revolving ~~credit facility (the “Credit Facility”) underwritten by Truist Securities, Citizens Bank, N.A., KeyBanc Capital Markets Inc., and Mizuho Bank, Ltd. The borrowing base of the $1.0 billion~~ Credit Facility, which was increased from $350.0 million to $600.0 million at the ~~closing of the transaction.~~closing. The remaining consideration ~~was in the form of stock, consisting~~consisted of 21,339,986 shares of Ring common stock and 153,176 shares of newly created Series A Convertible Preferred Stock, par value $0.001 (“Preferred Stock”)~~. Please see “Note 10 – STOCKHOLDERS’ EQUITY AND MEZZANINE EQUITY” for further discussion.~~ which were converted into 42,548,892 shares of common stock on October 27, 2022. In addition, Ring assumed $24.8 million of derivative liabilities, $1.7 million of items in suspense, and $14.5 million in asset retirement ~~obligations~~obligations.

Table of Contents

Delaware Basin Sale

On May 11, 2023, the Company completed the divestiture of its Delaware Basin assets to an unaffiliated party for $8.3 million. The sale had an effective date of March 1, 2023. The final cash consideration was approximately $7.6 million, subject to customary final purchase price adjustments. As part of the divestiture, the buyer assumed an asset retirement obligation balance of approximately $2.3 million.

Founders Acquisition

On July 10, 2023, the Company, as buyer, and Founders Oil & Gas IV, LLC (“Founders”), as seller, entered into an Asset Purchase Agreement (the “Founders Purchase Agreement”). Pursuant to the closing of the Purchase Agreement, on August 15, 2023 the Company acquired (the “Founders Acquisition”) interests in oil and gas leases and related property of Founders located in the ~~Stronghold Acquisition.~~

Central Basin Platform of the Texas Permian Basin in Ector County, Texas, for a purchase price (the “Purchase Price”) of (i) a cash deposit of $7.5 million paid on July 11, 2023 into a third-party escrow account as a deposit pursuant to the Founders Purchase ~~Price Allocation~~

Agreement, (ii) approximately $42.5 million in cash paid on the closing date, net of approximately $10 million of preliminary and customary purchase price adjustments with an effective date of April 1, 2023, and (iii) a deferred cash payment of $15.0 million due 4 months after closing, or December 15, 2023, subject to final post-closing settlement between the Company and Founders.

The ~~Stronghold~~Founders Acquisition has been accounted for as an asset acquisition in accordance with ASC 805. The fair value of the consideration paid by Ring and allocation of that amount to the underlying assets acquired, on a relative fair value basis, was recorded on Ring’s books as of the date of the closing of the ~~Stronghold~~Founders Acquisition. Additionally, costs directly related to the ~~Stronghold~~Founders Acquisition were capitalized as a component of the purchase price. Determining the fair value of the assets and liabilities acquired requires judgment and certain assumptions to be made, the most significant of these being related to the valuation of ~~Stronghold’s~~Founder’s oil and gas properties. The inputs and assumptions related to the oil and gas properties are categorized as level 3 in the fair value hierarchy.

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

The following table represents the preliminary allocation of the total cost of the ~~Stronghold~~Founders Acquisition to the assets acquired and liabilities assumed as of the ~~Stronghold~~Founders Acquisition date:


Consideration:
Cash consideration
Escrow deposit released at closing	$	7,500,000
Closing amount paid to Founders	42,502,799
Interest from escrow deposit	1,747
Fair value of deferred payment liability	14,657,383
Post-close adjustments	(1,463,632)
Total cash consideration	$	63,198,297
Direct transaction costs	$	1,361,843
Total consideration	$	64,560,140

Fair value of assets acquired:
Oil and natural gas properties	$	67,562,084

Amount attributable to assets acquired	$	67,562,084
Fair value of liabilities assumed:
Suspense liability	$	677,116
Asset retirement obligations	2,090,777
Ad valorem tax liability	234,051
Amount attributable to liabilities assumed	$	3,001,944
Net assets acquired	$	64,560,140

Consideration:

Shares of Ring Common Stock issued

21,339,986
Ring Common Stock price as of August 31, 2022

$
3.24
Common Stock Consideration

$
69,141,555

Shares of Ring Preferred Stock issued

153,176
Aggregate Liquidation Preference

$
153,176,000
Conversion Price

$
3.60
As-Converted Shares of Ring Common Stock

42,548,903
Ring Common Stock Price as of August 31, 2022

$
3.24
Preferred Stock Consideration

$
137,858,446

Cash consideration:

Closing amount paid to Stronghold by bank

121,392,455
Escrow deposit paid at closing

46,500,000
Cash paid for inventory and fixed assets

4,527,103
Cash paid for realized losses on August oil derivatives

1,777,925
Total cash consideration

174,197,483
Fair value of deferred payment liability

14,511,688
Fair value of consideration to be paid to seller

395,709,171

Direct transaction costs

9,162,143
Total consideration

$
404,871,314

Fair value of assets acquired:

Oil and natural gas properties

441,318,763
Inventory and fixed assets

4,527,103
Amount attributable to assets acquired

$
445,845,866
Fair value of liabilities assumed:

Suspense liability

1,651,596
Derivative liabilities, marked to market

24,784,406
Asset retirement obligations

14,538,550
Amount attributable to liabilities assumed

$
40,974,552
Net assets acquired

$
404,871,314

Approximately ~~$11.7~~$6.3 million of revenues and ~~$3.5~~$1.7 million of direct operating expenses attributed to the ~~Stronghold~~Founders Acquisition are included in the Company’s Statements of Operations for the period from ~~September 1, 2022~~August 16, 2023 through September 30, ~~2022.~~

2023.

Table of Contents

New Mexico Divestiture

On September 27, 2023, the Company completed the divestiture of its operated New Mexico assets to an unaffiliated party for $4.5 million, resulting in preliminary cash consideration of approximately $3.8 million, subject to customary final purchase price adjustments. The sale had an effective date of June 1, 2023. As part of the divestiture, the buyer assumed an asset retirement obligation balance of approximately $2.3 million.

NOTE 6 –— DERIVATIVE FINANCIAL INSTRUMENTS

The Company is exposed to fluctuations in crude oil and natural gas prices on its production. It utilizes derivative strategies that consist of either a single derivative instrument or a combination of instruments to manage the variability in cash flows associated with the forecasted sale of ~~its~~our future domestic oil and natural gas production. While the use of derivative instruments may limit or partially reduce the downside risk of adverse commodity price movements, ~~the~~their use also may limit future income from favorable commodity price movements.

From time to time, the Company enters into derivative contracts to protect the Company’s cash flow from price fluctuation and maintain its capital programs. The Company has historically used costless collars, deferred premium puts, or swaps for this purpose. Oil derivative contracts are based on WTI (West Texas Intermediate) crude oil prices and natural gas contacts are based on the Henry Hub. A “costless collar” is the combination of two options, a put option (floor) and call option (ceiling) with the options structured so that the premium paid for the put option will be offset by the premium received from selling the call option. Similar to costless collars, there is no cost to enter into the swap contracts. The deferred premium put contract has the premium established upon entering the contract, and due upon settlement of the contract.

The use of derivative transactions involves the risk that the counterparties, which generally are financial institutions, will be unable to meet the financial terms of such transactions. All of our derivative contracts are with lenders under our Credit Facility. Non-performance risk is incorporated in the discount rate by adding the quoted bank (counterparty) credit default swap (CDS) rates to the risk free rate. Although the counterparties hold the right to offset (i.e. netting) the settlement amounts with the Company, in accordance with ASC 815-10-50-4B, the Company classifies the fair value of all its derivative positions on a gross basis in the Condensed Balance Sheets.

The Company’s derivative financial instruments are recorded at fair value and included as either assets or liabilities in the accompanying Condensed Balance Sheets. The Company has not designated its derivative ~~financial~~ instruments as hedges for accounting purposes, and, as a result, any gains or losses resulting from changes in fair value of outstanding derivative financial instruments and from the settlement of

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

derivative financial instruments are recognized in earnings and included as a component of ~~“Other~~"Other Income (Expense)”" under the heading ~~“Gain~~"Gain (loss) on derivative ~~contracts”~~contracts" in the accompanying Condensed Statements of Operations.

The use of derivative transactions involves the risk that the counterparties, which generally are financial institutions, will be unable to meet the financial terms of such transactions. At September 30, 2022, 100% of the Company’s derivative instruments are with lenders under its Credit Facility (as defined in Note 8). Non-performance risk is incorporated in the discount rate by adding the quoted bank (counterparty) credit default swap (CDS) rates to the risk free rate. Beginning September 1, the Company assumed the derivative liabilities (novated hedges) associated with its acquisition of the Stronghold assets (see Note 5), which are subject to master netting agreements. Additional derivative contracts with the same counterparty are also subject to netting. Still, in accordance with ASC 815-10-50-4B, the Company continues to classify the fair value of all its derivative positions on a gross basis in its corresponding Balance Sheets.

The following presents the impact of the Company’s contracts on its Condensed Balance Sheets for the periods indicated.

As of


September 30, 2022

December 31, 2021
Commodity derivative instruments, marked to market:





Derivative assets, current

$
24,206,887

$
—
Discounted deferred premiums

(10,884,874)

—
Derivative assets, current, net of premiums

$
13,322,013

$
—

Derivative assets, noncurrent

15,204,782

—
Discounted deferred premiums

(3,658,800)

—
Derivative assets, noncurrent, net of premiums

$
11,545,982

$
—

Derivative liabilities, current

$
23,767,689

$
29,241,588

Derivative liabilities, noncurrent

$
8,734,388

$
—


	As of
	September 30, 2023		December 31, 2022
Commodity derivative instruments, marked to market:

Derivative assets, current	$	5,772,513	$	16,193,327
Discounted deferred premiums	(3,927,380)		(11,524,165)
Derivatives assets, current, net of premiums	$	1,845,133	$	4,669,162

Derivative assets, noncurrent	$	6,465,355	$	7,606,258
Discounted deferred premiums	—		(1,476,848)
Derivative assets, noncurrent, net of premiums	$	6,465,355	$	6,129,410

Derivative liabilities, current	$	23,906,800	$	13,345,619

Derivative liabilities, noncurrent	$	18,089,847	$	10,485,650

The components of “Gain (loss) on derivative ~~contracts~~”contracts” from the Condensed Statements of Operations are as follows for the respective periods:

Three Months Ended

Nine Months Ended

September 30,

September 30,


2022

2021

2022

2021
Oil derivatives:

Realized gain (loss) on oil derivatives

(13,958,195)

(14,921,008)

(47,690,961)

(34,021,310)
Unrealized gain (loss) on oil derivatives

49,680,492

8,200,688

48,360,099

(39,366,200)
Gain (loss) on oil derivatives

$
35,722,297

$
(6,720,320)

$
669,138

$
(73,387,510)

Natural gas derivatives:

Realized gain (loss) on natural gas derivatives

(902,921)

—

(902,921)

743,178
Unrealized gain (loss) on natural gas derivatives

(1,968,187)

—

(1,968,187)

(941,867)
Gain (loss) on natural gas derivatives

$
(2,871,108)

$
—

$
(2,871,108)

$
(198,689)

Gain (loss) on derivative contracts

$
32,851,189

$
(6,720,320)

$
(2,201,970)

$
(73,586,199)


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Oil derivatives:
Realized gain (loss) on oil derivatives	$	(5,825,427)	$	(13,958,195)	$	(7,323,030)	$	(47,690,961)
Unrealized gain (loss) on oil derivatives	(34,077,473)		49,680,492		(21,425,316)		48,360,099
Gain (loss) on oil derivatives	$	(39,902,900)	$	35,722,297	$	(28,748,346)	$	669,138

Natural gas derivatives:
Realized gain (loss) on natural gas derivatives	474,629		(902,921)		1,493,302		(902,921)
Unrealized gain (loss) on natural gas derivatives	205,516		(1,968,187)		771,854		(1,968,187)
Gain (loss) on natural gas derivatives	$	680,145	$	(2,871,108)	$	2,265,156	$	(2,871,108)

Gain (loss) on derivative contracts	$	(39,222,755)	$	32,851,189	$	(26,483,190)	$	(2,201,970)

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

The components of “Cash ~~(paid)~~paid for derivative settlements, net” within the Condensed Statements of Cash Flows are as follows for the respective periods:

Three Months Ended

Nine Months Ended

September 30,

September 30,


2022

2021

2022

2021
Cash flows from operating activities:

Cash (paid) on oil derivatives

$
(13,958,195)

$
(14,921,008)

$
(47,690,961)

$
(34,030,310)
Cash received (paid) on natural gas derivatives

(902,921)

—

(902,921)

743,178
Cash (paid) for derivative settlements, net

$
(14,861,116)

$
(14,921,008)

$
(48,593,882)

$
(33,287,132)


	For the Three Months Ended				For the Nine Months Ended
	September 30, 2023		September 30, 2022		September 30, 2023		September 30, 2022
Cash flows from operating activities
Cash received (paid) for oil derivatives	$	(5,825,427)	$	(13,958,195)	$	(7,323,030)	$	(47,690,961)
Cash received (paid) from natural gas derivatives	474,629		(902,921)		1,493,302		(902,921)
Cash received (paid) for derivative settlements, net	$	(5,350,798)	$	(14,861,116)	$	(5,829,728)	$	(48,593,882)

The following tables reflect the details of current derivative contracts as of September 30, ~~2022(Quantities~~2023 (Quantities are in barrels (Bbl) for the oil derivative contracts and in million British thermal units (MMBtu) for the natural gas derivative ~~contracts.)~~contracts):

Oil Hedges (WTI)

2022

2023

2024

Swaps:

Hedged volume (BBL)

379,250

389,250

526,000
Weighted average swap price

$
54.89

$
77.55

$
65.90

Deferred premium puts:

Hedged volume (BBL)

138,000

773,500

91,000
Weighted average strike price

$
97.93

$
90.64

$
83.75
Weighted average deferred premium price

$
11.81

$
15.25

$
17.32

Two-way collars:

Hedged volume (BBL)

97,201

487,622

475,350
Weighted average put price

$
53.93

$
52.16

$
67.88
Weighted average call price

$
67.68

$
62.94

$
83.32

Three-way collars:

Hedged volume (BBL)

89,985

66,061

—
Weighted average first put price

$
40.00

$
45.00

$
—
Weighted average second put price

$
50.00

$
55.00

$
—
Weighted average call price

$
62.03

$
80.05

$
—


	Oil Hedges (WTI)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

Swaps:
Hedged volume (Bbl)	138,000		170,625		156,975		282,900		368,000		—		—		184,000		—
Weighted average swap price	$	74.52	$	67.40	$	66.40	$	65.49	$	68.43	$	—	$	—	$	73.35	$	—

Deferred premium puts:
Hedged volume (Bbl)	165,600		45,500		45,500		—		—		—		—		—		—
Weighted average strike price	$	83.78	$	84.70	$	82.80	$	—	$	—	$	—	$	—	$	—	$	—
Weighted average deferred premium price	$	14.61	$	17.15	$	17.49	$	—	$	—	$	—	$	—	$	—	$	—

Two-way collars:
Hedged volume (Bbl)	274,285		339,603		325,847		230,000		128,800		474,750		464,100		184,000		—
Weighted average put price	$	56.73	$	64.20	$	64.30	$	64.00	$	60.00	$	57.06	$	60.00	$	65.00	$	—
Weighted average call price	$	70.77	$	79.73	$	79.09	$	76.50	$	73.24	$	75.82	$	69.85	$	80.08	$	—

Three-way collars:
Hedged volume (Bbl)	15,598		—		—		—		—		—		—		—		—
Weighted average first put price	$	45.00	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Weighted average second put price	$	55.00	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Weighted average call price	$	80.05	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—


	Gas Hedges (Henry Hub)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

NYMEX Swaps:
Hedged volume (MMBtu)	134,102		152,113		138,053		121,587		644,946		616,199		591,725		285,200		—
Weighted average swap price	$	3.35	$	3.62	$	3.61	$	3.59	$	4.45	$	3.78	$	3.43	$	3.73	$	—

Two-way collars:
Hedged volume (MMBtu)	383,587		591,500		568,750		552,000		—		—		—		285,200		—
Weighted average put price	$	3.15	$	4.00	$	4.00	$	4.00	$	—	$	—	$	—	$	3.00	$	—
Call hedged volume (MMBtu)	383,587		591,500		568,750		552,000		—		—		—		285,200		—
Weighted average call price	$	4.51	$	6.29	$	6.29	$	6.29	$	—	$	—	$	—	$	4.80	$	—


	Oil Hedges (basis differential)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

Argus basis swaps:
Hedged volume (MMBtu)	305,000		364,000		364,000		368,000		368,000		270,000		273,000		276,000		276,000
Weighted average spread price (1)	$	1.10	$	1.15	$	1.15	$	1.15	$	1.15	$	1.00	$	1.00	$	1.00	$	1.00


	Gas Hedges (basis differential)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

Waha basis swaps:
Hedged volume (MMBtu)	324,021		—		—		—		—		—		—		—		—
Weighted average spread price (1)	$	0.55	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—

El Paso Permian Basin basis swaps:
Hedged volume (MMBtu)	459,683		—		—		—		—		—		—		—		—
Weighted average spread price (1)	$	0.63	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—

(1) The oil basis swap hedges are calculated as the fixed price (weighted average spread price above) less the difference between WTI Midland and WTI Cushing, in the issue of Argus Americas Crude. The gas basis swap hedges are calculated as the Henry Hub natural gas price less the fixed amount specified as the weighted average spread price above.

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Gas Hedges (Henry Hub)


2022

2023

2024

NYMEX Swaps:






Hedged volume (MMBtu)

46,313

175,421

—
Weighted average swap price

$
2.51

$
2.40

$
—

Two-way collars: ⁽¹⁾






Put hedged volume (MMBtu)

715,661

2,486,514

1,712,250
Weighted average put price

$
3.76

$
3.18

$
4.00
Call hedged volume (MMBtu)

435,061

2,306,514

1,712,250
Weighted average call price

$
10.22

$
5.03

$
6.29

Three-way collar:






Hedged volume (MMBtu)

304,250

—

—
Weighted average first put price

$
2.20

$
—

$
—
Weighted average second put price

$
2.50

$
—

$
—
Weighted average call price

$
3.25

$
—

$
—
Weighted average deferred premium price

$
0.19

$
—

$
—

Gas Hedges (basis differential)


2022

2023

2024

Waha basis swaps:






Hedged volume (MMBtu)

505,024

1,339,685

—
Weighted average swap price

(2)

(3)

$
—

~~(1)~~

The two-way collars for the fourth quarter of 2022 and first quarter of 2023 include 2x1 collars where the put volumes of 561,200 and 360,000 are two times the call volumes of 280,600 and 180,000, respectively.

~~(2)~~

The WAHA basis swaps in place for the remainder of 2022 consist of five derivative contracts, each with a fixed price of the Henry Hub natural gas price less a fixed amount (weighted average of $0.57 per MMBtu).

~~(3)~~

The WAHA basis swaps in place for the calendar year of 2023 consist of two derivative contracts, each with a fixed price of the Henry Hub natural gas price less a fixed amount (weighted average of $0.55 per MMBtu).

NOTE 7 –— FAIR VALUE MEASUREMENTS

Fair value is 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 (exit price). The authoritative guidance requires disclosure of the framework for measuring fair value and requires that fair value measurements be classified and disclosed in one of the following categories:

Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. The Company considers active markets as those in which transactions for the assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2: Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that the Company values using observable market data. Substantially all inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3: Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e., supported by little or no market activity).


Level 1:			Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. We consider active markets as those in which transactions for the assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2:			Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that we value using observable market data. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3:			Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e., supported by little or no market activity).

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. ~~The Company’s~~Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy. ~~The Company continues~~We continue to evaluate ~~its~~our inputs to ensure the fair value level classification is appropriate. When transfers between levels occur, it is ~~the Company’s~~our policy to assume that the transfer occurred at the date of the event or change in circumstances that caused the transfer.

The fair values of the Company’s derivatives are not actively quoted in the open market. The Company uses a market approach to estimate the fair values of its derivative instruments on a recurring basis, utilizing commodity futures pricing for the underlying commodities provided by a reputable third party, a Level 2 fair value measurement.

Other financial instruments include cash, accounts receivable and accounts payable. 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 the carrying amounts and fair value are approximately equal.

The Company applies the provisions of the fair value measurement standard on a non-recurring basis to its non-financial assets and liabilities. 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.

Table of Contents

The following table summarizes the valuation of ~~the Company’s~~our assets and liabilities that are measured at fair value on a recurring ~~basis(further~~basis (further detail in ~~Note 6)~~"NOTE 6 — DERIVATIVE FINANCIAL INSTRUMENTS").

Fair Value Measurement Classification

Quoted prices

in Active

Markets

for Identical

Significant

Assets

Other

Significant

or

Observable

Unobservable

(Liabilities)

Inputs

Inputs


(Level 1)

(Level 2)

(Level 3)

Total
As of December 31, 2021

Commodity Derivatives - Liabilities

$
—

$
(29,241,588)

$
—

$
(29,241,588)
Total

$
—

$
(29,241,588)

$
—

$
(29,241,588)

Fair Value Measurement Classification

Quoted prices

in Active

Markets

for Identical

Significant

Assets

Other

Significant

or

Observable

Unobservable

(Liabilities)

Inputs

Inputs


(Level 1)

(Level 2)

(Level 3)

Total
As of September 30, 2022









Commodity Derivatives - Assets

$
—

$
24,867,995

$
—

$
24,867,995
Commodity Derivatives - Liabilities

—

(32,502,077)

—

(32,502,077)
Total

$
—

$
(7,634,082)

$
—

$
(7,634,082)


	Fair Value Measurement Classification
	Quoted prices in Active Markets for Identical Assets or (Liabilities) (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
As of December 31, 2022

Commodity Derivatives - Assets	$	—	$	10,798,572	$	—	$	10,798,572
Commodity Derivatives - Liabilities	$	—	$	(23,831,269)	$	—	$	(23,831,269)

Total	$	—	$	(13,032,697)	$	—	$	(13,032,697)

As of September 30, 2023

Commodity Derivatives - Assets	$	—	$	8,310,488	$	—	$	8,310,488
Commodity Derivatives - Liabilities	$	—	$	(41,996,647)	$	—	$	(41,996,647)

Total	$	—	$	(33,686,159)	$	—	$	(33,686,159)

The carrying amounts reported for the revolving line of credit approximates fair value because the underlying instruments are at interest rates which approximate current market rates. The carrying amounts of receivables and accounts payable and other current assets and liabilities approximate fair value because of the short-term maturities and/or liquid nature of these assets and liabilities.

NOTE 8 –— REVOLVING LINE OF CREDIT

On July 1, 2014, the Company entered into a Credit Agreement with SunTrust Bank (now Truist), as lender, issuing bank and administrative agent for several banks and other financial institutions and lenders (the “Administrative Agent”), (which was amended several times) that provided for a maximum borrowing base of $1 billion with security consisting of substantially all of the assets of the Company. In April 2019, the Company amended and restated ~~its~~the Credit Agreement with the Administrative Agent (as amended and restated, the “Credit Facility”). The amendment and restatement of the Credit Facility, among other things, increased the maximum borrowing amount to $1 billion, extended the maturity date through April 2024 and made other modifications to the terms of the Credit Facility. The fourth amendment on June 10, 2021, among other things, reaffirmed the borrowing base at $350 million and modified the definition for “Fall 2020 Borrowing Base Hedges,” from 4,000 barrels of oil per day to 3,100 barrels of oil per day for calendar year 2022. The

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

fifth amendment on June 25, 2021 incorporated contractual fallback language for US dollar LIBOR denominated syndicated loans, which language provides for the transition away from LIBOR to an alternative reference rate, and incorporates certain provisions that clarify the rights of agents to recover from lenders erroneous payments made to such lenders. The Credit Facility is secured by a first lien on substantially all of the Company’s assets. The borrowing base is subject to periodic redeterminations, mandatory reductions, and further adjustments from time to time. The borrowing base is redetermined semi-annually in May and November. The May 2022 redetermination was postponed due to the Stronghold Acquisition (see Note 5).

On August 31, 2022, the Company modified its Credit Facility through ~~the~~a Second Amended and Restated Credit ~~Agreement.~~Agreement (the "Second Credit Agreement"), extending the maturity date of the facility to August 2026 and the syndicate was modified to add five lenders, replacing five exiting lenders. In conjunction with the Stronghold Acquisition, with the newly acquired assets put up for collateral, the Company established a borrowing base of $600 million. The ~~syndicate was modified~~borrowing base is subject to ~~add five lenders, replacing five exiting lenders.~~ periodic redeterminations, mandatory reductions and further adjustments from time to time. The borrowing base is redetermined semi-annually each May and November. The borrowing base is subject to reduction in certain circumstances such as the sale or disposition of certain oil and gas properties of the Company or its subsidiaries and cancellation of certain hedging positions.

Rather than Eurodollar loans, the reference rate on the Second ~~Amended and Restated~~ Credit Agreement is the Standard Overnight Financing Rate (“SOFR”). ~~Beginning June 30, 2023,~~Also, it permits the ~~Credit Agreement will allow for the C~~Company to declare dividends for its equity owners, subject to certain ~~limitations.~~

~~The Credit Facility now allows for SOFR Loans~~limitations, including (i) no default or event of default has occurred or will occur upon such payments, (ii) the pro forma Leverage Ratio (outstanding debt to adjusted earnings before interest, taxes, depreciation and amortization, exploration expenses, and all other non-cash charges acceptable to the Administrative Agent) does not exceed 2.00 to 1.00, (iii) the amount of such payments does not exceed Available Free Cash Flow (as defined), and (iv) the Borrowing Base ~~Rate Loans~~Utilization Percentage (as ~~respectively defined in the Second Amended and Restated Credit Agreement)~~defined) is not greater than 80%.

The interest rate on each SOFR ~~Loan will be~~loan is the adjusted term SOFR for the applicable interest period plus a margin between 3.0% and 4.0% (depending on the then-current level of borrowing base usage). The annual interest rate on each ~~Base Rate Loan~~base rate

Table of Contents

loan is (a) the greatest of (i) the Administrative Agent’s prime lending rate, (ii) the Federal Funds Rate (as ~~defined in the Second Amended and Restated Credit Agreement)~~defined) plus 0.5% per annum, (iii) the adjusted term SOFR determined on a daily basis for an interest period of ~~one-month,~~one month, plus 1.00% per annum and (iv) 0.00% per annum, plus (b) a margin between 2.0% and 3.0% per annum (depending on the then-current level of borrowing base usage).

The Second ~~Amended and Restated~~ Credit Agreement contains certain covenants, which, among other things, require the maintenance of (i) a total Leverage Ratio ~~(outstanding debt to adjusted earnings before interest, taxes, depreciation and amortization, exploration expenses, and all other non-cash charges acceptable to the Administrative Agent)~~ of not more than 3.0 to 1.0 and (ii) a minimum ratio of Current Assets to Current Liabilities (as such terms are ~~defined in the Second Amended and Restated Credit Agreement)~~defined) of 1.0 to 1.0. The Second ~~Amended and Restated~~ Credit Agreement also contains other customary affirmative and negative covenants and events of default. As of September 30, 2022, $435,000,000 was outstanding under on the Credit Facility. The Company is in compliance with all covenants contained in the Second Amended and Restated Credit Agreement as of September 30, 2022.

The Company is required to maintain on a rolling 24 ~~month~~months basis, hedging transactions in respect of crude oil and natural gas, on not less than 50% of the projected production from ~~the~~its proved, developed, producing oil and gas. IfHowever, if the borrowing base utilization is less than 25% at the hedge testing date and the ~~leverage ratio~~Leverage Ratio is not greater than 1.25 to 1.00, the required hedging percentage for months 13 through 24 of the rolling 24 month period ~~provided for shall~~will be 0% from such hedge testing date to the next succeeding hedge testing ~~date. If~~date and if the borrowing base utilization percentage is equal to or greater than 25%, but less than 50% and the ~~leverage ratio~~Leverage Ratio is not greater than 1.25 to ~~1.0,~~1.00, the required hedging percentage for months 13 through 24 of the rolling 24 month period ~~provided for shall~~will be 25% from such hedge testing date to the next succeeding hedge testing date.

As of September 30, 2023, $428 million was outstanding on the Credit Facility and the Company was in compliance with all covenants in the Second Credit Agreement.

Under the Second Credit Agreement, the applicable percentage for the unused commitment fee is 0.5% per annum for all levels of borrowing base utilization. As of September 30, 2023, the Company's unused line of credit was $171.2 million, which was calculated by subtracting the outstanding Credit Facility balance of $428 million and standby letters of credit of $760,438 ($260,000 with state and federal agencies and $500,438 with an insurance company for New Mexico state surety bonds) from the $600 million borrowing base.

NOTE 9 –— ASSET RETIREMENT OBLIGATION

The Company records the obligation to plug and abandon oil and gas wells at the dates properties are either acquired or the wells are drilled. The asset retirement obligation is adjusted each quarter for any liabilities incurred or settled during the period, accretion expense and any revisions made to the costs or timing estimates. The asset retirement obligation is incurred using an annual credit-adjusted risk-free discount rate at the applicable dates. Changes in the asset retirement obligation during the nine months ended September 30, 2023 were as follows:

Balance, December 31, 2021

$
15,292,054
Liabilities incurred

218,082
Liabilities acquired

14,538,550
Liabilities sold

—
Revision of previous estimates

—
Liabilities settled

(1,239,634)
Accretion expense

617,685
Balance, September 30, 2022

$
29,426,737

Balance, December 31, 2022 $ 30,226,306
Liabilities acquired 2,090,777
Liabilities incurred 261,786
Liabilities sold (4,717,507)
Liabilities settled (226,424)
Revision of estimate 53,824
Accretion expense 1,073,901
Balance, September 30, 2023 $ 28,762,663

The following table presents the Company's current and non-current asset retirement obligation balances as of the periods specified.


	September 30, 2023		December 31, 2022
Asset retirement obligations, current	279,681		635,843
Asset retirement obligations, non-current	28,482,982		29,590,463
Asset retirement obligations	$	28,762,663	$	30,226,306

Table of Contents

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

NOTE 10 ~~– STOCKHOLDERS’~~— STOCKHOLDERS' EQUITY ~~AND MEZZANINE EQUITY~~

~~During the year ended~~

As of December 31, ~~2021, 13,428,500 pre-funded common stock warrants and 442,600~~2022, the Company had 19,107,793 exercisable common warrants, ~~were exercised. Gross proceeds from these transactions were $367,509. On April 5, April 6, and April 7, 2022,~~with a total of 6,453,907 common stock warrants were exercised at a price of $0.80 per share for gross proceeds of $5,163,126. On August 19, August 25, and September 8, a total of 3,000,000 common stock warrants were exercised at a price of $0.80 per share for gross proceeds of $2,400,000. At September 30, 2022, there remained 19,907,793 unexercised common stock warrants, with ancontractual exercise price of $0.80 per ~~share.~~

~~Common Stock~~warrant, expiring five years from initial issuance in October 2020. During the nine months ended September 30, 2023, a total of 19,029,593 common warrants were exercised. The following table reflects the common warrants exercised, including the proceeds received for such exercises. As of September 30, 2023 there remained 78,200 exercisable common warrants.


	Common Warrants	Exercise Price		Proceeds Received
Exercisable, December 31, 2021	29,361,700	$	0.80
Exercised	—	—		$	—
Exercisable, March 31, 2022	29,361,700	$	0.80
Exercised	(6,453,907)	0.80		$	5,163,126
Exercisable, June 30, 2022	22,907,793	$	0.80
Exercised	(3,000,000)	0.80		$	2,400,000
Exercisable, September 20, 2022	19,907,793	$	0.80

Exercisable, December 31, 2022	19,107,793	$	0.80
Exercised	(4,517,427)	0.80		$	3,613,941
Exercisable, March 31, 2023	14,590,366	$	0.80
Exercised (1)	(14,512,166)	0.62		$	8,997,543
Exercisable, June 30, 2023	78,200	$	0.80
Exercised	—	—		$	—
Exercisable, September 30, 2023	78,200	$	0.80

(1) On April 11 and ~~Convertible Preferred Stock~~

~~As part~~12, 2023, the Company and certain holders of the ~~Stronghold Acquisition, 21,339,986 shares~~common warrants (the “Participating Holders”) entered into a form of ~~our~~Warrant Amendment and Exercise Agreement (the “Exercise Agreement”) pursuant to which the Company agreed to reduce the exercise price of an aggregate of 14,512,166 common ~~stock were issued as “restricted shares”~~warrants held by such Participating Holders from $0.80 to ~~Stronghold OpCo.~~

~~Also as part~~$0.62 per share (the “Reduced Exercise Price”) in consideration for the immediate exercise of the ~~Stronghold Acquisition, 153,176 shares~~common warrants held by such Participating Holders in full at the Reduced Exercise Price in cash. The Company received aggregate gross proceeds of ~~Preferred Stock were issued. Each share of Preferred Stock is automatically convertible into 277.7778 shares of common stock upon stockholder approval~~$8,997,543 from the exercise of the ~~conversion (42,548,892 shares~~common warrants by the Participating Holders pursuant to the Exercise Agreement, which was recognized as an equity issuance cost in accordance with ASC 815-40-35-17(a). In the Statements of ~~common stock~~Stockholders' Equity, the net impact to Stockholders' Equity is $8,687,655, which is net of $309,888 in ~~total). We have classified the fair value of the Preferred Stock on our Balance Sheets under Mezzanine Equity.~~

On September 26, 2022, a proxy statement was filed under the Securities Exchange Act of 1934 for our stockholders to consider and vote upon the conversion of the preferred shares into 42,548,892 shares of common stock. A special meeting of stockholders to vote on the conversion was held on October 27, 2022. Please see Note 13 – SUBSEQUENT EVENTS for more information regarding the stockholder meeting at which the conversion was approved.

advisory fees.

NOTE 11 –— EMPLOYEE STOCK OPTIONS AND RESTRICTED STOCK ~~AWARD PLAN~~

UNITS

Compensation expense charged against income for share-based awards during the three and nine months ended September 30, 2023 and 2022 was ~~$1,543,033 and $4,964,188, respectively, compared to $777,461 and $1,484,730 for the three and nine months ended September 30, 2021.~~as follows. These amounts are included in General and administrative expense in the ~~accompanying financial statements.~~

Condensed Statements of Operations.


	Three Months Ended				Nine Months Ended
	September 30, 2023		September 30, 2022		Sep. 30, 2023		Sep. 30, 2022
Share-based compensation	$	2,170,735	$	1,543,033	$	6,374,743	$	4,964,188

In 2011, the ~~Company’s board of directors and stockholders~~Board approved and adopted a long-term incentive plan (the “2011 Plan”), which ~~allowed for~~was subsequently approved and amended by the issuance of up to 2,500,000 shares of common stock through the grant of qualified stock options, non-qualified stock options and restricted stock. In 2013, the Company’s board of directors and stockholders approved an amendment to the long-term incentive plan, increasing the number of shares eligible under the plan to 5,000,000 shares.shareholders. There were ~~341,155~~341,755 shares ~~remaining~~ eligible for grant, either as stock options or as restricted stock, as of September 30, ~~2022.~~

2023.

In ~~May~~ 2021, the ~~Company’s board of directors and stockholders~~Board approved and adopted ~~a long-term incentive plan~~the Ring Energy, Inc. 2021 Omnibus Incentive Plan (the “2021 Plan”), which ~~allowed for~~was subsequently approved by the ~~issuance of up to 9,900,000~~shareholders at the 2021 Annual Meeting. The 2021 Plan provides that the Company may grant options, stock appreciation rights, restricted shares, ~~including 341,155 shares that were reserved but unissued under the prior plan, of common stock subject to the grant of qualified stock options, non-qualified stock options,~~ restricted stock units, ~~and restricted stock. There were 5,577,843~~performance-based awards, other share-based awards, other cash-based awards, or any combination of the foregoing. At the 2023 Annual Meeting, the

Table of Contents

shareholders approved a Plan Amendment to increase the number of shares ~~eligible for grant~~available under the 2021 Plan by 6.0 million. Accordingly, there were 8,224,394 shares available for grant as of September 30, ~~2022.~~

2023 under the 2021 Plan.

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Stock Options

A summary of the status of the stock ~~option activity~~options as of September 30, ~~2022~~2023 and ~~2021, respectively,~~2022 and changes during the ~~three and~~respective nine ~~months~~month periods then ended isare as follows:

Weighted-


Weighted-

Average

Average

Remaining

Aggregate

Exercise

Contractual

Intrinsic


Shares

Price

Term

Value
Outstanding, December 31, 2020

465,500

$
3.26



Granted

—

—



Forfeited or rescinded

—

—



Exercised

—

—

Outstanding, March 31, 2021

465,500

$
3.26

3.00 Years

$
134,850
Granted

—

—

Forfeited or rescinded

—

—

Exercised

—

—



Outstanding, June 30, 2021

465,500

$
3.26

2.75 Years

$
426,300
Granted

—

—

Forfeited or rescinded

—

—

Exercised

—

—

Outstanding, September 30, 2021

465,500

$
3.26

2.61 Years

$
375,250
Exercisable, September 30, 2021

458,300

$
3.13

2.57 Years

Outstanding, December 31, 2021

365,500

$
3.61

Granted

—

—

Forfeited or rescinded

—

—

Exercised

—

—


Outstanding, March 31, 2022

365,500

$
3.61

2.21 Years

$
536,900
Granted

—

—



Forfeited or rescinded

—

—



Exercised

(100,000)

$
2.00



Outstanding, June 30, 2022

265,500

4.21

2.14 Years

$
128,700
Granted

—

—

Forfeited or rescinded

—

—

Exercised

—

—

Outstanding, September 30, 2022

265,500

$
4.21

1.89 Years

$
62,400
Exercisable, September 30, 2022

265,500

$
4.21

1.89 Years


	Options	Weighted- Average Exercise Price		Weighted-Average Remaining Contractual Term	Aggregate Intrinsic Value
Outstanding, December 31, 2021	365,500	$	3.61
Granted	—	—
Forfeited or rescinded	—	—
Exercised	—	—
Outstanding, March 31, 2022	365,500	$	3.61	2.21 years	$	536,900

Granted	—	—
Forfeited or rescinded	—	—
Exercised	(100,000)	2.00
Outstanding, June 30, 2022	265,500	$	4.21	2.14 years	$	128,700

Granted	—	—
Forfeited or rescinded	—	—
Exercised	—	—
Outstanding, September 30, 2022	265,500	$	4.21	1.89 years	$	62,400
Exercisable, September 30, 2022	265,500	$	4.21	1.89 years

Outstanding, December 31, 2022	265,500	$	4.21
Granted	—	—
Forfeited or rescinded	—	—
Exercised	—	—
Outstanding, March 31, 2023	265,500	$	4.21	1.39 years	$	—

Granted	—	—
Forfeited or rescinded	—	—
Exercised	—	—
Outstanding, June 30, 2023	265,500	$	4.21	1.14 years	$	—

Granted	—	$	—
Forfeited or rescinded	—	$	—
Exercised	—	$	—
Outstanding, September 30, 2023	265,500	$	4.21	0.89 years	$	—
Exercisable, September 30, 2023	265,500	$	4.21	0.89 years

The intrinsic values were calculated using the closing price on September 30, ~~2022~~2023 of ~~$2.32~~$1.95 and the closing price on September 30, ~~2021~~2022 of ~~$2.95.~~$2.32. As of September 30, ~~2022, there was~~2023, the Company had $0 of unrecognized compensation cost related to stock options.

~~Table of Contents~~

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Restricted Stock

Units

A summary of the restricted stock unit activity as of September 30, 2023 and 2022, ~~and 2021,~~respectively, and changes during the ~~three and~~respective nine ~~months~~month periods then ended isare as follows:

Table of Contents

Weighted-

Average Grant


Restricted stock

Date Fair Value
Outstanding, December 31, 2020

2,132,297

$
1.03
Granted

—

—
Forfeited or rescinded

—

—
Vested

(94,350)

4.95
Outstanding, March 31, 2021

2,037,947

$
0.85
Granted

1,196,102

2.77
Forfeited or rescinded

—

—
Vested

(3,480)

5.96
Outstanding, June 30, 2021

3,230,569

$
1.55
Granted

29,554

2.69
Forfeited or rescinded

—

—
Vested

(12,500)

2.15
Outstanding, September 30, 2021

3,247,623

$
1.56

Outstanding, December 31, 2021

2,572,596

$
1.75
Granted

1,247,061

2.79
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, March 31, 2022

3,819,657

$
2.09
Granted

19,642

4.27
Forfeited or rescinded

(17,204)

2.79
Vested

(610,195)

2.80
Outstanding, June 30, 2022

3,211,900

$
1.97
Granted

126,570

2.95
Forfeited or rescinded

—

—
Vested

(9,851)

2.69
Outstanding, September 30, 2022

3,328,619

$
2.00


	Restricted Stock Units	Weighted- Average Grant Date Fair Value
Outstanding, December 31, 2021	2,572,596	$	1.75
Granted	1,247,061	2.79
Forfeited or rescinded	—	—
Vested	—	—
Outstanding, March 31, 2022	3,819,657	$	2.09
Granted	19,642	$	4.27
Forfeited or rescinded	(17,204)	$	2.79
Vested	(610,195)	$	2.80
Outstanding, June 30, 2022	3,211,900	$	1.97
Granted	126,570	2.95
Forfeited or rescinded	—	—
Vested	(9,851)	2.69
Outstanding, September 30, 2022	3,328,619	$	2.00

Outstanding, December 31, 2022	2,623,790	$	2.29
Granted	2,270,842	2.22
Forfeited or rescinded	(11,712)	2.22
Vested	(659,479)	2.80
Outstanding, March 31, 2023	4,223,441	$	2.17
Granted	—	$	—
Forfeited or rescinded	(49,465)	$	2.22
Vested	(288,709)	$	2.85
Outstanding, June 30, 2023	3,885,267	$	2.12
Granted	—	—
Forfeited or rescinded	(4,997)	2.22
Vested	(39,443)	2.87
Outstanding, September 30, 2023	3,840,827	$	2.12

As of September 30, ~~2022 there was $3,468,926~~2023, the Company had $3,928,247 of unrecognized compensation cost related to restricted stock unit grants that will be recognized over a weighted average period of ~~1.90~~1.85 years.

Grant activity for the nine months ended September 30, ~~2022~~2023 was primarily restricted ~~shares~~stock units for the annual long-term incentive plan awards for employees.

Table of Contents

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Performance Stock Units

A summary of the status of the performance stock unit ~~activity~~("PSU") grants as of September 30, 2023 and 2022, ~~and 2021, and~~respectively, along with changes during the ~~three and~~respective nine ~~months~~month periods then ended isare as follows:

Weighted-

Performance

Average Grant

Stock Units

Date Fair Value
Outstanding, December 31, 2020

—

$
—
Granted

—

—
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, March 31, 2021

—

$
—
Granted

—

—
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, June 30, 2021

—

$
—
Granted

—

—
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, September 30, 2021

—

$
—

Outstanding, December 31, 2021

860,216

$
3.87
Granted

860,216

3.65
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, March 31, 2022

1,720,432

$
3.76
Granted

—

—
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, June 30, 2022

1,720,432

$
3.76
Granted

—

—
Forfeited or rescinded

—

—
Vested

—

—
Outstanding, September 30, 2022

1,720,432

$
3.76


	Performance Stock Units	Weighted- Average Grant Date Fair Value
Outstanding, December 31, 2021	860,216	$	3.87
Granted	860,216	3.65
Forfeited or rescinded	—	—
Vested	—	—
Outstanding, March 31, 2022	1,720,432	$	3.76
Granted	—	$	—
Forfeited or rescinded	—	$	—
Vested	—	$	—
Outstanding, June 30, 2022	1,720,432	$	3.76
Granted	—	—
Forfeited or rescinded	—	—
Vested	—	—
Outstanding, September 30, 2022	1,720,432	$	3.76

Outstanding, December 31, 2022	1,720,432	$	3.76
Granted	1,162,162	2.71
Forfeited or rescinded	—	—
Vested	—	—
Outstanding, March 31, 2023	2,882,594	$	3.34
Granted	—	$	—
Forfeited or rescinded	—	$	—
Vested	—	$	—
Outstanding, June 30, 2023	2,882,594	$	3.34
Granted	—	—
Forfeited or rescinded	—	—
Vested	—	—
Outstanding, September 30, 2023	2,882,594	$	3.34

As of September 30, ~~2022, there was $4,681,787~~2023, the Company had $5,314,823 of unrecognized compensation cost related to ~~performance stock units~~the PSU awards that will be recognized over a weighted average period of ~~1.79~~1.60 years.

NOTE 12 –— COMMITMENTS AND CONTINGENCIES ~~AND COMMITMENTS~~

Standby Letters of Credit – A commercial bank issued standby letters of credit on behalf of the Company totaling $260,000 to ~~a state agency for $250,000 on June 26, 2015, a~~the State of Texas and federal ~~agency for $10,000 on April 9, 2019,~~agencies and $500,438 to an insurance company ~~on May 19, 2020 for $500,438.~~to secure the surety bonds described below. The standby letters of credit are valid until cancelled or matured and are collateralized by the ~~Credit Facility.~~revolving credit facility with the bank. The terms of the letters of credit to the state and federal agencies are extended for a term of one year at a time. The Company intends to renew the standby letters of credit to the state and federal agencies for as long as the Company does business in the ~~States~~State of ~~Texas and New Mexico.~~Texas. The ~~letter~~letters of credit to the insurance company ~~relates~~will be renewed if the insurance requires them to retain the surety ~~bonds noted below.~~bonds; however, as the Company no longer operates any wells in the State of New Mexico, these standby letters of credit will not be renewed. No amounts have been drawn under the standby letters of credit.

Table of Contents

~~RING ENERGY, INC.~~

~~NOTES TO CONDENSED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

Surety Bonds -– An insurance company issued surety bonds on behalf of the Company totaling $500,438 to various State of New Mexico agencies in order for the Company to do business in the State of New Mexico. The surety bonds are valid until canceled or matured. The terms of the surety bonds are extended for a term of one year at a time. The Company ~~intends~~does not intend to renew the surety bonds ~~on $400,000 as long as the Company does business~~ in the State of New ~~Mexico. The remaining $100,438 is related~~Mexico, as these operated assets have now been sold to ~~inactive wells and will remain in place until the Company returns those wells to activity or plugs them.~~a third party. As of September 30, ~~2022,~~2023, the Company still had surety bonds in total of ~~$450,288, with $50,288 related~~$650,288 for the State of New Mexico; however, these bonds are expected to ~~inactive wells.~~

be eliminated once change of ownership is approved by the New Mexico Oil Conservation Division.

NOTE 13 –— SUBSEQUENT EVENTS

Effective October 1, 2022, the Company amended its Midland, Texas office lease to extend the term from October 1, 2022 to September 30, 2027 (five year lease). This will be reflected in the lease liability and future payments in the leases note disclosure for the year ending December 31, 2022.

On October 13, 2022, our Form S-3 Registration Statement was declared effective by the SEC in respect of 63,888,878 shares in aggregate of our common stock (21,339,986 shares of common stock issued at the closing of the Stronghold Acquisition and 42,548,892 shares of as-converted Preferred Stock), which shares may be offered by certain stockholders from time to time in one or more offerings.

On October 27, 2022, the Company’s stockholders approved the issuance of, 42,548,892 shares of common stock upon conversion of the 153,176 shares of our Preferred Stock. The preferred shares were automatically converted into such~~common shares as of October 27,2022.~~

In accordance with ASC Topic 855, Subsequent Events, the Company has evaluated all events subsequent to the balance sheet date of September 30, ~~2022,~~2023, through the date of this ~~report and has reported all~~report. The Company did not have any material subsequent ~~events.~~

events to report.

Table of Contents

Item 2.2: Management’s Discussion and Analysis of Financial Condition and Results of Operations

~~Management’s Discussion~~

The following discussion and ~~Analysis of Financial Condition and Results of Operations analyzes the major elements of our Balance Sheets and Statements of Operations. This section~~analysis should be read in conjunction with our ~~Annual Report on Form 10-K for the year ended December 31, 2021 and our interim unaudited~~accompanying condensed financial statements and ~~accompanying~~the notes to those condensed financial statements included elsewhere in this Quarterly Report. The following discussion includes forward-looking statements that reflect our plans, estimates and beliefs and our actual results could differ materially from those discussed in these ~~financial statements.~~

forward-looking statements as a result of many factors, including those discussed under “Risk Factors,” "Forward Looking Statements" and elsewhere in this Quarterly Report.

Overview

Ring Energy, Inc. ~~(“Ring,” the “Company,” “our,” “we,” “us,” or~~(the "Company," "Ring," "we," "us," "our" and similar terms) is a growth oriented independent exploration and production company ~~and is~~based in The Woodlands, Texas engaged in oil and natural gas development, production, acquisition, and exploration activities currently focused in ~~Texas and New Mexico.~~the Permian Basin of Texas. Our primary drilling operations target the oil and liquids rich producing formations in the Northwest Shelf and the Central Basin Platform, ~~and the Delaware Basin, all~~both of which are part of the Permian Basin.~~Our corporate headquarters are in The Woodlands, Texas.~~

~~Recent Developments~~

~~Stronghold Acquisition~~

On July 1, 2022, Ring, as buyer, and Stronghold Energy II Operating, LLC, a Delaware limited liability company (“Stronghold OpCo”) and Stronghold Energy II Royalties, LP, a Delaware limited partnership (“Stronghold RoyaltyCo”, together with Stronghold OpCo, collectively, “Stronghold”), as seller, entered into a purchase and sale agreement (the “Purchase Agreement”). Pursuant to the Purchase Agreement, Ring acquired (the “Stronghold Acquisition”) interests in oil and gas leases and related property of Stronghold consisting of approximately 37,000 net acres located in the Central Basin Platform of the Texas Permian Basin. On August 31, 2022, Ring completed the Stronghold Acquisition pursuant to the Purchase Agreement.

The fair value of consideration paid to Stronghold was approximately $395.7 million, of which $167.9 million, subject to post-closing adjustment was paid in cash at closing, $15.0 million will be payable in cash after the six-month anniversary of the closing date of the Stronghold Acquisition, and shortly after closing approximately $4.5 million was paid for inventory and vehicles and approximately $1.8 million was paid for August oil derivative settlements for the novated hedges. The cash portion of the consideration was funded primarily from borrowings under an amended and restated fully committed revolving credit facility (the “Credit Facility”) underwritten by Truist Securities, Citizens Bank, N.A., KeyBanc Capital Markets Inc., and Mizuho Bank, Ltd. The borrowing base of the $1.0 billion Credit Facility was increased from $350.0 million to $600.0 million at the closing of the transaction. The remaining consideration was in the form of stock, consisting of 21,339,986 shares of Ring common stock and 153,176 shares of newly created Series A Convertible Preferred Stock, par value $0.001 (“Preferred Stock”). Please see “Note 10 – STOCKHOLDERS’ EQUITY AND MEZZANINE EQUITY” for further discussion. In addition, Ring assumed $24.8 million of derivative liabilities, $1.7 million of items in suspense and $14.5 million in asset retirement obligations in the Stronghold Acquisition.

Business Description and Plan of Operation

~~We are~~

The Company is focused on ~~delivering~~balancing the need to reduce long-term debt and further developing our oil and gas properties to maintain or grow our annual production. We intend to achieve both through proper allocation of cash flow generated by our operations and potentially through the sale of non-core assets. We intend to continue evaluating potential transactions to acquire strategic producing assets with attractive acreage positions that can provide competitive returns for our shareholders.

•Growing production and ~~sustainable returns to our stockholders~~reserves by developing ~~acquiring, exploring for,~~our oil-rich resource base through conventional and ~~commercializing oil~~horizontal drilling. In an effort to maximize its value and ~~natural gas~~ resources ~~vital~~potential, Ring intends to drill and develop its acreage base in both the ~~world’s health~~Northwest Shelf and ~~welfare. Successfully achieving Ring’s mission requires a firm commitment~~Central Basin Platform assets, allowing Ring to execute on its plan of operating ~~safely in a socially responsible~~within its generated cash flow.

•Reduction of long-term debt and ~~environmentally friendly manner, while ensuring~~deleveraging of asset. Ring intends to reduce its long-term debt primarily through the use of excess cash flow and potentially through the sale of non-core assets. The Company believes that with its attractive field level margins, it is well positioned to maximize the value of its assets and deleverage its balance sheet. The Company also believes through potential accretive acquisitions and strategic asset dispositions, it can accelerate the strengthening of its balance sheet. During the three months ended September 30, 2023, the Company ~~conducts~~made net drawings of $31 million on its ~~business~~revolving line of credit, resulting in the outstanding long-term debt balance of $428 million.

•Employ industry leading drilling and completion techniques. Ring’s executive team intends to utilize new and innovative technological advancements for completion optimization, comprehensive geological evaluation, and reservoir engineering analysis to generate value and to build future development opportunities. These technological advancements have led to a low-cost structure that helps maximize the returns generated by our drilling programs.

•Pursue strategic acquisitions with ~~honesty~~attractive upside potential. Ring has a history of acquiring leasehold positions that it believes to have additional resource potential that meet its targeted returns on invested capital and ~~integrity. Specifically, our business~~comparable to its existing inventory of drilling locations. We pursue an acquisition strategy isdesigned to increase ~~our stockholders’ value through~~reserves at attractive finding costs and complement existing core properties. Management intends to continue to pursue strategic acquisitions and structure the ~~following:~~

●

~~Growing production and reserves by developing our oil-rich resource base through conventional and horizontal drilling.~~ In an effort to maximize its value and resource potential, Ring intends to drill and develop its acreage base in both the Northwest Shelf and Central Basin Platform assets, allowing Ring to execute on its plan of operating within its generated cash flow.

potential transactions financially, so they improve balance sheet metrics and are accretive to shareholders. Our executive team, with its extensive experience in the Permian Basin, has many relationships with operators and service providers in the region. Ring believes that leveraging the relationships of its management and board of directors will be a competitive advantage in identifying potential acquisition targets.

2023 Developments and Highlights

Drilling, Completion, and Recompletion

Table of Contents

In the first quarter of 2022, Ring contracted a rig on January 31, 2022, and drilled and completed three 1-mile horizontal Central Basin Platform wells and one 1.5-mile horizontal Central Basin Platform well and drilled two 1-mile horizontal wells2023, in the Northwest Shelf. The Company has a working interest of 100% in all wells drilled in the first quarter 2022. The newly completed wells resulted in minimal contribution to first quarter production but were situated to provide a strong contribution going forward. In addition to the six drilled wells and four new wells placed on production, during the first quarter, the Company continued its program of conversions from electrical submersible pumps to rod pumps “CTRs”, with four conversions in the Northwest Shelf.

~~Table of Contents~~

During the second quarter of 2022, Ring drilled a total of nine wells, completed seven wells, and began the completion process on four wells, all in the Northwest Shelf. Two of the wells completed were 1-mile horizontal wells that were drilled in the first quarter with both wells at a working interest of 100%. In addition, there were three 1-mile horizontal wells with a working interest of 100% and two 1.5-mile horizontal wells with a working interest of approximately 98.7% that were drilled and completed in the second quarter. Ring also drilled and began the completion process on an additional four 1-mile horizontal wells. Two of the wells have a working interest of 100%, one has a working interest of 87.5%, and the fourth has a working interest of 75%. In addition to the nine drilled wells and seven new wells placed on production, during the second quarter, the Company continued its program of conversions from electrical submersible pumps to rod pumps (“CTRs”), with three conversions in the Northwest Shelf and one conversion in the Central Basin Platform.

In the third quarter of 2022, Ring completed and placed on production the four 1-mile horizontal wells in the Northwest Shelf on which the Company had begun the completion process during the second quarter of 2022. In the Central Basin Platform, the Company drilled and completed two 1.5-mile horizontal wells and one 1-mile horizontal well, each with a working interest of 100%. In the Northwest Shelf, the Company drilled and completed two 1-mile horizontal wells (each with a working interest of 100%), and two 1.5-mile horizontal wells (one with a working interest of approximately 99.8% and the other with a working interest of approximately 75.4%). Next, in its Crane County acreage within the Central Basin Platform, the Company drilled and completed three vertical wells (each with a working interest of 100%) and performed six vertical well recompletions (each with a working interest of 100%).

In the second quarter of 2023, in the Northwest Shelf, the Company drilled and completed two 1.5-mile horizontal wells (one with a working interest of 100% and the other with a working interest of approximately 75.4%) and two 1-mile horizontal wells (both with a working interest of approximately 91.1%). Additionally, in its Crane County acreage within the Central Basin Platform, the Company drilled and completed two vertical wells (each with a working interest of 100%) and performed three vertical well recompletions (each with a working interest of 100%).

During the ~~last month~~third quarter of 2023, the ~~quarter,~~Company drilled and completed two 1-mile horizontal wells (one with a working interest of 100% and the other with a working interest of 75%) in the Northwest Shelf, and three 1.5-mile horizontal wells (each with a working interest of 100%) in the Central Basin Platform. Additionally, in its Crane County acreage within the Central Basin Platform, the Company drilled and completed three vertical wells (each with a working interest of 100%). Lastly, the Company drilled and began the completion process on three 1-mile horizontal wells in the Northwest Shelf ~~each~~(each with a working interest of ~~100%~~90%). In total, during the third quarter of 2022, Ring drilled eight horizontal wells, completed nine horizontal wells, and began the completion process on three horizontal wells. Ring performed three recompletions in the Central Basin Platform. In addition, the Company continued its CTR program, with five conversions in the Northwest Shelf and one conversion in the Central Basin Platform.

The table below sets forth our drilling and completion activities for ~~2022 by quarter through~~2023 in the nine months ended September 30, ~~2022.~~

Wells Began




Wells

Wells

Completion

Quarter

Area

Drilled

Completed

Process

CTRs

Recompletions

1Q 2022

Central Basin Platform

4

4

—

—

—

Delaware Basin

—

—

—

—

—

Northwest Shelf

2

—

—

4

—

2Q 2022

Central Basin Platform

—

—

—

1

—

Delaware Basin

—

—

—

—

—

Northwest Shelf

9

7

4

3

—

3Q 2022

Central Basin Platform

3

3

—

1

3

Delaware Basin

—

—

—

—

—

Northwest Shelf

5

6

3

5

—

●

~~Reduction of long-term debt and de-leveraging of asset.~~ Ring intends to reduce its long-term debt primarily through the use of free cash flow from operations and potentially through the sale of non-core assets. The Company believes that with its attractive field level margins, it is well positioned to maximize the value of its assets and de-lever its balance sheet. The Company also believes through potential accretive acquisitions and strategic asset dispositions, it can accelerate the strengthening of its balance sheet. During the three months ended September 30, 2022, the Company modified its debt agreement with a total borrowing base of $600 million. At the Closing of the Stronghold Acquisition, the Company had $452,000,000 outstanding on its line of credit. During the month of September, the Company used free cash flow from operations to pay down $17,000,000 on its new outstanding long-term debt bringing the principal balance down to $435,000,000.

●

~~Employ industry leading drilling and completion techniques.~~ Ring’s executive team intends to utilize new and innovative technological advancements for completion optimization, comprehensive geological evaluation, and reservoir engineering analysis to generate value and to build future development opportunities. These technological advancements have led to a low-cost structure that helps maximize the returns generated by our drilling programs. Given the current commodity environment, labor market and inflationary pressures, Ring also expects improved execution efficiencies from the continuous drilling program throughout2022.

●

~~Pursue strategic acquisitions with exceptional upside potential.~~ ~~Ring has a history of acquiring leasehold positions that it believes to have additional resource potential that meet its targeted returns on invested capital and comparable to its existing~~

2023.


Quarter	Area	Wells Drilled	Wells Completed	Recompletions

1Q 2023	Northwest Shelf (Horizontal)	4	4	—
	Central Basin Platform (Vertical)	3	3	6

	Total	7	7	6

2Q 2023	Northwest Shelf (Horizontal)	4	4	—
	Central Basin Platform (Vertical)	2	2	3

	Total	6	6	3

3Q 2023	Northwest Shelf (Horizontal)	5	2	—
	Central Basin Platform (Vertical)	3	3	—
	Central Basin Platform (Horizontal)	3	3	—
	Total	11	8	—

Market Conditions and Commodity Prices

~~Table~~Our financial results depend on many factors, particularly the price of ~~Contents~~

inventory of drilling locations. The Company pursues an acquisition strategy designed to increase reserves at attractive finding costs and complement existing core properties. Management intends to continue to pursue strategic acquisitions and structure the potential transactions financially, so they improve balance sheet metrics and are accretive to shareholders. The executive team, with its extensive experience in the Permian Basin, has many relationships with operators and service providers in the region. Ring believes that leveraging the relationships of its management and board of directors will be a competitive advantage in identifying potential acquisition targets.

~~Executive Summary - 2022 Developments and Highlights~~

~~COVID-19 and Geopolitical Uncertainties~~

In December of 2020, the Food and Drug Administration authorized the use of the COVID-19 vaccination in the United States. The shots were first administered to front line workers and the elderly but were soon made available to all adults. The daily new infections peaked in the first quarter of 2021 and have seen an overall steady decline, giving states the ability to reopen to certain extents. In March 2021, the Federal Government passed a $1.9 trillion coronavirus relief package which included direct payments to qualifying individuals, extended unemployment benefits, and provided state and local assistance. During 2021, the demand forcrude oil and natural gas ~~increased as the economy recovered from the effects~~and our ability to market our production on economically attractive terms. Commodity prices are affected by many factors outside of ~~the COVID-19 pandemic~~our control, including changes in market supply and demand both domestically and world wide, which ~~strengthened energy prices. Although both~~are impacted by many factors. As a result, we cannot accurately predict future commodity prices, and therefore, we cannot determine with any degree of certainty what effect increases or decreases in these prices will have on our drilling program, production volumes or revenues.

Average oil and natural gas prices ~~have exceeded pre-pandemic levels,~~received through 2022 and 2023 to date continue to demonstrate commodity price volatility ~~due to new~~ and ~~emerging variants of the COVID-19 virus, OPEC actions, the Russian-Ukrainian war, and other factors affecting the global supply and demand of~~we believe oil and natural gas ~~have continued into 2022. It is not clear whether these issues~~prices will continue to ~~cause~~be volatile ~~energy prices~~for the foreseeable future. The ability to find and ~~further challenges~~develop sufficient amounts of crude oil and natural gas reserves at economical costs are critical to our ~~business.~~

long-term success.

Natural Gas Takeaway Capacity

The Permian Basin has been experiencing a lack of sufficient pipeline transportation that is connected to markets which are purchasing the natural gas produced. This has resulted in negative natural gas prices at times, whereby the seller is actually

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paying the purchaser to take the gas. If these depressed or inverted natural gas prices continue in the region, our natural gas revenues will continue to be negatively impacted.

Inflation

Inflation has increased costs associated with our capital program and production operations. We have experienced increases in the costs of many of the materials, supplies, equipment and services used in our operations and we expect inflation to continue based on current economic circumstances. In addition, the attempts to reduce inflation by the U.S. Federal Reserve have resulted in increased interest rates on debt and contributed to debt and equity market volatility. We continue to closely monitor costs and take all reasonable steps to mitigate the inflationary effect on our cost structure and also work to enhance our efficiency to minimize additional cost increases where possible.

Results of Operations

Oil, Natural Gas, and ~~NGL~~Natural Gas Liquids Revenues

~~Our oil,~~ for the Three Months Ended September 30, 2023 and 2022


	For the Three Months Ended
	September 30, 2023		September 30, 2022		Change		% Change
Net sales:
Oil	$	90,392,004	$	86,413,665	$	3,978,339	5	%
Natural gas	562,374		4,655,002		(4,092,628)		(88)	%
Natural gas liquids	2,727,420		3,340,281		(612,861)		(18)	%
Total sales	$	93,681,798	$	94,408,948	$	(727,150)	(1)	%

Net production:
Oil (Bbls)	1,106,531		932,770		173,761		19	%
Natural gas (Mcf)	1,567,104		952,762		614,342		64	%
Natural gas liquids (Bbls)	243,142		130,052		113,090		87	%
Total production (Boe)(1)	1,610,857		1,221,616		389,241		32	%

Average sales price:
Oil (per Bbl)	$	81.69	$	92.64	$	(10.95)	(12)	%
Natural gas (per Mcf)	0.36		4.89		(4.53)		(93)	%
Natural gas liquids (Bbl)	11.22		25.68		(14.46)		(56)	%
Total per Boe	$	58.16	$	77.28	$	(19.12)	(25)	%

(1) Boe is calculated using six Mcf of natural gas ~~and NGL producing properties are located~~as the equivalent of one barrel of oil.

Oil sales. Oil sales increased approximately $4.0 million from $86.4 million to $90.4 million due to a increase in sales volume from 932,770 barrels of oil to 1,106,531 barrels of oil, offset by a decrease in the ~~Permian Basin. Oil~~average realized price per barrel from $92.64 to $81.69 . Of the increase in volume of 173,761 barrels of oil, 160,522 barrels of oil were attributable to wells acquired and new wells drilled in the acreage of the Stronghold Acquisition, 70,718 barrels of oil were from the Founders Acquisition, and the legacy assets had lower production by 57,479 barrels of oil. The decreased average realized price per barrel was primarily a result of lower market conditions.

Natural gas sales.Natural gas sales ~~represented~~decreased approximately ~~92%~~$4.1 million from $4.7 million to $0.6 million. While our natural gas sales volume increased from 952,762 Mcf to 1,567,104 Mcf, the average realized price per Mcf decreased from $4.89 to $0.36. Of the increase in volume of 614,342 Mcf, 533,860 Mcf was attributable to wells acquired and ~~93%~~new wells drilled in the acreage of ~~our total~~the Stronghold Acquisition and 36,365 Mcf was from the Founders Acquisition, with the remaining increase of 44,117 Mcf attributable to legacy assets. The price decrease was driven by a significant reduction in realized revenue pricing due to lower market conditions. The realized revenue pricing included the impact of gas plant processing fees that were netted from revenue. For the three months ended September 30, 2023, gross revenues were $2.16

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per Mcf and fees were $(1.80) per Mcf, compared to gross revenues of $7.28 per Mcf and fees of $(2.39) per Mcf for the three months ended September 30, 2022. This resulted in a net realized price of $0.36 per Mcf for the three months ended September 30, 2023 compared to $4.89 per Mcf for the three months ended September 30, 2022.

Natural gas liquids sales.NGL sales decreased approximately $0.6 million from $3.3 million to $2.7 million. NGL sales volumes for the three months ended September 30, 2023 were 243,142 barrels of NGLs compared to 130,052 barrels of NGLs for the comparable period in 2022. Of the increase in volume of 113,090 barrels, 96,358 barrels are attributable to wells acquired and new wells drilled in the acreage of the Stronghold Acquisition and 10,550 barrels from the Founders Acquisition, with the remaining 6,182 barrels attributable to legacy assets. The average realized price per barrel of NGLs was $11.22 for the three months ended September 30, 2023 compared to $25.68 for the three months ended September 30, 2022, from lower market conditions.

Oil, Natural Gas, and ~~2021, respectively.~~ Natural gas was a lower percentage of revenue in the three months ended September 30, 2022 due to the change from two-stream (oil and natural gas) to three-stream reporting (oil, natural gas, and NGLs) beginning July 1, 2022 and the modified contract associated with the Northwest Shelf gathering, transportation, and processing costs reported as a reduction to revenue beginning May 1, 2022. Oil had an average realized price of $92.64 per barrel, compared to $69.61 per barrelGas Liquids Revenues for the same period in 2021. Natural gas prices had an average realized price of $4.89 per Mcf for the quarter, compared to $5.86 per Mcf for the same period in 2021, due to the Company’s change in reporting presentation for its natural gas, which are presented on a three-stream basis beginning July 1, 2022 as well as the contract modification for the Northwest Shelf’s gathering, transportation, and processing costs to be a reduction of revenue beginning May 1, 2022. NGLs had an average realized price of $25.68 per barrel for the three months ended September 30, 2022.

~~Commodity Risk Management~~

Effective February 1, 2022 we entered into a swap for 1,000 barrels of oil per day for the remainder of calendar year 2022. Additionally, we entered into 12 deferred premium commodity put options for oil on June 28 and 29, 2022. During the month of July 2022, we entered into five deferred premium commodity put options and three two-way collar arrangements, each for oil. On August 5, 2022, we entered into swaps for an average of 814 barrels of oil per day. As a part of the Stronghold Acquisition, we novated hedge agreements for 33 derivative contracts in total, with 18 for oil and 15 for natural gas. At the end of the quarter on September 26, 2022, we entered into four derivative contracts, one for oil and three for natural gas.

For oil, we had derivative contracts for an average of 3,129 barrels of oil per day for the month of January 2022, 4,129 barrels per day for February through June 2022, 5,629 barrels per day during July 2022, and 7,716 barrels per day during August and September 2022. For October through December 2022, we have derivative contracts in place for an average of 9,216 barrels per day. For January through March 2023, we have derivative contracts in place for an average of 5,152 barrels per day. For April through June 2023, we have derivative contracts in place for an average of 5,012 barrels per day. For July through December 2023, we have derivative contracts in place for an average of 4,012 barrels per day. For January through June 2024, we have derivative contracts in place for an average of 3,956 barrels per day. For July through September 2024, we have derivative contracts in place for an average of 2,349 barrels per day.

For natural gas, we had derivative contracts for an average of 11,061 MMBtu per day during the month of September 2022. For October through December 2022, we have derivative contracts in place for an average of 13,592 MMBtu per day. For January through March 2023, we have derivative contracts in place for an average of 9,872 MMBtu per day. For April through December 2023, we have derivative contracts in place for an average of 12,212 MMBtu per day. For January through September 2024, we have derivative contracts in place for an average of 4,872 MMBtu per day.

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Our 2022 derivative financial instruments resulted in a total non-cash fair value gain of approximately $47.7 million during the three months ended September 30, 2022 and a realized loss of approximately $14.9 million, for a total gain on derivative contracts of approximately $32.9 million.

~~Borrowing Base~~

The Company’s borrowing base increased from $350 million to $600 million due to the Second Amended and Restated Credit Agreement, dated August 31, 2022 as part of the Stronghold Acquisition. At the Closing of the Stronghold Acquisition, the Company had $452 million outstanding on its line of credit. The Company paid down $17 million of this debt during the third quarter of 2022 and had $435 million of principal outstanding on our Credit Facility as of September 30, 2022. As our borrowing base is subject to a semi-annual redetermination, our available borrowings and liquidity could be impacted by a redetermination later in 2022.

~~Officers and Directors~~

Upon closing of the Stronghold Acquisition, Stronghold exercised its right to designate two directors to the Board of Directors (the "Board"). On September 1, 2022, Roy Ben-Dor and David Habachy were appointed to the Board.

~~Results of Operations – For the Three~~Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~

~~Oil,~~2022

For the Nine Months Ended
September 30, 2023 September 30, 2022 Change % Change
Net sales:
Oil $ 252,020,403 $ 229,532,827 $ 22,487,576 10 %
Natural gas 526,161 14,678,747 (14,152,586) (96) %
Natural gas liquids 8,566,719 3,340,281 5,226,438 156 %
Total sales $ 261,113,283 $ 247,551,855 $ 13,561,428 5 %
Net production:
Oil (Bbls) 3,325,323 2,338,469 986,854 42 %
Natural gas (Mcf) 4,726,056 2,408,241 2,317,815 96 %
Natural gas liquids (Bbls) 715,832 130,052 585,780 450 %
Total production (Boe)(1)
4,828,831 2,869,895 1,958,936 68 %
Average sales price:
Oil (per Bbl) $ 75.79 $ 98.16 $ (22.37) (23) %
Natural gas (per Mcf) 0.11 6.10 (5.99) (98) %
Natural gas liquids (Bbl) 11.97 25.68 (13.71) (53) %
Total per Boe $ 54.07 $ 86.26 $ (32.19) (37) %

(1) Boe is calculated using six Mcf of natural gas ~~and NGL sales.~~ ~~For~~as the ~~three months ended September 30, 2022, oil, natural gas, and NGL~~equivalent of one barrel of oil.

Oil sales revenue increased $45,032,772 to $94,408,948, compared to $49,376,176 for the same period during 2021, primarily as a result of higher oil and natural gas prices, as well as increased production. Of this, oil. Oil sales increased ~~$40,524,117, natural gas sales increased $1,168,374, and NGL sales increased $3,340,281. For the three months ended September 30, 2022, oil~~approximately $22.5 million from $229.5 million to $252.0 million due to an increase in sales volume ~~increased 273,523~~from 2,338,469 barrels of oil to ~~932,770~~3,325,323 barrels ~~compared to 659,247 barrels for~~of oil, offset by a decrease in the ~~same period in 2021. The~~ average realized price per barrel from $98.16 to $75.79. Of the increase in volume of 986,854 barrels, 755,881 barrels of oil were attributable to wells acquired and new wells drilled in the acreage of the Stronghold Acquisition, 70,718 barrels of oil were from the Founders Acquisition, and the remaining 160,255 increase in production was from the legacy assets, partly due to the sale of non-core assets. The decreased average realized price per barrel was primarily the result of lower market conditions.

Natural gas sales.Natural gas sales decreased approximately $14.2 million from $14.7 million to $526,161. While our natural gas sales volume increased ~~33%~~ from ~~$69.61 for~~2,408,241 Mcf to 4,726,056 Mcf, the ~~three~~average realized price per Mcf decreased from $6.10 to $0.11. Of the increase in volume of 2,317,815 Mcf, 2,370,686 Mcf was from wells acquired and new wells drilled in the acreage of the Stronghold Acquisition, 36,365 Mcf was from the Founders Acquisition, and the offsetting decrease of 89,236 Mcf was attributable to legacy assets. The price decrease was driven by lower market conditions. The realized revenue pricing includes the impact of gas plant processing fees that were netted from revenue. For the nine months ended September 30, ~~2021,~~2023, gross revenues were $1.73 per Mcf and fees were $(1.62) per Mcf, compared to ~~$92.64~~gross revenues of $7.71 per Mcf and fees of $(1.62) per Mcf for the ~~three~~nine months ended September 30, 2022. ~~For~~This resulted in a

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net realized price of $0.11 for the ~~three~~nine months ended September 30, ~~2022, natural gas sales volume increased 357,921 thousand cubic feet (Mcf) to 952,762 Mcf,~~2023 compared to ~~594,841~~$6.10 per Mcf for the same period in 2021 due to workovers completed, new wells placed on production, and the Stronghold Acquisition, with associated revenues beginning September 1, 2022. The average realized natural gas price per Mcf decreased 17% from $5.86 to $4.89 due to the change in reporting from two-stream to three-stream as of July 1, 2022 and the netting of gathering, transportation, and processing costs with revenues due to the contract modification on May 1, 2022. For the threenine months ended September 30, ~~2022,~~2022.

Natural gas liquids sales.NGL sales increased approximately $5.2 million from $3.3 million to $8.6 million. NGL sales volumes for the nine months ended September 30, 2023 were ~~130,052~~715,832 barrels of NGLs compared to ~~zero~~130,052 barrels of NGLs for the ~~same~~comparable period in ~~2021,~~2022 due to the ~~Company’s~~Company's change in reporting presentation for its natural gas products, which are presented on a three-stream basis beginning July 1, 2022. Of the increase in volume of 585,780 barrels, 390,206 barrels were attributable to the wells acquired and new wells drilled within the acreage of the Stronghold Acquisition, 10,550 barrels were from the Founders Acquisition, and the remaining 185,024 barrels are attributable to legacy assets. The average realized price per barrel of NGLs was ~~$25.68~~$11.97 for the ~~three~~nine months ended September 30, ~~2022.~~

~~The following table presents our sales revenues~~2023 compared to $25.68 for the ~~periods indicated (note that~~nine months ended September 30, 2022, from lower market conditions.

Production Costs for ~~periods prior to July 1,~~the Three Months Ended September 30, 2023 and 2022 ~~sales for NGLs were presented with natural gas):~~

For The Three Months

Ended September 30,


2022

2021
Operating Revenues




Oil

$
86,413,665

$
45,889,548
Natural gas

4,655,002

3,486,628
Natural gas liquids

3,340,281

—
Total operating revenues

$
94,408,948

$
49,376,176


	For the Three Months Ended
	September 30, 2023			September 30, 2022			Change			% Change

Lease operating expenses ("LOE")	$	18,015,348		$	13,029,098		$	4,986,250		38	%
Average LOE per Boe	$	11.18		$	10.67		$	0.51		5	%

Gathering, transportation and processing costs ("GTP")	$	(4,530)		$	—		$	(4,530)		100	%
Average GTP per Boe	$	—		$	—		$	—		—	%

Ad valorem taxes	$	1,779,163		$	1,199,385		$	579,778		48	%
Average Ad valorem taxes per Boe	$	1.10		$	0.98		$	0.12		12	%

Oil and natural gas production taxes	$	4,753,289		$	4,563,519		$	189,770		4	%
Average Production taxes per Boe	$	2.95		$	3.74		$	(0.79)		(21)	%
Production taxes as a percentage of total sales	5.07		%	4.83		%	0.24		%	5	%

Lease operating expenses.~~Total~~ Our total lease operating expenses (“LOE”) ~~expressed~~increased from $13.0 million to $18.0 million and increased on a per ~~barrel of oil equivalent (“Boe”)~~Boe basis from $10.67 to $11.18, due to rising service provider prices as well as higher LOE workover costs due to increased ~~approximately 18% from $9.21~~well count. These per Boe ~~for the three months ended September 30, 2021, to $10.67 per Boe for the three months ended September 30, 2022~~amounts are calculated by dividing our total lease operating expenses by our total volume sold, in Boe. Total LOE increased primarily due to ~~increases~~an 32% increase in labor costs and industry wide inflationary pressures. Total lease operating expenses increased approximately 87% from $6,983,196 for the three months ended September 30, 2021, to $13,029,098 for the three months ended September 30, 2022 primarily due to a 61% increase to production of ~~463,229~~389,241 Boe as a result of the new wells acquired from the Stronghold and Founders asset acquisitions as well as ~~the higher per Boe costs mentioned above~~

new wells drilled and completed from our development program.

Gathering, transportation and processing costs. Our total gathering, transportation and processing costs (“GTP”) decreased ~~100%~~ from ~~$1,051,163 for the three months ended September 30, 2021 to~~ $0 ~~for the three months ended September 30, 2022, due primarily~~ to a ~~change in cost recognition due~~negative $4,530. The negative $4,530 recognized during the third quarter of 2023 was a result of prior period payout adjustments made during the current period.

Ad valorem taxes. Our total ad valorem taxes increased from $1.2 million to ~~a modification of the contract agreement. Specifically, beginning May 1, 2022, the Company~~$1.8 million and ~~its processing entity modified the contract so that the Company no longer maintained ownership of the gas through processing. Accordingly,~~

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the Company from that point on accounts for any such fees and deductions as a direct reduction of the sales transaction price. Accordingly, total gathering, transportation and processing costs expressedincreased on a per Boe basis ~~decreased 100%~~ from ~~$1.39 per Boe for~~$0.98 to $1.10. Of the ~~three months ended September 30, 2021 to $0 per Boe for the three months ended September 30, 2022 primarily due to the aforementioned change~~approximate $0.6 million increase in ~~cost recognition.~~

~~Ad valorem taxes.~~ ~~Our~~ ad valorem taxes, ~~increased~~ approximately ~~70% from $703,774 for~~$0.4 million was attributable to assets acquired in the ~~three months ended September 30, 2021~~Stronghold Acquisition and $0.1 million was attributable to ~~$1,199,385 for~~assets acquired in the three months ended September 30, 2022 primarily due to the increase in tax commodity price from the prior year. Expressed on a per Boe basis, these costs increased approximately 5% from $0.93 per Boe for the three months ended September 30, 2021 to $0.98 for the three months ended September 30, 2022.

Founders Acquisition.

Oil and natural gas production ~~taxes.~~ ~~Production~~taxes.Oil and natural gas production taxes as a percentage of oil and natural gas sales ~~increased slightly to 4.8%~~were 4.83% for the three months ended September 30, 2022 ~~compared~~and increased to ~~4.5% for the third quarter of 2021. We expect these rates to stay relatively steady.~~

~~Depreciation, depletion and amortization.~~ ~~Our depreciation, depletion and amortization expense increased by $5,013,978 to $14,324,502~~5.07% for the three months ended September 30, ~~2022, compared to $9,310,524 during~~2023. Overall, the ~~same~~percentage was consistent period in 2021 due to higher 2022 production volumes. Average depreciation, depletion and amortization decreased to $11.73 per Boe for the three months ended September 30, 2022 compared to $12.28 per Boe for the three months ended September 30, 2021 due to the increased total estimated costs of properties acquired in the Stronghold Acquisition.

~~Asset retirement obligation accretion.~~ Accretion of asset retirement obligations (“AROs”) increased by $60,235 to $243,140 for the three months ended September 30, 2022, compared to $182,905 for the three months ended September 30, 2021 because of more wells added due to new drilling and from the Stronghold Acquisition.

~~Operating lease expense.~~ ~~Operating lease expense remained consistent at $83,590 for the three months ended September 30, 2022, compared to $83,589 for the three months ended September 30, 2021.~~

~~General and administrative expense.~~ General and administrative expense increased to $7,393,848 for the three months ended September 30, 2022 compared to $4,433,251 for the three months ended September 30, 2021. Within this change, we isolate share-based compensation, which increased to $1,543,033 for the three months ended September 30, 2022 compared to $777,461 for the three months ended September 30, 2021, primarily as the result of grants of equity awards in 2021 and 2022 pursuant to the Ring Energy, Inc. 2021 Omnibus Incentive Plan (the “2021 Plan”). For the three months ended September 30, 2022, general and administrative expenses excluding share-based compensation increased by $2,195,025 due to approximately $1.1 million in transaction costs primarily associated with the Stronghold Acquisition and approximately $1.4 million increased bonus compensation accruals and salaries and wages for new hires to support the Company’s growth, offset by a reduction in general legal and other professional fees.

over period.

For The Three Months

Ended September 30,

2022

2021

General and administrative expense (excluding share-based compensation)

$
5,850,815

$
3,655,790
Share-based compensation

1,543,033

$
777,461
General and administrative expense

$
7,393,848

$
4,433,251

~~Interest expense.~~ Interest expense increased $3,469,923 to $7,021,385 for the three months ended September 30, 2022, compared to $3,551,462 for the three months ended September 30, 2021 due to a $58.8 million higher average daily loan balance (as a result of the Stronghold Acquisition) as well as an increase in weighted average interest rate from 4.4% to 6.3%. Also, within interest expense, amortization of deferred financing costs increased $908,791 as a result of our entering into the Second Amended and Restated Credit Agreement, in which approximately $18.8 million was booked to deferred financing costs, thereby increasing amortization, and $564,111 of prior deferred financing costs were written off that were associated with five prior lenders under the Credit Facility.

~~Gain (loss) on derivative contracts~~. In the Statements of Operations, the total gain (loss) on derivative contracts changed from a loss of $6,720,320 for the three months ended September 30, 2021 to a gain of $32,851,189 for the three months ended September 30, 2022. Underlying this overall change were changes within the realized and unrealized portions of the derivative instruments. We experienced a decrease of $59,892 in realized losses from $14,921,008 during the three months ended September 30, 2021 to $14,861,116 during the three months ended September 30, 2022. The Company records all derivative instruments on the Balance Sheets as either an asset or liability measured at fair value. Changes in fair value are recognized currently in earnings unless certain specific hedge accounting criteria are met. The unrealized (mark to market) gain increased from $8,200,688 during the three months ended September 30, 2021 to

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~~$47,712,305 during the three months ended September 30, 2022 due to a decrease in commodity prices and the realization of third quarter derivative positions.~~

~~Net income (loss).~~ ~~For the three months ended September 30, 2022, the Company achieved net income of $75,085,891, compared to net income of $14,163,934~~

Production Costs for the three months ended September 30, 2021. The primary difference was due to the higher sales volumes and revenue in 2022 compared to 2021 resulting from increased workovers, drilling activities, the Stronghold Acquisition, and the significantly higher oil prices in 2022, as well as a significant gain of $32,851,189 on derivative contracts in the third quarter 2022 due to favorable positions.

~~Sales volumes and commodity prices received~~

~~The following table presents our sales volumes and received pricing information for the periods indicated (note that for periods prior to July 1, 2022, sales for NGLs were presented with natural gas):~~

For the Three Months

Ended September 30,

2022

2021
Oil volume (Bbls)

932,770

659,247
Natural gas volume (Mcf)

952,762

594,841
Natural gas liquids (Bbls)

130,052

—
Total Production (Boe)⁽¹⁾

1,221,616

758,387

Average Sales Price

Oil price (per Bbl)

$
92.64

$
69.61
Gas price (per Mcf)

$
4.89

$
5.86
Natural gas liquids (Bbl)

$
25.68

$
—
Total per Boe

$
77.28

$
65.11

~~(1)~~

~~Boe is calculated using six Mcf of natural gas as the equivalent of one barrel of oil.~~

~~Results of Operations – For~~ the Nine Months Ended September 30, ~~2022~~2023 and ~~2021~~

~~Oil, natural gas, and NGL sales.~~ ~~For the nine months ended September 30,~~ 2022 oil, natural gas, and NGL sales revenue increased $110,913,045 to $247,551,855, compared to $136,638,810 for the same period during 2021, primarily as a result of higher oil and natural gas prices, increased production, and the Stronghold Acquisition, with its associated revenues beginning September 1, 2022. Of this, oil sales increased $102,605,509, natural gas sales increased $4,967,255, and NGL sales increased $3,340,281. For the nine months ended September 30, 2022, oil sales volume increased 366,693 barrels to 2,338,469 barrels, compared to 1,971,776 barrels for the same period in 2021. The average realized price per barrel of oil price increased 52% from $64.37 for the nine months ended September 30, 2021, to $98.16 for the nine months ended September 30, 2022. For the nine months ended September 30, 2022, gas sales volume increased 634,735 Mcf to 2,408,241 Mcf, compared to 1,773,506 Mcf for the same period in 2021. The average realized natural gas price per Mcf increased 11% from $5.48 to $6.10. For the nine months ended September 30, 2022, NGL sales volumes were 130,052 barrels of NGLs, compared to zero barrels for the same period in 2021, due to the Company’s change in reporting presentation for its natural gas products, which are presented on a three-stream basis beginning July 1, 2022. The average realized price per barrel of NGLs was $25.68 for the nine months ended September 30, 2022.

~~The following table presents our sales revenues for the periods indicated (note that for periods prior to July 1, 2022, sales for NGLs were presented with natural gas):~~

For The Nine Months

Ended September 30,


2022

2021
Operating Revenues

Oil

$
229,532,827

$
126,927,318
Natural gas

14,678,747

9,711,492
Natural gas liquids

3,340,281

—
Total operating revenues

$
247,551,855

$
136,638,810


	For the Nine Months Ended
	September 30, 2023			September 30, 2022			Change			% Change

Lease operating expenses ("LOE")	$	51,426,145		$	30,283,706		$	21,142,439		70	%
Average LOE per Boe	$	10.65		$	10.55		$	0.10		1	%

Gathering, transportation and processing costs ("GTP")	$	(6,985)		$	1,846,247		$	(1,853,232)		(100)	%
Average GTP per Boe	$	—		$	0.64		$	(0.64)		(100)	%

Ad valorem taxes	$	5,120,119		$	3,100,578		$	2,019,541		65	%
Average Ad valorem taxes per Boe	$	1.06		$	1.08		$	(0.02)		(2)	%

Oil and natural gas production taxes	$	13,173,568		$	11,939,338		$	1,234,230		10	%
Average Production taxes per Boe	$	2.73		$	4.16		$	(1.43)		(34)	%
Production taxes as a percentage of total sales	5.05		%	4.82		%	0.23		%	5	%

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Lease operating expenses. ~~Total~~ Our total LOE ~~expressed~~increased from $30.3 million to $51.4 million and increased on a per Boe basis from $10.55 to $10.65, due to rising service provider prices as well as higher LOE workover cost due to increased approximately 6% from $9.98 per Boe for the nine months ended September 30, 2021, to $10.55 per Boe for the nine months ended September 30, 2022 primarily due an increase to labor costs and industry wide inflationary pressures.well count. Total ~~lease operating expenses~~LOE increased ~~approximately 34% from $22,634,259 for the nine months ended September 30, 2021, to $30,283,706 for the nine months ended September 30, 2022~~ primarily due to a ~~27%~~68% increase toin production of ~~602,535~~1,958,936 Boe as a result of the new wells acquired from the Stronghold and ~~the higher per Boe costs mentioned above~~

Founders asset acquisitions as well as new wells drilled and completed from our development program.

Gathering, transportation and processing costs. Our total ~~gathering, transportation~~GTP decreased from $1,846,247 to a negative $6,985 and ~~processing~~decreased on a per Boe basis from $0.64 to $0. GTP costs decreased ~~by approximately 36%~~ from ~~$2,883,348 for the nine months ended September 30, 2021 to $1,846,247 for the nine months ended September 30, 2022, due to costs classified~~being re-classified as a reduction to oil and natural gas sales revenues, due to ~~the~~a natural gas processing entity ~~beginning to take~~taking control of transportation at the wellhead beginning on May 1, 2022. ~~Total gathering, transportation and processing costs expressed on a per Boe basis decreased approximately 50% from $1.27 per Boe for~~The negative $6,985 recognized during the nine months ended September 30, ~~2021 to $0.64 per Boe for~~2023 was a result of prior period payout adjustments made during the ~~nine months ended September 30, 2022 due to increased Boe as well as the change in cost recognition effective May 1, 2022.~~

current period.

Ad valorem taxes. Our total ad valorem taxes increased ~~approximately 45%~~ from ~~$2,144,800 for the nine months ended September 30, 2021~~$3.1 million to ~~$3,100,578 for the nine months ended September 30, 2022 primarily due to the increase in taxed commodity prices from the prior year. Expressed~~$5.1 million and decreased on a per Boe basis ~~these costs increased~~from $1.08 to $1.06. Of the $2.0 million increase in ad valorem taxes, approximately ~~14% from $0.95 per Boe for~~$1.7 million was attributable to the ~~nine months ended September 30, 2021 to $1.08 for~~assets acquired in the ~~nine months ended September 30, 2022.~~

Stronghold Acquisition.

Oil and natural gas production ~~taxes.~~ ~~Production~~taxes.Oil and natural gas production taxes as a percentage of oil and natural gas sales ~~increased slightly to 4.8%~~were 4.82% for the nine months ended September 30, 2022 ~~compared~~and increased to ~~4.6%~~5.05% for the ~~same~~nine months ended September 30, 2023. Overall, the percentage was consistent period ~~in 2021. We expect these rates to stay relatively steady.~~

over period.

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Other Costs and Operating Expenses for the Three Months Ended September 30, 2023 and 2022
For the Three Months Ended
September 30, 2023 September 30, 2022 Change % Change
Depreciation, depletion and amortization (DD&A):
     Depletion $ 21,711,123 $ 14,163,574 $ 7,547,549 53 %
     Depreciation 80,690 53,946 26,744 50 %
     Amortization of financing lease assets 197,221 106,982 90,239 84 %
Total depreciation, depletion and amortization $ 21,989,034 $ 14,324,502 $ 7,664,532 54 %
Depletion per Boe $ 13.48 $ 11.59 $ 1.89 16 %
Depreciation, depletion and amortization per Boe $ 13.65 $ 11.73 $ 1.92 16 %
Asset retirement obligation ("ARO") accretion $ 354,175 $ 243,140 $ 111,035 46 %
Operating lease expense $ 138,220 $ 83,590 $ 54,630 65 %
General and administrative expense ("G&A"):
     General and administrative expense (excluding Share-based compensation) $ 4,912,839 $ 5,850,815 $ (937,976) (16) %
     Share-based compensation 2,170,735 1,543,033 627,702 41 %
Total general and administrative expense $ 7,083,574 $ 7,393,848 $ (310,274) (4) %
G&A per Boe $ 4.40 $ 6.05 $ (1.65) (27) %
G&A excluding Share-based compensation, per Boe $ 3.05 $ 4.79 $ (1.74) (36) %

Depreciation, depletion and ~~amortization.~~amortization.Our depreciation, depletion and amortization increased from $14.3 million to $22.0 million due to a higher depletion rate as well as an increase of 389,241 in Boe produced. Additional trucks were purchased and leased for field operations, resulting in higher depreciation and finance lease amortization costs. Our average depreciation, depletion and amortization per Boe increased from $11.73 per Boe to $13.65 per Boe. These per Boe amounts are calculated by dividing our total depreciation, depletion and amortization expense by our total Boe volumes sold. The increase in DD&A per Boe was from a significant increase in the total estimated costs of property compared to a decrease in the Boe amortization base.

Asset retirement obligation accretion. Our asset retirement obligation (“ARO”) accretion increased from $243,140 to $354,175 primarily as a result of acquisitions and new wells added, offset by wells sold or plugged and abandoned. Between the beginning of the fourth quarter of 2022 and the end of the third quarter of 2023, 176 wells were acquired as part of the Founders Acquisition, 33 new wells were added from drilling and completion activities, and 4 wells from participation in non-operating activities, offset by 190 wells sold through non-core property divestitures, as well as 15 wells plugged and abandoned during that time period.

Operating lease expense. Our operating lease expense increased from $83,590 to $138,220 due to additional office space leased in both the Midland and The Woodlands offices.

General and administrative expense.General and administrative ("G&A") expense decreased from $7.4 million to $7.1 million. Of the $0.3 million cost decrease, $1.3 million was associated with lower transaction costs, and $0.6 million in lower bonus accruals, offset by ~~$8,161,185~~an increase of $0.6 million in share-based compensation costs, $0.5 million in salaries and wages, $0.2 million in legal fees, $0.2 million in software costs, and $0.1 million in other professional fees.

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Other Costs and Operating Expenses for the Nine Months Ended September 30, 2023 and 2022


	For the Nine Months Ended
	September 30, 2023		September 30, 2022		Change		% Change

Depreciation, depletion and amortization (DD&A):
Depletion	$	63,203,473	$	34,417,978	$	28,785,495	84	%
Depreciation	277,420		102,568		174,852		170	%
Amortization of financing lease assets	572,744		334,447		238,297		71	%
Total depreciation, depletion and amortization	$	64,053,637	$	34,854,993	$	29,198,644	84	%

Depletion per Boe	$	13.09	$	11.99	$	1.10	9	%
Depreciation, depletion and amortization per Boe	$	13.26	$	12.15	$	1.11	9	%

Asset retirement obligation ("ARO") accretion	$	1,073,900	$	617,685	$	456,215	74	%

Operating lease expense	$	366,711	$	250,770	$	115,941	46	%

General and administrative expense ("G&A"):
General and administrative expense (excluding Share-based compensation)	$	14,649,213	$	13,784,239	$	864,974	6	%
Share-based compensation	6,374,743		4,964,188		1,410,555		28	%
Total general and administrative expense	$	21,023,956	$	18,748,427	$	2,275,529	12	%

G&A per Boe	$	4.35	$	6.53	$	(2.18)	(33)	%
G&A excluding Share-based compensation, per Boe	$	3.03	$	4.80	$	(1.77)	(37)	%

Depreciation, depletion and amortization.Our depreciation, depletion and amortization increased from $34.9 million to ~~$34,854,993~~$64.1 million due to a higher depletion rate as well as an increase of 1,958,936 in Boe produced. Additional trucks were purchased and leased for field operations, resulting in higher depreciation and finance lease amortization costs. Our average depreciation, depletion and amortization per Boe increased from $12.15 per Boe to $13.26 per Boe, due to a higher increase in the total costs of property than the increase in the Boe amortization base.

Asset retirement obligation accretion. Our ARO accretion increased from $617,685 to $1,073,900 primarily as a result of the additional ARO accretion associated with the properties added from the Stronghold Acquisition (total of 913 wells added). Additionally, during the prior 12 months, 8 new wells were added from acquisitions, drilling and completion, and non-operated activities, net of wells plugged and abandoned and sold.

Operating lease expense. Our operating lease expense increased from $250,770 to $366,711 due to additional office space leased in both the Midland and The Woodlands offices.

General and administrative expense.General and administrative ("G&A") expense increased from $18.7 million to $21.0 million, with $1.4 million of the $2.3 million cost increase due to an increase in share-based compensation costs. The remaining $0.9 million increase in G&A costs were primarily attributable to a $1.7 million increase in salaries and wages, a $0.5 million increase in legal fees, and a $0.4 million increase in software costs, offset by a $1.1 million decrease in transaction costs and a $0.6 million reduction in G&A costs from the Employee Retention Tax Credit.

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Other Income (Expense) for the Three Months Ended September 30, 2023 and 2022


	For the Three Months Ended
	September 30, 2023		September 30, 2022		Change		% Change

Interest income	$	80,426	$	4	$	80,422	2010550	%

Interest expense:
Interest on revolving line of credit	$	9,711,871	$	5,804,069	$	3,907,802	67	%
Fees associated with revolving line of credit	239,218		103,935		135,283		130	%
Amortization of deferred financing costs	1,258,466		1,095,073		163,393		15	%
Interest on financing lease liabilities	23,416		10,391		13,025		125	%
Interest paid for notes payable	22,286		7,917		14,369		181	%
Deferred cash payment accretion	126,497		—		126,497		100	%
Total interest expense	$	11,381,754	$	7,021,385	$	4,360,369	62	%

Gain (loss) on derivative contracts:
Realized gain (loss):
Crude oil	$	(5,825,427)	$	(13,958,195)	$	8,132,768	(58)	%
Natural gas	474,629		(902,921)		1,377,550		(153)	%
Total realized gain (loss)	$	(5,350,798)	$	(14,861,116)	$	9,510,318	(64)	%
Unrealized gain (loss):
Crude oil	$	(34,077,473)	$	49,680,492	$	(83,757,965)	(169)	%
Natural gas	205,516		(1,968,187)		2,173,703		(110)	%
Total unrealized gain (loss)	$	(33,871,957)	$	47,712,305	$	(81,584,262)	(171)	%
Total gain (loss) on derivative contracts:	$	(39,222,755)	$	32,851,189	$	(72,073,944)	(219)	%

Interest income. Interest income recognized included $78,679 from depositing excess cash balances in bank sweep accounts and $1,747 from interest earned on the escrow deposit made for the Founders Acquisition.

Interest expense. Interest expense increased from $7.0 million to $11.4 million primarily due to higher amounts outstanding on our credit facility, with a weighted average daily debt of approximately $422.6 million during the third quarter of 2023 compared to approximately $365.8 million during the third quarter of 2022. Additionally, the increase in interest expense was due to higher interest rates, with a weighted average annual interest rate of 9.2% in the third quarter of 2023 compared to 6.3% in the third quarter of 2022.

Gain (loss) on derivative contracts.We recorded a loss on derivative contracts of $39.2 million for the three months ended September 30, 2023 compared to a gain on derivative contracts of $32.9 million for the three months ended September 30, 2022. For the derivative contract settlements, we recorded a realized loss of $5.4 million for the three months ended September 30, 2023 and a realized loss of $14.9 million for the three months ended September 30, 2022. The reduction of $9.5 million in the realized loss was a result of our more favorable derivative contract portfolio during the three months ended September 30, 2023. In the same quarter of the prior year, we were party to swaps with prices as low as $44.22, compared to oil settlement prices as high as $99.39. For the marked-to-market contracts, we recorded an unrealized loss of $33.9 million for the three months ended September 30, 2023 and an unrealized gain of $47.7 million for the three months ended September 30, 2022. This significant unrealized gain recognized for the three months ended September 30, 2022 was primarily due to the average increase of over $11 per barrel in crude oil prices.

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Other Income (Expense) for the Nine Months Ended September 30, 2023 and 2022


	For the Nine Months Ended
	September 30, 2023		September 30, 2022		Change		% Change

Interest income	$	160,171	$	4	$	160,167	4004175	%

Interest expense:
Interest on revolving line of credit	$	27,478,591	$	11,921,056	$	15,557,535	131	%
Fees associated with revolving line of credit	717,468		252,983		464,485		184	%
Amortization of deferred financing costs	3,699,235		1,483,621		2,215,614		149	%
Interest on financing lease liabilities	73,115		24,184		48,931		202	%
Interest paid for notes payable	35,211		17,201		18,010		105	%
Deferred cash payment accretion	319,220		—		319,220		100	%
Total interest expense	$	32,322,840	$	13,699,045	$	18,623,795	136	%

Gain (loss) on derivative contracts:
Realized gain (loss):
Crude oil	$	(7,323,030)	$	(47,690,961)	$	40,367,931	(85)	%
Natural gas	1,493,302		(902,921)		2,396,223		(265)	%
Total realized gain (loss)	$	(5,829,728)	$	(48,593,882)	$	42,764,154	(88)	%
Unrealized gain (loss):
Crude oil	$	(21,425,316)	$	48,360,099	$	(69,785,415)	(144)	%
Natural gas	771,854		(1,968,187)		2,740,041		(139)	%
Total unrealized gain (loss)	$	(20,653,462)	$	46,391,912	$	(67,045,374)	(145)	%
Total gain (loss) on derivative contracts:	$	(26,483,190)	$	(2,201,970)	$	(24,281,220)	1103	%

Gain (loss) on disposal of assets	$	(132,109)	$	—	$	(132,109)	100	%
Other income	$	126,210	$	—	$	126,210	100	%

Interest income. Interest income recognized included $129,382 from depositing excess cash balances in bank sweep accounts beginning in May 2023, $29,042 from interest earned on the Employee Retention Tax Credit, and $1,747 from interest earned on the escrow deposit made for the Founders Acquisition.

Interest expense. Interest expense increased from $13.7 million to $32.3 million primarily due to the result of higher amounts outstanding on our credit facility, with a weighted average daily debt of approximately $420.6 million during the nine months ended September 30, 2023 compared to approximately $311.4 million during the nine months ended September 30, 2022. Additionally, the increase in interest expense was due to higher interest rates, with a weighted average annual interest rate of 8.7% during the nine months ended September 30, 2023 compared to 5.1% during the nine months ended September 30, 2022.

Gain (loss) on derivative contracts.We recorded a loss on derivative contracts of $26.5 million for the nine months ended September 30, 2023 and a loss on derivative contracts of $2.2 million for the nine months ended September 30, 2022. For the derivative contract settlements, we recorded a realized loss of $5.8 million for the nine months ended September 30, 2023 and a realized loss of $48.6 million for the nine months ended September 30, 2022. The reduction of $42.8 million in the realized loss was a result of more favorable settlements of derivative contracts during the current year. For the marked-to-market contracts, we recorded an unrealized loss of $20.7 million for the nine months ended September 30, 2023 and an unrealized gain of $46.4 million for the nine months ended September 30, 2022. This change in unrealized derivatives primarily was due to losses on higher crude oil prices.

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Gain (loss) on disposal of assets. We recognized a loss of $132,109 on disposal from selling multiple company owned vehicles.

Other income. This income primarily resulted from our termination of The Woodlands office operating lease as of May 31, 2023.

Benefit from (Provision for) Income Taxes for the Three Months Ended September 30, 2023 and 2022


	For the Three Months Ended
	September 30, 2023		September 30, 2022		Change		% Change

Benefit from (Provision for) Income Taxes:
Deferred federal income tax benefit (provision)	$	3,381,104	$	(3,611,381)	$	6,992,485	(194)	%
Current state income tax benefit (provision)	(165,780)		(36,736)		(129,044)		351	%
Deferred state income tax benefit (provision)	196,012		(667,666)		863,678		(129)	%
Benefit from (Provision for) Income Taxes	$	3,411,336	$	(4,315,783)	$	7,727,119	(179)	%

Benefit from (Provision for) income taxes.The benefit from (provision for) income taxes changed from a provision of $4.3 million for the three months ended September 30, 2022 to a benefit of $3.4 million for the three months ended September 30, 2023. Income taxes for discrete items are calculated and recorded in the period that a specific transaction occurred. For the three months ended September 30, 2023, the overall effective rate was different than the federal statutory rate due primarily to state income taxes and valuation allowances. The current year federal tax benefit was the result of the release in valuation allowance. As a result of increased commodity prices and other positive evidence, we released the federal valuation allowances in the first nine months of 2023, of which $10.5 million was recorded as a discrete item.

Benefit from (Provision for) Income Taxes for the Nine Months Ended September 30, 2023 and 2022


	For the Nine Months Ended
	September 30, 2023		September 30, 2022		Change		% Change

Benefit from (Provision for) Income Taxes:
Deferred federal income tax benefit (provision)	$	8,492,595	$	(4,625,429)	$	13,118,024	(284)	%
Current state income tax benefit (provision)	(264,261)		(36,736)		(227,525)		619	%
Deferred state income tax benefit (provision)	(490,646)		(1,204,579)		713,933		(59)	%
Benefit from (Provision for) Income Taxes	$	7,737,688	$	(5,866,744)	$	13,604,432	(232)	%

Benefit from (Provision for) income taxes.The benefit from (provision for) income taxes changed from a provision of $5.9 million for the nine months ended September 30, 2022 ~~compared~~ to ~~$26,693,808 during the same period in 2021 due to higher 2022 production volumes. Average depreciation, depletion and amortization increased to $12.15 per Boe~~a benefit of $7.7 million for the nine months ended September 30, ~~2022 from $11.77 per Boe for the nine months ended September 30, 2021 due to the increased total estimated costs of property.~~

~~Asset retirement obligation accretion.~~ Accretion of AROs increased $57,023 to $617,685 for the nine months ended September 30, 2022, compared to $560,662 for the nine months ended September 30, 2021 due to new drilling and from the Stronghold Acquisition.

~~Operating lease expense.~~ Operating lease expense decreased $189,126 to $250,770 for the nine months ended September 30, 2022, compared to $439,896 for the nine months ended September 30, 2021 due to the change in treatment of the compressor leases beginning April 1, 2021.

~~General and administrative expense.~~ General and administrative expense increased to $18,748,427 for the nine months ended September 30, 2022 compared to $11,103,394 for the nine months ended September 30, 2021. Within this change, we isolate share-based compensation, which increased to $4,964,188 for the nine months ended September 30, 2022 compared to $1,484,730 for the nine months ended September 30, 2021, primarily as2023. The current year federal tax provision was the result of ~~grants of equity awards~~the release in ~~2021~~valuation allowance. Due to increased commodity prices and ~~2022 pursuant to~~other positive evidence, we released the ~~2021 Plan. For~~federal valuation allowances in the first nine months ~~ended September 30, 2022, general and administrative expenses excluding share-based compensation increased $4,165,575 due to approximately $1.3~~of 2023, of which $10.5 million in transaction costs primarily associated with the Stronghold Acquisition, approximately $2.4 million increased bonus compensation accruals and salaries and wages for new hires to support the Company’s growth,was recorded as ~~well as increased insurance and software costs, offset by~~ a ~~reduction in general legal and other professional fees.~~

discrete item.

For The Nine Months

Ended September 30,


2022

2021

General and administrative expense (excluding share-based compensation)

$
13,784,239

$
9,618,664
Share-based compensation

4,964,188

1,484,730
General and administrative expense

$
18,748,427

$
11,103,394

~~Interest expense.~~ Interest expense increased $2,751,085 to $13,699,045 for the nine months ended September 30, 2022, compared to $10,947,960 for the nine months ended September 30, 2021 due to an increase in the weighted average year to date interest rate to 5.1% compared to 4.4% for the prior year.

~~Gain (loss) on derivative contracts.~~ In the Statements of Operations, the total loss on derivative contracts decreased by approximately 97%, from $73,586,199 for the nine months ended September 30, 2021 to $2,201,970 for the nine months ended September 30, 2022. Underlying this overall change in loss were changes within the realized and unrealized portions of the derivative instruments. We

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experienced an increase of $15,315,750 in realized losses from $33,278,132 during the nine months ended September 30, 2021 to $48,593,882 during the nine months ended September 30, 2022 due to an increase in oil prices. The Company records all derivative instruments on the Balance Sheets as either an asset or liability measured at fair value. Changes in fair value are recognized currently in earnings unless certain specific hedge accounting criteria are met. The unrealized (mark to market) loss changed from $40,308,067 during the nine months ended September 30, 2021 to an unrealized gain of $46,391,912 during the nine months ended September 30, 2022 due to favorable positions entered into during the current year.

~~Net income (loss).~~ For the nine months ended September 30, 2022, the Company achieved net income of $124,142,356, compared to a net loss of $20,789,318 for the nine months ended September 30, 2021. The primary difference was the higher sales volumesLiquidity and ~~revenue in 2022 compared to 2021 resulting from increased workovers and drilling activities, and the significantly higher oil prices in 2022, as well as much a lower loss on derivative contracts.~~

~~Sales volumes and commodity prices received~~

~~The following table presents our sales volumes and received pricing information for the periods indicated (Note that for periods prior to July 1, 2022, sales for NGLs were presented with natural gas):~~

For the Nine Months

Ended September 30,


2022

2021
Oil volume (Bbls)

2,338,469

1,971,776
Natural gas volume (Mcf)

2,408,241

1,773,506
Natural gas liquids (Bbls)

130,052

Total Production (Boe)⁽¹⁾

2,869,895

2,267,360

Average Sales Price

Oil price (per Bbl)

$
98.16

$
64.37
Gas price (per Mcf)

$
6.10

$
5.48
Natural gas liquids (Bbl)

$
25.68

Total per Boe

$
86.26

$
60.26

⁽¹⁾ ~~Boe is calculated using six Mcf of natural gas as the equivalent of one barrel of oil.~~

Capital Resources ~~and Liquidity~~

As of September 30, ~~2022, the Company~~2023, we had cash on hand of ~~$890,567,~~$0.1 million, compared to ~~$2,408,316~~$3.7 million as of December 31, ~~2021. The Company~~2022. We had net cash provided by operating activities for the nine months ended September 30, ~~2022~~2023 of ~~$133,335,223,~~$142.4 million, compared to ~~$49,523,439~~net cash provided by operating activities of $133.3 million for the same period in ~~2021~~2022 primarily due to higher year to date revenues, which resulted in more cash received from ~~customers, as well as a significant decrease in working capital. The Company used~~purchasers. We had net cash used in investing activities of ~~$268,346,299~~$170.9 million for the nine months ended September 30, ~~2022,~~2023, compared to ~~$33,869,724~~net cash used in investing activities of $268.3

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million for the same period in ~~2021,~~2022, driven by the higher cash spent on the Stronghold Acquisition in 2022 compared to the Founders Acquisition in 2023, and ~~an increase~~due to the divestitures of non-core properties in ~~capital expenditures to develop oil~~New Mexico and ~~natural gas properties.~~the Delaware Basin which occurred during 2023. Net cash provided by financing activities was ~~$133,493,327~~$24.9 million for the nine months ended September 30, ~~2022~~2023 during which time ~~$145,000,000~~$13 million was the net borrowing of principal on our Credit Facility.

We will continue to focus on maximizing ~~free~~ cash flow in ~~2022~~2023 through a combination of cost monitoring and prudent capital allocation, which includes prioritizing our capital to projects we believe will provide high rates of return in the current commodity price environment. In response to higher commodity prices, our continuous drilling program and successful wells on the Stronghold properties resulted in capital expenditures for 2022 that are significantly higher than 2021 levels. With the increased level of capital expenditures, our oil and natural gas production has increased throughout 2022. We will continue our pursuit of acquisitions and business combinations, seeking opportunities that we believe will provide high margin properties with attractive returns at current commodity prices.

During the remainder of ~~2022,~~2023, we will remain focused on maximizing ~~free~~ cash flow, reducing our debt level, and maximizing our liquidity.

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Availability of Capital Resources under Credit Facility

In April 2019, the Company amended and restated its Credit Agreement with Truist, as lender, issuing bank and administrative agent for several banks and other financial institutions and lenders (the “Administrative Agent”), (as amended and restated, the “Credit Facility”). The amendment and restatement of the Credit Agreement, among other things, increased the maximum borrowing amount to $1 billion, extended the maturity date through April 2024 and made other modifications to the terms of the Credit Facility. This Credit Facility was amended on August 31, 2022, June 25, 2021, June 10, 2021, December 23, 2020 and June 17, 2020.

On August 31, 2022, the Company modified its Credit Facility with the Administrative Agent through the Second Amended and Restated Credit Agreement. In conjunction with the Stronghold Acquisition, with the newly acquired assets put up for collateral, the Company established a borrowing base of $600 million. The syndicate was modified to add five lenders, replacing five exiting lenders.

The Credit Facility provides for SOFR Loans and Base Rate Loans (as respectively defined in the Second Amended and Restated Credit Agreement). The annual interest rate on each SOFR Loan will be the adjusted term SOFR for the applicable interest period plus a margin between 3.0% and 4.0% per annum (depending on the then-current level of borrowing base usage). The annual interest rate on each Base Rate Loan is (a) the greatest of (i) the Administrative Agent’s prime lending rate, (ii) the Federal Funds Rate (as defined in the Credit Facility) plus 0.5% per annum, (iii) the adjusted term SOFR determined on a daily basis for an interest period of one month, plus 1.00% per annum and (iv) 0.00% per annum, plus (b) a margin between 2.0% and 3.0% (depending on the then-current level of borrowing base usage).

The Credit Facility contains certain covenants, which, among other things, require the maintenance of (i) a total Leverage Ratio (outstanding debt to adjusted earnings before interest, taxes, depreciation and amortization, exploration expenses, and all other non-cash charges acceptable to the Administrative Agent) of not more than 3.0 to 1.0 and (ii) a minimum ratio of Current Assets to Current Liabilities (as such terms are defined in the Second Amended and Restated Credit Agreement) of 1.0 to 1.0. The Credit Facility also contains other customary affirmative and negative covenants and events of default.

As of September 30, ~~2022, $435,000,000~~2023, $428 million was outstanding on ~~the~~our Credit Facility and we were in compliance with all of ~~our covenants.~~

the covenants under the Credit Facility. The ~~Company is required to maintain on a rolling 24 month basis, hedging transactions~~Credit Facility matures in ~~respect of crude oil and natural gas, on not less than 50% of the projected production from the proved, developed, producing oil and gas. If the~~August 2026. The borrowing base utilization is less than 25% at the hedge testing date and the leverage ratio is not greater than 1.25 to 1.00, the required hedging percentage for months 13 through 24 of the rolling 24 month period provided for shall be 0% from such hedge testing date to the next succeeding hedge testing date. If the borrowing base utilization percentage is equal to or greater than 25%, but less than 50% and the leverage ratio is not greater than 1.25 to 1.0, the required hedging percentage for months 13 through 24 of the rolling 24 month period provided for shall be 25% from such hedge testing date to the next succeeding hedge testing date.

~~Derivative Financial Instruments~~

During February and March of 2020, the Company entered into derivative contracts in the form of costless collars of WTI Crude Oil prices in seeking to protect the Company’s cash flow from price fluctuation and maintain its capital programs. “Costless collars” are the combination of two options, a put option (floor) and a call option (ceiling) with the options structured so that the premium paid for the put option will be offset by the premium received from selling the call option. The trades were for a total 4,500 barrels of oil per day for the period of January 2021 through December 2021.

In November and December of 2020, the Company entered into swap contracts with a weighted average of $45.42 for 4,500 barrels per day for 2021 and 1,750 barrels per day for 2022 with a weighted average of $44.84. In January and February of 2021, we entered into swap contracts for 500 barrels per day for 2022 for a weighted average price of $48.53. Similar to costless collars, there is no cost to enter into the swap contracts. On swap contracts, there is no spread and payments will be made or received based on the difference between WTI and the swap contract price.

In November of 2020, we entered into natural gas swap contracts for 6,000 MMBtu per day at $2.991 and 5,000 MMBtu per day at $2.726 for 2021 and 2022, respectively. On March 30, 2021, we unwound all remaining gas swaps for 2021 and 2022 for a realized value of $581,424.

In May of 2021, we bought back a 1,500 barrels of oil per day call option for June 1 through December 31, 2021 and entered into an approximate 879 Bbls/d calendar 2022 swap contract for no net cost. This allowed us to unlock additional upside to increase our cash flow for the remainder of 2021, while retaining the put to protect our downside.

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Effective February 1, 2022, the Company entered into a derivative contract with a Credit Facility lender for 1,000 barrels of oil per day for the remainder of 2022 (total notional quantity of 334,000 barrels). Fixed swap prices vary by month, ranging from $90.78 per barrel in February to $80.01 per barrel by the end of the year, with a weighted average swap price of $84.61 per barrel.

Near the end of the second quarter 2022, on June 28 and 29, the Company entered into 12 oil derivative contracts with a Credit Facility lender. On July 1, 8, and 25, and August 5, the Company entered into nine oil derivative contracts. As part of the Stronghold Acquisition, 18 oil derivative contracts and 15 natural gas derivative contracts were entered into on August 23 and 29. On September 26, we entered into one oil and three natural gas derivative contracts. Details are shown in the table below, all of which are with lenders under our Credit Facility is $600 million. The borrowing base is redetermined semi-annually on each May and November. See "NOTE 8 — REVOLVING LINE OF CREDIT" in the Notes to the condensed financial statements for more information on our Credit Facility.

Derivative Financial Instruments

The following table reflects the contracts outstanding as of September 30, ~~2022 (quantities~~2023 (Quantities are in barrels (Bbl) for the oil derivative contracts and in million British thermal units (MMBtu) for the natural gas derivative contracts.):

Oil Hedges (WTI)


2022

2023

2024

Swaps:






Hedged volume (BBL)

379,250

389,250

526,000
Weighted average swap price

$
54.89

$
77.55

$
65.90

Deferred premium puts:






Hedged volume (BBL)

138,000

773,500

91,000
Weighted average strike price

$
97.93

$
90.64

$
83.75
Weighted average deferred premium price

$
11.81

$
15.25

$
17.32

Two-way collars:






Hedged volume (BBL)

97,201

487,622

475,350
Weighted average put price

$
53.93

$
52.16

$
67.88
Weighted average call price

$
67.68

$
62.94

$
83.32

Three-way collars:






Hedged volume (BBL)

89,985

66,061

—
Weighted average first put price

$
40.00

$
45.00

$
—
Weighted average second put price

$
50.00

$
55.00

$
—
Weighted average call price

$
62.03

$
80.05

$
—


	Oil Hedges (WTI)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

Swaps:
Hedged volume (Bbl)	138,000		170,625		156,975		282,900		368,000		—		—		184,000		—
Weighted average swap price	$	74.52	$	67.40	$	66.40	$	65.49	$	68.43	$	—	$	—	$	73.35	$	—

Deferred premium puts:
Hedged volume (Bbl)	165,600		45,500		45,500		—		—		—		—		—		—
Weighted average strike price	$	83.78	$	84.70	$	82.80	$	—	$	—	$	—	$	—	$	—	$	—
Weighted average deferred premium price	$	14.61	$	17.15	$	17.49	$	—	$	—	$	—	$	—	$	—	$	—

Two-way collars:
Hedged volume (Bbl)	274,285		339,603		325,847		230,000		128,800		474,750		464,100		184,000		—
Weighted average put price	$	56.73	$	64.20	$	64.30	$	64.00	$	60.00	$	57.06	$	60.00	$	65.00	$	—
Weighted average call price	$	70.77	$	79.73	$	79.09	$	76.50	$	73.24	$	75.82	$	69.85	$	80.08	$	—

Three-way collars:
Hedged volume (Bbl)	15,598		—		—		—		—		—		—		—		—
Weighted average first put price	$	45.00	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Weighted average second put price	$	55.00	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Weighted average call price	$	80.05	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—

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Gas Hedges (basis differential)


2022

2023

2024

Waha basis swaps:






Hedged volume (MMBtu)

505,024

1,339,685

—
Weighted average swap price

(2)

(3)

$
—


	Gas Hedges (Henry Hub)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

NYMEX Swaps:
Hedged volume (MMBtu)	134,102		152,113		138,053		121,587		644,946		616,199		591,725		285,200		—
Weighted average swap price	$	3.35	$	3.62	$	3.61	$	3.59	$	4.45	$	3.78	$	3.43	$	3.73	$	—

Two-way collars:
Hedged volume (MMBtu)	383,587		591,500		568,750		552,000		—		—		—		285,200		—
Weighted average put price	$	3.15	$	4.00	$	4.00	$	4.00	$	—	$	—	$	—	$	3.00	$	—
Call hedged volume (MMBtu)	383,587		591,500		568,750		552,000		—		—		—		285,200		—
Weighted average call price	$	4.51	$	6.29	$	6.29	$	6.29	$	—	$	—	$	—	$	4.80	$	—


	Oil Hedges (basis differential)
	Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

Argus basis swaps:
Hedged volume (MMBtu)	305,000		364,000		364,000		368,000		368,000		270,000		273,000		276,000		276,000
Weighted average spread price (1)	$	1.10	$	1.15	$	1.15	$	1.15	$	1.15	$	1.00	$	1.00	$	1.00	$	1.00

~~(1)~~

~~(2)~~	~~The WAHA~~Q4 2023		Q1 2024		Q2 2024		Q3 2024		Q4 2024		Q1 2025		Q2 2025		Q3 2025		Q4 2025

Waha basis ~~swaps in place for the remainder of 2022 consist of five derivative contracts, each with a fixed~~swaps:
Hedged volume (MMBtu)	324,021		—		—		—		—		—		—		—		—
Weighted average spread price ~~of the Henry Hub natural gas~~(1)	$	0.55	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—

El Paso Permian Basin basis swaps:
Hedged volume (MMBtu)	459,683		—		—		—		—		—		—		—		—
Weighted average spread price ~~less a fixed amount (weighted average of $0.57 per MMBtu).~~(1)	$	0.63	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—

~~(3)~~

Derivative financial instruments are recorded at fair value and included as either assets or liabilities in the accompanying Condensed Balance Sheets. Any gains or losses resulting from changes in fair value of outstanding derivative financial instruments and from the settlement of derivative financial instruments are recognized in earnings and included as a component of Other Income (Expense) in the accompanying Condensed Statements of Operations.

Effects of Inflation and Pricing

The oil and natural gas industry is cyclical and the demand for goods and services of oil field companies, suppliers and others associated with the industry puts significant pressure on the economic stability and pricing structure within the industry. Typically, as prices for oil and natural gas increase, so do associated costs. Material changes in prices impact our current revenue stream, estimates of future reserves, borrowing base calculations of bank loans and the value of properties in purchase and sale transactions. Material changes in prices can impact the value of oil and natural gas companies and their ability to raise capital, borrow money and retain personnel. We anticipate business costs will vary in accordance with

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commodity prices for oil and natural gas, and the associated increase or decrease in demand for services related to production and exploration.

Off-Balance Sheet Financing Arrangements

As of September 30, 2023, we had no off-balance sheet financing arrangements.

Capital Resources for Future Acquisition and Development Opportunities

We continuously evaluate potential acquisitions and development opportunities. To the extent possible, we intend to acquire producing properties with lower-risk undeveloped drilling opportunities rather than properties with higher-risk exploratory opportunities. We do not intend to limit our evaluation to any one state, but we presently have no intention to acquire offshore properties or properties located outside of the United States.

The pursuit of and the acquisition of accretive oil and gas properties is highly competitive and may require substantially greater capital than we currently have available and obtaining additional capital may require that we obtain either short-term or long-term debt or sell our equity or both. ~~Furthermore,~~Further, it may be necessary for us to retain outside consultants and others in our endeavors to locate desirable oil and gas properties.

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The process of acquiring one or more additional oil and gas properties would impact our financial position, ~~and~~ reduce our cash ~~position.~~position and possibly increase our debt. The types of costs that we may incur include the costs to retain consultants and investment bankers specializing in the purchase of oil and gas properties, obtaining petroleum engineering reports relative to the oil and gas properties that we are investigating, legal fees associated with any such acquisitions including title reports, SEC reporting expenses, and negotiating definitive agreements. Additionally, accounting fees may be incurred relative to obtaining and evaluating historical and ~~pro forma~~proforma information regarding such oil and gas properties. Even though we may incur such costs, there is no assurance that we will ultimately be able to consummate other acquisitions of oil and gas producing properties.

~~Effects of Inflation and Pricing~~

The oil and natural gas industry is very cyclical and the demand for goods and services of oil field companies, suppliers and others associated with the industry puts pressure on the economic stability and pricing structure within the industry. Typically, as prices for oil and natural gas increase, so do all associated costs. Material changes in prices will impact our cash flow, estimates of future reserves, borrowing base calculations of bank loans and the value of properties in purchase and sale transactions. Material changes in prices can also impact the value of oil and natural gas companies and their ability to raise capital, borrow money and retain personnel. We anticipate business costs will vary in accordance with commodity prices for oil and natural gas, and the associated increase or decrease in demand for services related to production and exploration.We further expect that prices to explore, develop and produce oil and gas may increase depending in large part on government spending and regulations.

~~Off-Balance Sheet Arrangements~~

~~The Company does not have any off-balance sheet arrangements, and it is not anticipated that the Company will enter into any off-balance sheet arrangements.~~

~~Disclosures About Market Risks~~

Like other natural resource producers, the Company faces market risks associated with the exploration and production of oil and natural gas. The most salient risk factors are the volatile prices of oil and gas, transportation of oil and natural gas, competition in the oil and natural gas industry, retention of key personnel, and environmental and regulatory concerns and obligations.

~~Oil and Gas Prices~~

The price we receive for our oil and natural gas will heavily influence our revenue, profitability, access to capital and future rate of growth. Oil and natural gas are commodities and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. The prices we receive for our production depend on numerous factors beyond our control. These factors include, without limitation, the following: worldwide and regional economic conditions impacting the global supply and demand for oil and natural gas; geopolitical events such as military actions, threats of war, war and the imposition of sanctions in connection with these events; the price and quantity of imports of foreign oil and natural gas; the level of global oil and natural gas inventories; localized supply and demand fundamentals; the availability of refining capacity; price and availability of transportation and pipeline systems with adequate capacity; weather conditions, natural disasters and public health threats; governmental regulations; speculation as to the future price of oil and the speculative trading of oil and natural gas futures contracts; price and availability of competitors’ supplies of oil and natural gas; energy conservation and environmental measures; technological advances affecting energy consumption; the price and availability of alternative fuels and energy sources; and domestic and international drilling activity.

A substantial or extended decline in oil or natural gas prices may result in impairments of our proved oil and gas properties and may materially and adversely affect our future business, financial condition, cash flows, and results of operations.

~~Transportation of Oil and Natural Gas~~

Ring is presently committed to using the services of the existing gatherers in its present areas of production. This gives such gatherers certain short-term relative monopolistic powers to set gathering and transportation costs. Obtaining the services of an alternative gathering company would require substantial additional costs since an alternative gatherer would be required to lay new pipeline and/or obtain new rights-of-way.

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~~Competition in the Oil and Natural Gas Industry~~

We operate in a highly competitive environment for developing and acquiring properties, marketing oil and natural gas and securing equipment and trained personnel. As a relatively small oil and natural gas company, many large producers possess and employ financial, technical and personnel resources substantially greater than ours. Those companies may be able to develop and acquire more prospects and productive properties than our financial or personnel resources permit. It is also significant that more favorable prices can usually be negotiated for larger quantities of oil and/or gas product, such that Ring views itself as having a price disadvantage compared to larger producers.

~~Retention of Key Personnel~~

We depend to a large extent on the services of our officers. These individuals have extensive experience in the energy industry, as well as expertise in evaluating and analyzing producing oil and natural gas properties and drilling prospects, maximizing production from oil and natural gas properties, and developing and executing financing strategies. The loss of any of these individuals could have a material adverse effect on our operations and business prospects. Our success is dependent on our ability to continue to hire, retain and utilize skilled executive and technical personnel.

~~Environmental and Regulatory Risks~~

Our business and operations are subject to and impacted by a wide array of federal, state, and local laws and regulations governing the exploration for and development, production, and marketing of oil and natural gas, the operation of oil and natural gas wells, taxation, and environmental and safety matters. Many laws and regulations require drilling permits and govern the spacing of wells, rates of production, water and waste use and disposal, prevention of waste, hydraulic fracturing, and other matters. From time to time, regulatory agencies have imposed price controls and limitations on production in order to conserve supplies of oil and natural gas. In addition, the production, handling, storage, transportation and disposal of oil and natural gas, byproducts thereof and other substances and materials produced or used in connection with oil and natural gas operations are subject to regulation under federal, state and local laws and regulations. Compliance with these regulations may constitute a significant cost and effort for Ring. In the event of a violation of environmental regulations, these environmental regulatory agencies have a broad range of alternative or cumulative remedies, including ordering a cleanup of any spills or waste material and restoration of the soil or water to conditions existing prior to the environmental violation; fines; or enjoining further drilling, completion, or production activities.

Item 3.3: Quantitative and Qualitative Disclosures ~~about~~About Market Risk

~~Interest Rate Risk~~

The Company is subject to market risk exposure related to changes in interest rates on its indebtedness under its Credit Facility, which bears variable interest based upon a prime rate and is therefore susceptible to interest rate fluctuations. Changes in interest rates affect the interest earned on the Company’s cash and cash equivalents and the interest rate paid on borrowings under the Credit Facility. As of September 30, 2022, the Company had $435,000,000 outstanding borrowings under the Credit Facility. Our weighted average annual interest rate on borrowings under the Credit Facility was 5.1% for the nine months ended September 30, 2022. An increase or decrease of 1% in the interest rate would have a corresponding decrease or increase in our annualized interest expense of $4.4 million based on the aggregate of $435,000,000 outstanding under the Credit Facility as of September 30, 2022.

~~Currently, the Company does not use interest rate derivative instruments to manage exposure to interest rate changes.~~

Commodity Price Risk

Our major market risk exposure is in the pricing applicable to our oil and natural gas production. Market risk refers to the risk of loss from adverse changes in oil and natural gas prices. Realized pricing is primarily driven by the prevailing domestic price for crude oil and spot prices applicable to the region in which we produce oil and natural gas. Historically, prices received for oil and natural gas production have been volatile and unpredictable. We expect pricing volatility to continue.

The prices we receive depend on many factors outside of our control. A significant decline in the prices of oil or natural gas would likely have a material adverse effect on our financial condition and results of operations. In order to reduce commodity price uncertainty and increase cash flow predictability relating to the marketing of our crude oil and natural gas, we enter into crude oil and natural gas price hedging arrangements with respect to a portion of our expected production.

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The Company’s revenues, profitability and future growth depend substantially on prevailing prices for oil and natural gas. Prices also affect the amount of cash flow available for capital expenditures and Ring’s ability to borrow and raise additional capital. The Company’s borrowing base under its Credit Facility is subject to periodic redetermination based in part on changing expectations of future prices. Lower prices may also reduce the amount of oil and natural gas that the Company can economically produce. Ring currently sells all its oil and natural gas production under price sensitive or market price contracts.

Customer Credit Risk

Our principal ~~exposures~~exposure to credit risk ~~are~~is through receivables from the sale of our oil and natural gas production (approximately ~~$44.7~~$43.8 million atas of September 30, ~~2022) and through receivables from our joint interest partners (approximately $1.9 million at September 30, 2022)~~2023). We are subject to credit risk due to the concentration of our oil and natural gas receivables with our most significant ~~customers.~~customers, or purchasers. We do not require our ~~customers~~purchasers to post collateral, and the inability of our significant ~~customers~~purchasers to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. ~~For~~Refer to the following table for detail on the top three purchasers of our oil, natural gas, and NGL revenues for the nine months ended September 30, ~~2022, sales to two customers, Phillips 66 and NGL Crude represented 69% and 14%~~2023. We believe that the loss of any of these purchasers would not materially impact our business because we could readily find other purchasers for our oil and ~~gas revenues, respectively.~~ natural gas.

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For the Nine Months Ended

As of

September 30, 2023

Percentage of Oil, Natural Gas, and Natural Gas Liquids Revenues

Percentage of accounts receivables from the sale of our oil and natural gas production

Purchaser:

Phillips 66 Company ("Phillips")

67%

69%

Enterprise Crude Oil LLC ("Enterprise")

12%

NGL Crude Partners ("NGL Crude")

10%

Interest Rate Risk

We are subject to market risk exposure related to changes in interest rates on our indebtedness under our Credit Facility, which bears variable interest based upon a prime rate and is therefore susceptible to interest rate fluctuations. Changes in interest rates affect the interest earned on the Company’s cash and cash equivalents and the interest rate paid on borrowings under the Credit Facility.

As of September 30, ~~2022, Phillips 66 and NGL Crude represented 58% and 12%~~2023, we had $428.0 million outstanding on our Credit Facility with a weighted average annual interest rate for the nine months ended September 30, 2023 of 8.7%. A 1% change in the interest rate on our Credit Facility would result in an estimated $4.3 million change in our annual interest expense. See "NOTE 8 — REVOLVING LINE OF CREDIT" in the Notes to the condensed financial statements for more information on the Company’s interest rates of our ~~accounts receivable, respectively. Due to availability of other purchasers,~~Credit Facility.

Currently, we do not ~~believe the loss of any single oil or natural gas customer would have a material adverse effect on our results of operations.~~

use interest rate derivative instruments to manage exposure to interest rate changes.

Currency Exchange Rate Risk

Foreign sales accounted for none of the ~~Company’s~~Company's sales; ~~further,~~ the Company accepts payment for its commodity sales only in U.S. dollars. Ring is therefore not exposed to foreign currency exchange rate risk on these sales.

Please also see Item 1A “Risk Factors” for a discussion of other risks and uncertainties we face in our business.

Item 4.4: Controls and Procedures

Evaluation of disclosure controls and ~~procedures~~

procedures.

Our management, with the participation of Paul D. McKinney, our principal executive officer, and Travis T. Thomas, our principal financial officer, evaluated the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 under the Exchange Act. In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures must reflect the fact that there are resource constraints, and that management is required to apply its judgment in evaluating the benefits of possible controls and procedures relative to their costs.

Based on management’s evaluation, Messrs. McKinney and Thomas concluded that our disclosure controls and procedures as of the end of the period covered by this report were effective in ensuring that information required to be disclosed by us in reports that we file or submit under the Exchange Act (i) is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and (ii) is accumulated and communicated to the Company’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

We will continue to monitor and evaluate the effectiveness of our disclosure controls and procedures and our internal controls over financial reporting on an ongoing basis and are committed to taking further action and implementing additional enhancements or improvements, as necessary and as funds allow.

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Changes in internal control over financial ~~reporting~~

reporting.

We regularly review our system of internal control over financial reporting and make changes to our processes and systems to improve controls and increase efficiency, while ensuring that we maintain an effective internal control environment. Changes may include such activities as implementing new, more efficient systems, consolidating activities, and migrating processes.

There were no changes in our internal control over financial reporting that occurred during the ~~nine~~three months ended September 30, ~~2022~~2023 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 1.1: Legal ~~Proceedings.~~

~~We may be~~Proceedings

There were no material developments during the ~~subject of threatened or pending legal actions and contingencies~~quarter ended September 30, 2023 in the normal course of conducting our business. We provide for costs related to these matters when a loss is probable and the amount can be reasonably estimated. The effect of the outcome of these matters on our future results of operations and liquidity cannot be predicted because any such effect depends on future results of operations and the amount or timing of the resolution of such matters. For certain types of claims, we maintain insurance coverage for personal injury and property damage, product liability and other liability coverages in amounts and with deductibles that we believe are prudent, but there can be no assurance that these coverages will be applicable or adequate to cover adverse outcomes of claims or legal ~~proceedings against us. Reference is made to Item 3. Legal Proceedings,~~proceeding described in our Annual Report on Form 10-K for the year ended December 31, ~~2021 as filed with the SEC on March 16, 2022. The information in such Item is incorporated herein by reference.~~

2022.

Item ~~1A.~~1A: Risk Factors

We are subject to certain risks and hazards due to the nature of the business activities we conduct. For a discussion of these risks, see “Item 1A. Risk Factors” in our ~~2021 Form 10-K. The following are risks that have arisen since the filing of our 2021~~Annual Report on Form 10-K ~~on March 16, 2022.~~for the year ended December 31, 2022 as filed with the SEC. We may experience additional risks and uncertainties not currently known to us. Further, as a result of developments occurring in the future, conditions that we currently deem to be immaterial may also materially and adversely affect us. Any such risks may materially and adversely affect our business, financial condition, cash flows, and results of operations.

~~We have recently registered 63,888,878 shares of our common stock for possible resale by certain of our stockholders.~~

In connection with the recently completed Stronghold Acquisition as discussed above, we registered 63,888,878 shares of our common stock, par value $0.001 per share, with the SEC for possible resale by Stronghold stockholders. This represents approximately 37% of our presently outstanding shares of common stock and if the selling stockholders choose to sell all or a large number of their shares, from time to time, it could have a depressive effect on the market price of our common stock.

~~We have significant indebtedness.~~

We have a credit facility in place with $600 million in commitments for borrowings and letters of credit under our Second Amended and Restated Credit Agreement dated August 31, 2022 with Truist Bank, as Administrative Agent (“Credit Agreement”). As of September 30, 2022, $435 million was outstanding on our credit facility. If we further utilize this facility, the level of our indebtedness could affect our operations in several ways, including the following:

●

~~a significant portion of our cash flow could be used to service the indebtedness;~~

●

~~a high level of debt would increase our vulnerability to general adverse economic and industry conditions;~~

●

~~the covenants contained in our credit facility limit our ability to borrow additional funds, dispose of assets, pay dividends and make certain investments; and~~

●

~~a high level of debt could impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions, general corporate or other purposes.~~

In addition, our bank borrowing base is subject to semi-annual redeterminations. We could be required to repay a portion of our bank borrowings due to redeterminations of our borrowing base. If we are required to do so, we may not have sufficient funds to make such repayments, and we may need to negotiate renewals of our borrowings or arrange new financing or sell significant assets. Any such actions could have a material adverse effect on our business and financial results.

~~We currently do not pay cash dividends on our common stock.~~

We currently intend to retain future earnings, if any, to finance the expansion of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our business, financial condition, results of operations, capital requirements, and investment opportunities. In addition, the terms of our Credit Agreement have restrictions on dividend payments to our equity holders, including our common stockholders.

~~Table of Contents~~

Item 2.2: Unregistered Sales of Equity Securities and Use of Proceeds

~~The information required by this item was disclosed and reported under Item 3.02, Unregistered Sales of Equity Securities, of our~~ ~~Form 8-K dated August 30, 2022, filed with the SEC on September 6, 2022, which disclosure is incorporated herein by reference.~~

None.

Item 3.3: Defaults Upon Senior ~~Securities.~~

Securities

None.

Item 4.4: Mine Safety ~~Disclosures.~~

Disclosures

None.

Item 5.5: Other ~~Information.~~

Information

During the quarter ended September 30, 2023, none of our directors or officers (as defined in Rule 16a-1(f) of the Securities Exchange Act of 1934) adopted, terminated or modified a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (as such terms are defined in Item 408 of Regulation S-K).

Table of Contents

~~None.~~

Item 6.6: Exhibits

Incorporated by Reference

Exhibit
Number

Exhibit Description

Form

File No.

Exhibit

Filing Date

Filed
Here-with

Furnished
Herewith

31.1

~~Rule 13a-14(a) Certification by Principal Executive Officer~~

~~31.2~~

Rule 13a-14(a) ~~Certification by Principal Financial Officer~~

~~32.1~~

~~Section 1350~~ Certification by Chief Executive Officer

~~32.2~~

31.2

~~Section 1350~~Rule 13a-14(a) Certification by Chief Financial Officer

~~101.SCH~~

32.1

Section 1350 Certification of Chief Executive Officer

32.2

Section 1350 Certification Chief Financial Officer

101.SCH

Inline XBRL Taxonomy Extension Schema Document

101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB

Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE

Inline XBRL Taxonomy Extension Presentation Linkbase Document

104

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

Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


			Ring Energy, Inc.


Date: November ~~9, 2022~~ 2, 2023			By:	/s/ Paul D. McKinney
				Paul D. McKinney
				Chief Executive Officer ~~and Director~~
				(Principal Executive Officer)


Date: November ~~9, 2022~~ 2, 2023	By:	/s/ Travis T. Thomas
				Travis T. Thomas
				Chief Financial Officer
				(Principal Financial and Accounting Officer)


	September 30, 2022		December 31, 2021
ASSETS
Current Assets
Cash and cash equivalents	$	890,567	$	2,408,316
Accounts receivable		45,864,400		24,026,807
Joint interest billing receivable		1,897,125		2,433,811
Derivative assets		13,322,013		—
Prepaid expenses and other assets		3,246,569		938,029
Total Current Assets		65,220,674		29,806,963
Properties and Equipment
Oil and natural gas properties, full cost method		1,418,931,111		883,844,745
Financing lease asset subject to depreciation		2,067,375		1,422,487
Fixed assets subject to depreciation		2,985,778		2,089,722
Total Properties and Equipment		1,423,984,264		887,356,954
Accumulated depreciation, depletion and amortization		(269,541,416)		(235,997,307)
Net Properties and Equipment		1,154,442,848		651,359,647
Operating lease asset		1,071,482		1,277,253
Derivative assets		11,545,982		—
Deferred financing costs		19,029,907		1,713,466
Total Assets	$	1,251,310,893	$	684,157,329

LIABILITIES, MEZZANINE EQUITY AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts payable	$	86,822,997	$	46,233,452
Income tax liability		36,736		—
Financing lease liability		406,890		316,514
Operating lease liability		306,715		290,766
Derivative liabilities		23,767,689		29,241,588
Notes payable		877,631		586,410
Deferred cash payment		14,511,687		—
Total Current Liabilities		126,730,345		76,668,730

Noncurrent Liabilities
Deferred income taxes		5,920,300		90,292
Revolving line of credit		435,000,000		290,000,000
Financing lease liability, less current portion		564,205		343,727
Operating lease liability, less current portion		905,524		1,138,319
Derivative liabilities		8,734,388		—
Asset retirement obligations		29,426,737		15,292,054
Total Liabilities		607,281,499		383,533,122
Mezzanine Equity
Convertible preferred stock - $0.001 par value; 153,176 shares outstanding		137,858,446		—
Stockholders’ Equity
Preferred stock - $0.001 par value; 50,000,000 shares authorized; 153,176 shares issued or outstanding		—		—
Common stock - $0.001 par value; 225,000,000 shares authorized; 131,586,927 shares and 100,192,562 shares issued and outstanding, respectively		131,587		100,193
Additional paid-in capital		634,845,283		553,472,292
Accumulated deficit		(128,805,922)		(252,948,278)
Total Stockholders’ Equity		506,170,948		300,624,207
Total Liabilities, Mezannine Equity and Stockholders’ Equity	$	1,251,310,893	$	684,157,329


	For the Three Months				For the Nine Months
	Ended September 30,				Ended September 30,
	2022		2021		2022		2021
Oil Natural Gas and Natural Gas Liquids Revenues	$	94,408,948	$	49,376,176	$	247,551,855	$	136,638,810

Costs and Operating Expenses
Lease operating expenses		13,029,098		6,983,196		30,283,706		22,634,259
Gathering, transportation and processing costs		—		1,051,163		1,846,247		2,883,348
Ad valorem taxes		1,199,385		703,774		3,100,578		2,144,800
Oil and natural gas production taxes		4,563,519		2,240,759		11,939,338		6,291,860
Depreciation, depletion and amortization		14,324,502		9,310,524		34,854,993		26,693,808
Asset retirement obligation accretion		243,140		182,905		617,685		560,662
Operating lease expense		83,590		83,589		250,770		439,896
General and administrative expense		7,393,848		4,433,251		18,748,427		11,103,394
Total Costs and Operating Expenses		40,837,082		24,989,161		101,641,744		72,752,027

Income from Operations		53,571,866		24,387,015		145,910,111		63,886,783

Other Income (Expense)
Interest income		4		—		4		1
Interest (expense)		(7,021,385)		(3,551,462)		(13,699,045)		(10,947,960)
Gain (loss) on derivative contracts		32,851,189		(6,720,320)		(2,201,970)		(73,586,199)
Net Other Income (Expense)		25,829,808		(10,271,782)		(15,901,011)		(84,534,158)

Income (Loss) Before Provision for Income Taxes		79,401,674		14,115,233		130,009,100		(20,647,375)

Benefit from (Provision for) Income Taxes		(4,315,783)		48,701		(5,866,744)		(141,943)
Net Income (Loss)	$	75,085,891	$	14,163,934	$	124,142,356	$	(20,789,318)

Basic Earnings (Loss) per share	$	0.65	$	0.14	$	1.16	$	(0.21)
Diluted Earnings (Loss) per share	$	0.49	$	0.12	$	0.92	$	(0.21)


				Additional		Retained Earnings		Total
	Common Stock			Paid-in		(Accumulated		Stockholders’
For the Nine Months Ended September 30, 2022	Shares	Amount		Capital		Deficit)		Equity
Balance, December 31, 2021	100,192,562	$	100,193	$	553,472,292	$	(252,948,278)	$	300,624,207
Share-based compensation	—		—		1,521,910		—		1,521,910
Net income	—		—		—		7,112,043		7,112,043
Balance, March 31, 2022	100,192,562	$	100,193	$	554,994,202	$	(245,836,235)	$	309,258,160
Exercise of common warrants issued in offering	6,453,907		6,454		5,156,672		—		5,163,126
Options exercised	100,000		100		(100)		—		—
Shares elected to be withheld for options exercised	(47,506)		(48)		48		—		—
Restricted stock vested	610,195		610		(610)		—		—
Shares to cover tax withholdings for restricted stock vested	(73,047)		(73)		73		—		—
Payments to cover tax withholdings for restricted stock vested	—		—		(257,694)		—		(257,694)
Share-based compensation	—		—		1,899,245		—		1,899,245
Net income	—		—		—		41,944,422		41,944,422
Balance, June 30, 2022	107,236,111	$	107,236	$	561,791,836	$	(203,891,813)	$	358,007,259
Exercise of common warrants issued in offering	3,000,000		3,000		2,397,000		—		2,400,000
Restricted stock vested	13,504		14		(14)		—		—
Shares to cover tax withholdings for restricted stock vested	(2,674)		(3)		3		—		—
Payments to cover tax withholdings for restricted stock vested	—		—		(6,790)		—		(6,790)
Common stock issuance for Stronghold	21,339,986		21,340		69,120,215		—		69,141,555
Share-based compensation	—		—		1,543,033		—		1,543,033
Net income	—		—		—		75,085,891		75,085,891
Balance, September 30, 2022	131,586,927	$	131,587	$	634,845,283	$	(128,805,922)	$	506,170,948

For the Nine Months Ended September 30, 2021
Balance, December 31, 2020	85,568,287	$	85,568	$	550,951,415	$	(256,271,170)	$	294,765,813
Common stock and warrants issued for cash, net	—		—		(65,000)		—		(65,000)
Exercise of pre-funded warrants issued in offering	13,428,500		13,429		—		—		13,429
Exercise of common warrants issued in offering	184,800		185		147,655		—		147,840
Restricted stock vested	94,350		94		(94)		—		—
Share-based compensation	—		—		355,494		—		355,494
Net (loss)	—		—		—		(19,066,093)		(19,066,093)
Balance, March 31, 2021	99,275,937	$	99,276	$	551,389,470	$	(275,337,263)	$	276,151,483
Exercise of common warrants issued in offering	100,000		100		79,900		—		80,000
Restricted stock vested	3,480		3		(3)		—		—
Shares to cover tax withholdings for restricted stock vested	(28,272)		(28)		28		—		—
Share-based compensation	—		—		351,775		—		351,775
Net (loss)	—		—		—		(15,887,159)		(15,887,159)
Balance, June 30, 2021	99,351,145	$	99,351	$	551,821,170	$	(291,224,422)	$	260,696,099
Restricted stock vested	12,500		13		(13)		—		—
Shares to cover tax withholdings for restricted stock vested	(3,707)		(4)		4		—		—
Share-based compensation	—				777,461		—		777,461
Net income	—				—		14,163,934		14,163,934
Balance, September 30, 2021	99,359,938	$	99,360	$	552,598,622	$	(277,060,488)	$	275,637,494


	2022		2023		2024		2025		2026
Operating lease payments⁽¹⁾	$	87,282	$	356,991	$	376,855	$	384,719	$	110,096
Financing lease payments⁽²⁾		109,582		438,328		372,056		99,796		—


	As of
	September 30, 2022		December 31, 2021
Operating lease liability, current portion	$	306,715	$	290,766
Operating lease liability, non-current portion		905,524		1,138,319
Operating lease liability, total	$	1,212,239	$	1,429,085
Total undiscounted future cash flows		1,315,943		1,577,786
Imputed interest		103,704		148,701
Undiscounted future cash flows less imputed interest	$	1,212,239	$	1,429,085

Financing lease liability, current portion	$	406,890	$	316,514
Financing lease liability, non-current portion		564,205		343,727
Financing lease liability, total	$	971,095	$	660,241
Total undiscounted future cash flows		1,019,762		692,091
Imputed interest		48,667		31,850
Undiscounted future cash flows less imputed interest	$	971,095	$	660,241


	Three months ended				Nine months ended
	September 30,				September 30,
	2022		2021		2022		2021
Operating lease costs	$	83,590	$	83,589	$	250,770	$	439,896
Short term lease costs ⁽¹⁾		639,708		964,873		1,937,310		2,903,387
Financing lease costs:
Amortization of financing lease assets ⁽²⁾		106,982		85,367		334,447		189,831
Interest on lease liabilities ⁽³⁾		10,391		5,160		24,184		14,166


Consideration:
Shares of Ring Common Stock issued		21,339,986
Ring Common Stock price as of August 31, 2022	$	3.24
Common Stock Consideration	$	69,141,555

Shares of Ring Preferred Stock issued		153,176
Aggregate Liquidation Preference	$	153,176,000
Conversion Price	$	3.60
As-Converted Shares of Ring Common Stock		42,548,903
Ring Common Stock Price as of August 31, 2022	$	3.24
Preferred Stock Consideration	$	137,858,446

Cash consideration:
Closing amount paid to Stronghold by bank		121,392,455
Escrow deposit paid at closing		46,500,000
Cash paid for inventory and fixed assets		4,527,103
Cash paid for realized losses on August oil derivatives		1,777,925
Total cash consideration		174,197,483
Fair value of deferred payment liability		14,511,688
Fair value of consideration to be paid to seller		395,709,171

Direct transaction costs		9,162,143
Total consideration	$	404,871,314

Fair value of assets acquired:
Oil and natural gas properties		441,318,763
Inventory and fixed assets		4,527,103
Amount attributable to assets acquired	$	445,845,866
Fair value of liabilities assumed:
Suspense liability		1,651,596
Derivative liabilities, marked to market		24,784,406
Asset retirement obligations		14,538,550
Amount attributable to liabilities assumed	$	40,974,552
Net assets acquired	$	404,871,314


	Oil Hedges (WTI)
	2022		2023		2024

Swaps:
Hedged volume (BBL)		379,250		389,250		526,000
Weighted average swap price	$	54.89	$	77.55	$	65.90

Deferred premium puts:
Hedged volume (BBL)		138,000		773,500		91,000
Weighted average strike price	$	97.93	$	90.64	$	83.75
Weighted average deferred premium price	$	11.81	$	15.25	$	17.32

Two-way collars:
Hedged volume (BBL)		97,201		487,622		475,350
Weighted average put price	$	53.93	$	52.16	$	67.88
Weighted average call price	$	67.68	$	62.94	$	83.32

Three-way collars:
Hedged volume (BBL)		89,985		66,061		—
Weighted average first put price	$	40.00	$	45.00	$	—
Weighted average second put price	$	50.00	$	55.00	$	—
Weighted average call price	$	62.03	$	80.05	$	—


	Gas Hedges (Henry Hub)
	2022		2023		2024

NYMEX Swaps:
Hedged volume (MMBtu)		46,313		175,421		—
Weighted average swap price	$	2.51	$	2.40	$	—

Two-way collars: ⁽¹⁾
Put hedged volume (MMBtu)		715,661		2,486,514		1,712,250
Weighted average put price	$	3.76	$	3.18	$	4.00
Call hedged volume (MMBtu)		435,061		2,306,514		1,712,250
Weighted average call price	$	10.22	$	5.03	$	6.29

Three-way collar:
Hedged volume (MMBtu)		304,250		—		—
Weighted average first put price	$	2.20	$	—	$	—
Weighted average second put price	$	2.50	$	—	$	—
Weighted average call price	$	3.25	$	—	$	—
Weighted average deferred premium price	$	0.19	$	—	$	—


	Gas Hedges (basis differential)
	2022	2023	2024

Waha basis swaps:
Hedged volume (MMBtu)	505,024	1,339,685		—
Weighted average swap price	(2)	(3)	$	—


	Fair Value Measurement Classification
	Quoted prices
	in Active
	Markets
	for Identical		Significant
	Assets		Other		Significant
	or		Observable		Unobservable
	(Liabilities)		Inputs		Inputs
	(Level 1)		(Level 2)		(Level 3)		Total
As of December 31, 2021
Commodity Derivatives - Liabilities	$	—	$	(29,241,588)	$	—	$	(29,241,588)
Total	$	—	$	(29,241,588)	$	—	$	(29,241,588)


Balance, December 31, 2021	$	15,292,054
Liabilities incurred		218,082
Liabilities acquired		14,538,550
Liabilities sold		—
Revision of previous estimates		—
Liabilities settled		(1,239,634)
Accretion expense		617,685
Balance, September 30, 2022	$	29,426,737


				Weighted-
		Weighted-		Average
		Average		Remaining	Aggregate
		Exercise		Contractual	Intrinsic
	Shares	Price		Term	Value
Outstanding, December 31, 2020	465,500	$	3.26
Granted	—		—
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, March 31, 2021	465,500	$	3.26	3.00 Years	$	134,850
Granted	—		—
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, June 30, 2021	465,500	$	3.26	2.75 Years	$	426,300
Granted	—		—
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, September 30, 2021	465,500	$	3.26	2.61 Years	$	375,250
Exercisable, September 30, 2021	458,300	$	3.13	2.57 Years

Outstanding, December 31, 2021	365,500	$	3.61
Granted	—		—
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, March 31, 2022	365,500	$	3.61	2.21 Years	$	536,900
Granted	—		—
Forfeited or rescinded	—		—
Exercised	(100,000)	$	2.00
Outstanding, June 30, 2022	265,500		4.21	2.14 Years	$	128,700
Granted	—		—
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, September 30, 2022	265,500	$	4.21	1.89 Years	$	62,400
Exercisable, September 30, 2022	265,500	$	4.21	1.89 Years


		Weighted-
		Average Grant
	Restricted stock	Date Fair Value
Outstanding, December 31, 2020	2,132,297	$	1.03
Granted	—		—
Forfeited or rescinded	—		—
Vested	(94,350)		4.95
Outstanding, March 31, 2021	2,037,947	$	0.85
Granted	1,196,102		2.77
Forfeited or rescinded	—		—
Vested	(3,480)		5.96
Outstanding, June 30, 2021	3,230,569	$	1.55
Granted	29,554		2.69
Forfeited or rescinded	—		—
Vested	(12,500)		2.15
Outstanding, September 30, 2021	3,247,623	$	1.56

Outstanding, December 31, 2021	2,572,596	$	1.75
Granted	1,247,061		2.79
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, March 31, 2022	3,819,657	$	2.09
Granted	19,642		4.27
Forfeited or rescinded	(17,204)		2.79
Vested	(610,195)		2.80
Outstanding, June 30, 2022	3,211,900	$	1.97
Granted	126,570		2.95
Forfeited or rescinded	—		—
Vested	(9,851)		2.69
Outstanding, September 30, 2022	3,328,619	$	2.00


		Weighted-
	Performance	Average Grant
	Stock Units	Date Fair Value
Outstanding, December 31, 2020	—	$	—
Granted	—		—
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, March 31, 2021	—	$	—
Granted	—		—
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, June 30, 2021	—	$	—
Granted	—		—
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, September 30, 2021	—	$	—

Outstanding, December 31, 2021	860,216	$	3.87
Granted	860,216		3.65
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, March 31, 2022	1,720,432	$	3.76
Granted	—		—
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, June 30, 2022	1,720,432	$	3.76
Granted	—		—
Forfeited or rescinded	—		—
Vested	—		—
Outstanding, September 30, 2022	1,720,432	$	3.76


				Wells Began
		Wells	Wells	Completion
Quarter	Area	Drilled	Completed	Process	CTRs	Recompletions

1Q 2022	Central Basin Platform	4	4	—	—	—
	Delaware Basin	—	—	—	—	—
	Northwest Shelf	2	—	—	4	—

2Q 2022	Central Basin Platform	—	—	—	1	—
	Delaware Basin	—	—	—	—	—
	Northwest Shelf	9	7	4	3	—

3Q 2022	Central Basin Platform	3	3	—	1	3
	Delaware Basin	—	—	—	—	—
	Northwest Shelf	5	6	3	5	—