Ring Energy (REI) 10-Q 2021 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended: September 30, 2021

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

Commission File Number: 001-36057

RING ENERGY, INC.

(Exact Name of registrant as specified in its charter)

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

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

(281) 397-3699

(Registrant’s telephone number, including area code)

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

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

☒ Yes ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

☒ Yes ☐ No

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

Large accelerated filer ☐	Accelerated filer ☒
Non-accelerated filer ☐	Smaller reporting company ☒
Emerging growth company ☐

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

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

☐ Yes ☒ No

The registrant has one class of common stock of which 99,640,162 shares were outstanding at November 9, 2021.

INDEX

Ring Energy, Inc.

For the Quarter Ended September 30, 2021

PART I – FINANCIAL INFORMATION	5
Item 1.  Financial Statements.	5
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 3. Quantitative and Qualitative Disclosures About Market Risk	35
Item 4. Controls and Procedures	36
PART II – OTHER INFORMATION	38
Item 1. Legal Proceedings	38
Item 1A. Risk Factors	38
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	38
Item 3. Defaults Upon Senior Securities	38
Item 4. Mine Safety Disclosure	38
Item 5. Other Information	38
Item 6. Exhibits	39
SIGNATURES	40

2

Forward-Looking Statements

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). The statements contained in this report that are not historical facts are forward-looking statements that represent management’s beliefs and assumptions based on currently available information. Forward-looking statements include information concerning our possible or assumed future results of operations, business strategies, need for financing, competitive position and potential growth opportunities. Our forward-looking statements do not consider the effects 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. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we cannot give any assurances that these expectations will prove to be correct. Such statements by their 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 factors that could cause actual future results to differ materially are the risks and uncertainties discussed in this report and in our annual report on Form 10-K for the year ended December 31, 2020. While it is not possible to identify all factors, we continue to face many risks and uncertainties including, but not limited to:

● 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;

● risks and liabilities associated with acquired companies and properties;

● risks related to integration of acquired companies and properties;

● 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;

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

3

● 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 and other areas of the world;

● economic and competitive conditions;

● lack of available insurance;

● cash flow and anticipated liquidity;

● continuing compliance with the financial covenant contained in our amended and restated credit agreement;

● 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, 2020.

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 we are unable to predict at this time or that we do not now expect to have a material adverse impact on our business.

Forward-looking statements speak only as to the date hereof. All such forward-looking statements and any subsequent written or oral forward-looking statements attributable to us or any person acting on our behalf 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 statements whether as a result of new information, future events or otherwise.

4

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

The unaudited condensed financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain disclosures required by accounting principles generally accepted in the United States 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 financial statements should be read in conjunction with the Company’s audited financial statements and related footnotes included in its most recent Annual Report on Form 10-K.

5

RING ENERGY, INC.

CONDENSED BALANCE SHEETS

(Unaudited)

		September 30,		December 31,
	2021		2020
ASSETS
Current Assets
Cash and cash equivalents	$	2,046,946	$	3,578,634
Accounts receivable		20,306,264		14,997,979
Joint interest billing receivable		1,672,334		1,327,262
Derivative receivable		0		499,906
Prepaid expenses and retainers		1,298,801		396,109
Total Current Assets		25,324,345		20,799,890
Properties and Equipment
Oil and natural gas properties, full cost method		872,258,987		836,514,815
Financing lease asset subject to depreciation		1,422,487		858,513
Fixed assets subject to depreciation		2,130,523		1,520,890
Total Properties and Equipment		875,811,997		838,894,218
Accumulated depreciation, depletion and amortization		(225,744,692)		(200,111,658)
Net Properties and Equipment		650,067,305		638,782,560
Operating lease asset		1,344,378		1,494,399
Deferred financing costs		1,882,815		2,379,348
Total Assets	$	678,618,843	$	663,456,197
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts payable	$	45,259,500	$	32,500,081
Financing lease liability		385,866		295,311
Operating lease liability		268,512		859,017
Derivative liabilities		38,402,944		3,287,328
Notes Payable		857,151		—
Total Current Liabilities		85,173,973		36,941,737
Noncurrent Liabilities
Deferred income taxes		141,943		—
Revolving line of credit		295,000,000		313,000,000
Financing lease liability, less current portion		393,340		126,857
Operating lease liability, less current portion		1,212,239		635,382
Derivative liabilities		6,061,724		869,273
Asset retirement obligations		14,998,130		17,117,135
Total Liabilities		402,981,349		368,690,384
Stockholders' Equity
Preferred stock - $0.001 par value; 50,000,000 shares authorized; 0 shares issued or outstanding		—		—
Common stock - $0.001 par value; 150,000,000 shares authorized; 99,359,938 shares and 85,568,287 shares issued and outstanding, respectively		99,360		85,568
Additional paid-in capital		552,598,622		550,951,415
Accumulated deficit		(277,060,488)		(256,271,170)
Total Stockholders’ Equity		275,637,494		294,765,813
Total Liabilities and Stockholders' Equity	$	678,618,843	$	663,456,197

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

6

RING ENERGY, INC.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

	For the Three Months Ended				For the Nine Months Ended
	September 30,				September 30,
	2021		2020		2021		2020
Oil and Natural Gas Revenues	$	49,376,176	$	31,466,544	$	136,638,810	$	81,673,465
Costs and Operating Expenses
Lease operating expenses		6,983,196		7,819,639		22,634,259		21,887,356
Gathering, transportation and processing costs		1,051,163		1,058,372		2,883,348		2,833,957
Ad valorem taxes		703,774		800,000		2,144,800		2,407,455
Oil and natural gas production taxes		2,240,759		1,427,041		6,291,860		3,731,046
Depreciation, depletion and amortization		9,310,524		10,826,989		26,693,808		31,848,093
Ceiling test impairment		—		—		—		147,937,943
Asset retirement obligation accretion		182,905		230,784		560,662		694,113
Operating lease expense		83,589		295,631		439,896		876,889
General and administrative expense		4,433,251		2,496,927		11,103,394		9,709,431
Total Costs and Operating Expenses		24,989,161		24,955,383		72,752,027		221,926,283
Income (Loss) from Operations		24,387,015		6,511,161		63,886,783		(140,252,818)
Other Income (Expense)
Interest income		0		1		1		7
Interest (expense)		(3,551,462)		(4,457,250)		(10,947,960)		(12,958,788)
Gain (loss) on derivative contracts		(6,720,320)		(4,502,080)		(73,586,199)		32,900,767
Net Other Income (Expense)		(10,271,782)		(8,959,329)		(84,534,158)		19,941,986
Income (Loss) Before Provision for Income Taxes		14,115,233		(2,448,168)		(20,647,375)		(120,310,832)
Benefit from (Provision for) Income Taxes		48,701		486,565		(141,943)		27,153,281
Net Income (Loss)	$	14,163,934	$	(1,961,603)	$	(20,789,318)	$	(93,157,551)
Basic Earnings (Loss) per share	$	0.14	$	(0.03)	$	(0.21)	$	(1.37)
Diluted Earnings (Loss) per share	$	0.12	$	(0.03)	$	(0.21)	$	(1.37)

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

7

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, 2021	Shares	Amount		Capital		Deficit)		Equity
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	0		0		(65,000)		0		(65,000)
Exercise of pre-funded warrants issued in offering	13,428,500		13,429		0		0		13,429
Exercise of common warrants issued in offering	184,800		185		147,655		0		147,840
Restricted stock vested	94,350		94		(94)		0		0
Share-based compensation	0		0		355,494		0		355,494
Net income (loss)	0		0		0		(19,066,093)		(19,066,093)
Balance, March 31, 2021	99,275,937	$	99,276	$	551,389,470	$	(275,337,263)	$	276,151,483
Common stock and warrants issued for cash, net	0		0		0		0		0
Exercise of pre-funded warrants issued in offering	0		0		0		0		0
Exercise of common warrants issued in offering	100,000		100		79,900		0		80,000
Restricted stock vested	3,480		3		(3)		0		0
Shares to cover tax withholdings	(28,272)		(28)		28		0		0
Share-based compensation	0		0		351,775		0		351,775
Net income (loss)	0		0		0		(15,887,159)		(15,887,159)
Balance, June 30, 2021	99,351,145	$	99,351	$	551,821,170	$	(291,224,422)	$	260,696,099
Common stock and warrants issued for cash, net	0		0		0		0		0
Exercise of pre-funded warrants issued in offering	0		0		0		0		0
Exercise of common warrants issued in offering	0		0		0		0		0
Restricted stock vested	12,500		13		(13)		0		0
Shares to cover tax withholdings	(3,707)		(4)		4		0		0
Share-based compensation	0		0		777,461		0		777,461
Net income (loss)	0		0		0		14,163,934		14,163,934
Balance, September 30, 2021	99,359,938	$	99,360	$	552,598,622	$	(277,060,488)	$	275,637,494
For the Nine Months Ended September 30, 2020
Balance, December 31, 2019	67,993,797	$	67,994	$	526,301,281	$	(2,859,342)	$	523,509,933
Common stock and warrants issued for cash, net	0		0		0		0		0
Exercise of pre-funded warrants issued in offering	0		0		0		0		0
Exercise of common warrants issued in offering	0		0		0		0		0
Restricted stock vested	0		0		0		0		0
Share-based compensation	0		0		673,795		0		673,795
Net income (loss)	0		0		0		43,804,118		43,804,118
Balance, March 31, 2020	67,993,797	$	67,994	$	526,975,076	$	40,944,776	$	567,987,846
Common stock and warrants issued for cash, net	0		0		0		0		0
Exercise of pre-funded warrants issued in offering	0		0		0		0		0
Exercise of common warrants issued in offering	0		0		0		0		0
Return of common stock issued as consideration in asset acquisition	(16,702)		(17)		(103,368)		0		(103,385)
Restricted stock vested	3,480		4		(4)		0		0
Share-based compensation	0		0		1,317,542		0		1,317,542
Net income (loss)	0		0		0		(135,000,066)		(135,000,066)
Balance, June 30, 2020	67,980,575	$	67,981	$	528,189,246	$	(94,055,290)	$	434,201,937
Common stock and warrants issued for cash, net	0		0		0		0		0
Exercise of pre-funded warrants issued in offering	0		0		0		0		0
Exercise of common warrants issued in offering	0		0		0		0		0
Restricted stock vested	2,500		2		(2)		0		0
Shares to cover tax withholdings	0		0		0		0		0
Share-based compensation	0		0		565,819		0		565,819
Net income (loss)	0		0		0		(1,961,603)		(1,961,603)
Balance, September 30, 2020	67,983,075	$	67,983	$	528,755,063	$	(96,016,893)	$	432,806,153

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

8

RING ENERGY, INC.

STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Nine Months Ended September 30,
		2021	2020
Cash Flows From Operating Activities
Net income (loss)	$	(20,789,318)	$	(93,157,551)
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization		26,693,808		31,848,093
Ceiling test impairment		0		147,937,943
Accretion expense		560,662		694,113
Amortization of deferred financing costs		496,533		567,248
Share-based compensation		1,484,730		2,557,156
Deferred income tax expense (benefit)		141,943		(25,573,920)
Excess tax expense (benefit) related to share-based compensation		0		(1,579,361)
(Gain) loss on derivative contracts		73,586,199		(32,900,767)
Cash received (paid) for derivative settlements, net		(33,278,132)		18,814,068
Changes in assets and liabilities:
Accounts receivable		(5,017,078)		9,867,026
Prepaid expenses and retainers		(902,692)		3,483,645
Accounts payable		8,329,563		(17,225,782)
Settlement of asset retirement obligation		(1,782,779)		(428,605)
Net Cash Provided by (Used In) Operating Activities		49,523,439		44,903,306
Cash Flows From Investing Activities
Payments to purchase oil and natural gas properties		(579,156)		(1,189,433)
Payments to develop oil and natural gas properties		(34,680,935)		(33,586,337)
Payments to acquire or improve fixed assets		(609,633)		0
Proceeds from divestiture of oil and natural gas properties		2,000,000		4,500,000
Net Cash Provided by (Used in) Investing Activities		(33,869,724)		(30,275,770)
Cash Flows From Financing Activities
Proceeds from revolving line of credit		34,400,000		21,500,000
Payments on revolving line of credit		(52,400,000)		(28,000,000)
Proceeds from issuance of common stock and warrants		241,269		0
Proceeds from notes payable		1,233,138		0
Payments on notes payable		(375,987)		0
Payment of deferred financing costs		(76,887)		0
Reduction of financing lease liabilities		(206,936)		(211,341)
Net Cash Provided by (Used in) Financing Activities		(17,185,403)		(6,711,341)
Net Change in Cash		(1,531,688)		7,916,195
Cash at Beginning of Period		3,578,634		10,004,622
Cash at End of Period	$	2,046,946	$	17,920,817
Supplemental Cash Flow Information
Cash paid for interest	$	10,622,077	$	12,387,670
Noncash Investing and Financing Activities
Asset retirement obligation incurred during development	$	160,285	$	66,387
Asset retirement obligation acquired	$	662,704	$	0
Asset retirement obligation revisions	$	153,475	$	0
Asset retirement obligation sold	$	(2,934,126)	$	0
Capitalized expenditures attributable to drilling projects financed through current liabilities	$	5,921,816	$	2,600,000
Operating lease assets obtained in exchange for new operating lease liability	$	839,536	$	0
Operating lease asset revision	$	(621,636)	$	0

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

9

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE 1 – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Condensed Financial Statements – The accompanying condensed financial statements prepared by Ring Energy, Inc. (the “Company” or “Ring”) have not been audited by an independent registered public accounting firm. In the opinion of the Company’s management, the accompanying 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 results of operations for the nine months ended September 30, 2021, are not necessarily indicative of the results to be expected for the full year ending December 31, 2021, 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 required by GAAP for complete financial statements. Therefore, these financial statements should be read in conjunction with the financial statement and notes included in the Company’s annual report on Form 10-K for the year ended December 31, 2020.

Reclassifications – Certain prior period amounts relating to components of operating expense have been reclassified to conform to current year presentation within “Costs and Operating Expenses” in the Statements of Operations. Additionally, certain prior amounts associated with realized and unrealized gains (losses) have been reclassified within the Statements of Operations and Statements of Cash Flows to conform with current year presentation.

Organization and Nature of Operations – The Company is a Nevada corporation that owns interests in oil and natural gas properties located in Texas and New Mexico. The Company’s oil and natural gas sales, profitability and future growth are dependent upon prevailing and future prices for oil and natural gas and the successful acquisition, exploration and development 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 has been marked by significant slowdown and uncertainty, which in turn has 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 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 earlier this year 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 continued spread of COVID-19, including-vaccine resistant strains such as the Delta variant, or repeated 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.

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, 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 to protect, to some extent, its cash flows from such price declines; however, if oil or natural gas prices rapidly deteriorate due to a resurgence of COVID-19 or other reasons, this could have a material adverse effect on the Company's cash flows.

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

10

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

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

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 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 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.

Derivative Instruments and Commodity Risk Activities – The Company may periodically enter into derivative contracts to manage its exposure to commodity 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 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 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 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 $8,200,688 for the three months ended September 30, 2021 and an unrealized loss of $40,308,067 for the nine months ended September 30, 2021. During the three and nine months ended September 30, 2020, the change in fair value resulted in the recognition of unrealized loss of $6,228,453 and unrealized gain of $14,086,699, respectively, on derivative contracts. 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 including $581,424 from unwinding the Company’s remaining gas swaps for 2021 and 2022. During the three and nine months ended September 30, 2020, the Company had realized gains of $1,726,373 and $ 18,814,068, respectively, on derivatives.

Concentration of Credit Risk and Major Customers – The Company had $1,546,946 of cash on deposit in excess of federally insured limits at September 30, 2021 and $3,328,634 of cash in excess of federally insured limits at December 31, 2020. During the nine months ended September 30, 2021, sales to three customers represented 78%, 6% and 6%, respectively, of the Company’s oil and gas revenues. At September 30, 2021, these three customers made up 79%, 5% and 3%, respectively, of the Company’s accounts receivable.

11

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

Approximately 92% of the Company’s accounts receivables and joint interest billing receivables are from purchasers of oil and gas. Oil and gas sales are generally unsecured. The Company also has joint interest billing receivables which are collateralized by the pro rata revenue attributable to the joint interest holders and further by the interest itself. The Company has not had any significant credit losses in the past and believes its accounts and joint interest billing receivables are collectable. Accordingly, no material allowance for credit losses has been provided at September 30, 2021.

Oil and Gas Properties – The Company uses the full cost method of accounting for oil and gas properties. Under this method, all costs associated with the acquisition, leasing, exploration and development of oil and gas reserves 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 and drilling 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 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 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, 2021. During the three months ended June 30, 2020, the Company incurred write downs of oil and natural gas properties as a result of ceiling test impairments in the amount of $147,937,943. Depreciation, depletion and amortization expense for the three and nine months ended September 30, 2021 was $9,310,524 and $26,693,808, respectively, based on depletion at the rate of $12.12 and $11.64, respectively, per barrel of oil equivalent compared to $10,826,989 and $31,848,093, respectively, based on depletion at the rate of $12.22 and $13.37 for the three and nine months ended September 30, 2020. These amounts include $120,817 and $276,677, respectively, of depreciation for the three and nine months ended September 30, 2021, compared to $88,928 and $289,106, respectively, of depreciation for the three and nine months ended September 30, 2020.

Equipment, vehicles and leasehold improvements – Office equipment is 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.

Share-Based Employee Compensation – The Company has outstanding stock option grants and restricted stock awards to directors, officers and employees, which are described more fully in Note 11. 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 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 current year and deferred taxes. Deferred taxes are based on differences between the tax bases 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.

12

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

The CARES Act was enacted on March 27, 2020, and includes income tax provisions that, among other things, allow net operating losses to be carried back, permits interest expense to be deducted up to a higher percentage of adjusted taxable income and modifies tax depreciation of qualified improvement property. Due to the Company having taxable losses in all years eligible for the NOL carryback, no benefit was recorded, and these provisions have no material impact on the Company.

For the period ended September 30, 2021, the Company recorded 0 federal income tax expense or benefit due to the Company having a full valuation allowance against its net federal deferred tax assets. 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. The Company reviews its Deferred Tax Assets (“DTAs”) and valuation allowance on a quarterly basis. The Company anticipates that it will continue to record a valuation allowance against its federal DTAs until such time it is able to determine it is more likely than not that its DTAs will be realized. During the year 2021, the Company expects to be in a net deferred tax liability position for Texas and recorded state deferred income tax expense of $141,943 for the period ending September 30, 2021. The Company has immaterial operations in certain other states which are in a net deferred tax asset position for which a full valuation allowance is still recorded.

New and Recently Adopted Accounting Pronouncements – In August 2018, the FASB issued Accounting Standards Updated (“ASU”) 2018-13, Fair Value Measurement (Topic 820): Changes to the Disclosure Requirements for Fair Value Measurement (“ASU 2018-13”). ASU 2018-13 eliminates, adds and modifies certain disclosure requirements for fair value measurement. ASU 2018-13 is effective for annual and interim periods beginning January 1, 2020, with early adoption permitted for either the entire standard or only the provisions that eliminate or modify requirements. ASU 2018-13 requires that the additional disclosure requirements be adopted using a retrospective approach. The adoption of this guidance did not have a material impact on the Company’s financial statements.

Effective January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842). The purpose of this guidance is to increase transparency and comparability among organizations by recognizing certain lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. See Note 3 for a discussion of the impact on the Company’s financial statements.

In December 2019, the FASB released 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, the FASB issued ASU 2020-10, Codification Improvements, which clarifies or improves disclosure requirements for various topics to align with SEC regulations. This update is effective for the Company beginning in the first quarter of 2021 and will be applied retrospectively. The adoption and implementation of this ASU did not have a material impact on the Company’s financial statements.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (“ASU 2020-04”), which provides optional expedients and exceptions for applying GAAP to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another rate that is expected to be discontinued. ASU 2020-04 will be in effect through December 31, 2022.  In January 2021, 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 Company is currently assessing the impact of adopting this new guidance.

Basic and Diluted Earnings per Share – Basic earnings per share is computed by dividing net income by the weighted-average number 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.

13

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE 2 – REVENUE RECOGNITION

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 customer. Revenue is recorded in the month the product is delivered to the purchaser and the Company receives payment from one to three months after delivery. The Company has utilized the practical expedient in ASC (Accounting Standards Codification) 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 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 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 sales

Under the Company’s natural gas sales processing contracts for its Central Basin Platform properties, Delaware Basin properties and part 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 at the wellhead. The midstream processing entity gathers and processes the natural gas and remits proceeds to the Company for the resulting sale of natural gas. Under these processing agreements, the Company recognizes revenue 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. As such, the Company accounts for any fees and deductions as a reduction of the transaction price.

Under the Company’s natural gas sales processing contracts for the bulk of its Northwest Shelf assets, the Company delivers unprocessed natural gas to a midstream processing entity at the well head. However, the Company maintains ownership of the gas through processing and receives proceeds from the marketing of the resulting products. Under this processing agreement, the Company recognizes the fees associated with the processing as an expense rather than netting these costs against Oil and Natural Gas Revenues in the Statements of Operations.

Disaggregation of Revenue. The following table presents revenues disaggregated by product for the three and nine months ended September 30, 2021 and 2020:

	For The Three Months				For The Nine Months
	Ended September 30,				Ended September 30,
	2021		2020		2021		2020
Operating Revenues
Oil	$	45,889,548	$	30,327,668	$	126,927,318	$	79,379,242
Natural gas		3,486,628		1,138,876		9,711,492		2,294,223
Total operating revenues	$	49,376,176	$	31,466,544	$	136,638,810	$	81,673,465

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

14

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE 3 – LEASES

Effective January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842). The purpose of this guidance is to increase transparency and comparability among organizations by recognizing certain lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The main difference between previous GAAP methodology and the method under this new guidance is the recognition on the balance sheet of certain lease assets and lease liabilities by lessees for those leases that were classified as operating leases under previous GAAP.

The Company made accounting policy elections to not capitalize leases with a lease term of twelve months or less and to not separate lease and non-lease components for all asset classes. The Company has 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.

The Company has operating leases for its offices in The Woodlands, Texas and Midland, Texas. The month-to-month Tulsa, Oklahoma lease was terminated as of March 31, 2021. The office space that was previously leased in Tulsa is owned by Arenaco, LLC, a company that is owned by Mr. Rochford, former Chairman of the Board of the Company, and Mr. McCabe, a former Director of the Company.

The Company also has month to month leases for office equipment and compressors used in its operations on which the Company had previously elected to apply ASU 2016-02. The office equipment and compressors are not subject to ASU 2016-02 based on the agreement and nature of use. The costs are recorded as short-term lease costs and amounts included in Oil and gas production costs.

The Company also has month to month leases or other short-term leases for equipment used in its operations on which the Company has made accounting policy elections not to capitalize these leases. 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 are reflected in the short-term lease costs 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 new vehicles.

Future lease payments associated with these operating and financing leases as of September 30, 2021 are as follows:

	2021		2022		2023		2024		2025
Operating lease payments (1)	$	68,132	$	349,127	$	356,991	$	376,855	$	384,719
Financing lease payments (2)		126,889		336,206		215,530		142,354		—

(1) The weighted average discount rate as of September 30, 2021 for operating leases was 4.5%. Based on this rate, the future lease payments above include imputed interest of $165,167.

(2) The weighted average discount rate as of September 30, 2021 for financing leases was 4.3%. Based on this rate, the future lease payments above include imputed interest of $39,771.

15

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

The following table provides supplemental information regarding cash flows from operations for the nine months ended:

	Three months ended				Nine months ended
	September 30,				September 30,
	2021		2020		2021		2020
Operating lease costs	$	83,589	$	295,631	$	439,896	$	876,889
Short term lease costs (1)		964,873		1,205,407		2,903,387		3,347,484
Financing lease costs:
Amortization of financing lease assets (2)		85,367		71,854		189,831		215,560
Interest on lease liabilities (3)		5,160		7,172		14,166		24,022

(1) Amount included in Oil and gas production costs

(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,
	2021		2020		2021		2020
Net Income (Loss)	$	14,163,934	$	(1,961,603)	$	(20,789,318)	$	(93,157,551)
Basic Weighted-Average Shares Outstanding		99,358,504		67,980,961		99,251,532		67,985,168
Effect of dilutive securities:
Stock options		135,536		—		—		—
Restricted stock		1,463,690		—		—		—
Common warrants		20,263,018		—		—		—
Diluted Weighted-Average Shares Outstanding		121,220,748		67,980,961		99,251,532		67,985,168
Basic Earnings (Loss) per Share	$	0.14	$	(0.03)	$	(0.21)	$	(1.37)
Diluted Earnings (Loss) per Share	$	0.12	$	(0.03)	$	(0.21)	$	(1.37)

Stock options to purchase 70,500 share of common stock and 14,709 share of unvested restricted stock were excluded from the computation of diluted earnings per share during the three months ended September 30, 2021. Stock options to purchase 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 during the nine months ended September 30, 2021, as their effect would have been anti-dilutive. Stock options to purchase 483,500 shares of common stock and 1,326,709 shares of unvested restricted stock were excluded from the computation of diluted earnings per share during both the three and nine months ended September 30, 2020, as their effect would have been anti-dilutive.

NOTE 5 – ACQUISITIONS & DIVESTITURES

The Company entered into a Purchase, Sale and Exchange Agreement dated February 1, 2021, effective January 1, 2021, with an unrelated party, covering the sale and exchange of certain oil and gas interests in Andrews County, Texas. Upon the sale and transfer of wells and leases between the two parties, the Company received a net value consideration in cash of $2,000,000 and reduced the Company’s asset retirement obligations by $2,934,126 for the properties sold and added $662,705 of asset retirement obligations for the wells acquired.

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 future domestic oil and natural gas production. While the use of derivative instruments may limit or partially reduce

16

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

the downside risk of adverse commodity price movements, the use also may limit future income from favorable commodity price movements.

The Company’s derivative financial instruments are recorded at fair value and included as either assets or liabilities in the accompanying 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 derivative financial instruments are recognized in earnings and included as a component of “Other income (expense)” under the heading “Gain (loss) on derivative contracts” in the accompanying 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, 2021, 100% of the Company’s volumes subject to derivative instruments are with lenders under its Credit Facility (as defined in Note 8). The Company is not subject to master netting agreements and classifies the fair value of its derivative positions on a gross basis in its corresponding balance sheets. The following presents the impact of the Company’s contracts on its balance sheets for the periods indicated.

	As of
	September 30, 2021		December 31, 2020
Liabilities
Commodity derivative instruments	$	(38,402,944)	$	(3,287,328)
Derivative liabilities, current	$	(38,402,944)	$	(3,287,328)
Commodity derivative instruments	$	(6,061,724)	$	(869,273)
Derivative liabilities, non-current	$	(6,061,724)	$	(869,273)

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

	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021			2020
Gain (loss) on oil derivative	$	(6,720,320)	$	(4,502,080)	$	(73,387,510)	$	32,900,767
Gain (loss) on natural gas derivatives		—		—		(198,689)		—
Gain (loss) on derivative contracts	$	(6,720,320)	$	(4,502,080)	$	(73,586,199)	$	32,900,767

The components of “Cash (paid) received for commodity derivative settlements” are as follows for the respective periods:

	Three months ended September 30,				Nine months ended September 30,
	2021		2020		2021		2020
Cash flows from operating activites
Cash (paid) received on oil derivatives	$	(14,921,008)	$	1,726,373	$	(34,030,310)	$	18,814,068
Cash (paid) received on natural gas derivatives		—		—		743,178		—
Cash (paid) received from derivative settlements	$	(14,921,008)	$	1,726,373	$	(33,287,132)	$	18,814,068

17

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

Throughout 2020 and the first half of 2021, the Company entered into additional derivative contracts in the form of costless collars, puts and swaps for 2021 and 2022 calendar period for both oil and natural gas. The following tables reflect the details of current contracts as of September 30, 2021:

Date entered into	Period covered	Barrels per day		Put price		Call price		Swap price
Oil derivative contracts
2021 costless collars
2/25/2020	Calendar year 2021	1,000		$	45.00	$	54.75
2/25/2020	Calendar year 2021	1,000			45.00		52.71
2/27/2020	Calendar year 2021	1,000			40.00		55.08
2021 put
3/2/2020	Calendar year 2021	1,500			40.00
2021 swaps
11/25/2020	Calendar year 2021	2,000						$	45.37
12/2/2020	Calendar year 2021	500							45.38
12/3/2020	Calendar year 2021	500							45.00
12/4/2020	Calendar year 2021	500							45.40
12/4/2020	Calendar year 2021	500							45.60
12/7/2020	Calendar year 2021	500							45.96
2022 swaps
12/4/2020	Calendar year 2022	500							44.22
12/7/2020	Calendar year 2022	500							44.75
12/10/2020	Calendar year 2022	500							44.97
12/17/2020	Calendar year 2022	250							45.98
1/4/2021	Calendar year 2022	250							47.00
2/4/2021	Calendar year 2022	250							50.05
5/11/2021	Calendar year 2022	879	(1)						49.03

(1) The notional quantity per the swap contract entered into on May 11, 2021 is for 26,750 barrels of oil per month. The 879 represents the daily amount on an annual basis.

18

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

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. 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).

Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. 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. We continue to evaluate our inputs to ensure the fair value level classification is appropriate. When transfers between levels occur, it is 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 payable, and revenue royalties. The carrying amount of these instruments approximates fair value because of their short-term nature. The Company’s long-term debt obligation bears interest at floating market rates, therefore 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, including oil and gas properties, goodwill, business combinations and asset retirement obligations. These assets and liabilities are not measured at fair value on an ongoing basis but are subject to fair value adjustments if events or changes in certain circumstances indicate that adjustments may be necessary.

The Company assessed the fair values of its oil and natural gas properties and goodwill due to significant declines in commodity prices and global demand for oil and natural gas products resulting from the COVID-19 pandemic, resulting in non-cash impairment charges during the nine months ended September 30, 2020,. No such triggering events that require further assessment were observed during the nine months ended September 30, 2021.

19

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

The following table summarizes the valuation of our assets and liabilities that are measured at fair value on a recurring basis.

	Fair Value Measurement Classification
	Quoted prices in
	Active Markets for		Significant Other		Significant
	Identical Assets or		Observable		Unobservable		Total
	(Liabilities) (Level 1)		Inputs (Level 2)		Inputs (Level 3)
As of December 31, 2020
Commodity Derivatives - Liabilities	$	0	$	(4,156,601)	$	0	$	(4,156,601)
Total	$	0	$	(4,156,601)	$	0	$	(4,156,601)

	Fair Value Measurement Classification
	Quoted prices in
	Active Markets for		Significant Other		Significant
	Identical Assets or		Observable		Unobservable		Total
	(Liabilities) (Level 1)		Inputs (Level 2)		Inputs (Level 3)
As of September 30, 2021
Commodity Derivatives - Liabilities	$	0	$	(44,464,668)	$	0	$	(44,464,668)
Total	$	0	$	(44,464,668)	$	0	$	(44,464,668)

NOTE 8 – REVOLVING LINE OF CREDIT

In April 2019, the Company amended and restated its 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 fifth amendment on June 25, 2021 incorporates 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 Credit Facility allows for Eurodollar Loans and Base Rate Loans (as respectively defined in the Credit Facility). The interest rate on each Eurodollar Loan will be the adjusted LIBOR for the applicable interest period plus a margin between 2.5% and 3.5% (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 LIBOR 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 1.5% and 2.5% (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) of not more than 4.0 to 1.0 and (ii) a minimum ratio of Current Assets to Current Liabilities (as such terms are defined in the Credit Facility) 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, 2021, $295,000,000 was outstanding on the Credit Facility. The Company is in compliance with all covenants contained in the Credit Facility as of September 30, 2021.

20

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

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 were as follows:

Balance, December 31, 2020	$	17,117,135
Liabilities incurred		160,285
Liabilities acquired		662,704
Liabilities sold		(2,934,126)
Revision of previous estimates		153,475
Liabilities settled		(722,005)
Accretion expense		560,662
Balance, September 30, 2021	$	14,998,130

NOTE 10 – STOCKHOLDERS’ EQUITY

During the nine months ended September 30, 2021, the remaining 13,428,500 pre-funded warrants and 284,800 of common warrants were exercised. Gross proceeds from these transactions were $241,269. At September 30, 2021, there remains 29,519,500 unexercised common warrants.

NOTE 11 – EMPLOYEE STOCK OPTIONS AND RESTRICTED STOCK AWARD PLAN

Compensation expense charged against income for share-based awards during the three and nine months ended September 30, 2021, was $777,461 and $1,484,730, respectively as compared to $565,819 and $2,557,156 for the three months and nine months ended September 30, 2020. These amounts are included in general and administrative expense in the accompanying financial statements.

In 2011, the Company’s board of directors and stockholders approved and adopted a long-term incentive plan which allowed for 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.

In June 2020, officers and directors of the Company voluntarily returned stock options that had previously been granted to them. In total, 2,265,000 options with an average exercise price of $6.87 per share were returned to and cancelled by the Company. NaN grants, cash payments or other consideration has been or will be made to replace the options or otherwise in connection with the return. As a result of the return and cancellation of the options, the Company recognized additional compensation expense of $768,379.

In May 2021, the Company’s board of directors and stockholders approved and adopted a long-term incentive plan which allowed for the issuance of up to 9,900,000 shares, including 341,155 shares that are reserved but unissued under the prior plan, of common stock subject to the grant of qualified stock options, non-qualified stock options and restricted stock.

21

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

Stock Options

A summary of the stock option activity as of September 30, 2020 and 2021, respectively, and changes during the three and nine months then ended is as follows:

				Weighted-
		Weighted-		Average
		Average		Remaining	Aggregate
		Exercise		Contractual	Intrinsic
	Shares	Price		Term	Value
Outstanding, December 31 2019	2,748,500	$	6.28
Granted	0		0
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, March 31, 2020	2,748,500	$	6.28	3.7 Years	$	—
Granted	—		—
Forfeited or rescinded	(2,265,000)		6.87
Exercised	0		0
Outstanding, June 30, 2020	483,500	$	3.52	2.2 Years	$	—
Granted	—		—
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, September 30, 2020	483,500	$	3.52	1.9 Years	$	0
Exercisable, September 30, 2020	460,700	$	3.15	1.7 Years
Outstanding, December 31 2020	465,500	$	3.26		$
Granted	0		0
Forfeited or rescinded	—		—
Exercised	—		—
Outstanding, March 31, 2021	465,500	$	3.26	3.00 Years	$	134,850
Granted	—		—
Forfeited or rescinded	—		—
Exercised	0		0
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

The intrinsic values were calculated using the closing price on September 30, 2021 of $2.95 and the closing price on September 30, 2020 of $0.68. As of September 30, 2021, there was $1,986 of unrecognized compensation cost related to stock options that is expected be recognized over a weighted-average period of 0.2 years.

22

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

Restricted Stock

A summary of the restricted stock activity as of September 30, 2021 and 2020, and changes during the nine months then ended is as follows:

		Weighted-
		Average Grant
	Restricted stock	Date Fair Value
Outstanding, December 31, 2019	1,341,889	$	4.94
Granted	0		0
Forfeited or rescinded	(2,400)		4.78
Vested	0		0
Outstanding, March 31, 2020	1,339,489	$	4.93
Granted	0		0
Forfeited or rescinded	(6,800)		3.68
Vested	(3,480)		5.96
Outstanding, June 30, 2020	1,329,209	$	4.99
Granted	0		0
Forfeited or rescinded	0		0
Vested	(2,500)		5.96
Outstanding, September 30, 2020	1,326,709	$	4.99
Outstanding, December 31, 2020	2,132,297	$	1.03
Granted	0		0
Forfeited or rescinded	0		0
Vested	(94,350)		4.95
Outstanding, March 31, 2021	2,037,947	$	0.85
Granted	1,196,102		2.77
Forfeited or rescinded	0		0
Vested	(3,480)		5.96
Outstanding, June 30, 2021	3,230,569	$	1.55
Granted	29,554		2.69
Forfeited or rescinded	0		0
Vested	(12,500)		2.15
Outstanding, September 30, 2021	3,247,623	$	1.56

As of September 30, 2021 there was $3,481,966 of unrecognized compensation cost related to restricted stock grants that will be recognized over a weighted average period of 2.21 years.

Grant activity for the three months ended September 30, 2021 was primarily restricted shares for the annual long-term incentive plan awards for employees.

NOTE 12 – CONTINGENCIES AND COMMITMENTS

Standby Letters of Credit – A commercial bank issued standby letters of credit on behalf of the Company to a state agency for $250,000 on June 26, 2016, a federal agency for $10,000 on April 9, 2019, and to an insurance company on May 19, 2020 for $500,438. The standby letters of credit are valid until cancelled or matured and are collateralized by the Credit Facility. 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 of Texas and New Mexico. The letter of credit to the insurance company relates to the surety bonds noted below. NaN amounts have been drawn under the standby letters of credit.

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.

23

RING ENERGY, INC.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

The terms of the surety bonds are extended for a term of one year at a time. The Company intends 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 to inactive wells and will remain in place until we return those wells to activity or plug them.

NOTE 13 – SUBSEQUENT EVENTS

In accordance with ASC Topic 855, Subsequent Events, the Company has evaluated all events subsequent to the balance sheet date of September 30, 2021, through the date of this report. Accordingly, the Company has determined that there were no material subsequent events required to be reported.

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

Management’s Discussion and Analysis of Financial Condition and Results of Operations analyzes the major elements of our balance sheets and statements of operations. This section should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2020 and our interim unaudited financial statements and accompanying notes to these financial statements.

Overview

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

Business Description and Plan of Operation

We are focused on optimizing the development of our existing properties, while continuing to pursue acquisitions of oil and gas properties with upside potential.  One of our goals is to increase stockholder value by investing in oil and natural gas projects with attractive rates of return on capital employed. We seek to achieve this goal by investing in the undeveloped opportunities in our existing oil and natural gas properties that have high rates of return and pursuing strategic accretive acquisitions of additional properties that have undeveloped opportunities with similar rates of return. Another goal is to focus on generating free cash flow by continuously seeking ways to lower operating costs, and maintaining a disciplined capital spending program that will result in moderate production growth while reducing the Company’s debt. Specifically, our business strategy is to increase our stockholders’ value through the following:

● Growing production and reserves by developing our oil-rich resource base through conventional and horizontal drilling. Ring intends to drill and develop its acreage base in an effort to maximize its value and resource potential, with a primary focus on drilling and developing its Northwest Shelf asset, allowing Ring to execute on its plan of operating within its generated cash flow on an annual basis.  In the third quarter of 2021, Ring drilled and completed two additional 1-mile horizontal Northwest Shelf San Andres wells and two 1.5-mile horizontal Central Basin Platform San Andres wells.  Each of the third quarter wells has a working interest of approximately 100% and were placed on production between September 9 and September 18, 2021, which resulted in minimal contribution to third quarter production, but a strong contribution to current production.  In addition to the four new wells, during the third quarter, the Company continued its program of conversions from electrical submersible pumps to rod pumps “CTRs”, with seven conversions in the Northwest Shelf and three in the Central Basin Platform, bringing the total CTRs through third quarter to 24 (18 in the Northwest Shelf and 6 in the central Basin Platform).  For 2021, the Company expects to complete 13 horizontal wells (ten in the Northwest Shelf and three in the Central Basin Platform), of which 2 were drilled in 2020.

● Reduction of long-term debt and de-leveraging of asset.  Ring intends to reduce its long-term debt, either through the sale of non-core assets, the use of excess cash flow from operations, or a combination of them.  In April 2019, Ring incurred long-term indebtedness in connection with the acquisition of core assets from Wishbone Energy Partners, LLC and its related entities.  The Company believes that with its market-leading 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 strategic asset dispositions and potential accretive acquisitions, it can accelerate the strengthening of its balance sheet.  During the three months ended September 30, 2021, the Company used its excess cash from operations to pay down $5,500,000 on its outstanding long-term debt bringing the principal balance down to $295,000,000.  

● Employ industry leading drilling and completion techniques. Ring’s executive team intends to utilize new and innovative technological advancements, comprehensive geological evaluation, and reservoir engineering analysis to generate value for its stockholders and to build future development opportunities. These technological advancements have led to an industry leading low cost structure that helps maximize the returns generated by our drilling programs. In the future improved efficiencies can be obtained in a continuous drilling program such as the one Ring contemplates for its inventory of drilling locations.

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● 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 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 its relationships will be a competitive advantage in identifying potential acquisition targets.

Executive Summary - 2021 Developments and Highlights

COVID-19 Impact

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. The demand for oil and gas has increased as the economy continues to recover which  strengthened oil prices. While oil prices have exceeded pre-pandemic levels, volatility due to OPEC actions and other factors affecting the global supply and demand of oil and natural gas may continue. Unfortunately, it is not clear whether variations of COVID-19 will continue to occur, what governmental mandates may be adopted or what unforeseen but related events may arise, presenting further challenges to our business.

Crude Price Impact

The WTI monthly oil price averaged from $39.40-$42.34 from July of 2020 through November 2020, before breaking past the $45.00 threshold in December for a monthly average of $47.02.  Supported by the rising price environment and armed with added liquidity from our equity raise in October of 2020, we initiated a targeted Northwest Shelf drilling program of eight to ten wells focused on our most attractive drilling inventory in Yoakum County, Texas.  Phase I of the drilling program consisted of four wells, including three 1.5-mile horizontal wells and one 1.0-mile horizontal well, which were completed and placed on production during the three months ended March 31, 2021. As prices continued to climb into the second quarter of 2021, we initiated and completed Phase II of the drilling program which consisted of three Northwest Shelf 1.0 mile horizontal wells with a working interest of 74%. During the third quarter of 2021, Ring drilled and completed two additional 1-mile horizontal Northwest Shelf San Andres wells and two 1.5-mile horizontal Central Basin Platform San Andres wells all with a working interest of 100%.

Winter Storm Impact

The severe winter storm in Texas in February 2021 resulted in the shut-in and deferral of more than 60% of Ring’s production which negatively impacted sales volumes and increased lease operating expense with restoration of most of the production taking more than two weeks to complete. Temporary downtime associated with completion activity and conversion to rod pumps also contributed to lower production numbers. The decrease in sales volumes coupled with the additional cost of bringing the wells back online resulted in higher lease operating expense per Boe in the first quarter of 2021. The Company benefited from higher gas prices during the freeze which helped offset the decreased production and incremental costs.

Our oil and natural gas producing properties are located in the Permian Basin. Oil sales represented approximately 93% and 96% of our total revenue for the three months ended September 30, 2021 and 2020, respectively. Gas was a higher percentage of revenue in the three months ended March 31, 2021 because of the spike in natural gas prices resulting from the winter storm in February 2021, with an average realized price of $6.46 per Mcf for the quarter, compared to $1.22 per Mcf for the same period in 2020. Natural gas prices decreased during the second quarter of 2021 as more normal supply deliveries occurred.

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Commodity Risk Management

During the three months ended June 30, 2021, we entered into swaps for 879 barrels of oil per day for calendar year 2022 at an average price at $49.03.  In total, we have costless collars, puts, and swaps for 3,000, 1,500 and 4,500 barrels of oil per day, respectively, for 2021 and swaps for 3,129 barrels of oil per day for 2022. On March 30, 2021, we unwound gas swaps for 6,000 and 5,000 MMbtu per day for 2021 and 2022, respectively, for a realized value of $581,424.  At September 30, 2021, our 2021 and 2022 derivative financial instruments resulted in a total non-cash fair value gain of approximately $8.2 million during the three months ended September 30, 2021 and cash paid on derivates of approximately $14.9 million.

Headquarters Relocation

Effective January 1, 2021, we moved our corporate headquarters to The Woodlands, Texas. In conjunction with the new office lease, we incurred operating lease obligations. During the first quarter of 2021, we downsized our Midland office and closed the Tulsa office.

Officers and Directors of the Company

On March 24, 2021, Company’s board of directors appointed Travis Thomas as Chief Financial Officer.

Borrowing Base Amendment

The fourth amendment on June 10, 2021, among other things, 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, and reaffirmed the borrowing base at $350 million, subject to its semi-annual redetermination.  We paid down $5.5 million of debt in the third quarter of 2021 and had $295 million of principal outstanding on the Credit Facility as of September 30, 2021. As our borrowing base is subject to a semi-annual redetermination, our available borrowings and liquidity could be impacted by a redetermination later in 2021.

Results of Operations – For the Three Months Ended September 30, 2021 and 2020

Oil and natural gas sales. For the three months ended September 30, 2021, oil and natural gas sales revenue increased $17,909,632 to $49,376,176, compared to $31,466,544 for the same period during 2020, primarily as a result of higher oil  and natural gas prices which were partially offset by decreased production. Of this, oil sales increased $15,561,880 and natural gas sales increased $2,347,752. For the three months ended September 30, 2021, oil sales volume decreased 122,379 barrels to 659,247 barrels, compared to 781,626 barrels for the same period in 2020. The average realized per barrel of oil price increased 79% from $38.80 for the three months ended September 30, 2020, to $69.61 for the three months ended September 30, 2021.  For the three months ended September 30, 2021, gas sales volume increased 13,718 thousand cubic feet (Mcf) to 594,841 Mcf, compared to 581,123 Mcf for the same period in 2020. The average realized natural gas price per Mcf increased 199% from $1.96 for the three months ended September 30, 2020, to $5.86 for the three months ended September 30, 2021.

The following table presents our sales revenues for the three months periods ended September 30, 2021 and 2020:

	For The Three Months Ended September 30,
	2021		2020
Operating Revenues
Oil	$	45,889,548	$	30,327,668
Natural gas		3,486,628		1,138,876
Total operating revenues	$	49,376,176	$	31,466,544

Oil and gas production costs. Total lease operating expenses decreased approximately 11% from $7,819,639 for the three months ended September 30, 2020, to $6,983,196 for the three months ended September 30, 2021 primarily due to the benefits of our CTR Program.  However our total lease operating expenses (LOE) expressed on a per barrel of oil equivalent (Boe) basis increased approximately 3% from $8.90 per Boe for the three months ended September 30, 2020, to $9.21 per Boe for the three months ended September 30, 2021 primarily because of lower production during the three months ended September 30, 2021. Although our total gathering, transportation and processing costs decreased approximately 1% from $1,058,372 for the three months ended September 30, 2020 to $1,051,163 for the three months ended September 30, 2021, due to increased gas volumes in 2021,  total gathering, transportation and processing costs

27

expressed on a per Boe basis increased approximately 15% from $1.20 per Boe for the three months ended September 30, 2020 to $1.39 per Boe for the three months ended September 30, 2021.

Production taxes. Production taxes as a percentage of oil and natural gas sales were 4.5% during the three months ended September 30, 2020 and remained steady at 4.5% for the three months ended September 30, 2021. These rates are expected to stay relatively steady unless we make acquisitions in other states with differing production tax rates or the states of Texas or New Mexico change their production tax rates.

Depreciation, depletion, amortization and accretion. Our depreciation, depletion, amortization and accretion expense decreased by $1,516,465 to $9,310,524 for the three months ended September 30, 2021, compared to $10,826,989 during the same period in 2020 due to a combination of higher 2020 production volumes and a lower depletion rate per Boe in the current period. The lower depletion rate is primarily the result of the ceiling test write down during 2020. Accretion of asset retirement obligations (“AROs”) also decreased because of the liabilities sold through the transaction discussed in Note 5.

General and administrative expenses. General and administrative expense increased $1,936,324 to $4,433,521 for the three months ended September 30, 2021 compared to $2,496,927. For the three months ended September 30, 2021, general and administrative expenses excluding share-based compensation were higher due to higher insurance and legal costs, the hiring of additional accounting, engineering, land, and operations personnel, and relocation expenses.

	For The Three Months Ended
	September 30,
	2021		2020
General and administrative expense (excluding Stock Based Compensation)	$	3,655,790	$	1,931,108
Share-based compensation		777,461		565,819
General and administrative expense	$	4,433,251	$	2,496,927

Interest expense. Interest expense decreased $905,788 to $3,551,462 for the three months ended September 30, 2021, as compared to $4,457,250 for the three months ended September 30, 2020 due to a $64.8 million lower average daily loan balance for the three months ended September 30, 2021 compared to the same period in 2020. Interest rates were also lower due to a lower margin rate associated with a reduced borrowing base utilization.

Realized gain (loss) on derivative instruments. Cash paid on derivatives for the three months ended September 30, 2021 was $14,921,008 compared to cash received on derivatives of $1,726,373 the same period in 2020. The realized loss was entirely due to oil derivative contract losses as a result of higher oil prices.

Change in fair value of derivative instruments. The Company records all derivative instruments, other than those that meet the normal purchases and sales exception, on the 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.  During the three months ended September 30, 2021, the change in fair value resulted in the recognition of a gain of $8,200,688 on derivative contracts compared to a loss of $6,228,453 during the same period in 2020.

Net income (loss). For the three months ended September 30, 2021, the Company had net income of $14,163,934, compared to a net loss of $1,961,603 for the three months ended September 30, 2020. The primary difference was the higher sales volumes and revenue in 2021 compared to 2020 due to the shut in wells in 2020 during the same period, and the rise of oil prices in 2021, as well as lower lease operating expenses in the third quarter 2021 due to benefits of the CTR Program.

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Sales volumes and commodity prices received

The following table presents our sales volumes and received pricing information for the three month periods ended September 30, 2021 and 2020:

	For the Three Months Ended
	September 30,
	2021		2020
Oil volume (Bbls)		659,247		781,626
Natural gas volume (Mcf)		594,841		581,123
Total Production (Boe)(1)		758,387		878,480
Average Sales Price
Oil price (per Bbl)	$	69.61	$	38.80
Gas price (per Mcf)	$	5.86	$	1.96
Total per Boe	$	65.11	$	35.82

⁽¹⁾ Boe is calculated using 6 Mcf of natural gas as the equivalent of one barrel of oil.

Results of Operations – For the Nine Months Ended September 30, 2021 and 2020

Oil and natural gas sales. For the nine months ended September 30, 2021, oil and natural gas sales revenue increased $54,965,345 to $136,638,810, compared to $81,673,465 for the same period during 2020, primarily as a result of higher commodity prices. Oil sales increased $47,548,076 and natural gas sales increased $7,417,269.  For the nine months ended September 30, 2021, oil sales volume decreased 95,204 barrels to 1,971,776 barrels, compared to 2,066,980 barrels for the same period in 2020.  The average realized per barrel of oil price increased 68% from $38.40 for the nine months ended September 30, 2020, to $64.37 for the nine months ended September 30, 2021.  For the nine months ended September 30, 2021, gas sales volume increased 9,341 thousand cubic feet (Mcf) to 1,773,506 Mcf, compared to 1,764,165 Mcf for the same period in 2020. The average realized natural gas price per Mcf increased 322% from $1.30 for the nine months ended September 30, 2020, to $5.48 for the nine months ended September 30, 2021.

The following table presents our sales revenues for the nine months periods ended September 30, 2021 and 2020:

	For The Nine Months Ended September 30,
	2021		2020
Operating Revenues
Oil	$	126,927,318	$	79,379,242
Natural gas		9,711,492		2,294,223
Total operating revenues	$	136,638,810	$	81,673,465

Oil and gas production costs. Our total lease operating expenses (LOE) expressed on a per barrel of oil equivalent (Boe) basis increased from $9.36 per Boe or $21,887,356 for the nine months ended September 30, 2020 to $9.98 per Boe or $22,634,259 for the nine months ended September 30, 2021. LOE for the nine months ended September 30, 2021 included freeze-related repair expenses and the reduction in production during the downtime caused by the winter storm in Texas, which increased the LOE per Boe. Our total gathering, transportation and processing costs increased from $2,833,957, or $1.21 per Boe for the nine months ended September 30, 2020 to $2,883,348, or $1.27 per Boe for the nine months ended September 30, 2021, due to shut in volumes associated with Covid in 2020.

Production taxes. Production taxes as a percentage of oil and natural gas sales were 4.6% during the nine months ended September 30, 2020 and remained steady at 4.6% for the nine months ended September 30, 2021. These rates are expected to stay relatively steady unless we make acquisitions in other states with differing production tax rates or the states of Texas or New Mexico change their production tax rates.

Depreciation, depletion, amortization and accretion. Our depreciation, depletion, amortization and accretion expense decreased by $5,154,285 to $26,693,808 for the nine months ended September 30, 2021, compared to $31,848,093 during the same period in 2020 due to a combination of a lower depletion rate per Boe and lower production volumes between periods. The lower depletion rate was primarily the result of the ceiling test write down during 2020. Accretion of ARO also decreased because of the liabilities sold through the transaction discussed in Note 5.

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General and administrative expenses. Notwithstanding a decrease of $1,072,427 in stock-based compensation, the Company’s general and administrative expense increased $1,393,963 to $11,103,394 for the nine months ended September 30, 2021 compared to $9,709,431 for the nine months ended September 30, 2020, due to higher insurance and legal costs, the hiring of additional accounting, engineering, land, and operations personnel, and relocation expenses.

	For The Nine Months Ended
	September 30,
	2021		2020
General and administrative expense (excluding Stock Based Compensation)	$	9,618,664	$	7,152,275
Share-based compensation		1,484,730		2,557,156
General and administrative expense	$	11,103,394	$	9,709,431

Interest expense. Interest expense decreased $2,010,828 to $10,947,960 for the nine months ended September 30, 2021, compared to $12,958,788 for the like period in 2020 due to $62.8 million lower average daily balance on the Company’s credit facility for the nine months ended September 30, 2021 compared to the same period in 2020. Interest rates were also lower due to a lower margin rate associated with a reduced borrowing base utilization.

Realized gain (loss) on derivative instruments. Cash paid on derivatives for the nine months ended September 30, 2021 was $33,278,132 compared to cash received on derivatives of $18,814,068 the same period in 2020.  The cash paid was comprised of a $34,021,310 oil derivatives contract loss and a $743,178 gain on the gas derivative contracts. This change is the result of significantly higher oil prices and lower gas prices and the full unwinding of the remaining 2021 and 2022 gas derivative contracts in March 2021.

Change in fair value of derivative instruments. The Company records all derivative instruments, other than those that meet the normal purchases and sales exception, on the 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.  During the nine months ended September 30, 2021, the change in fair value resulted in the recognition of a loss of $40,308,067 on derivative contracts as compared to a gain of $14,086,699 during the same period in 2020.

Net income (loss). For the nine months ended September 30, 2021, the Company incurred a net loss of $20,789,318, compared to a net loss of $93,157,551 for the nine months ended September 30, 2020. The primary contributors to this change in the nine-month period were the 2020 impairment ($148 million in the first quarter 2020), offset by higher 2021 commodity prices resulting in a significant loss on the change in fair value of derivative instruments (approximately $40 million loss year-to-date third quarter 2021 compared to $14 million gain during the same period in 2020).

Sales volumes and commodity prices received

The following table presents our sales volumes and received pricing information for the nine month periods ended September 30, 2021 and 2020:

	For the Nine Months
	ended September 30,
	2021		2020
Oil volume (Bbls)		1,971,776		2,066,980
Natural gas volume (Mcf)		1,773,506		1,764,165
Total Production (Boe)		2,267,360		2,361,008
Average Sales Price
Oil price (per Bbl)	$	64.37	$	38.40
Gas price (per Mcf)	$	5.48	$	1.30
Total per Boe	$	60.26	$	34.59

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Capital Resources and Liquidity

As of September 30, 2021, the Company had cash on hand of $2,046,946, compared to $3,578,634 as of December 31, 2020.  The Company had net cash provided by operating activities for the nine months ended September 30, 2021, of $49,523,439, compared to $44,903,306 for the same period of 2020. The primary difference in the cash from operations was the difference in cash received from customers due to higher year to date production in 2021 compared to 2020. The Company had net cash used in investing activities of $33,869,724 for the nine months ended September 30, 2021, compared to $30,275,770 in 2020, due to its increased payments to develop oil and natural gas properties. The $35,869,724 in 2021 capex was offset by $2,000,000 in proceeds from the transaction described in Note 5 which was a reduction to our full cost pool. Net cash used in financing activities was $17,185,403 for the nine months ended September 30, 2021 during which time $18,000,000 was paid on our credit facility.

We will continue to focus on maximizing free cash flow in 2021 through a combination of cost control measures and the continued exercise of financial discipline and prudent capital allocation, which includes limiting our capital projects to projects we believe will provide high rates of return in the current commodity price environment. In response to higher commodity prices,  our planned capital expenditures for 2021 will be significantly higher than our 2020 levels primarily due to reduced capital levels in 2020 as a result of COVID-19. Given this expected level of capital expenditures, our oil and natural gas production will likely improve in the near future. We will also continue our pursuit of acquisitions and business combinations, which provide high margin properties with attractive returns at current commodity prices.

The COVID-19 pandemic reduced global economic activity and negatively impacted energy demand during the previous twelve months. Demand for oil and natural gas is returning to pre-pandemic levels as COVID-19 vaccines rates and economic activity have increased. During this time, we will remain focused on maximizing free cash flow, reducing our debt level, and maximizing our liquidity which we believe develops greater stockholder value.

Availability of Capital Resources under Credit Facility

On July 1, 2014, the Company entered into a Credit Agreement which was amended on June 14, 2018, May 18, 2016, July 24, 2015, and June 26, 2015. In April 2019, the Company amended and restated its 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”), (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 June 25, 2021, June 10, 2021, December 23, 2020 and June 17, 2020.   The June 10, 2021 amendment, among other things, 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, and reaffirmed the borrowing base at $350 million. The 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 clarifying 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 each May and November and will be reduced in certain circumstances such as the sale or disposition of certain oil and gas properties of the Company and the cancellation of certain hedging positions.

The Credit Facility allows for Eurodollar Loans and Base Rate Loans (as respectively defined in the Credit Facility). The interest rate on each Eurodollar Loan will be the adjusted LIBOR for the applicable interest period plus a margin between 2.5% and 3.5% (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 LIBOR 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 1.5% and 2.5% (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) of not more than 4.0 to 1.0 and (ii) a minimum ratio of Current Assets to Current Liabilities (as such terms are defined in the Credit Facility) of 1.0 to 1.0. Per the amendments to the credit facility in June and December 2020, the total Leverage Ratio is not allowed to be greater than 4.25 for the period ending March 31, 2021.  The Credit Facility also contains other customary affirmative and negative covenants and events of default.  As of

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September 30, 2021, $295,000,000 was outstanding on the Credit Facility and we were in compliance with all covenants contained in the Credit Facility.

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 order 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. During May 2020, the Company unwound the costless collars for June 2020 and July 2020, resulting in the receipt of a cash payment of $5,435,136.

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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The following table reflects the prices of contracts outstanding as of September 30, 2021:

Oil contracts (WTI)
Date entered into	Barrels per day		Put price		Call price
2021 costless collars, in place for January through December 2021
02/25/2020	1,000		$	45.00	$	54.75
02/25/2020	1,000			45.00		52.71
02/27/2020	1,000			40.00		55.08
2021 put
03/02/2020	1,500			40.00
					Swap price
2021 Swap, in place January through December 2021
11/25/2020	2,000				$	45.37
12/02/2020	500					45.38
12/03/2020	500					45.00
12/04/2020	500					45.40
12/04/2020	500					45.60
12/07/2020	500					45.96
2022 Swap, in place January through December 2022
12/04/2020	500				$	44.22
12/07/2020	500					44.75
12/10/2020	500					44.97
12/17/2020	250					45.98
01/04/2021	250					47.00
02/04/2021	250					50.05
05/11/2021	879	(1)​				49.03

(1) The notional quantity per the swap contract entered into on May 11, 2021 is for 26,750 barrels of oil per month. The 879 represents the daily amount on an annual basis.

Derivative financial instruments are recorded at fair value and included as either assets or liabilities in the accompanying 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 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, 2021, 100% of our volumes subject to derivative instruments are with lenders under our Credit Facility.

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 drilled properties rather than properties with higher-risk exploratory opportunities. We do not intend to limit our evaluation to any one state, and 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 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, 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. The types of costs that we may incur include travel costs relating to meeting with individuals instrumental to the acquisition of oil and gas properties, the costs to retain consultants 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 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 a transaction resulting in our acquisition 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 (inflation) will impact our 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 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 certain unique 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, operational risks, ability to integrate properties and businesses, and certain environmental 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; 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 may be 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. To date, no specific accounting for environmental compliance has been maintained or projected by Ring. Ring does not presently know of any environmental demands, claims, adverse actions, litigation or administrative proceedings in which it or the acquired properties are involved or subject to or arising out of its predecessor operations.

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. Quantitative and Qualitative Disclosures 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, 2021, the Company had $295,000,000 outstanding borrowings under the Credit Facility. Our weighted average annual interest rate on borrowings under the Credit Facility was 4.4%. An increase or decrease of 1% in the interest rate would have a corresponding decrease or increase in our annualized interest expense of approximately $3 million based on the aggregate of $295,000,000 outstanding under the Credit Facility as of September 30, 2021.

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

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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.

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 amount the Company can borrow 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 of its oil and natural gas production under price sensitive or market price contracts.

Customer Credit Risk

Our principal exposures to credit risk are through receivables from the sale of our oil and natural gas production (approximately $20.3 million at September 30, 2021) and through receivables from our joint interest partners (approximately $1.7 million at September 30, 2021). We are subject to credit risk due to the concentration of our oil and natural gas receivables with our most significant customers. We do not require our customers to post collateral, and the inability of our significant customers to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. For the three months ended September 30, 2021, sales to three customers, Phillips 66, NGL Crude and BP represented 78%, 6% and 6% of oil and gas revenues, respectively.  As of September 30, 2021, Phillips 66, NGL Crude and BP represented 79%, 5% and 3% of our accounts receivable, respectively. Due to availability of other purchasers, 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.

Currency Exchange Rate Risk

Foreign sales accounted for none of the 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.

Item 4. Controls and Procedures

Evaluation of disclosure controls and 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 Securities and Exchange Commission’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

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. During the first quarter of 2021, the Company transitioned its accounting and reporting functions from Tulsa in conjunction with its corporate headquarters relocation. On March 24, 2021, Travis Thomas was named Chief Financial Officer, replacing William Broaddrick.

Except as described above, there were no changes in our internal control over financial reporting that occurred during the three months ended September 30, 2021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1. Legal Proceedings.

We may be the subject of threatened or pending legal actions and contingencies 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.

Item 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 2020 Form 10-K. There have been no material changes to the risks described in the 2020 Form 10-K.  We may experience additional risks and uncertainties not currently known to us.  Furthermore, 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.

Item 2. Recent Sales of Unregistered Securities; Use of Proceeds from Registered Securities.

None.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

None.

Item 5. Other Information.

None.

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Item 6. Exhibits

		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	File No.	Exhibit	Filing Date	Filed Here-with
3.1	Articles of Incorporation (as amended)	10-K	000-53920	3.1	04/01/13
3.2	Amended and Restated Bylaws	8-K	001-36057	3.1	04/14/21
31.1	Rule 13a-14(a) Certification by Chief Executive Officer					X
31.2	Rule 13a-14(a) Certification by Chief Financial Officer					X
32.1	Section 1350 Certification by Chief Executive Officer					X
32.2	Section 1350 Certification by Chief Financial Officer					X
101.SCH	XBRL Taxonomy Extension Schema Document					X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document					X
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document					X
101.LAB	XBRL Taxonomy Extension Label Linkbase Document					X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document					X
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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SIGNATURES

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

	Ring Energy, Inc.
Date: November 9, 2021	By:	/s/ Paul D. McKinney
		Paul D. McKinney
		Chief Executive Officer and Director
		(Principal Executive Officer)
Date: November 9, 2021	By:	/s/ Travis T. Thomas
		Travis T. Thomas
		Chief Financial Officer
		(Principal Financial and Accounting Officer)

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