Exhibit 99.2

www. ringenergy.com NYSE American: REI VALUE FOCUSED PROVEN STRATEGY

www.ringenergy.com NYSE American: REI Forward - Looking Statements and Cautionary Note Regarding Hydrocarbon Disclosures Forward – Looking Statements This Presentation includes "forward - looking statements" within the meaning of the Private Securities Litigation Reform Act of 19 95, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of strictly historical facts included in this Presentation constitute forward - loo king statements and may often, but not always, be identified by the use of such words as “may,” “will,” “should,” “could,” “intends,” “estimates,” “expects,” “anticipates,” “plans,” “project,” “guidance,” “target,” “potential,” “possible,” “probabl y,” and “believes” or the negative variations thereof or comparable terminology. These forward - looking statements include statements regarding the Company's financial position, future revenues, net income, potential evaluations, business strategy and plans and objectives for future operations. The forward - looking statements include statements about the expected benefits to the Company and to its stockholders from the acquisition of certain assets (the “Stronghold Assets”) from Strongh old Energy II Operating, LLC (“Stronghold OpCo ”) and Stronghold Energy II Royalties, LP (“Stronghold RoyaltyCo ”, together with Stronghold OpCo , collectively, “Stronghold”); Forward - looking statements are subject to numerous assumptions, risks and uncertainties that may cause actual results to be mate rially different than any future results expressed or implied in those statements. However, whether actual results and developments will conform to expectations is subject to a number of material ris ks and uncertainties, including but not limited to: the Company’s ability to integrate the Stronghold Assets and achieve the anticipated benefits therefrom; risks relating to any unforeseen liability of the Company or the Stronghold Assets; declines in oil, natural gas liquids or natural gas prices; the level of success in exploration, development and production a ct ivities; the timing of exploration and development expenditures; inaccuracies of reserve estimates or assumptions underlying them; rev isi ons to reserve estimates as a result of changes in commodity prices or production history; impacts to financial statements as a result of impairment write - downs; risks related to level of indebtedness and periodic redeterminations of the bo rrowing base under the Company’s credit facility; the impacts of hedging on results of operations; the Company’s ability to replace oil and natural gas reserves; any loss of senior management or technical personnel; and the direct and indirect im pac t on most or all of the foregoing due to the COVID - 19 pandemic. Some of the factors that could cause actual results to differ materially from expected results are described under “Risk Factors” in our 2021 annual report on Form 10 - K filed with the U.S. Securities and Exchange Commission (“SEC”) on March 16, 2022, and in our subsequent quarterly reports on Form 10 - Q and current reports on Form 8 - K. Although the Company believes that the assumptions upon which such forward - looking stateme nts are based are reasonable, it can give no assurance that such assumptions will prove to be correct. All forward - looking statements in this Presentation are expressly qualified by the cautionary statements and by reference to the underlyi ng assumptions that may prove to be incorrect. The Company undertakes no obligation to publicly revise these forward - looking statements to reflect events or circumstances that arise after the date hereof, except as required by applicable law. The financial and operating estimates contained in this presentation represent our reasonable estimates as of the date of this Presentation. Neither our independent auditors no r a ny other third party has examined, reviewed or compiled the projections and, accordingly, none of the foregoing expresses an opinion or other form of assurance with respect thereto. The assumptions upon which the projections are based ar e d escribed in more detail herein. Some of these assumptions inevitably will not materialize, and unanticipated events may occur that could affect our results. Therefore, our actual results achieved during the periods covered by the estimates w ill vary from the projected results. Prospective investors are cautioned not to place undue reliance on the estimates included herein. Cautionary Note regarding Hydrocarbon Disclosures The SEC has generally permitted oil and natural gas companies, in their filings with the SEC, to disclose proved reserves, wh ich are reserve estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, and certain probable and possible reserv es that meet the SEC’s definitions for such terms. We use the terms “estimated ultimate recovery,” or “EURs,” “probable,” “possible,” and “non - proven” reserves, reserve “potential” or “upside” or other descriptions of volumes of reserves potentially recoverable through additional drilling or recovery techniques that the SEC’s guidelines prohibit us from including in filings with the SEC. Reference to EURs of natural gas and oil includes amounts that are not yet classified as p rov ed reserves under SEC definitions, but that we believe should ultimately be produced and are based on previous operating experience in a given area and publicly available information relating to the operations of producers who are conducting oper ati ons in these areas. These estimates are by their nature more speculative than estimates of proved reserves and accordingly are subject to substantially greater risk of being actually realized by us. Factors affecting the ultimate recove ry of reserves that may be recovered include the scope of our drilling programs, which will be directly affected by capital availability, drilling and production costs, commodity prices, availability of services and equipment, permit expirations, tr ans portation constraints, regulatory approvals and other factors, and actual drilling results, including geological and mechanic al factors affecting recovery rates. Accordingly, actual quantities that may be recovered from our interests will differ from ou r e stimates and could be significantly less than our targeted recovery rate. In addition, our estimates may change significantly as we receive additional data. Supplemental Non - GAAP Financial Measures This Presentation includes financial measures that are not in accordance with accounting principles generally accepted in the Un ited States (“GAAP”), such as “Adjusted Net Income,” “Adjusted EBITDA,” “PV - 10,” “Free Cash Flow,” or “FCF,” and “Cash Flow from Operations.” While management believes that such measures are useful for investors, they should not be used as a re pla cement for financial measures that are in accordance with GAAP. For definitions of such non - GAAP financial measures and their reconciliations to GAAP measures, please see the Appendix. 2

www.ringenergy.com NYSE American: REI Ring Energy – Independent Oil & Gas Company Focused on Conventional Permian Assets in Texas & New Mexico 2021 SEC Proved Reserves 2,3 77.8 MMBoe/PV10 $1,332MM 85% Oil Gross / Net Acres 2 83,604 / 64,380 1. Based on Q3’22 financials 2. As of December 31, 2021 (2 - stream) Ring Legacy Only SEC Proved Reserves 3. PV - 10 is a Non - GAAP financial measure. See appendix for reconciliation to GAAP measure 4. As of November 8, 2022 5. Enterprise Value (EV) is market cap plus outstanding debt based on number of shares outstanding at end of Q3 2022 Market Cap ~$544 million 4 Consistently Generated Positive Cash Flow for 12 Qtrs NEW MEXICO “NWS” Northwest Shelf “CBP” Central Basin Platform “DB” Delaware Basin “SE II” Stronghold Energy II Acquisition Enterprise Value ~$979 million 4,5 REI Closing Price $3.12 4 52 - week range $1.81 - $5.09 REI Avg. Daily Share Volume (90 - Day) ~2.05 million 4 Non - Core Area DB CBP NWS Core Areas SEII Deliver competitive and sustainable returns by developing, acquiring, exploring for, and commercializing oil and natural gas resources VITAL TO THE WORLD’S HEALTH AND WELFARE Q3 2022 Net Sales 1 13,278 Boe/d 76% oil 13% gas 11% NGL 3

www.ringenergy.com NYSE American: REI Q3 2022 Highlights Executing our Strategy ▪ Successfully closed accretive transaction ▪ Record quarterly sales revenue of $94.4 MM – highest in Company history ▪ Increased sales volumes 2 42% to 13,278 Boe /d (76% oil, 13% natural gas, 11% NGLs) ▪ Grew net income 79% over Q2 2022 to $75.1 million ▪ Grew Adj. EBITDA 1 18% over Q2 2022 to $56.0 MM – highest in Company history ▪ Paid down debt 3 by $17.0 million since closing Stronghold acquisition ▪ Reduced leverage ratio 4 to 1.4x compared to ~ 3.5x at YE 2021 ▪ Increased liquidity to ~$165 million, more than $100 million higher than YE 2021 ▪ Drilled 8 wells, completed 9 wells and performed 3 recompletions ▪ Grew Cash Flow from Operations 1 by 10% to $48.9 million $9.7 1 MM Free Cash Flow $56.0 1 MM Adjusted EBITDA $75.1 MM Net Income $17.0 3 MM Debt Repayment 13 ,278 Boe /d (76% oil) Net Sales per day $10.67 LOE per Boe 1. Adjusted EBITDA, Free Cash Flow and Cash Flow from Operations are Non - GAAP financial measures and reconciled in Ring’s earnings releases 2. Includes 1 month of Stronghold acquisition closed on August 31, 2022 as well as conversion from 2 - stream to 3 - stream 3. Debt repayment Ring as of Aug. 31, 2022, pro - forma debt balance at closing ~ $452 million 4. Leverage ratio based on annualized third quarter EBITDA adjusted for the pro - forma effects of the Transaction from the beginning of the quarters as per credit agreement. Q3 2022 Highlights 4

www.ringenergy.com NYSE American: REI Committed to ESG Critical to Sustainable Success 5

www.ringenergy.com NYSE American: REI Focus on FCF and Strengthening Balance Sheet Pursue Operational Excellence with a Sense of Urgency Invest in High - Margin, High ROR Projects YTD Drill 23 & Complete 20 Successful Hz Wells 2 (FY 2021 13 Hz wells) YTD Average 10,512 Boepd (81% Oil) (27% Increase over 2021 for same time period) YTD ~$139 MM Adj. EBITDA 1 (134% Increase over 2021 for same time period) Reduced Lev. Ratio 4 to ~1.4x (LQA 1.4x) (Forecasted to operate within CF, further reduce leverage over time) Successfully Closed Accretive Acquisition (Enhances metrics and lowers break - even costs) 2022 Value Focused Proposition Proven Strategy Leads to Shareholder Value YTD Lifting Cost 3 at $10.55/Boe (Safe, efficient operations & continued CTR program) 1. Source ties to financials Q3 2022. Pro Forma company as of Sept. 1, 2022 2. 7 CBP & 16 NWS HZ wells as of Sept 2022 (does not account for any Stronghold activity pre closing) 3. Lifting Cost ties to financials 3Q 2022 and does not include GP&T 4. Leverage ratio based on annualized third quarter EBITDA adjusted for the pro - forma effects of the Transaction from the beginning of the quarters as per credit agreement. 6

Financials

www.ringenergy.com NYSE American: REI Sustainable Value Focused Results 8,243 9,153 8,870 9,341 13,278 0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 Boe /d Net Sales $6.8 $9.9 $22.3 $31.3 $32.5 $0.0 $5.0 $10.0 $15.0 $20.0 $25.0 $30.0 $35.0 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 $MM Adjusted Net Income 1 $19.7 $24.0 $35.6 $47.4 $56.0 $0.0 $10.0 $20.0 $30.0 $40.0 $50.0 $60.0 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 $MM Adjusted EBITDA 1 $2.6 $9.3 $12.6 $2.5 $9.7 $0.0 $5.0 $10.0 $15.0 $20.0 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 $MM Free Cash Flow 1 Executing Disciplined Strategy 1. Adjusted EBITDA, Adjusted Net Income and Free Cash Flow are Non - GAAP financial measures and reconciled in the appendix 2. Ring pro - forma in Q3 2022 switched from 2 - stream to 3 - stream volume reporting Continuous drill program Stronghold Acquisition ~85% Oil ~85% Oil ~87% Oil ~76% Oil 3 - Stream 2 Phase III drill program ~86% Oil Phase IV drill program Continuous drill program Continuous drill program Accelerated the completion process of 4 x 1.0mile Hz wells in Q2 Stronghold Acquisition 8

www.ringenergy.com NYSE American: REI Historical Metrics Quarterly Analysis of FCF 1 $MM Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 Adj EBITDA 1 $19.7 $24.0 $35.6 $47.4 $56.0 Capital - $13.7 - $11.3 - $19.7 - $41.8 - $40.3 Interest Exp. 2 - $3.4 - $3.4 - $3.2 - $3.1 - $5.9 Free Cash Flow 1 $2.6 $9.3 $12.6 $2.5 $9.7 $19.7 $24.0 $35.6 $47.4 $56.0 - $13.7 - $11.3 - $19.7 - $41.8 - $40.3 - $3.4 - $3.4 - $3.2 - $3.1 - $5.9 $2.6 $9.3 $12.6 $2.5 $9.7 -$50.0 -$40.0 -$30.0 -$20.0 -$10.0 $0.0 $10.0 $20.0 $30.0 $40.0 $50.0 $60.0 $70.0 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 Adj. EBITDA/ Capital / Int Exp Adj EBITDA $MM Capital $MM Interest Exp $MM Free Cash Flow $MM ▪ Disciplined & efficient capital spending ▪ Focused on sustainably generating FCF ▪ Unrelenting goal to strengthen the balance sheet 1) Adjusted EBITDA and Free Cash Flow are Non - GAAP financial measures and reconciled in the appendix 2) Excludes amortization of deferred financing costs 3) Leverage ratio based on annualized third quarter EBITDA adjusted for the pro - forma effects of the Transaction from the beginning of the quarters as per credit agreement. Leverage Ratio (LTM) 2.8x 3.5x 3.5x 2.1x 1.4x Leverage Ratio 3 (LQA) 9

www.ringenergy.com NYSE American: REI $8 $5 $6 $5 $10 $10 $17 $0 $5 $10 $15 $20 $25 $30 $35 $40 $45 $50 $0 $2 $4 $6 $8 $10 $12 $14 $16 $18 Q1 2021 Q2 2021 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 Debt Paydown $MM $313 MM outstanding debt with $36 MM in Surplus Cash Reducing Debt & Increasing Liquidity Disciplined Capital Spending & Sustainably Generating FCF is the Key $46.2 $51.4 $56.2 $61.6 $71.4 $81.5 $165.0 $0 $20 $40 $60 $80 $100 $120 $140 $160 $180 Q1 2021 Q2 2021 Q3 2021 Q4 2021 Q1 2022 Q2 2022 Q3 2022 Liquidity $MM Stronghold Acquisition % RBL Capacity Drawn 87% 86% 84% 83% 80% 77% 73% 10

Asset Areas

www.ringenergy.com NYSE American: REI Ring + Stronghold Pro - Forma Overview 1. Proved reserves for REI are management estimates as of June 1, 2022 and Stronghold management estimates as of June 1, 2022 we re prepared by CGA, both used June 21, 2022 NYMEX Strip prices June 21, 2022 NYMEX Strip Pricing for WTI /HH : 2022:$107.12 / $7.10; 2023: $92.89 / $5.35; 2024: $83.09 / $4.76; 202 5: $76.31 / $4.63; 2026+: $71.68 / $4.62 2. As of November 9, 2022 3. Transaction fair value calculation of stock consideration and other details refer to Q3’22 10Q page 19 & 20 ▪ Successfully closed the acquisition on August 31, 2022 ▪ $172.4MM cash at close after certain purchase price adjustments and funded from new credit facility borrowings ▪ $15MM deferred cash payment due 6 months after close ▪ Stock consideration consisted 3 of ~21.3 million shares of Ring common stock and 153.1K Ring preferred stock that converted to ~42.5 million shares of Ring common stock after the successful shareholder vote Oct. 27, 2022 Operating Statistics Asset Map Key Transaction Structure & Terms Pro Forma Snapshot Pro Forma Q4 2022 Net Production ( MBoe /d) 18,000 - 19,000 Oil (Bo/d) ~ 70% Gas (Mcf/d) ~ 17% NGLs ( Bbls /d) ~ 13% 12,600 - 13,300 18,400 - 19,400 2,300 - 2,500 LOE (per Boe ) $10.25 - $11.40 PD Reserves 1 PV10 ($MM) $1,739 PD Reserves 1 ( MMBoe ) 87.0 Acreage ~101,000 Capex ($MM) $42 - 46 Basic Shares Outstanding 2 (MM) 174.4 Vertical Development Multi - Stacked Pay Horizonal Development San Andres Play Northern CBP Southern CBP 12

www.ringenergy.com NYSE American: REI ▪ Meaningful inventory of horizontal drilling locations ▪ Actively developing asset ▪ Low D&C and LOE costs drive strong economics ▪ Improving drilling efficiencies: ▪ 1 mile HZ well drill time spud to rig release and move to next location 7 - 9 days ▪ 1.5 mile HZ well drill time spud to rig release and move to next location 10 - 12 days ▪ Spud to Online in 40 - 55 days 3 Providing Significant Organic Growth 3Q22 Avg Sales 7,669 Boe /d (77% Oil) 3Q22 D&C Completed 6 Hz wells 2 (~93.75% WI) Gross / Net Acres 1 35,810 / 26,655 Northwest Shelf Asset Area 3Q22 CTR’s 5 Conversions 1. As of December 31, 2021 2. 4 NWS HZ new wells drilled in Q2 but not completed until Q3 2022 3. Depending on lateral length and frac crew availability Northwest Shelf Delaware Basin CBP Midland Ring Acreage Northwest Shelf 2020 2021 YTD 2022 NWS 4 10 16 0 2 4 6 8 10 12 14 16 18 HZ Drilled Wells 2020 - 2022 13

www.ringenergy.com NYSE American: REI Proven, Conventional, Top Tier Returns San Andres Hz Delaware Hz Midland Hz High ROR Oil Play x x x Low D&C Costs x Lower 1 st Year Decline x Low Lease Acquisition Cost x Long life wells x Oil IPs >750 Bbl /d x x Multiple Benches x x > 85% Oil x $25 - 30/ Bbl D&C Break - even 2 x ▪ Permian Basin has produced >30 BBbl , ▪ San Andres accounts for 40% ▪ Low D&C costs 1 $2.8 - $3.8 MM per well ▪ Vertical depth of ~5,000’ ▪ Typical oil column of 200’ - 300’ ▪ Life >35+ years ▪ Initial peak oil rates of 300 - 700 Bbl/d ▪ Higher primary recovery than shales ▪ Potential for waterflood and CO 2 Source: US Department of Energy & DrillingInfo San Andres Reservoir 1. D&C capex range is for both 1.0 & 1.5 mile laterals and includes inflation adjustments 2. Break - even costs range depends on lateral length, asset area and inflation adjustments 14

www.ringenergy.com NYSE American: REI NWS HZ Performance Average – Cum BOE vs Time Days ( 1.5 Mile Lateral ) 2 1,000 10,000 100,000 0 180 360 2016 & 2017 2018 & 2019 2020, 2021 & 2022 NWS HZ Well Performance & Costs Significant Improvements Driving Top Tier Returns D&C Cost Range per Year ( 1 Mile Lateral ) 1 NWS HZ Performance Average – Cum BOE vs Time Days ( 1 Mile Lateral ) 2,3 1. Wells categorized by spud year; capex ties to financials 2. Downtime associated with 2020 pandemic curtailment removed 3. Well set comprised of single mile wells normalized to 5,080’ lateral length (does not include 1.5 Mile wells) ~530 Avg ~410 Avg ~420 Avg D&C Cost Range per Year ( 1.5 Mile Lateral ) 1 BOE (85 - 90% Oil) $1.5 M $2.0 M $2.5 M $3.0 M $3.5 M 2019 2020 2021 YTD 2022 $2.0 M $2.5 M $3.0 M $3.5 M $4.0 M 2019 2020 2021 YTD 2022 1,000 10,000 100,000 0 180 360 2015 2016 & 2017 2018 2019 -2021 2022 15 BOE (85 - 90% Oil)

www.ringenergy.com NYSE American: REI 3Q22 Avg Sales 1 5,376 Boe /d (76% Oil) 3Q 22 CTR’s 1 Conversion 3 Recompletions 3Q22 D&C Completed 3 Hz wells (100% WI) Gross / Net Acres 2 29,065 / 20,288 Technical Focus Reinvigorates Legacy Area Central Basin Platform Asset Areas 1. Includes Stronghold acquisition volumes for month of Sept. 2022 2. As of December 31, 2021 3. Depending on lateral length and frac crew availability ▪ Meaningful inventory of vertical & horizontal drilling locations ▪ Meaningful inventory of recompletion opportunities ▪ Actively developing asset areas ▪ Low D&C and LOE costs drive strong economics ▪ Improving Hz drilling efficiencies: ▪ 1 mile HZ well drill time spud to rig release and move to next location 7 - 9 days ▪ 1.5 mile HZ well drill time spud to rig release and move to next location 10 - 12 days ▪ Spud to Online in 40 - 55 days 3 Northwest Shelf Delaware Basin CBP Midland Ring Acreage Central Basin Platform 2020 2021 YTD 2022 CBP 0 3 7 0 2 4 6 8 HZ Drilled Wells 2020 - 2022 Northern CBP Horizonal Development San Andres Play Southern CBP Vertical Development Multi - Stacked Pay 16

www.ringenergy.com NYSE American: REI Northern Central Basin Platform HZ Well Performance & Costs Annual D&C per HZ Cost Range ( 1.0 & 1.5 Mile ) 1 ~530 Avg ~410 Avg ~420 Avg CBP 1.0 & 1.5 Mile HZ Performance – Cum BO vs Time (2021 & 2022 vs Historic) 2,3 1) Wells categorized by spud year; capex ties to financials 2) Downtime associated with 2020 pandemic curtailment removed and contains only University Lands “UL” wells in the CBP (No norma liz ation) 3) 2021 & ‘22 Well set comprised of 1.0 and 1.5 mile laterals drilled in CBP UL area (9 wells included) $2.0 M $2.5 M $3.0 M $3.5 M $4.0 M 2020 2021 YTD 2022 No drilling in 2020 CBP 2021 & 2022 CBP HZ Program Average Historical CBP HZ well performance Technical Improvements to Completion and Landing Zone 17

www.ringenergy.com NYSE American: REI 1 10 100 1,000 10,000 100,000 0 100 200 300 Cum Production, BOE Days Online 2022 Target Area 1 Vertical R/C Avg Historical 2019 - 2021 well RC performance Southern Central Basin Platform Vertical Well Performance & Costs ~530 Avg ~410 Avg ~420 Avg Modern Completion Methods x Conventional “high quality rock” stacked pay formations targeted with today's modern multi - stage completion methods x Significant remaining upside with high RORs – high return/low - cost opportunities Legacy Simple Single Stage Completion Modern Multi - Stage Completion Technique Crane Co . – Vertical New Drills “ND” – Cum BOE vs Time (Days) Crane Co . – Vertical Recompletion “RC” – Cum BOE vs Time (Days) 1 10 100 1,000 10,000 100,000 0 100 200 300 Cum Production, BOE Days Online 2022 Target Area 1 Vertical ND Avg 2022 Target area 2 Vertical ND Avg Historical 2019 - 2021 well ND performance CBP South Type Log CAPEX per project - $500 - 950K CAPEX per project - $1.5 - $1.8 MM Stacked Pay Zones 18

www.ringenergy.com NYSE American: REI 0 50 100 150 200 2018 2019 2020 2021 YTD 2022 NWS CBP Maintains Solid PDP Reserve Base that Generates Consistent FCF Increases reserves by reducing operating & well repair costs and extending well life ▪ ~ 50% long - term reduction in LOE ▪ Up to 75% reduction in future pulling costs ▪ Extends economic life & increases EUR CTRs Significantly Reduce Operating Costs 2020 2021 YTD 2022 NWS 16 19 12 CBP 12 6 2 0 10 20 $- $25,000 $50,000 $75,000 $100,000 $125,000 $150,000 $175,000 $200,000 $225,000 $250,000 Range of Avg Well Repair Cost ESP ROD $190,000 $65,000 $30,000 Cost Savings ESP vs ROD Maximizing Operational Margin is Predicated on Being a Leading LOW - COST OPERATOR ~75% Lower $240,000 CTR Projects 2020 - 2022 ESP Failures 1 2018 – 2022 1. ESP failures are any time a service rig is necessary to repair ESP downhole equipment in order to bring a well back on production 19

www.ringenergy.com NYSE American: REI Turnkey Asset with Predictable Cash Flow and Upside Potential Delaware Basin Asset ▪ Sales process for Delaware Assets underway ▪ Truist Securities running a marketed process ▪ Asset infrastructure in - place to enable efficient development ▪ Produced water, gas gathering and pipeline ▪ Long life and shallow decline PDP base ▪ High ownership - working interest ~ 98% (75% NRI) ▪ Large inventory of re - activations, re - completions, and new drills Ring Acreage Non - Core asset that can be catalyst to pay down debt and/or provide funds for potential accretive acquisition 20

www.ringenergy.com NYSE American: REI Value Proposition 2022 and Beyond Positioned for Substantial Increase in Revenue and FCF Achieving High - Return Organic Growth Pursuing Acquisition Opportunities to Further Increase Scale and Lower Break - Even Costs 21

Appendix

www.ringenergy.com NYSE American: REI Gas Hedges (basis differential) 2022 2023 2024 Waha basis swaps: Hedged volume (MMBtu) 505,024 1,339,685 - Weighted average swap price (2) (3) $ - Financial Overview Derivative Summary Summary of Hedges Oil Hedges (WTI) 2022 2023 2024 Swaps: Hedged volume (BBL) 379,250 389,250 526,000 Weighted average swap price $ 54.89 $ 77.55 $ 65.90 Deferred premium puts: Hedged volume (BBL) 138,000 773,500 91,000 Weighted average strike price $ 97.93 $ 90.64 $ 83.75 Weighted average deferred premium price $ 11.81 $ 15.25 $ 17.32 Two - way collars: Hedged volume (BBL) 97,201 487,622 475,350 Weighted average put price $ 53.93 $ 52.16 $ 67.88 Weighted average call price $ 67.68 $ 62.94 $ 83.32 Three - way collars: Hedged volume (BBL) 89,985 66,061 - Weighted average first put price $ 40.00 $ 45.00 $ - Weighted average second put price $ 50.00 $ 55.00 $ - Weighted average call price $ 62.03 $ 80.05 $ - Gas Hedges (Henry Hub) 2022 2023 2024 NYMEX Swaps: Hedged volume (MMBtu) 46,313 175,421 - Weighted average swap price $ 2.51 $ 2.40 $ - Two - way collars: (1) Hedged volume (MMBtu) 715,661 2,486,514 1,712,250 Weighted average put price $ 3.76 $ 3.18 $ 4.00 Call hedged volume (MMBtu) 435,061 2,306,514 1,712,250 Weighted average call price $ 10.22 $ 5.03 $ 6.29 Three - way collar: Hedged volume (MMBtu) 304,250 - - Weighted average first put price $ 2.20 $ - $ - Weighted average second put price $ 2.50 $ - $ - Weighted average call price $ 3.25 $ - $ - Weighted average deferred premium price $ 0.19 $ - $ - (1) The two - way collars for the fourth quarter of 2022 and first quarter of 2023 include 2x1 collars where the put volumes of 561,200 and 360,000 are two times the call volumes of 280,600 and 180,000, respectively. (2) The WAHA basis swaps in place for the remainder of 2022 consist of five derivative contracts, each with a fixed price of the Henry Hub natural gas price less a fixed amount (weighted average of $0.57 per MMBtu). (3) The WAHA basis swaps in place for the calendar year of 2023 consist of two derivative contracts, each with a fixed price of the Henry Hub natural gas price less a fixed amount (weighted average of $0.55 per MMBtu) 23

www.ringenergy.com NYSE American: REI Income Statement and Operational Stats Income Statement Operational Stats (Unaudited) Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 Oil, Natural Gas, and Natural Gas Liquids Revenues $ 94,408,948 $ 84,961,875 $ 49,376,176 $ 247,551,855 $ 136,638,810 Costs and Operating Expenses Lease operating expenses 13,029,098 8,301,443 6,983,196 30,283,706 22,634,259 Gathering, transportation and processing costs - 549,389 1,051,163 1,846,247 2,883,348 Ad valorem taxes 1,199,385 949,239 703,774 3,100,578 2,144,800 Oil and natural gas production taxes 4,563,519 4,157,457 2,240,759 11,939,338 6,291,860 Depreciation, depletion and amortization 14,324,502 10,749,204 9,310,524 34,854,993 26,693,808 Asset retirement obligation accretion 243,140 186,303 182,905 617,685 560,662 Operating lease expense 83,590 83,590 83,589 250,770 439,896 General and administrative expense (including share - based compensation) 7,393,848 5,832,302 4,433,251 18,748,427 11,103,394 Total Costs and Operating Expenses 40,837,082 30,808,927 24,989,161 101,641,744 72,752,027 Income from Operations 53,571,866 54,152,948 24,387,015 145,910,111 63,886,783 Other Income (Expense) Interest income 4 - - 4 1 Interest expense (7,021,385) (3,279,299) (3,551,462) (13,699,045) (10,947,960) Loss on derivative contracts 32,851,189 (7,457,018) (6,720,320) (2,201,970) (73,586,199) Net Other Expense 25,829,808 (10,736,317) (10,271,782) (15,901,011) (84,534,158) Income (Loss) Before Provision for Income Taxes 79,401,674 43,416,631 14,115,233 130,009,100 (20,647,375) (Provision For) Benefit From Income Taxes (4,315,783) (1,472,209) 48,701 (5,866,744) (141,943) Net Income (Loss) $ 75,085,891 $ 41,944,422 $ 14,163,934 $ 124,142,356 $ (20,789,318) Basic Earnings (Loss) per Share $ 0.65 $ 0.39 $ 0.14 $ 1.16 $ (0.21) Diluted Earnings (Loss) per Share $ 0.49 $ 0.32 $ 0.12 $ 0.92 $ (0.21) Basic Weighted - Average Shares Outstanding 115,376,280 106,390,776 99,358,504 107,349,184 99,251,532 Diluted Weighted - Average Shares Outstanding 151,754,998 130,597,589 121,220,748 134,826,276 99,251,532 (Unaudited) Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 Net sales volumes : Oil (Bbls) 932,770 729,484 659,247 2,338,469 1,971,776 Natural gas (Mcf) 952,762 723,196 594,841 2,408,241 1,773,506 Natural gas liquids (Bbls) (1) 130,052 - - 130,052 - Total oil, natural gas and natural gas liquids (Boe) (1)(2) 1,221,616 850,017 758,387 2,869,895 2,267,360 % Oil 76% 86% 87% 81% 87% Average daily equivalent sales (Boe/d) 13,278 9,341 8,243 10,512 8,305 Average realized sales prices : Oil ($/Bbl) $ 92.64 $ 109.24 $ 69.61 $ 98.16 $ 64.37 Natural gas ($/Mcf) 4.89 7.29 5.86 6.10 5.48 Natural gas liquids ($/Bbls) 25.68 - - 25.68 - Barrel of oil equivalent ($/Boe) $ 77.28 $ 99.95 $ 65.11 $ 86.26 $ 60.26 Average costs and expenses per Boe ( $ /Boe) : Lease operating expenses $ 10.67 $ 9.77 $ 9.21 $ 10.55 $ 9.98 Gathering, transportation and processing costs - 0.65 1.39 0.64 1.27 Ad valorem taxes 0.98 1.12 0.93 1.08 0.95 Oil and natural gas production taxes 3.74 4.89 2.95 4.16 2.77 Depreciation, depletion and amortization 11.73 12.65 12.28 12.15 11.77 Asset retirement obligation accretion 0.20 0.22 0.24 0.22 0.25 Operating lease expense 0.07 0.10 0.11 0.09 0.19 General and administrative expense (including share - based compensation) 6.05 6.86 5.85 6.53 4.90 General and administrative expense (excluding share - based compensation) 4.79 4.63 4.82 4.80 4.24 (1) Beginning July 1, 2022, revenues were reported on a three - stream basis, separately reporting crude oil, natural gas, and nat ural gas liquids volumes and sales. For periods prior to July 1, 2022, volumes and sales for natural gas liquids were presented with natural gas. (2) Boe is determined using the ratio of six Mcf of natural gas to one Bbl of oil (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, natural gas, and natural gas liquids may differ significantly . 24

www.ringenergy.com NYSE American: REI (Unaudited) Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 Cash Flows From Operating Activities Net income (loss) $ 75,085,891 $ 41,944,422 $ 14,163,934 $ 124,142,356 $ (20,789,318) Adjustments to reconcile net income (loss) to net cash provided by operating activities: Depreciation, depletion and amortization 14,324,503 10,749,203 9,310,524 34,854,993 26,693,808 Asset retirement obligation accretion 243,140 186,303 182,905 617,685 560,662 Amortization of deferred financing costs 1,095,073 189,274 166,282 1,483,621 496,533 Share - based compensation 1,543,033 1,899,245 777,461 4,964,188 1,484,730 Deferred income tax (benefit) expense 4,279,047 1,485,022 1,886,118 5,830,008 141,943 Excess tax (benefit) expense related to share - based compensation - - (1,934,819) - - (Gain) Loss on derivative contracts (32,851,189) 7,457,018 6,720,320 2,201,970 73,586,199 Cash (paid) for derivative settlements, net (14,861,116) (19,617,265) (14,921,008) (48,593,882) (33,278,132) Changes in assets and liabilities: Accounts receivable (6,907,079) (4,315,730) 1,656,229 (21,300,907) (5,017,078) Prepaid expenses and other assets (40,823) (2,470,602) 278,870 (2,308,540) (902,692) Accounts payable 27,144,096 4,328,968 (329,555) 33,992,075 8,329,563 Settlement of asset retirement obligation (881,768) (1,113,208) (444,502) (2,548,344) (1,782,779) Net Cash Provided by Operating Activities 68,172,808 40,722,650 17,512,759 133,335,223 49,523,439 Cash Flows From Investing Activities Payments for the Stronghold Acquisition (183,359,626) - - (183,359,626) - Payments to purchase oil and natural gas properties (467,840) (383,003) (141,468) (1,211,691) (579,156) Payments to develop oil and natural gas properties (34,121,878) (35,793,923) (11,957,917) (83,776,050) (34,680,935) Purchase of fixed assets subject to depreciation (66,838) (81,646) (548,730) (158,598) (609,633) Sale of fixed assets subject to depreciation - 126,100 - 134,600 - Proceeds from divestiture of oil and natural gas properties - 25,066 - 25,066 2,000,000 Net Cash Used in Investing Activities (218,016,182) (36,107,406) (12,648,115) (268,346,299) (33,869,724) Cash Flows From Financing Activities Proceeds from revolving line of credit 541,500,000 40,500,000 14,500,000 592,000,000 34,400,000 Payments on revolving line of credit (376,500,000) (50,500,000) (20,000,000) (447,000,000) (52,400,000) Proceeds from issuance of common stock and warrants 2,400,000 5,163,126 - 7,563,126 241,269 Payments to cover tax withholdings (6,790) (257,694) - (264,484) - Proceeds from notes payable 316,677 928,626 323,671 1,245,303 1,233,138 Payments on notes payable (333,341) (253,360) (224,670) (954,082) (375,987) Payment of deferred financing costs (18,762,502) - - (18,762,502) (76,887) Reduction of financing lease liabilities (103,392) (111,864) (86,941) (334,034) (206,936) Net Cash Used in Financing Activities 148,510,652 (4,531,166) (5,487,940) 133,493,327 (17,185,403) Net (Decrease) Increase in Cash (1,332,722) 84,078 (623,296) (1,517,749) (1,531,688) Cash at Beginning of Period 2,223,289 2,139,211 2,670,242 2,408,316 3,578,634 Cash at End of Period $ 890,567 $ 2,223,289 $ 2,046,946 $ 890,567 $ 2,046,946 (Unaudited) September 30, December 31, 2022 2021 ASSETS Current Assets Cash and cash equivalents $ 890,567 $ 2,408,316 Accounts receivable 45,864,400 24,026,807 Joint interest billing receivable 1,897,125 2,433,811 Derivative assets 13,322,013 - Prepaid expenses and other assets 3,246,569 938,029 Total Current Assets 65,220,674 29,806,963 Properties and Equipment Oil and natural gas properties subject to amortization 1,418,931,111 883,844,745 Financing lease asset subject to depreciation 2,067,375 1,422,487 Fixed assets subject to depreciation 2,985,778 2,089,722 Total Properties and Equipment 1,423,984,264 887,356,954 Accumulated depreciation, depletion and amortization (269,541,416) (235,997,307) Net Properties and Equipment 1,154,442,848 651,359,647 Operating lease asset 1,071,482 1,277,253 Derivative assets 11,545,982 - Deferred financing costs 19,029,907 1,713,466 TOTAL ASSETS $ 1,251,310,893 $ 684,157,329 LIABILITIES, MEZZANINE EQUITY AND STOCKHOLDERS' EQUITY Current Liabilities Accounts payable $ 86,822,997 $ 46,233,452 Income tax liability 36,736 - Financing lease liability 406,890 316,514 Operating lease liability 306,715 290,766 Derivative liabilities 23,767,689 29,241,588 Notes payable 877,631 586,410 Deferred cash payment 14,511,687 - Total Current Liabilities 126,730,345 76,668,730 Non - Current Liabilities Deferred income taxes 5,920,300 90,292 Revolving line of credit 435,000,000 290,000,000 Financing lease liability, less current portion 564,205 343,727 Operating lease liability, less current portion 905,524 1,138,319 Derivative liabilities 8,734,388 - Asset retirement obligations 29,426,737 15,292,054 Total Non - Current Liabilities 480,551,154 306,864,392 Total Liabilities 607,281,499 383,533,122 Mezzanine Equity Convertible preferred stock - $0.001 par value; 153,176 shares outstanding 137,858,446 - Stockholders' Equity Preferred stock - $0.001 par value; 50,000,000 shares authorized; 153,176 shares issued or outstanding - - Common stock - $0.001 par value; 225,000,000 shares authorized; 131,586,927 shares and 100,192,562 shares issued and outstanding, respectively 131,587 100,193 Additional paid - in capital 634,845,283 553,472,292 Accumulated deficit (128,805,922) (252,948,278) Total Stockholders' Equity 506,170,948 300,624,207 TOTAL LIABILITIES, MEZZANINE EQUITY AND STOCKHOLDERS' EQUITY $ 1,251,310,893 $ 684,157,329 Balance Sheet and Cash Flow Statement Balance Sheet Cash Flow 25

www.ringenergy.com NYSE American: REI Non - GAAP Disclosure Certain financial information included in Ring’s financial results are not measures of financial performance recognized by ac cou nting principles generally accepted in the United States, or GAAP. These non - GAAP financial measures are “Adjusted Net Income”, “Adjusted EBITDA”, “Free Cash Flow” and “Cash Flow from Operations”. Management uses these non - GAAP financial measu res in its analysis of performance. In addition, Adjusted EBITDA is a key metric used to determine the Company’s incentive compensation awards. These disclosures may not be viewed as a substitute for results determined in accord anc e with GAAP and are not necessarily comparable to non - GAAP performance measures which may be reported by other companies. Adjusted Net Income does not include the estimated after - tax impact of share - based compensation, ceiling test impairment, and un realized loss (gain) on change in fair value of derivatives, as well an add back of the full valuation against the Company’s deferred tax assets during the fourth quarter of 2020. Adjusted Net Income is presented because the timing and amou nt of these items cannot be reasonably estimated and affect the comparability of operating results from period to period, and current periods to prior periods. The Company also presents the non - GAAP financial measures Adjusted EBITDA and Free Cash Flow. The Company defines Adjusted EBITD A as net (loss) income plus net interest expense, unrealized loss on change in fair value of derivatives, ceiling test impairment, income tax (benefit) expense, depreciation, depletion and amortization and accretion, asset retireme nt obligation accretion and share - based compensation. Company management believes this presentation is relevant and useful because it helps investors understand Ring’s operating performance and makes it easier to compare its results with th ose of other companies that have different financing, capital and tax structures. Adjusted EBITDA should not be considered in isolation from or as a substitute for net income, as an indication of operating performance or cash flows from ope rating activities or as a measure of liquidity. Adjusted EBITDA, as Ring calculates it, may not be comparable to Adjusted EBITDA measures reported by other companies. In addition, Adjusted EBITDA does not represent funds available for dis cre tionary use. The Company defines Free Cash Flow as Adjusted EBITDA (defined above) less net interest expense (excluding amortization of de fer red financing cost) and capital expenditures. For this purpose, the Company’s definition of capital expenditures includes costs incurred related to oil and natural gas properties (such as drilling and infrastructure costs and the lease ma int enance costs) and equipment, furniture and fixtures, but excludes acquisition costs of oil and gas properties from third parties that are not included in the Company’s capital expenditures guidance provided to investors. Company management believ es that Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of its current operating activities after the impact of accrued capital expenditures and net interest expense and wit hout being impacted by items such as changes associated with working capital, which can vary substantially from one period to another. There is no commonly accepted definition for Free Cash Flow within the industry. Accordingly, Free Cash Fl ow, as defined and calculated by the Company, may not be comparable to Free Cash Flow or other similarly named non - GAAP measures reported by other companies. While the Company includes net interest expense in the calculation of Free Cash F low, other mandatory debt service requirements of future payments of principal at maturity (if such debt is not refinanced) are excluded from the calculation of Free Cash Flow. These and other non - discretionary expenditures that are not deducted from Free Cash Flow would reduce cash available for other uses. PV - 10 is a measure not prepared in accordance with GAAP that differs from a measure under GAAP known as “standardized measure of discounted future net cash flows” in that PV - 10 is calculated without including future income taxes. Management believes that the presentation of the PV - 10 value of our oil and natural gas properties is relevant and useful to inv estors because it presents the estimated discounted future net cash flows attributable to our estimated proved reserves independent of our income tax attributes, thereby isolating the intrinsic value of the estimated future cash flows a ttr ibutable to our reserves. We believe the use of a pre - tax measure provides greater comparability of assets when evaluating companies because the timing and quantification of future income taxes is dependent on company - specific factors, many of which are difficult to determine. For these reasons, management uses and believes that the industry generally uses the PV - 10 measure in evaluating and comparing acquisition candidates and assessing the potential rate of return o n investments in oil and natural gas properties. PV - 10 does not necessarily represent the fair market value of oil and natural gas properties. PV - 10 is not a measure of financial or operational performance under GAAP, nor should it be consider ed in isolation or as a substitute for the standardized measure of discounted future net cash flows as defined under GAAP. The Company also presents the non - GAAP financial measure Cash Flow from Operations. The Company defines Cash Flow from Operation s as Net Cash Provided by Operating Activities plus Changes in operating assets and liabilities. The table below provides a reconciliation of PV - 10 to the standardized measure of discounted future net cash flows as of Decembe r 31, 2021. 26

www.ringenergy.com NYSE American: REI Non - GAAP Reconciliations Adjusted Net Income Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 (Unaudited for All Periods) Net Income (Loss) $ 75,085,891 $ 41,944,422 $ 14,163,934 $ 124,142,356 $ (20,789,318) Share - based compensation 1,543,033 1,899,245 777,461 4,964,188 1,484,730 Unrealized loss (gain) on change in fair value of derivatives (47,712,305) (12,160,247) (8,200,688) (46,391,912) 40,308,067 Transaction costs - Stronghold Acquisition 1,142,963 - - 1,142,963 - Tax impact of adjusted items 2,447,351 (347,939) - 1,817,876 - Adjusted Net Income $ 32,506,933 $ 31,335,481 $ 6,740,707 $ 85,675,471 $ 21,003,479 Basic Weighted - Average Shares Outstanding 115,376,280 106,390,776 99,358,504 107,349,184 99,251,532 Adjusted Net Income per Share $ 0.28 $ 0.29 $ 0.07 $ 0.80 $ 0.21 Adjusted EBITDA Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 (Unaudited for All Periods) Net Income (Loss) $ 75,085,891 $ 41,944,422 $ 14,163,934 $ 124,142,356 $ (20,789,318) Interest expense, net 7,021,381 3,279,299 3,551,462 13,699,041 10,947,959 Unrealized loss (gain) on change in fair value of derivatives (47,712,305) (12,160,247) (8,200,688) (46,391,912) 40,308,067 Income tax provision (benefit) 4,315,783 1,472,209 (48,701) 5,866,744 141,943 Depreciation, depletion and amortization 14,324,502 10,749,204 9,310,524 34,854,993 26,693,808 Asset retirement obligation accretion 243,140 186,303 182,905 617,685 560,662 Transaction costs - Stronghold Acquisition 1,142,963 - - 1,142,963 - Share - based compensation 1,543,033 1,899,245 777,461 4,964,188 1,484,730 Adjusted EBITDA $ 55,964,388 $ 47,370,435 $ 19,736,897 $ 138,896,058 $ 59,347,851 Adjusted EBITDA Margin 59% 56% 40% 56% 43% Basic Weighted - Average Shares Outstanding 115,376,280 106,390,776 99,358,504 107,349,184 99,251,532 Adjusted EBITDA per Share $ 0.49 $ 0.45 $ 0.20 $ 1.29 $ 0.60 Free Cash Flow Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 (Unaudited for All Periods) Adjusted EBITDA $ 55,964,388 $ 47,370,435 $ 19,736,897 $ 138,896,058 $ 59,347,851 Net interest expense (excluding amortization of deferred financing costs) (5,926,308) (3,090,025) (3,385,180) (12,215,420) (10,451,426) Capital expenditures (1) (40,295,388) (41,810,442) (13,720,336) (110,245,399) (39,701,834) Proceeds from divestiture of oil and natural gas properties - 25,066 - 25,066 2,000,000 Free Cash Flow $ 9,742,692 $ 2,495,034 $ 2,631,381 $ 16,460,305 $ 11,194,591 (1) The three and nine months ended September 30, 2022 excludes the Stronghold acquisition. Cash Flow From Operations Three Months Ended Nine Months Ended September 30, June 30, September 30, September 30, 2022 2022 2021 2022 2021 (Unaudited for All Periods) Net Cash Provided by Operating Activities $ 68,172,808 $ 40,722,650 $ 17,512,759 $ 133,335,223 $ 49,523,439 Changes in operating assets and liabilities (19,314,426) 3,570,572 (1,161,042) (7,834,284) (627,014) Cash Flow from Operations $ 48,858,382 $ 44,293,222 $ 16,351,717 $ 125,500,939 $ 48,896,425 27

www.ringenergy.com NYSE American: REI 50% 41% 9% D,C&E Recomp/CTRs/Cap Workovers Land/Non-op CAPEX Allocation Mid Point $44 million Q4 2022 Guidance Grow Production, Generate FCF, Pay Down Debt Sales Volumes Total (Boe/d) 18,000 – 19,000 Oil (Bo/d) ~70% 12,600 – 13,300 Gas (Mcf/d) ~17% 18,400 – 19,400 NGLs (Bbls/d) ~ 13% 2,300 – 2,500 Capital Spending Capital spending 1 (millions) $42 – $46 New Horizontal (Hz) wells drilled 4 New Vertical wells drilled 4 – 5 New Hz wells completed and online 7 New Vertical wells completed and online 2 – 3 Operating Expenses LOE (per Boe) $10.25 – $11.40 1. In addition to Company - directed drilling and completion activities, the capital spending outlook includes funds for targeted wel l reactivations, recompletions, workovers, infrastructure upgrades, and continuing the Company's successful CTR program in its NWS and CBP areas. Also included is anticipated spending for lease costs, contractual drilling ob ligations and non - operated drilling, completion and capital workovers. 28

www.ringenergy.com NYSE American: REI Add Photo Add Photo Add Photo Add Photo Add Photo Paul D. McKinney Chairman & Chief Executive Officer 39+ years of domestic & international oil & gas industry experience Executive & board roles include CEO, President, COO, Region VP and public & private board directorships Travis Thomas EVP & Chief Financial Officer 17+ years of oil & gas industry experience & accounting experience High level financial experience including CAO, VP Finance, Controller, Treasurer Alexander Dyes EVP of Engineering & Corporate Strategy 15+ years of oil & gas industry experience Multi - disciplined experience including VP A&D, VP Engineering, Director Strategy, multiple engineering & operational roles Marinos Baghdati EVP of Operations 19+ years of oil & gas industry experience Operational experience in drilling, completions and production including VP Operations, Operations manager, multiple engineering roles Stephen D. Brooks EVP of Land, Legal, HR & Marketing 45+ years of oil & gas industry experience Extensive career as landman including VP Land & Legal, VP HR VP Land and Land Manager Hollie Lamb VP of Compliance & GM of Midland Office 20+ years of oil & gas industry experience Previously Partner of HeLMS Oil & Gas, VP Engineering, Reservoir & Geologic Engineer Experienced Management Team Shared Vision with a Track Record of Success 29

www.ringenergy.com NYSE American: REI Paul D. McKinney Chairman & Chief Executive Officer 35+ years of domestic & international oil & gas industry experience Executive & board roles include CEO, President, COO, Region VP and public & private board directorships Anthony D. Petrelli Lead Independent Director 43+ years of banking, capital markets, governance & financial experience Executive and Board positions include CEO, President, multiple board chairs & directorships Refreshed Board of Directors Accomplished and Diversified Experience Roy I. Ben - Dor Director 14+ years of finance & capital markets experience Extensive financial and capital markets acumen and experience including Managing Director and numerous Board Director positions David S. Habachy Independent Director 24+ years of oil & gas industry, finance & capital markets experience Wide range of operations, engineering, financial and capital markets roles and experience including Managing Director and numerous Board Director positions John A. Crum Independent Director 45+ years of domestic & international oil & gas industry experience Extensive executive roles including CEO, President & COO, and multiple public & private board chairs & directorships Richard E. Harris Independent Director 40+ years of experience across multiple industries Executive positions in oil & gas, industrial equipment, and technology including CIO, Treasurer, Finance and Business Development Thomas L. Mitchell Independent Director 35+ years of domestic & international oil & gas industry experience Executive & board roles include CFO, VP Accounting, Controller and public & private board directorships Regina Roesener Independent Director 35+ years of banking, capital markets, governance & financial experience Executive and Board positions including COO, director and Board Director positions Clayton E. Woodrum Independent Director 50+ years of accounting, tax & finance experience Wide range of financial acumen including positions as CFO, Partner in Charge and Board Director positions 30

www.ringenergy.com NYSE American: REI PD 60% PUD 40% 1P Summary Reserve Category Net Oil, MBbl Net Gas, MMcf Net MBOE Net Capex 2 , $MM PV - 10 3 , $MM PD 36,821 39,749 43,446 $55 $794 PUD 29,018 32,025 34,355 $293 $538 TOTAL 65,839 71,774 77,801 $348 $1,332 SEC Proved Reserves 1 Year - End 2021 2021 SEC Pricing Reserves by Category ( % ) Reserves by PV 10 ( $ MM) Reserves by Product Oil/$ Bbl $63.04 Gas $/ Mmbtu $3.598 Oil 85% Gas 15% PD 56% PUD 44% 1) Based on Cawley, Gillespie & Associates YE 2021 SEC Proved Reserve report 2) Net capex includes P&A 3) PV10 is reconciled in Non - GAAP disclosure 31

www.ringenergy.com NYSE American: REI Corporate Strategy Value Focused for Sustainable Success Attract and Retain Highly Qualified People Pursue Operational Excellence with a Sense of Urgency Invest in High - Margin, High RoR Projects Focus on FCF and Strengthen Balance Sheet Pursue Strategic A&D to Lower Breakeven Costs 32

ANALYST COVERAGE Alliance Global Partners (A.G.P.) Jeff Campbell (203) 577 - 5427 jcampbell@allianceg.com Tuohy Brothers Investment Noel Parks (215) 913 - 7320 nparks@tuohybrothers.com ROTH Capital Partners John M. White (949) 720 - 7115 jwhite@roth.com Truist Financial Neal Dingmann (713) 247 - 9000 neal.dingmann@truist.com COMPANY CONTACT Al Petrie (281) 975 - 2146 apetrie@ringenergy.com Chris Delange (281) 975 - 2146 cdelange @ringenergy.com