8-K
Ring Energy, Inc. (REI)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_____________________________________________________________________________________________________________________________________________________________________________
FORM 8-K
_____________________________________________________________________________________________________________________________________________________________________________
CURRENT REPORT
Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
Date of Report: May 7, 2025
(Date of earliest event reported)
______________________________________________________________________________________
RING ENERGY, INC.
(Exact name of registrant as specified in its charter)
_______________________________________________________________________________________________________
| Nevada | 001-36057 | 90-0406406 |
|---|---|---|
| (State or other jurisdiction of incorporation) | (Commission File Number) | (IRS Employer Identification No.) |
1725 Hughes Landing Blvd., Suite 900
The Woodlands, TX 77380
(Address of principal executive offices) (Zip Code)
(281) 397-3699
(Registrant’s telephone number, including area code)
Not Applicable.
(Former name or former address, if changed since last report)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
| ☐ | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) | |||
|---|---|---|---|---|
| ☐ | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) | |||
| --- | --- | ☐ | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) | |
| --- | --- | ☐ | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) | |
| --- | --- |
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
|---|---|---|
| Common Stock, $0.001 par value | REI | NYSE American |
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
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. ☐
Item 2.02 Results of Operations and Financial Condition.
On May 7, 2025, Ring Energy, Inc. (the “Company”) issued a press release announcing its financial and operating results for the first quarter ended March 31, 2025. A copy of the press release is furnished herewith as Exhibit 99.1.
The information in this Current Report on Form 8-K furnished pursuant to Item 2.02, including Exhibit 99.1, shall not be deemed to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to liability under that section, and they shall not be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.
Item 7.01 Regulation FD Disclosure.
On May 8, 2025, the Company posted to its website a company presentation (the “Presentation Materials”) that management intends to use from time to time. The Company may use the Presentation Materials, possibly with modifications, in presentations to current and potential investors, lenders, creditors, vendors, customers and others with an interest in the Company and its business.
The information contained in the Presentation Materials is summary information that should be considered in the context of the Company’s filings with the Securities and Exchange Commission and other public announcements that the Company may make by press release or otherwise from time to time. The Presentation Materials speak as of the date of this Current Report on Form 8-K. While the Company may elect to update the Presentation Materials in the future or reflect events and circumstances occurring or existing after the date of this Current Report on Form 8-K, the Company specifically disclaims any obligation to do so. The Presentation Materials are furnished herewith as Exhibit 99.2 to this Current Report on Form 8-K and are incorporated herein by reference.
The information in this Current Report on Form 8-K furnished pursuant to Item 7.01, including Exhibit 99.2, shall not be deemed to be “filed” for the purposes of Section 18 of the Exchange Act, or otherwise subject to liability under that section, and they shall not be deemed incorporated by reference in any filing under the Securities Act or the Exchange Act, except as shall be expressly set forth by specific reference in such filing. By filing this Current Report on Form 8-K and furnishing this information pursuant to Item 7.01, the Company makes no admission as to the materiality of any information in this Current Report on Form 8-K, including Exhibit 99.2, that is required to be disclosed solely by Regulation FD.
Item 9.01 Financial Statements and Exhibits.
(d) Exhibits.
The following exhibits are included with this Current Report on Form 8-K:
| Exhibit No. | Description |
|---|---|
| 99.1 | Press Release dated May 7, 2025 |
| 99.2 | Presentation Materials dated May 8, 2025 |
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document). |
SIGNATURE
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 hereunto duly authorized.
| RING ENERGY, INC. | |||
|---|---|---|---|
| Date: | May 9, 2025 | By: | /s/ Travis T. Thomas |
| Travis T. Thomas | |||
| Chief Financial Officer |
Document
Exhibit 99.1
RING ENERGY ANNOUNCES FIRST QUARTER 2025 RESULTS AND PROVIDES UPDATED 2025 OUTLOOK
The Woodlands, TX – May 7, 2025 – Ring Energy, Inc. (NYSE American: REI) (“Ring” or the “Company”) today reported operational and financial results for first quarter 2025 and provided updated guidance for the second half of the year.
First Quarter 2025 Highlights
•Sold 12,074 barrels of oil per day (“Bo/d”) (> high end of guidance) and 18,392 barrels of oil equivalent per day (“Boe/d”) (> mid point of guidance);
•Reported net income of $9.1 million, or $0.05 per diluted share, and Adjusted Net Income1 of $10.7 million, or $0.05 per diluted share;
•Recorded Adjusted EBITDA1 of $46.4 million and Lease Operating Expense (“LOE”) of $11.89 per Boe (< mid point of guidance);
•Invested $32.5 million in capital expenditures (within guidance, excluding acquisitions) that was 14% lower than 4Q 2024
•Generated Adjusted Cash Flow from Operations1 of $38.2 million and Adjusted Free Cash Flow (“AFCF”)1 of $5.8 million;
•Remained cash flow positive for the 22nd consecutive quarter and had liquidity of $141.1 million at the end of the period;
•Completed highly-accretive acquisition of Central Basin Platform (“CBP”) assets from Lime Rock Resources IV, LP (“Lime Rock’) on March 31, 2025 with operations to date exceeding expectations; and
•Provided updated guidance for the remainder of 2025, which reflects more than a 47% decrease in capital spending from original guidance for time period 2Q to 4Q 2025.
Management Commentary
Mr. Paul D. McKinney, Chairman of the Board and Chief Executive Officer, commented, “We’re excited to kick off 2025 with a strong first quarter, showcasing the flexibility, resilience, and strength of our proven, value-focused strategy amid fluctuating oil prices. Our performance met or surpassed all guidance targets, driven by exceptional oil sales volumes. As shared earlier, this success stemmed from the outperformance of our newly drilled wells and the tireless dedication of our operations team, who kept our PDP assets running at peak efficiency. On the final day of the quarter, we closed the highly accretive acquisition of Lime Rock’s CBP assets, which are outperforming the forecasts originally used to value them, adding more value to our portfolio. To set the stage for this synergistic transaction, we strategically adjusted the timing of our drilling program and capital spending initiatives, optimizing our financial position and reinforcing our balance sheet. With this strong foundation, we’re poised to continue delivering value to our stockholders despite the uncertainties currently facing our industry.”
Mr. McKinney concluded, “We have been looking forward to sharing more about our proactive approach to navigating the recent dip in oil prices, showcasing the strength of our value-focused strategy. As previously announced, we’ve strategically reduced our second quarter capital spending by over 50%, while maintaining our sales volume guidance. Looking ahead, our updated full-year guidance reflects a 36% reduction in capital spending with only a 5% reduction to sales volumes, made possible by the exceptional performance of both our existing and newly acquired assets so far this year. This represents a 2% increase of year-over-year total sales. Should oil prices rise later in the year, we’re positioned to accelerate our debt reduction efforts, channeling the
1 A non-GAAP financial measure; see the “Non-GAAP Financial Information” section in this release for more information including reconciliations to the most comparable GAAP measures.
benefits of higher prices into strengthening our balance sheet. This disciplined approach highlights our proven strategy. We’re committed to delivering value for our stockholders and are deeply grateful for your trust and investment in Ring Energy as we build a brighter, more resilient future together.”
Summary Results and Additional Key Items
| Q1 2025 | Q4 2024 | Q1 2025 to Q4 2024 % Change | Q1 2024 | Q1 2025 to Q1 2024 % Change | |
|---|---|---|---|---|---|
| Average Daily Sales Volumes (Boe/d) | 18,392 | 19,658 | (6)% | 19,034 | (3)% |
| Crude Oil (Bo/d) | 12,074 | 12,916 | (7)% | 13,394 | (10)% |
| Net Sales (MBoe) | 1,655.3 | 1,808.5 | (8)% | 1,732.1 | (4)% |
| Realized Price - All Products ($/Boe) | $47.78 | $46.14 | 4% | $54.56 | (12)% |
| Realized Price - Crude Oil ($/Bo) | $70.40 | $68.98 | 2% | $75.72 | (7)% |
| Revenues ($MM) | $79.1 | $83.4 | (5)% | $94.5 | (16)% |
| Net Income ($MM) | $9.1 | $5.7 | 60% | $5.5 | 65% |
| Adjusted Net Income1 ($MM) | $10.7 | $12.3 | (13)% | $20.3 | (47)% |
| Adjusted EBITDA1 ($MM) | $46.4 | $50.9 | (9)% | $62.0 | (25)% |
| Capital Expenditures ($MM) | $32.5 | $37.6 | (14)% | $36.3 | (10)% |
| Adjusted Free Cash Flow1 ($MM) | $5.8 | $4.7 | 23% | $15.6 | (63)% |
Adjusted Net Income, Adjusted EBITDA, and Adjusted Free Cash Flow are non-GAAP financial measures, which are described in more detail and reconciled to the most comparable GAAP measures, in the tables shown later in this release under “Non-GAAP Financial Information.” In addition, see section titled “Condensed Operating Data” for additional details concerning costs and expenses discussed below.
Sales volumes for 1Q 2025 were 18,392 Boe/d (66% oil, 18% natural gas liquids (“NGLs”) and 16% natural gas) versus 4Q 2024 sales volumes of 19,658 Boe/d (66% oil, 19% NGLs and 15% natural gas) and 1Q 2024 sales volumes of 19,034 Boe/d (70% oil, 15% NGLs and 15% natural gas).
Average realized sales prices for 1Q 2025 were $70.40 per barrel of crude oil, $(0.19) per Mcf of natural gas, and $9.65 per barrel of NGLs. The realized natural gas and NGL prices were impacted by increased fees resulting in lower realized prices. The weighted average natural gas price per Mcf was $1.86 and the weighted average fee per Mcf was $(2.05); the weighted average NGL price per barrel was $22.64 offset by a weighted average fee per barrel of $(12.99). The weighted average natural gas price for 1Q 2025 reflects continued natural gas product takeaway constraints, which are being alleviated through additional third-party pipeline capacity. The average oil price differential the Company experienced from NYMEX WTI ("West Texas Intermediate") futures pricing in 1Q 2025 was a negative $0.89 per barrel of crude oil, while the average natural gas price differential from NYMEX futures pricing was a negative $3.81 per Mcf.
Revenues were $79.1 million for 1Q 2025 compared to $83.4 million for 4Q 2024 and $94.5 million for 1Q 2024. The 5% decrease in 1Q 2025 revenues from 4Q 2024 was driven by a negative $7.3 million volume variance offset by a positive $3.0 million price variance.
Select Expenses and Other Items
| Q1 2025 | Q4 2024 | Q1 2025 to Q4 2024 % Change | Q1 2024 | Q1 2025 to Q1 2024 % Change | |
|---|---|---|---|---|---|
| Lease operating expenses (“LOE”) ($MM) | $19.7 | $20.3 | (3)% | $18.4 | 7% |
| Lease operating expenses ($/BOE) (1) | $11.89 | $11.24 | 6% | $10.60 | 12% |
| Depreciation, depletion and amortization ($MM) | $22.6 | $24.5 | (8)% | $23.8 | (5)% |
| Depreciation, depletion and amortization ($/BOE) | $13.66 | $13.57 | 1% | $13.74 | (1)% |
| General and administrative expenses (“G&A”) ($MM) | $8.6 | $8.0 | 8% | $7.5 | 15% |
| General and administrative expenses ($/BOE) | $5.21 | $4.44 | 17% | $4.31 | 21% |
| G&A excluding share-based compensation ($MM) | $6.9 | $6.4 | 8% | $5.7 | (21)% |
| G&A excluding share-based compensation ($/BOE) | $4.19 | $3.52 | 19% | $3.32 | 26% |
| G&A excluding share-based compensation & transaction costs ($MM) | $6.9 | $6.3 | 10% | $5.7 | 21% |
| G&A excluding share-based compensation & transaction costs ($/BOE) | $4.18 | $3.51 | 19% | $3.32 | 26% |
| Interest expense ($MM) (2) | $9.5 | $10.1 | (6)% | $11.5 | (17)% |
| Interest expense ($/BOE) | $5.74 | $5.59 | 3% | $6.64 | (14)% |
| Gain (loss) on derivative contracts ($MM) (3) | $(0.9) | $(6.3) | 85% | $(19.0) | 95% |
| Realized gain (loss) on derivative contracts ($MM) | $(0.5) | $0.7 | (171)% | $(1.4) | 64% |
| Unrealized gain (loss) on derivative contracts ($MM) | $(0.4) | $(7.0) | 94% | $(17.6) | 98% |
(1) LOE was within the Company’s guidance of $11.75 to $12.25 per Boe for 1Q 2025.
(2) The decline in interest expense from prior quarters was due to lower interest rates and reduced borrowings on the credit facility.
(3) A summary listing of the Company’s outstanding derivative positions at March 31, 2025 is included in the tables shown later in this release. For the remainder (April through December) of 2025, the Company has approximately 1.7 million barrels of oil (approximately 47% of oil sales guidance midpoint) hedged at an average downside protection price of $64.44 and approximately 2.0 billion cubic feet of natural gas (approximately 37% of natural gas sales guidance midpoint) hedged at an average downside protection of $3.43.
Capital Investment
During 1Q 2025, capital expenditures for the Company’s drilling and development activities were $32.5 million, which was within the Company’s guidance of $26 million to $34 million. Ring also invested approximately $70.9 million for the Lime Rock Acquisition that closed on March 31, 2025 (including the $63.6 million cash payment at closing, the $5.0 million deposit payment made in February, and $2.3 million in direct transaction costs).
Drilling and Development
Ring drilled, completed, and placed on production seven wells. In the Northwest Shelf in Yoakum County, Ring drilled and completed three 1-mile horizontal wells and one 1.25-mile horizontal well, all with a working interest of 75%. In the CBP in Ector County, the Company drilled and completed three vertical wells, all with a working interest of 100%.
| Quarter | Area | Wells Drilled | Wells Completed |
|---|---|---|---|
| 1Q 2025 | Northwest Shelf (Horizontal) | 4 | 4 |
| Central Basin Platform (Horizontal) | — | — | |
| Central Basin Platform (Vertical) | 3 | 3 | |
| Total | 7 | 7 |
Acquisition - CBP Assets of Lime Rock
During 1Q 2025, Ring completed the acquisition of CBP assets from Lime Rock. Those properties are located in the Permian Basin in Andrews County, Texas, and are focused on the development of approximately 17,700 net acres where the majority are similar to Ring’s existing CBP assets in the Shafter Lake area, and the remaining acreage exposes the Company to new active plays.
The key transaction highlights include:
•Highly Accretive: ~2,300 Boe/d (>75% oil) of low-decline net production from ~101 gross wells;
•Increased Scale and Operational Synergies: ~17,700 net acres (100% HBP) mostly contiguous to Ring’s existing footprint;
•Meaningful AFCF Generation: Supported by $121 million of oil-weighted reserves (based on NYMEX strip pricing as of February 19, 2025; and
•Strengthens High-Return Inventory Portfolio: >40 gross locations that immediately compete for capital.
After taking into account preliminary purchase price adjustments, consideration for the acquisition consisted of:
•A cash payment of approximately $63.6 million net of the $5.0 million deposit payment made in February;
•$10.0 million deferred cash payment due on or about December 31, 2025; and
•The issuance of approximately 6.5 million shares of common stock.
The cash payment at closing on March 31, 2025 was funded with cash on hand and borrowings under Ring’s senior revolving credit facility.
Balance Sheet and Liquidity
Total liquidity (defined as cash and cash equivalents plus borrowing base availability under the Company’s credit facility) at March 31, 2025 was approximately $141.1 million, consisting of $140.0 million of availability under Ring’s revolving credit facility, which included a reduction of $35 thousand for letters of credit, and $1.1 million in cash and cash equivalents. On March 31, 2025, the Company had $460 million in borrowings outstanding on its credit facility that has a current borrowing base of $600 million and reflects the draw on the revolving credit facility to fund the Lime Rock Acquisition. The Company is targeting continued debt reduction, dependent on market conditions, the timing and level of capital spending, and other considerations.
Second Half of 2025 Sales Volumes, Capital Investment and Operating Expense Guidance
Ring’s 2025 development program has been updated to reflect a reduction in capital spending in response to the weakened price environment. For full year 2025, Ring now expects total capital spending of $85 million to $113 million (versus $138 million to $170 million previously disclosed). In addition to wells that the Company plans to drill and complete, the full year capital spending program includes funds for targeted well recompletions, capital workovers, infrastructure upgrades, reactivations, and leasing costs, as well as non-operated drilling, completion, capital workovers, and facility improvements.
All projects and estimates are based on assumed WTI oil prices of $50 to $70 per barrel and Henry Hub prices of $3.00 to $4.00 per Mcf. As in the past, Ring has designed its spending program with flexibility to respond to changes in commodity prices and other market conditions as appropriate.
Based on the $99 million midpoint of spending guidance, the Company continues to expect the following estimated allocation of capital, including:
•61% for drilling, completion, and related infrastructure;
•33% for recompletions and capital workovers;
•4% for facility improvements (environmental and emission reducing upgrades); and
•2% for land, non-operated capital, and other.
The guidance in the table below represents the Company's current good faith estimate of the range of likely future results. Guidance could be affected by the factors discussed below in the "Safe Harbor Statement" section.
| Q2 | 2H | |
|---|---|---|
| 2025 | 2025 | |
| Sales Volumes: | ||
| Total Oil (Bo/d) | 13,700 – 14,700 | 12,500 - 14,000 |
| Midpoint (Bo/d) | 14,200 | 13,250 |
| Total (Boe/d) | 20,500 – 22,500 | 19,000 - 21,000 |
| Midpoint (Boe/d) | 21,500 | 20,000 |
| Oil (%) | 66% | 66% |
| NGLs (%) | 18% | 18% |
| Gas (%) | 16% | 16% |
| Capital Program: | ||
| Capital spending(1) (millions) | $14 - $22 | $38 - $58 |
| Midpoint (millions) | $18 | $48 |
| New Hz and vertical wells (2) | 2 - 3 | 11 - 13 |
| Recompletions and CTRs | 6 - 8 | 17 - 22 |
| Operating Expenses: | ||
| LOE (per Boe) | $11.50 - $12.50 | $11.50 - $12.50 |
| Midpoint (per Boe) | $12.00 | $12.00 |
(1) In addition to Company-directed drilling and completion activities, the capital spending outlook includes funds for targeted well recompletions, capital workovers, infrastructure upgrades, and well reactivations. Also included is anticipated spending for leasing acreage; and non-operated drilling, completion, capital workovers, and facility improvements.
(2) Includes wells drilled, completed, and placed online.
Conference Call Information
Ring will hold a conference call on Thursday, May 8, 2025 at 12:00 p.m. ET (11 a.m. CT) to discuss its 1Q 2025 operational and financial results. An updated investor presentation will be posted to the Company’s website prior to the conference call.
To participate in the conference call, interested parties should dial 833-953-2433 at least five minutes before the call is to begin. Please reference the “Ring Energy 1Q 2025 Earnings Conference Call”. International callers may participate by dialing 412-317-5762. The call will also be webcast and available on Ring’s website at www.ringenergy.com under “Investors” on the “News & Events” page. An audio replay will also be available on the Company’s website following the call.
About Ring Energy, Inc.
Ring Energy, Inc. is an oil and gas exploration, development, and production company with current operations focused on the development of its Permian Basin assets. For additional information, please visit www.ringenergy.com.
Safe Harbor Statement
This release 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. Forward-looking statements involve a wide variety of risks and uncertainties, and include, without limitation, statements with respect to the Company’s strategy and prospects. The forward-looking statements include statements about the expected future reserves, production, financial position, business strategy, revenues, earnings, costs, capital expenditures and debt levels of the Company, expected benefits to the Company and its stockholders from the Lime Rock Acquisition, and plans and objectives of management for future operations. Forward-looking statements also include assumptions and projections for second quarter and full year 2025 guidance for sales volumes, oil mix as a percentage of total sales, capital expenditures, operating expenses and the projected impacts thereon, and the number of wells expected to be drilled and completed. Forward-looking statements are based on current expectations and assumptions and analyses made by Ring and its management in light of their experience and perception of historical trends, current conditions and expected future developments, as well as other factors appropriate under the circumstances. However, whether actual results and developments will conform to expectations is subject to a number of material risks and uncertainties, including but not limited to: declines in oil, natural gas liquids or natural gas prices; the level of success in exploration, development and production activities; adverse weather conditions that may negatively impact development or production activities particularly in the winter; the timing of exploration and development expenditures; inaccuracies of reserve estimates or assumptions underlying them; revisions to reserve estimates as a result of changes in commodity prices; impacts to financial statements as a result of impairment write-downs; risks related to level of indebtedness and periodic redeterminations of the borrowing base and interest rates under the Company’s credit facility; Ring’s ability to generate sufficient cash flows from operations to meet the internally funded portion of its capital expenditures budget; the impacts of hedging on results of operations; changes in U.S. energy, environmental, monetary and trade policies, including with respect to tariffs or other trade barriers, and any resulting trade tensions; cost and availability of transportation and storage capacity as a result of oversupply, government regulation or other factors; and Ring’s ability to replace oil and natural gas reserves. Such statements are subject to certain risks and uncertainties which are disclosed in the Company’s reports filed with the Securities and Exchange Commission (“SEC”), including its Form 10-K for the fiscal year ended December 31, 2024, and its other SEC filings. Ring undertakes no obligation to revise or update publicly any forward-looking statements, except as required by law.
Contact Information
Al Petrie Advisors
Al Petrie, Senior Partner
Phone: 281-975-2146 Email: apetrie@ringenergy.com
RING ENERGY, INC.
Condensed Statements of Operations
(Unaudited)
| Three Months Ended | ||||||
|---|---|---|---|---|---|---|
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| Oil, Natural Gas, and Natural Gas Liquids Revenues | $ | 79,091,207 | $ | 83,440,546 | $ | 94,503,136 |
| Costs and Operating Expenses | ||||||
| Lease operating expenses | 19,677,552 | 20,326,216 | 18,360,434 | |||
| Gathering, transportation and processing costs | 203,612 | 130,230 | 166,054 | |||
| Ad valorem taxes | 1,532,108 | 2,421,595 | 2,145,631 | |||
| Oil and natural gas production taxes | 3,584,455 | 3,857,147 | 4,428,303 | |||
| Depreciation, depletion and amortization | 22,615,983 | 24,548,849 | 23,792,450 | |||
| Asset retirement obligation accretion | 326,549 | 323,085 | 350,834 | |||
| Operating lease expense | 175,091 | 175,090 | 175,091 | |||
| General and administrative expense | 8,619,976 | 8,035,977 | 7,469,222 | |||
| Total Costs and Operating Expenses | 56,735,326 | 59,818,189 | 56,888,019 | |||
| Income from Operations | 22,355,881 | 23,622,357 | 37,615,117 | |||
| Other Income (Expense) | ||||||
| Interest income | 90,058 | 124,765 | 78,544 | |||
| Interest (expense) | (9,498,786) | (10,112,496) | (11,498,944) | |||
| Gain (loss) on derivative contracts | (928,790) | (6,254,448) | (19,014,495) | |||
| Gain (loss) on disposal of assets | 124,610 | — | 38,355 | |||
| Other income | 8,942 | 80,970 | 25,686 | |||
| Net Other Income (Expense) | (10,203,966) | (16,161,209) | (30,370,854) | |||
| Income Before Benefit from (Provision for) Income Taxes | 12,151,915 | 7,461,148 | 7,244,263 | |||
| Benefit from (Provision for) Income Taxes | (3,041,177) | (1,803,629) | (1,728,886) | |||
| Net Income (Loss) | $ | 9,110,738 | $ | 5,657,519 | $ | 5,515,377 |
| Basic Earnings (Loss) per Share | $ | 0.05 | $ | 0.03 | $ | 0.03 |
| Diluted Earnings (Loss) per Share | $ | 0.05 | $ | 0.03 | $ | 0.03 |
| Basic Weighted-Average Shares Outstanding | 199,314,182 | 198,166,543 | 197,389,782 | |||
| Diluted Weighted-Average Shares Outstanding | 201,072,594 | 200,886,010 | 199,305,150 |
RING ENERGY, INC.
Condensed Operating Data
(Unaudited)
| December 31, | March 31, | |||||||
| 2024 | 2024 | |||||||
| Net sales volumes: | ||||||||
| Oil (Bbls) | 1,188,272 | 1,218,837 | ||||||
| Natural gas (Mcf) | 1,683,793 | 1,496,507 | ||||||
| Natural gas liquids (Bbls) | 339,589 | 263,802 | ||||||
| Total oil, natural gas and natural gas liquids (Boe)(1) | 1,808,493 | 1,732,057 | ||||||
| % Oil | % | 66 | % | 70 | % | |||
| % Natural Gas | % | 15 | % | 15 | % | |||
| % Natural Gas Liquids | % | 19 | % | 15 | % | |||
| Average daily sales volumes: | ||||||||
| Oil (Bbls/d) | 12,916 | 13,394 | ||||||
| Natural gas (Mcf/d) | 18,302 | 16,445 | ||||||
| Natural gas liquids (Bbls/d) | 3,691 | 2,899 | ||||||
| Average daily equivalent sales (Boe/d) | 19,658 | 19,034 | ||||||
| Average realized sales prices: | ||||||||
| Oil (/Bbl) | 70.40 | $ | 68.98 | $ | 75.72 | |||
| Natural gas (/Mcf) | (0.96) | (0.55) | ||||||
| Natural gas liquids (/Bbls) | 9.08 | 11.47 | ||||||
| Barrel of oil equivalent (/Boe) | 47.78 | $ | 46.14 | $ | 54.56 | |||
| Average costs and expenses per Boe (/Boe): | ||||||||
| Lease operating expenses | 11.89 | $ | 11.24 | $ | 10.60 | |||
| Gathering, transportation and processing costs | 0.07 | 0.10 | ||||||
| Ad valorem taxes | 1.34 | 1.24 | ||||||
| Oil and natural gas production taxes | 2.13 | 2.56 | ||||||
| Depreciation, depletion and amortization | 13.57 | 13.74 | ||||||
| Asset retirement obligation accretion | 0.18 | 0.20 | ||||||
| Operating lease expense | 0.10 | 0.10 | ||||||
| G&A (including share-based compensation) | 4.44 | 4.31 | ||||||
| G&A (excluding share-based compensation) | 3.52 | 3.32 | ||||||
| G&A (excluding share-based compensation and transaction costs) | 3.51 | 3.32 |
All values are in US Dollars.
(1) 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.
RING ENERGY, INC.
Condensed Balance Sheets
(Unaudited)
| As of | ||||
|---|---|---|---|---|
| March 31, 2025 | December 31, 2024 | |||
| ASSETS | ||||
| Current Assets | ||||
| Cash and cash equivalents | $ | 1,100,851 | $ | 1,866,395 |
| Accounts receivable | 35,680,686 | 36,172,316 | ||
| Joint interest billing receivables, net | 2,121,035 | 1,083,164 | ||
| Derivative assets | 5,309,892 | 5,497,057 | ||
| Inventory | 3,300,755 | 4,047,819 | ||
| Prepaid expenses and other assets | 1,156,529 | 1,781,341 | ||
| Total Current Assets | 48,669,748 | 50,448,092 | ||
| Properties and Equipment | ||||
| Oil and natural gas properties, full cost method | 1,932,616,777 | 1,809,309,848 | ||
| Financing lease asset subject to depreciation | 4,272,259 | 4,634,556 | ||
| Fixed assets subject to depreciation | 3,359,292 | 3,389,907 | ||
| Total Properties and Equipment | 1,940,248,328 | 1,817,334,311 | ||
| Accumulated depreciation, depletion and amortization | (496,993,139) | (475,212,325) | ||
| Net Properties and Equipment | 1,443,255,189 | 1,342,121,986 | ||
| Operating lease asset | 1,753,693 | 1,906,264 | ||
| Derivative assets | 5,020,380 | 5,473,375 | ||
| Deferred financing costs | 6,911,264 | 8,149,757 | ||
| Total Assets | $ | 1,505,610,274 | $ | 1,408,099,474 |
| LIABILITIES AND STOCKHOLDERS’ EQUITY | ||||
| Current Liabilities | ||||
| Accounts payable | $ | 86,417,436 | $ | 95,729,261 |
| Income tax liability | 537,591 | 328,985 | ||
| Financing lease liability | 846,380 | 906,119 | ||
| Operating lease liability | 661,487 | 648,204 | ||
| Derivative liabilities | 5,426,195 | 6,410,547 | ||
| Notes payable | — | 496,397 | ||
| Deferred cash payment | 9,415,066 | — | ||
| Asset retirement obligations | 441,611 | 517,674 | ||
| Total Current Liabilities | 103,745,766 | 105,037,187 | ||
| Non-current Liabilities | ||||
| Deferred income taxes | 31,496,585 | 28,591,802 | ||
| Revolving line of credit | 460,000,000 | 385,000,000 | ||
| Financing lease liability, less current portion | 708,304 | 647,078 | ||
| Operating lease liability, less current portion | 1,234,690 | 1,405,837 | ||
| Derivative liabilities | 3,632,133 | 2,912,745 | ||
| Asset retirement obligations | 28,826,738 | 25,864,843 | ||
| Total Liabilities | 629,644,216 | 549,459,492 | ||
| Commitments and contingencies | ||||
| Stockholders' Equity | ||||
| Preferred stock - $0.001 par value; 50,000,000 shares authorized; no shares issued or outstanding | — | — | ||
| Common stock - $0.001 par value; 450,000,000 shares authorized; 206,509,126 shares and 198,561,378 shares issued and outstanding, respectively | 206,509 | 198,561 | ||
| Additional paid-in capital | 808,627,109 | 800,419,719 | ||
| Retained earnings (Accumulated deficit) | 67,132,440 | 58,021,702 | ||
| Total Stockholders’ Equity | 875,966,058 | 858,639,982 | ||
| Total Liabilities and Stockholders' Equity | $ | 1,505,610,274 | $ | 1,408,099,474 |
RING ENERGY, INC.
Condensed Statements of Cash Flows
(Unaudited)
| Three Months Ended | |||||||
|---|---|---|---|---|---|---|---|
| March 31, | December 31, | March 31, | |||||
| 2025 | 2024 | 2024 | |||||
| Cash Flows From Operating Activities | |||||||
| Net income | $ | 9,110,738 | $ | 5,657,519 | $ | 5,515,377 | |
| Adjustments to reconcile net income to net cash provided by operating activities: | |||||||
| Depreciation, depletion and amortization | 22,615,983 | 24,548,849 | 23,792,450 | ||||
| Asset retirement obligation accretion | 326,549 | 323,085 | 350,834 | ||||
| Amortization of deferred financing costs | 1,238,493 | 1,299,078 | 1,221,607 | ||||
| Share-based compensation | 1,690,958 | 1,672,320 | 1,723,832 | ||||
| Credit loss expense | 17,917 | (26,747) | 163,840 | ||||
| (Gain) loss on disposal of assets | (124,610) | — | — | ||||
| Deferred income tax expense (benefit) | 2,805,346 | 1,723,338 | 1,585,445 | ||||
| Excess tax expense (benefit) related to share-based compensation | 99,437 | 9,011 | 40,808 | ||||
| (Gain) loss on derivative contracts | 928,790 | 6,254,448 | 19,014,495 | ||||
| Cash received (paid) for derivative settlements, net | (553,594) | 745,104 | (1,461,515) | ||||
| Changes in operating assets and liabilities: | |||||||
| Accounts receivable | (564,158) | 349,474 | (5,240,487) | ||||
| Inventory | 747,064 | 580,161 | 171,416 | ||||
| Prepaid expenses and other assets | 624,812 | 295,555 | 503,704 | ||||
| Accounts payable | (10,385,137) | 4,462,089 | (1,601,276) | ||||
| Settlement of asset retirement obligation | (207,580) | (613,603) | (591,361) | ||||
| Net Cash Provided by Operating Activities | 28,371,008 | 47,279,681 | — | 45,189,169 | |||
| Cash Flows From Investing Activities | |||||||
| Payments for the Lime Rock Acquisition | (70,859,769) | — | — | ||||
| Payments to purchase oil and natural gas properties | (647,106) | (1,423,483) | (475,858) | ||||
| Payments to develop oil and natural gas properties | (31,083,507) | (36,386,055) | (38,904,808) | ||||
| Payments to acquire or improve fixed assets subject to depreciation | (34,275) | — | (124,937) | ||||
| Proceeds from sale of fixed assets subject to depreciation | 17,360 | — | — | ||||
| Proceeds from divestiture of equipment for oil and natural gas properties | — | 121,232 | — | ||||
| Net Cash Used in Investing Activities | (102,607,297) | (37,688,306) | (39,505,603) | ||||
| Cash Flows From Financing Activities | |||||||
| Proceeds from revolving line of credit | 114,000,000 | 22,000,000 | 51,500,000 | ||||
| Payments on revolving line of credit | (39,000,000) | (29,000,000) | (54,500,000) | ||||
| Payments for taxes withheld on vested restricted shares, net | (896,431) | — | (814,985) | ||||
| Proceeds from notes payable | — | 58,774 | — | ||||
| Payments on notes payable | (496,397) | (475,196) | (533,734) | ||||
| Payment of deferred financing costs | — | (42,746) | — | ||||
| Reduction of financing lease liabilities | (136,427) | (265,812) | (255,156) | ||||
| Net Cash Provided by (Used in) Financing Activities | 73,470,745 | (7,724,980) | (4,603,875) | ||||
| Net Increase (Decrease) in Cash | (765,544) | 1,866,395 | 1,079,691 | ||||
| Cash at Beginning of Period | 1,866,395 | — | 296,384 | ||||
| Cash at End of Period | $ | 1,100,851 | $ | 1,866,395 | $ | 1,376,075 |
RING ENERGY, INC.
Financial Commodity Derivative Positions
As of March 31, 2025
The following tables reflect the details of current derivative contracts as of March 31, 2025 (quantities are in barrels (Bbl) for the oil derivative contracts and in million British thermal units (MMBtu) for the natural gas derivative contracts):
| Oil Hedges (WTI) | ||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Q2 2025 | Q3 2025 | Q4 2025 | Q1 2026 | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | |||||||||||||||||||||||||||
| Swaps: | ||||||||||||||||||||||||||||||||||
| Hedged volume (Bbl) | 151,763 | 351,917 | 141,755 | 477,350 | 457,101 | 59,400 | 423,000 | 381,500 | ||||||||||||||||||||||||||
| Weighted average swap price | $ | 68.53 | $ | 71.41 | $ | 69.13 | $ | 70.16 | $ | 69.38 | $ | 66.70 | $ | 66.70 | $ | 63.80 | ||||||||||||||||||
| Two-way collars: | ||||||||||||||||||||||||||||||||||
| Hedged volume (Bbl) | 464,100 | 225,400 | 404,800 | — | — | 379,685 | — | — | ||||||||||||||||||||||||||
| Weighted average put price | $ | 60.00 | $ | 65.00 | $ | 60.00 | $ | — | $ | — | $ | 60.00 | $ | — | $ | — | ||||||||||||||||||
| Weighted average call price | $ | 69.85 | $ | 78.91 | $ | 75.68 | $ | — | $ | — | $ | 72.50 | $ | — | $ | — | Gas Hedges (Henry Hub) | |||||||||||||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | ||||||||||||||||||
| Q2 2025 | Q3 2025 | Q4 2025 | Q1 2026 | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | |||||||||||||||||||||||||||
| NYMEX Swaps: | ||||||||||||||||||||||||||||||||||
| Hedged volume (MMBtu) | 513,900 | 455,250 | 128,400 | 140,600 | 662,300 | 121,400 | 613,300 | — | ||||||||||||||||||||||||||
| Weighted average swap price | $ | 3.60 | $ | 3.88 | $ | 4.25 | $ | 4.20 | $ | 3.54 | $ | 4.22 | $ | 3.83 | $ | — | ||||||||||||||||||
| Two-way collars: | ||||||||||||||||||||||||||||||||||
| Hedged volume (MMBtu) | 18,300 | 308,200 | 598,000 | 553,500 | — | 515,728 | — | 700,000 | ||||||||||||||||||||||||||
| Weighted average put price | $ | 3.00 | $ | 3.00 | $ | 3.00 | $ | 3.50 | $ | — | $ | 3.00 | $ | — | $ | 4.00 | ||||||||||||||||||
| Weighted average call price | $ | 4.15 | $ | 4.75 | $ | 4.15 | $ | 5.03 | $ | — | $ | 3.93 | $ | — | $ | 5.20 | ||||||||||||||||||
| Oil Hedges (basis differential) | ||||||||||||||||||||||||||||||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | ||||||||||||||||||
| Q2 2025 | Q3 2025 | Q4 2025 | Q1 2026 | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | |||||||||||||||||||||||||||
| Argus basis swaps: | ||||||||||||||||||||||||||||||||||
| Hedged volume (Bbl) | 183,000 | 276,000 | 276,000 | — | — | — | — | — | ||||||||||||||||||||||||||
| Weighted average spread price (1) | $ | 1.00 | $ | 1.00 | $ | 1.00 | $ | — | $ | — | $ | — | $ | — | $ | — | ||||||||||||||||||
| Gas Hedges (basis differential) | ||||||||||||||||||||||||||||||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | ||||||||||||||||||
| Q2 2025 | Q3 2025 | Q4 2025 | Q1 2026 | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | |||||||||||||||||||||||||||
| El Paso Permian Basin basis swaps: | ||||||||||||||||||||||||||||||||||
| Hedged volume (MMBtu) | — | — | — | — | — | — | — | 700,000 | ||||||||||||||||||||||||||
| Weighted average spread price (2) | $ | — | $ | — | $ | — | $ | — | $ | — | $ | — | $ | — | $ | 0.74 |
(1) The oil basis swap hedges are calculated as the fixed price (weighted average spread price above) less the difference between WTI Midland and WTI Cushing, in the issue of Argus Americas Crude.
(2) The gas basis swap hedges are calculated as the Henry Hub natural gas price less the fixed amount specified as the weighted average spread price above.
RING ENERGY, INC.
Non-GAAP Financial Information
Certain financial information included in this release are not measures of financial performance recognized by accounting principles generally accepted in the United States (“GAAP”). These non-GAAP financial measures are “Adjusted Net Income,” “Adjusted EBITDA,” “Adjusted Free Cash Flow” or “AFCF,” “Adjusted Cash Flow from Operations” or “ACFFO,” “G&A Excluding Share-Based Compensation,” “G&A Excluding Share-Based Compensation and Transaction Costs,” “Leverage Ratio,” “All-In Cash Operating Costs,” and “Cash Operating Margin.” Management uses these non-GAAP financial measures in its analysis of performance. These disclosures may not be viewed as a substitute for results determined in accordance with GAAP and are not necessarily comparable to non-GAAP performance measures which may be reported by other companies.
Reconciliation of Net income to Adjusted Net Income
“Adjusted Net Income” is calculated as net income minus the estimated after-tax impact of share-based compensation, ceiling test impairment, unrealized gains and losses on changes in the fair value of derivatives, and transaction costs for executed acquisitions and divestitures (“A&D”). Adjusted Net Income is presented because the timing and amount of these items cannot be reasonably estimated and affect the comparability of operating results from period to period, and current period to prior periods. The Company believes that the presentation of Adjusted Net Income provides useful information to investors as it is one of the metrics management uses to assess the Company’s ongoing operating and financial performance, and also is a useful metric for investors to compare Ring’s results with its peers.
| (Unaudited for All Periods) | ||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Three Months Ended | ||||||||||||
| March 31, | December 31, | March 31, | ||||||||||
| 2025 | 2024 | 2024 | ||||||||||
| Total | Per share - diluted | Total | Per share - diluted | Total | Per share - diluted | |||||||
| Net income | $ | 9,110,738 | $ | 0.05 | $ | 5,657,519 | $ | 0.03 | $ | 5,515,377 | $ | 0.03 |
| Share-based compensation | 1,690,958 | 0.01 | 1,672,320 | 0.01 | 1,723,832 | 0.01 | ||||||
| Unrealized loss (gain) on change in fair value of derivatives | 375,196 | — | 6,999,552 | 0.03 | 17,552,980 | 0.08 | ||||||
| Transaction costs - executed A&D | 1,776 | — | 21,017 | — | 3,539 | — | ||||||
| Tax impact on adjusted items | (500,646) | (0.01) | (2,008,740) | (0.01) | (4,447,977) | (0.02) | ||||||
| Adjusted Net Income | $ | 10,678,022 | $ | 0.05 | $ | 12,341,668 | $ | 0.06 | $ | 20,347,751 | $ | 0.10 |
| Diluted Weighted-Average Shares Outstanding | 201,072,594 | 200,886,010 | 199,305,150 | |||||||||
| Adjusted Net Income per Diluted Share | $ | 0.05 | $ | 0.06 | $ | 0.10 |
Reconciliation of Net income to Adjusted EBITDA
The Company defines “Adjusted EBITDA” as net income plus net interest expense (including interest income and expense), unrealized loss (gain) on change in fair value of derivatives, ceiling test impairment, income tax (benefit) expense, depreciation, depletion and amortization, asset retirement obligation accretion, transaction costs for executed acquisitions and divestitures (A&D), share-based compensation, loss (gain) on disposal of assets, and backing out the effect of other income. Company management believes Adjusted EBITDA is relevant and useful because it helps investors understand Ring’s operating performance and makes it easier to compare its results with those 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 operating 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 discretionary use.
| (Unaudited for All Periods) | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Three Months Ended | |||||||||
| March 31, | December 31, | March 31, | |||||||
| 2025 | 2024 | 2024 | |||||||
| Net income | $ | 9,110,738 | $ | 5,657,519 | $ | 5,515,377 | |||
| Interest expense, net | 9,408,728 | 9,987,731 | 11,420,400 | ||||||
| Unrealized loss (gain) on change in fair value of derivatives | 375,196 | 6,999,552 | 17,552,980 | ||||||
| Income tax (benefit) expense | 3,041,177 | 1,803,629 | 1,728,886 | ||||||
| Depreciation, depletion and amortization | 22,615,983 | 24,548,849 | 23,792,450 | ||||||
| Asset retirement obligation accretion | 326,549 | 323,085 | 350,834 | ||||||
| Transaction costs - executed A&D | 1,776 | 21,017 | 3,539 | ||||||
| Share-based compensation | 1,690,958 | 1,672,320 | 1,723,832 | ||||||
| Loss (gain) on disposal of assets | (124,610) | — | (38,355) | ||||||
| Other income | (8,942) | (80,970) | (25,686) | ||||||
| Adjusted EBITDA | $ | 46,437,553 | $ | 50,932,732 | $ | 62,024,257 | |||
| Adjusted EBITDA Margin | 59 | % | 61 | % | 66 | % |
Reconciliations of Net Cash Provided by Operating Activities to Adjusted Free Cash Flow and Adjusted EBITDA to Adjusted Free Cash Flow
The Company defines “Adjusted Free Cash Flow” or “AFCF” as Net Cash Provided by Operating Activities less changes in operating assets and liabilities (as reflected on Ring’s Condensed Statements of Cash Flows), plus transaction costs for executed acquisitions and divestitures (A&D), current income tax expense (benefit), proceeds from divestitures of equipment for oil and natural gas properties, loss (gain) on disposal of assets, and less capital expenditures, credit loss expense, and other income. 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 lease maintenance costs) but excludes acquisition costs of oil and gas properties from third parties that are not included in Ring’s capital expenditures guidance provided to investors. Management believes that Adjusted Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of the Company’s current operating activities after the impact of capital expenditures and net interest expense (including interest income and expense, excluding amortization of deferred financing costs) and without being impacted by items such as changes associated with working capital, which can vary substantially from one period to another. Other companies may use different definitions of Adjusted Free Cash Flow.
| (Unaudited for All Periods) | ||||||
|---|---|---|---|---|---|---|
| Three Months Ended | ||||||
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| Net Cash Provided by Operating Activities | $ | 28,371,008 | $ | 47,279,681 | $ | 45,189,169 |
| Adjustments - Condensed Statements of Cash Flows | ||||||
| Changes in operating assets and liabilities | 9,784,999 | (5,073,676) | 6,758,004 | |||
| Transaction costs - executed A&D | 1,776 | 21,017 | 3,539 | |||
| Income tax expense (benefit) - current | 136,393 | 71,280 | 102,633 | |||
| Capital expenditures | (32,451,531) | (37,633,168) | (36,261,008) | |||
| Proceeds from divestiture of equipment for oil and natural gas properties | — | 121,232 | — | |||
| Credit loss expense | (17,917) | 26,747 | (163,840) | |||
| Loss (gain) on disposal of assets | — | — | (38,355) | |||
| Other income | (8,942) | (80,970) | (25,686) | |||
| Adjusted Free Cash Flow | $ | 5,815,786 | $ | 4,732,143 | $ | 15,564,456 |
| (Unaudited for All Periods) | ||||||
| --- | --- | --- | --- | --- | --- | --- |
| Three Months Ended | ||||||
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| Adjusted EBITDA | $ | 46,437,553 | $ | 50,932,732 | $ | 62,024,257 |
| Net interest expense (excluding amortization of deferred financing costs) | (8,170,235) | (8,688,653) | (10,198,793) | |||
| Capital expenditures | (32,451,531) | (37,633,168) | (36,261,008) | |||
| Proceeds from divestiture of equipment for oil and natural gas properties | — | 121,232 | — | |||
| Adjusted Free Cash Flow | $ | 5,815,787 | $ | 4,732,143 | $ | 15,564,456 |
Reconciliation of Net Cash Provided by Operating Activities to Adjusted Cash Flow from Operations
The Company defines “Adjusted Cash Flow from Operations” or “ACFFO” as Net Cash Provided by Operating Activities, as reflected in Ring’s Condensed Statements of Cash Flows, less the changes in operating assets and liabilities, which includes accounts receivable, inventory, prepaid expenses and other assets, accounts payable, and settlement of asset retirement obligations, which are subject to variation due to the nature of the Company’s operations. Accordingly, the Company believes this non-GAAP measure is useful to investors because it is used often in its industry and allows investors to compare this metric to other companies in its peer group as well as the E&P sector.
| (Unaudited for All Periods) | ||||||
|---|---|---|---|---|---|---|
| Three Months Ended | ||||||
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| Net Cash Provided by Operating Activities | $ | 28,371,008 | $ | 47,279,681 | $ | 45,189,169 |
| Changes in operating assets and liabilities | 9,784,999 | (5,073,676) | 6,758,004 | |||
| Adjusted Cash Flow from Operations | $ | 38,156,007 | $ | 42,206,005 | $ | 51,947,173 |
Reconciliation of General and Administrative Expense (G&A) to G&A Excluding Share-Based Compensation and Transaction Costs
The following table presents a reconciliation of General and Administrative Expense (“G&A”), a GAAP measure, to G&A excluding share-based compensation, and G&A excluding share-based compensation and transaction costs for executed acquisitions and divestitures (A&D).
| (Unaudited for All Periods) | ||||||
|---|---|---|---|---|---|---|
| Three Months Ended | ||||||
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| General and administrative expense (G&A) | $ | 8,619,976 | $ | 8,035,977 | $ | 7,469,222 |
| Shared-based compensation | 1,690,958 | 1,672,320 | 1,723,832 | |||
| G&A excluding share-based compensation | 6,929,018 | 6,363,657 | 5,745,390 | |||
| Transaction costs - executed A&D | 1,776 | 21,017 | 3,539 | |||
| G&A excluding share-based compensation and transaction costs | $ | 6,927,242 | $ | 6,342,640 | $ | 5,741,851 |
Calculation of Leverage Ratio
“Leverage” or the “Leverage Ratio” is calculated under the Company’s existing senior revolving credit facility and means as of any date, the ratio of (i) Consolidated total debt as of such date to (ii) Consolidated EBITDAX for the four consecutive fiscal quarters ending on or immediately prior to such date for which financial statements are required to have been delivered under the Company’s existing senior revolving credit facility.
The Company defines “Consolidated EBITDAX” in accordance with its existing senior revolving credit facility that means for any period an amount equal to the sum of (i) consolidated net income (loss) for such period plus (ii) to the extent deducted in determining consolidated net income for such period, and without duplication, (A) consolidated interest expense, (B) income tax expense determined on a consolidated basis in accordance with GAAP, (C) depreciation, depletion and amortization determined on a consolidated basis in accordance with GAAP, (D) exploration expenses determined on a consolidated basis in accordance with GAAP, and (E) all other non-cash charges acceptable to Ring’s senior revolving credit facility administrative agent determined on a consolidated basis in accordance with GAAP, in each case for such period minus (iii) all noncash income added to consolidated net income (loss) for such period; provided that, for purposes of calculating compliance with the financial covenants, to the extent that during such period the Company shall have consummated an acquisition permitted by the credit facility or any sale, transfer or other disposition of any property or assets permitted by the senior revolving credit facility, Consolidated EBITDAX will be calculated on a pro forma basis with respect to the property or assets so acquired or disposed of.
Also set forth in Ring’s existing senior revolving credit facility is the maximum permitted Leverage Ratio of 3.00. The following tables show the leverage ratio calculations for the quarters ended March 31, 2025 and March 31, 2024.
| (Unaudited) | ||||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| Three Months Ended | ||||||||||
| June 30, | September 30, | December 31, | March 31, | Last Four Quarters | ||||||
| 2024 | 2024 | 2024 | 2025 | |||||||
| Consolidated EBITDAX Calculation: | ||||||||||
| Net Income (Loss) | $ | 22,418,994 | $ | 33,878,424 | $ | 5,657,519 | $ | 9,110,738 | $ | 71,065,675 |
| Plus: Consolidated interest expense | 10,801,194 | 10,610,539 | 9,987,731 | 9,408,728 | 40,808,192 | |||||
| Plus: Income tax provision (benefit) | 6,820,485 | 10,087,954 | 1,803,629 | 3,041,177 | 21,753,245 | |||||
| Plus: Depreciation, depletion and amortization | 24,699,421 | 25,662,123 | 24,548,849 | 22,615,983 | 97,526,376 | |||||
| Plus: non-cash charges acceptable to Administrative Agent | 1,664,064 | (26,228,108) | 8,994,957 | 2,392,703 | (13,176,384) | |||||
| Consolidated EBITDAX | $ | 66,404,158 | $ | 54,010,932 | $ | 50,992,685 | $ | 46,569,329 | $ | 217,977,104 |
| Plus: Pro Forma Acquired Consolidated EBITDAX | 10,329,116 | 7,838,163 | 5,244,078 | 7,392,359 | 30,803,716 | |||||
| Less: Pro Forma Divested Consolidated EBITDAX | (469,376) | (600,460) | 77,819 | 8,855 | (983,162) | |||||
| Pro Forma Consolidated EBITDAX | $ | 76,263,898 | $ | 61,248,635 | $ | 56,314,582 | $ | 53,970,543 | $ | 247,797,658 |
| Non-cash charges acceptable to Administrative Agent: | ||||||||||
| Asset retirement obligation accretion | $ | 352,184 | $ | 354,195 | $ | 323,085 | $ | 326,549 | ||
| Unrealized loss (gain) on derivative assets | (765,898) | (26,614,390) | 6,999,552 | 375,196 | ||||||
| Share-based compensation | 2,077,778 | 32,087 | 1,672,320 | 1,690,958 | ||||||
| Total non-cash charges acceptable to Administrative Agent | $ | 1,664,064 | $ | (26,228,108) | $ | 8,994,957 | $ | 2,392,703 | ||
| As of | ||||||||||
| March 31, | Corresponding | |||||||||
| 2025 | Leverage Ratio | |||||||||
| Leverage Ratio Covenant: | ||||||||||
| Revolving line of credit | $ | 460,000,000 | 1.86 | |||||||
| Lime Rock deferred payment | 10,000,000 | 0.04 | ||||||||
| Consolidated Total Debt | $ | 470,000,000 | 1.90 | |||||||
| Pro Forma Consolidated EBITDAX | 247,797,658 | |||||||||
| Leverage Ratio | 1.90 | |||||||||
| Maximum Allowed | ≤ 3.00x | |||||||||
| (Unaudited) | ||||||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Three Months Ended | ||||||||||
| June 30, | September 30, | December 31, | March 31, | Last Four Quarters | ||||||
| 2023 | 2023 | 2023 | 2024 | |||||||
| Consolidated EBITDAX Calculation: | ||||||||||
| Net Income (Loss) | $ | 28,791,605 | $ | (7,539,222) | $ | 50,896,479 | $ | 5,515,377 | $ | 77,664,239 |
| Plus: Consolidated interest expense | 10,471,062 | 11,301,328 | 11,506,908 | 11,420,400 | 44,699,698 | |||||
| Plus: Income tax provision (benefit) | (6,356,295) | (3,411,336) | 7,862,930 | 1,728,886 | (175,815) | |||||
| Plus: Depreciation, depletion and amortization | 20,792,932 | 21,989,034 | 24,556,654 | 23,792,450 | 91,131,070 | |||||
| Plus: non-cash charges acceptable to Administrative Agent | (470,875) | 36,396,867 | (29,695,076) | 19,627,646 | 25,858,562 | |||||
| Consolidated EBITDAX | $ | 53,228,429 | $ | 58,736,671 | $ | 65,127,895 | $ | 62,084,759 | $ | 239,177,754 |
| Plus: Pro Forma Acquired Consolidated EBITDAX | 9,542,529 | 4,810,123 | — | — | 14,352,652 | |||||
| Less: Pro Forma Divested Consolidated EBITDAX | (357,122) | (672,113) | (66,463) | 40,474 | (1,055,224) | |||||
| Pro Forma Consolidated EBITDAX | $ | 62,413,836 | $ | 62,874,681 | $ | 65,061,432 | $ | 62,125,233 | $ | 252,475,182 |
| Non-cash charges acceptable to Administrative Agent: | ||||||||||
| Asset retirement obligation accretion | $ | 353,878 | $ | 354,175 | $ | 351,786 | $ | 350,834 | ||
| Unrealized loss (gain) on derivative assets | (3,085,065) | 33,871,957 | (32,505,544) | 17,552,980 | ||||||
| Share-based compensation | 2,260,312 | 2,170,735 | 2,458,682 | 1,723,832 | ||||||
| Total non-cash charges acceptable to Administrative Agent | $ | (470,875) | $ | 36,396,867 | $ | (29,695,076) | $ | 19,627,646 | ||
| As of | ||||||||||
| March 31, | ||||||||||
| 2024 | ||||||||||
| Leverage Ratio Covenant: | ||||||||||
| Revolving line of credit | $ | 422,000,000 | ||||||||
| Pro Forma Consolidated EBITDAX | 252,475,182 | |||||||||
| Leverage Ratio | 1.67 | |||||||||
| Maximum Allowed | ≤ 3.00x |
All-In Cash Operating Costs
The Company defines All-In Cash Operating Costs, a non-GAAP financial measure, as “all in cash” costs which includes lease operating expenses, G&A costs excluding share-based compensation, net interest expense (including interest income and expense, excluding amortization of deferred financing costs), workovers and other operating expenses, production taxes, ad valorem taxes, and gathering/transportation costs. Management believes that this metric provides useful additional information to investors to assess the Company’s operating costs in comparison to its peers, which may vary from company to company.
| (Unaudited for All Periods) | ||||||
|---|---|---|---|---|---|---|
| Three Months Ended | ||||||
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| All-In Cash Operating Costs: | ||||||
| Lease operating expenses (including workovers) | $ | 19,677,552 | $ | 20,326,216 | $ | 18,360,434 |
| G&A excluding share-based compensation | 6,929,018 | 6,363,657 | 5,745,390 | |||
| Net interest expense (excluding amortization of deferred financing costs) | 8,170,235 | 8,688,653 | 10,198,793 | |||
| Operating lease expense | 175,091 | 175,090 | 175,091 | |||
| Oil and natural gas production taxes | 3,584,455 | 3,857,147 | 4,428,303 | |||
| Ad valorem taxes | 1,532,108 | 2,421,595 | 2,145,631 | |||
| Gathering, transportation and processing costs | 203,612 | 130,230 | 166,054 | |||
| All-in cash operating costs | $ | 40,272,071 | $ | 41,962,588 | $ | 41,219,696 |
| Boe | 1,655,259 | 1,808,493 | 1,732,057 | |||
| All-in cash operating costs per Boe | $ | 24.33 | $ | 23.20 | $ | 23.80 |
Cash Operating Margin
The Company defines Cash Operating Margin, a non-GAAP financial measure, as realized revenues per Boe less all-in cash operating costs per Boe. Management believes that this metric provides useful additional information to investors to assess the Company’s operating margins in comparison to its peers, which may vary from company to company.
| (Unaudited for All Periods) | ||||||
|---|---|---|---|---|---|---|
| Three Months Ended | ||||||
| March 31, | December 31, | March 31, | ||||
| 2025 | 2024 | 2024 | ||||
| Cash Operating Margin | ||||||
| Realized revenues per Boe | $ | 47.78 | $ | 46.14 | $ | 54.56 |
| All-in cash operating costs per Boe | 24.33 | 23.20 | 23.80 | |||
| Cash Operating Margin per Boe | $ | 23.45 | $ | 22.94 | $ | 30.76 |
19
reiq12025earningsvf2025-
NYSE American: REIwww.ringenergy.com May 8, 2025 Q1 2025 EARNINGS & UPDATED GUIDANCE
Ring Energy, Inc. Forward –Looking Statements This Presentation includes 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. All statements, other than statements of historical fact included in this Presentation, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, guidance, plans and objectives of management are forward-looking statements. When used in this Presentation, the words “could,” “may,” “will,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “guidance,” “project,” “goal,” “plan,” “potential,” “probably,” “target” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Forward-looking statements also include assumptions and projections for second and full year 2025 guidance for sales volumes, oil mix as a percentage of total sales, capital expenditures, operating expenses and the projected impacts thereon, and the number of wells expected to be drilled and completed. These forward-looking statements are based on management’s current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. However, whether actual results and developments will conform to expectations is subject to a number of material risks and uncertainties, including but not limited to: declines in oil, natural gas liquids or natural gas prices; the level of success in exploration, development and production activities; adverse weather conditions that may negatively impact development or production activities particularly in the winter; the timing of exploration and development expenditures; inaccuracies of reserve estimates or assumptions underlying them; revisions to reserve estimates as a result of changes in commodity prices; impacts to financial statements as a result of impairment write-downs; risks related to level of indebtedness and periodic redeterminations of the borrowing base and interest rates under the Company’s credit facility; Ring’s ability to generate sufficient cash flows from operations to meet the internally funded portion of its capital expenditures budget; the expected benefits to the Company and its stockholders from the acquisition of oil and gas properties (the “LRR Acquisition”) from Lime Rock Resources IV-A, L.P. and Lime Rock Resources IV-C, L.P. (collectively, “Lime Rock” or “LRR”); the impacts of hedging on results of operations; the effects of future regulatory or legislative actions; cost and availability of transportation and storage capacity as a result of oversupply, changes in U.S. energy, environmental, monetary and trade policies, including with respect to tariffs or other trade barriers, and any resulting trade tensions; and Ring’s ability to replace oil and natural gas reserves. Such statements are subject to certain risks and uncertainties which are disclosed in the Company’s reports filed with the Securities and Exchange Commission (“SEC”), including its Form 10-K for the fiscal year ended December 31, 2024, and its other filings with the SEC. All forward-looking statements, expressed or implied, included in this Presentation are expressly qualified by the cautionary statements and by reference to the underlying assumptions that may prove to be incorrect. The Company undertakes no obligation to 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 nor any other third party has examined, reviewed or compiled the estimates and, accordingly, none of the foregoing expresses an opinion or other form of assurance with respect thereto. The assumptions upon which the estimates are based are described 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 will vary from the estimated results. Investors are not to place undue reliance on the estimates included herein. Forward-Looking Statements and Supplemental Non-GAAP Financial Measures 2 Supplemental Non-GAAP Financial Measures This Presentation includes financial measures that are not in accordance with accounting principles generally accepted in the United States (“GAAP”), such as “Adjusted Net Income,” “Adjusted EBITDA,” “PV-10,” “Adjusted Free Cash Flow” or “AFCF,” “Adjusted Cash Flow from Operations” or “ACFFO,” “Cash Return on Capital Employed” or “CROCE,” “Leverage Ratio,” “All- in Cash Operating Costs,” and “Cash Operating Margin.” While management believes that such measures are useful for investors, they should not be used as a replacement 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. Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI-
Ring Energy, Inc. Ring Energy - Independent Oil & Gas Company 3 Focused on Conventional Permian Assets in Texas Ring Energy Assets Northwest Shelf Central Basin Platform 1.Pro Forma net production Q2 ‘25 guidance 2.SEC Proved Reserves as of 12/31/2024 utilizing SEC prices, YE 2024 SEC Pricing Oil $71.96 per bbl Gas $2.13 per Mcf. 3.PV-10 is a Non-GAAP financial measure. See Appendix for reconciliation to GAAP measure. 4.LRR acquisition utilizing SEC prices for TTM ended March 31, 2025, Oil $71.00 per bbl Gas $2.44 per Mcf. 5.Includes all acreage and identified new drill locations as of year-end 2024 operated and non- operated across 1P, 2P and 3P reserve categories. Pro Forma “PF” Net Production1 ~21,500 Boe/d (66% oil and 84% liquids) 2024 PF SEC Proved Reserves2,3 134 MMBoe/PV10 ~$1.5 Billion Proved Developed ~69% Lime Rock Acquisition4 adds ~12 MMBoe/ PV10 ~$160 million Proved Developed ~79% PF Permian Acreage Gross / Net Acres3 ~98,000 / ~81,000 Lime Rock Acquisition adds ~18K net acres 400+ Locations5 Lime Rock Acquisition adds ~40 locations5 Includes operated & non-operated Differentiated approach by applying unconventional technology and thinking to conventional Permian assets Ring Assets Characteristics: ü Shallow Base Decline ü Long Life Wells (> 35 years) ü Highly Oil Weighted ü High Operating Margin ü High Netbacks (NRI > 79%) ü Low D&C Cost Inventory ü Low Breakevens Yoakum Gaines Andrews Ector Crane Ward High Operational Ownership ~96% Operated WI ~79% Oil NRI ~82% Gas NRI Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Matador Arch Capitan Re f Trend
Ring Energy, Inc. Adding Size and Scale to the Portfolio • Since 2021 our production has increased 23% CAGR from accretive acquisitions & organic development • Successfully closed accretive acquisition of Lime Rock CBP assets on March 31, 2025 • Proved Reserves including LRR assets increased by ~88% since YE 2021 Maintaining Operational Excellence • In 2024, reduced Y-O-Y all-in cash operating costs (on a Boe basis) by 2% • In 2024, improved Y-O-Y capital efficiency on horizontal wells by 11% per lateral foot and vertical wells by ~3%1 on a per frac stage basis • Drilled and completed 7 wells in Q1’25 with average costs 7% less than budget with all wells exceeding pre-drill expectations enabling our oil sales to beat high end of guidance Meaningful Free Cash Flow Generation • High margin portfolio with TTM EBITDA margin greater than 60% • Delivered positive Adjusted Free Cash Flow for over 5 years, 22 consecutive quarters • Projected AFCF range for FY 2025 ~$30 to $80 million ($50 to $70 per Bbl of oil using updated guidance) Maintains Strong Balance Sheet • Deleveraged Company from ~ 4.0x in early 2021 to 1.9x in Q1’25 (including LRR Acquisition) • Paid off Founders Acquisition ($75 million in 2023) in less than 5 quarters • Remainder 2025, Company has ~ 1.7 million barrels of oil hedged at an avg floor price of $64.44/Bbl (47% mid- point oil guidance) and in 2026, 1.8 million barrels of oil hedged at avg floor price of $66.89/Bbl • Due to lower oil prices, cut capex 50% in Q2’25 guidance, resulting in ~47% reduction in capex for remainder of 2025 (Q2-Q4’25) Creates a Stronger, More Resilient Ring • Maintaining sales guidance in Q2’25 and 5% reduction in FY’25 sales guidance, with 2% Y-O-Y growth • Focused on maximizing FCF and debt reduction with clear sight to paying off the LRR Acquisition • Ring’s strong foundation with shallow PDP base decline, high EBITDA margins, long well lives and high netbacks positions the Company to deliver value despite market volatility Flexible and Resilient in 2025 4 Value Proven Strategy Designed to Endure Volatile Oil Prices Source: REI YE 2024 Press release dated March 5, 2025. Note: See Appendix for disclaimers regarding non-GAAP financial measures and footnotes 1. See slide page 25 for capital efficiency drilling metrics for horizontal and verticals. Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI ~~ ~ - ENERGY
Ring Energy, Inc. 1. Adjusted EBITDA and Adjusted Free Cash Flow are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 2. Total Operating costs is defined as all “cash” costs including LOE, cash G&A, interest expense, workovers and other operating expenses, production taxes and gathering/transportation costs on a $ per Boe basis. 3. Leverage Ratio see appendix. 4. SEC Proved Reserves as of 12/31/2024 utilizing SEC prices, YE 2024 SEC Pricing Oil $71.96 per bbl Gas $2.13 per Mcf. Q1 2025 Scorecard 5 Closed LRR AQ at end of Q1 – LRR did not affect production, EBITDA, Capex or FCF Realized $/ Boe Oil Sales Bo Adjusted EBITDA1 CapEx Lease Operating Costs2 Adjusted Free Cash Flow1 Leverage Ratio3 12,074 Bo/d Q1 2025 $47.78 Per Boe Q1 2025 12,916 Bo/d Q4 2024 $46.4 Million Q1 2025 $32.5 Million Q1 2025 $5.8 Million Q1 2025 1.90x Ratio Q1 2025 $11.89 Per Boe Q1 2025 $46.14 Per Boe Q4 2024 $50.9 Million Q4 2024 $37.6 Million Q4 2024 $11.24 Per Boe Q4 2024 1.66x Ratio Q4 2024 $4.7 Million Q4 2024 Sales Boe 18,392 Boe/d Q1 2025 19,658 Boe/d Q4 2024 Debt Balance $460 Million Q1 2025 $385 Million Q4 2024 SEC 1P Reserves4 146 MMBoe PF YE 2024 134 MMBoe YE 2024 66% Oil 66% Oil -6% -9% 6% 4% -19% 9%-14% 14% 23% -7% Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI with LRR AQ with LRR AQ with LRR AQ with LRR AQ @ 0 0 -
Ring Energy, Inc. LRR Acquisition Expands Legacy High-Return Area 6 Continuing Our Transformation to a Scaled Conventional Permian Operator Asset Overview ü Closed on March 31, 2025 ü ~19,250 gross / 17,700 net acres (100% HBP) mostly contiguous to Ring’s existing footprint ü ~2,300 Boe/d (>75% Oil)1 average Q1’25 net production ü Shallow PDP NTM decline at 13% ü ~$121mm of oil-weighted PD PV-10 at YE’24 SEC pricing ü ~$31mm LTM Adj. EBITDA2 generated with no drilling capital by prior operator ü >40 gross drilling locations3 weighted to San Andres that immediately compete for capital ü Q1’25 Adj EBITDA3 margin of 59% and <$40/bbl breakeven on San Andres inventory ü Low total well count with minimal P&A liability ü Exposure to emerging plays (Barnett & Woodford Shale) ü Robust SWD capacity Transaction Summary ($MM) ü Bolt-on acquisition of Lime Rock’s Shafter Lake and Midland Farms assets in Andrews County ü $100mm purchase price ü Effective October 1, 2024 ü 6-mo Purchase price adjustment ~$13mm Legend Ring Energy Leasehold Lime Rock Resources Strategic Fit Midland Farms Shafter Lake ~100 active producing wells 68% 13% 9% 10% 1. Source: Lime Rock Preliminary Settlement Statement. 2. Adjusted EBITDA, and Adjusted Free Cash Flow are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 3. Includes all locations operated and non-operated across “PDNP” and “PUD” reserve categories and 2P/3P locations.Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI $100 $75 $50 $25 $0 - ■ Cash Due @ Close ■ Eff Date (Purchase$ Adj) REI Stock ■ Deferred Payment Andrews " _-....::.■ ...... O RING E N E R G y Yoakum • ecos • Gaines I I I Andrews I I L ~~-I Ector ..- ~ -· ~-. ' ~ Crane ~ . Dawson Martin Midland Upton
Ring Energy, Inc. ~12 MMBoe $160 MM PD $127MM PUD $33MM Oil Gas NGL ~12 MMBoe 16 PUDs Proved Reserves1 and Inventory 7 Reserves by Category (%) Reserves by PV-102 ($MM) Reserves by Product (%) Locations by Area PD ~93 MMBoe PUD ~42 MMBoe Organic Reserve Replacement in 2024 Increased Proved Reserves 3% Increased PD Reserves 5% ~134 MMBoe 1. Reserves as of Dec 31, 2024 utilizing SEC prices, YE24 SEC Pricing Oil $71.96 per bbl Gas $2.130 per Mcf. 2. PV-10 is a Non-GAAP financial measure. See Appendix for reconciliation to GAAP measure. 3. Includes all locations operated and non-operated across “PDNP” and “PUD” reserve categories and project types. 4. LRR acquisition utilizing SEC prices for TTM ended March 31, 2025, Oil $71.00 per bbl Gas $2.44 per Mcf. $1,463 MM PD $1,130 MM PUD $333 MM Oil Gas NGL ~134 MMBoe 210+ PUDs, 220+ PDNPs Replaced Production and Divested Volumes 7.2MM BOE Produced 1.2MM BOE Divested 16MM BOE of Extensions 3.3x previous year extensions of 4.8MM BOE Maintained YoY PUD count at 210+ without acquisition Replaced the 44 wells that were drilled in 2024 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI R E I L eg ac y SE C Y E 20 24 , e xc l. LR R L R R A cq ui si ti o n4 PD ~9 MMBoe PUD ~3 MMBoe-== -==-== - CBP-S NWS CBP-N Penwell
Ring Energy, Inc. Updated Pro Forma Guidance 8 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI 3 Full Quarters of Lime Rock Asset1 Operations FY 2025 CAPEX Allocation $99 million Mid Point 61% 33% 2% 1. LRR Acquisition closed on March 31, 2025. 2. In addition to Company-directed drilling and completion activities, the capital spending outlook includes funds for targeted well recompletions, capital workovers, infrastructure upgrades, and well reactivations. Also included is anticipated spending for leasing acreage; and non-operated drilling, completion, capital workovers, and facility improvements. 3. All guidance capex numbers in 2025 are mid-points. 4% Sales Volumes Q1 2025 Q1 2025 % Q2 2025 2H 2025 REI Only Actuals Difference PF UPDATE PF UPDATE Total (Bo/d) 11,700 – 12,000 13,700 – 14,700 12,500 – 14,000 Mid Point (Bo/d) 11,850 12,074 2% 14,200 13,250 Total (Boe/d) 18,000 – 18,500 20,500 – 22,500 19,000 – 21,000 Mid Point (Boe/d) 18,250 18,392 1% 21,500 20,000 - Oil (%) 65% 66% 66% 66% - NGLs (%) 19% 18% 18% 18% - Gas (%) 16% 16% 16% 16% Capital Program Capital2 ($MM) $26 – $34 $14 – $22 $38 – $58 Mid Point ($MM) $30 $32 8% $18 $48 Operating Expenses LOE (per Boe) $11.75 – $12.25 $11.50 – $12.50 $11.50 – $12.50 Mid Point (per Boe) $12.00 $11.89 -1% $12.00 $12.00 -36% -47% - $175 $150 $125 $100 $75 $50 $25 $0 ■ D&C / Infrastructure / CTR ■ Recompl / Cap Workovers ■ Land / Non-op / Other Facility Improvements Total Capex Spend Comparison SMM3 FY2024 Original Guidance FY'25 Updated Guidance FY'25 Original Guidance Q2-Q4'25 Updated Guidance Q2-Q4'2
Ring Energy, Inc. Oil Sales Q2-Q4 PF 12,750 to 14,250 Bo/d Mid-point 13,500 Bo/d FY 2026E Focused on Maximizing FCF in 2025 & Beyond 9 1. Estimated AFCF is based on actuals in Q1’25 and projections of internal management financial model assumes mid point of guidance for Net Sales production & capex with adjustable oil price as of Apr‘25, gas HH strip price 04/20/2025 and NGL realizations of ~17% of WTI oil price in 2025. 2. Estimated AFCF yield is based on assumptions above for AFCF and Ring’s stock price and market capitalization as 05/06/2025. 2023 2025E Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI 2023 Outlook – High Margin, Low Decline, High Netback Assets Drive Success Through Volatile Oil Prices Pursue Operational Excellence & Building Scale Maximizing 2025E AFCF1,2 AFCF Outlook for 2026E1 Maintaining Production & Capex Spend YoY Disciplined Capital Investment ’25E Capital Projects: ~ 20-23 New Drills ~30-40 Recompl/CTRs FY Sales ‘26E ~ 20K Boe/d (67% oil) FY Capex ‘26E ~$110 Million 2024 Total Sales Q2-Q4 PF 19,500 to 21,500 Boe/d Mid-point 20,000 Boe/d Up ~2%Up ~4% FY 2025E 2024 $50 $55 $60 $65 $70 WTI Pro Forma guidance for 2025 (Q2-Q4) post LRR AQ close on March 31, 2025 $50 $55 $60 $65 $70 WTI 3. Outlook 2026E, based on internal management financial model, including referenced above ‘26E for production & capex and improvements in NGL realizations of ~20% of WTI oil price and a $0.25/mcf gas differential. 22 ................................................................................................................. 20 ............ . 18 ....... . 16 11-- Cl) C) 2023 □ D $150 ; Ill fl:: 5 $125 >< = Cl)= Q.~ J $100 $75 - 2024 20.5 02-04 PF 2025E 14 13 .. .. ........................... . 12 r-■ 2023 2024 -.................... . . .,. .. ,,. .. ,. .. ,. ...... . 02-04 PF 2025E ► ► $20 ..... . $0 .... . $80 ~ ! $60 LL ~ $40 < $20 .. ...... .. $0 ........ . -~--·-------:;--- O RING ENERGY 50% 4001 /0 ~ 30% ~ > ..... 2001 LI. /0 (J LL 10% < ..... 0%
Ring Energy, Inc. Distinguishing Attributes: What Makes Ring Different? 10 Netbacks: NRI % 1. Source: Enverus as of Feb 2025, using ENVERUS base decline model function. The declines are all yearly declines using Aug/Sep/Oct 2024 as starting period for each company selected (by any size). Includes: Civitas, Devon, Diamondback, Mach Natural Resources, Magnolia, Ovintiv, Permian Resources, Riley Permian, SM Energy (Midland) and Vital Energy. 2. Ring Energy decline is Pro Forma internal management estimates for PDP Ring legacy and the acquisition of Lime Rock’s CBP assets. Differentiated Approach by Applying Unconventional Technology and Thinking to Conventional Permian Assets PDP Decline1: 2024E PDP Base Decline % Reserve Life2,3: YE 2024 SEC Proved Reserves / FY’24 Annualized Prod. % Oil2,3: FY’24 Oil Sales Production Median 33% ü Ring Conventional Assets Characteristics: Shallow Base Decline, High Netbacks (NRI> 79%), Long Life Wells (> 35 years) and Highly Oil Weighted 3. Peers based on similar size sub $2B market cap and/or other similar companies that have Permian assets: Amplify Energy, Berry Corporation, Crescent Energy, HighPeak Energy, Mach Natural Resources, Permian Resources, Riley Permian, Vital Energy, TXO Partners and W&T Offshore. 4. Source information for data obtained from Peer Reports and Capital IQ and Factset as of 03/13/2025. 2 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI 40% 35% 30% 25% 25% 22% 20% 20% 15% 10% 5% 0% Peer 1 O R1.":I~ Peer2 jt - 29% Peer3 36% 30% Peer 4 Peer 5 Peers Peer? Peer8 Peer9 High Operational Ownership ~96% Operated WI ~79% Oil NRI ~82% Gas NRI 37% 20.0 15.0 10.0 I 5.0 0.0 Peer 10 0 !"!1,t-:J~ Peerl Peer 2 Peer3 Peer4 Peer 5 Median Peer6 Peer 7 Peer 8 Peer9 Peer 10 100% 80% 60% 40% 20% 0% 11111111 Peer 1 Peer 2 Peer 3 0 !"!1,":I~ Peer4 Median Peer 5 Peer 6 Peer 7 Peer 8 Peer 9
Ring Energy, Inc. Distinguishing Attributes: High Operating Margins 11 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Ring’s Conventional Assets with High Netbacks Drive Strong Cash Operating Margins vs. Peers1,2 4Q 2024 TTM Cash Operating Margin and Realized Pricing ($/Boe) Operational Excellence and Cost Control Drive Profitability • High oil weighting of 66% (85% liquids) contributes to high realized pricing per Boe • Low cash operating costs and maintaining cost discipline drive margin expansion • Generating ~$28 per Boe in margin TTM demonstrates strength of long-life asset base • Strong cash operating margins allow the Company to withstand volatile commodity price swings • Robust margins lead to increased cash flow, debt reduction and stronger returns “ Improving operational margins leads to higher returns...pursuing strategic acquisitions of high margin assets leads to sustainable higher returns “ - Paul McKinney 1. Peers include: Amplify Energy, Battalion, Baytex, Berry Corporation, Civitas, Crescent Energy, Mach Natural Resources, Riley Permian, TXO Partners, Vital Energy and W&T Offshore. 2. Source information for data obtained from Peer Reports and Capital IQ and Factset as of 03/13/2025. 3. Cash Operating Margins is defined as revenues (excluding hedges) less LOE, cash G&A (excluding share-based compensation), interest expense, workovers, operating expenses, production taxes, ad valorem taxes and gathering/transportation costs. $70 $SO $40 $30 $20 $10 $0 - • $49.70 VI- lJJ I-' 0 00 Peer 1 • $69.65 VI- N 00 0 00 Peer2 • $50.94 RE I • $41.23 • $38.19 VI- VI- N N ?' ~ .... w N ~ Peer 3 Peer 4 Cash Operating Margin • $39.53 VI- N I-' 00 lJl Peer s $40.42 Median • $37.94 VI-.... 00 0 I-' Peer 6 $29.53 VI-.... ~ -....J O'I Peer 7 • Realized Pricing • $39.61 VI- ?J w ~ Peer 8 • $42.23 VI- -....J 00 lJl Peer 9 • $41.72 VI- ?' -....J lJJ Peer 10 • $33.19 -(7). lJl \0 O'I Peer 11
Ring Energy, Inc. Enhanced Value for Stockholders 12 Improved Metrics - Increased Production, Reduction in Costs, and Increased Proved Reserves on per Share Basis Production/Share Boe/Share 0.034 Up 6% 1. See Appendix for calculation of All-in Cash Operating Costs. 2. YE 2023 & 2024 CGA SEC Proved Reserves (MMBoe) divided by total shares outstanding in the period. All-in-Cash Operating Costs1 $/Boe SEC 1P Reserves/Share2 Boe/Share Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Up 1% $22.99 all-in cash operating costs decreased despite inflationary pressures Down 2% 0.036 0.040 $ 25 0.700 0.038 $ 24 23.46 0.680 0.67 23.04 0.66 0.036 $ 23 0.660 0.034 $ 22 0.640 0.032 $ 21 0.620 0.030 2023 2024 $ 20 2023 2024 0.600 2023 2024 -
Ring Energy, Inc. Consistent Value for Stockholders 13 Minimized the Effect of a 7% Reduction in Realized Prices 1. Adjusted Cash Flow from Operations (ACFFO), Adjusted EBITDA and Adjusted FCF are Non-GAAP financial measures. See Appendix and prior releases for reconciliation to GAAP measures. Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Adjusted EBITDA1 $MM Adjusted Free Cash Flow1 ACFFO1 $MM $MM $ 250 $ 275 $55 $ 225 $ 250 $50 $236 $233 $45 $ 200 $197 $195 $ 225 $45 $44 $175 $ 200 $40 $150 $175 2023 2024 2023 2024 $35 2023 2024 -
Ring Energy, Inc. Track Record of Strategic Consolidation 14 Acquisition Track Record § Ring’s pursuit of accretive, balance sheet enhancing acquisitions is a key component of our future growth § M&A wave of conventional Permian assets from majors, large independents, private equity-backed operators and private family-owned companies § Limited buyer competition from public companies uniquely positions Ring as a consolidator for future acquisitions § Experienced management team with shared vision and positioned to capitalize on attractive M&A opportunities § Track record of disciplined M&A, which has allowed Ring to acquire undeveloped locations at a minimal acreage cost since proved developed value of reserves has underpinned purchase price for the past four acquisitions Four Acquisitions Since 2019 Increases Net Production by >3.0x Year Completed Wishbone (2019) Stronghold (2022) Founders (2023) Lime Rock (2025) Total Acquired Acquisition Price ($MM) $300 $465 $75 $100 $940 Consideration Mix (% Cash / % Stock) 90% / 10% 51% / 49% 100% / 0% 90% / 10% 64% / 36% Acquired Net Acreage ~38,000 ~37,000 ~3,600 ~17,700 ~96,300 Number of New Drill Locations1 >190 (Hz) >280 (Vt) >50 (Vt) >40 (Hz) >560 Acreage includes operated and Non-Operated WI Legend Ring Energy Legacy Lime Rock Resources Founders Oil & Gas Stronghold Energy Operating Wishbone Energy Partners Note: See Appendix for disclaimers regarding non-GAAP measures and footnotes 1. Includes all locations operated and non-operated “PUD” reserve categories and 2P / 3P locations at the time of the acquisition. Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI ~20,000 - 2018A Dally Production {Boe/d) ,l Wishbone ♦'♦ w!!'!~ Stronghold • ~N~!~l~P~~l~\Pc Founders @~?~~~~~ UmeRock ~,LIME ROCK llf!!'1~ RESOURCES 2H202SE Dally Production (Boe/dJ ■ ■ ■ □ ■
Ring Energy, Inc. G ro ss P ro d uc ti o n (2 -S tr ea m M b o e/ d ) Permian Basin – Conventional Opportunities Source: Enverus, Companies include Basin O&G, Blackbeard Operating, Boyd & McWilliams, Burk Royalty, Citation O&G, ConocoPhillips, Crescent Energy, Diversified, Elevation Resources, Formentera Partners, Hilcorp, Kinder Morgan, OXY, Riley Petroleum, Ring Energy, Sabinal Energy, Scout Energy, Texland Petroleum, and Two P Partners. Delaware Basin CBP NWS Eastern Shelf Midland Basin Publics Privates REI CBP/NWS Publics CBP/NWS Privates The Prize in CBP & NWS (Texas Only) is… ~ 420,000 Boepd (G) 82% Oil (Dec. 2024) % Oil 80% 69% 80% 76% 82% 80% 84% 60% 91% 71% 64% 91% 82% 50% 77% 95% 67% 92% 88% 86% Peers 15 Two P Partners Boyd & McWilliams Acquire accretive, balance sheet enhancing CBP & NWS assets ü CBP & NWS remain the “shale era” underexplored opportunity in the Permian Basin ü Conventional opportunities are the focus of Ring Energy’s deep bench of technical talent ü Ring has a proven track record of generating superior returns by applying new drilling and completion technologies to overlooked conventional zones ü M&A wave of conventional targets continues with divestitures from majors and large independents ü Lower cost, shallower decline, and less public E&P competition sets the stage for accretive acquisitions ü We view CBP & NWS assets as targets for growth Focused on Consolidating Conventional Assets in the Central Basin Platform & Northwest Shelf Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI ■ ■ ■ - ~ DXV ~ 110 1 .. BL~~~~~fD ~ ~;;1 ., •••• • ORGAN ■ r1,uR1< I =•~OO 47 28 I 123 2 I I 3 I 4 15 ... - - - ,~'.\ u ~ibtU,, ' Sabinal Energy Cono~ hillips J-lilcorp ELEVATION 20 20 ·~ 11 11 6 7 8 9 10 ~) 1f FORMENTERA G Crescent l'IBASIN JP sypd wo ~ SC$ UT .., Oil&Gas Ene,gy DIVERSIFIED 9 8 6 o nergy 6 5 3 3 3 2 11 12 13 14 15 16 17 18 19 20
Ring Energy, Inc. Ring Trading at Discount Compared to Recent Transaction REI Suggested Valuation Using APA CBP & NWS Assets Divestiture Valuation Metrics Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI16 Private Buyers Paying Higher Valuation Multiples for Conventional Permian Assets $950MM $644MM $905MM APA Non-Core asset divestiture in CBP & NWS REI trading share price and EV as of April 30, 2025 REI indicative trading share price and EV using APA Valuation Metrics 1. APA Corp press release on September 10, 2024, asset sale of non-core properties in Permian Basin. 2. Source ENVERUS as of 11/5/2024. 3. Field Level Margin $ per Boe is calculated as realized $ per Boe minus LOE, GP&T, operating lease exp., severance and ad valorem taxes. 4. Ring Energy decline is Pro Forma internal management estimates for PDP Ring legacy and the acquisition of Lime Rock’s CBP assets. APA Permian Divestiture1 Date Announced 9/10/2024 Sale Price ($MM) $950 Net Production (Boe/d) 21,000 $ per Boe/d $45,238 Current REI Valuation3 4/30/2025 Share Price $0.89 Shares Outstanding (MM) ~207 Equity Value ($MM) $184 Debt Outstanding Q125 $460 Enterprise Value ($MM) $644 2025 Net Production (Boe/d) 20,000 $ per Boe/d $32,200 REI at APA Valuation Metrics EV ($MM) @ Production metric 45.2K $905 Equity Value ($MM) $445 Share Price ($) $2.15 Asset Metrics Comparison REI APA Divestiture1,2 2025E Net Production (Boe/d) ~20,000 21,000 % Oil 66% 57% Q1 2025 Field Level Margin3 ($/Boe) >$32 < REI NTM PDP4 Decline % 22% 7% Q1 2025 LOE ($/Boe) $11.89 > REI CO2 Operations NO YES Operated Well Count (G) ~1,030 ~5,100+ $1,000 $2.50 • Share Price ($/sh) .------- $950 $2.15 I • I $900 1$2.00 - I a, :E $850 I ... :E ro ..r:: -v,. $800 1s1.so ~ -cu :::s I Q) ta $750 I u > ·;:: cu 0.. VI I Q) ·c $700 $0.89 1s1.oo] Q. ... • cu V') ... $650 I C w w 0::: I $600 ,so.so $550 I I $500 1$0.00 APA Divestiture REI @ 4/30/2025 REI @ APA Prod Mult I .-------- -
Ring Energy, Inc. Robust Value Proposition Through Commodity Price Cycles 17 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI 2025 and Beyond Target leverage ratio below 1.0x and position Ring to return capital to stockholders Remaining focused on maximizing FCF generation to strengthen the balance sheet Strong Cash Operating margins help deliver superior results & helps manage risk in market downturns Disciplined capital program retains flexibility to respond to changing market conditions, delivering competitive returns Pursuing accretive, balance sheet enhancing acquisitions to increase scale, lower break-even costs, build inventory and accelerate ability to pay down debt -
www.ringenergy.com FINANCIAL OVERVIEW VALUE FOCUSED PROVEN STRATEGY | MAY 8, 2025 | NYSE AMERICAN: REI
Ring Energy, Inc. 1.67x 1.59x 1.59x 1.66x Historical Metrics 19 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Quarterly Analysis of AFCF1 Leverage Ratio (LTM)1 Disciplined and Efficient Capital Spending Focused on Sustainably Generating AFCF Enhances Our Unrelenting Goal to Strengthen the Balance Sheet 1. Adjusted EBITDA, Adjusted Free Cash Flow and Leverage Ratio are Non-GAAP financial measures. See Appendix and prior releases for reconciliation to GAAP measures. 2. Net Interest Expense included in table is interest expense net of interest income and excludes deferred financing costs amortization. 1.9x Realized $/Boe $54.56 $55.06 $48.24 $46.14 $47.78 1 12 Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 - Adj EBITDA $MM -capEx $MM - Net Interest Exp $MM Adj Free Cash Flow $MM -
Ring Energy, Inc. Reducing Debt & Increasing Liquidity 20 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Disciplined Capital Spending & Sustainably Generating AFCF RBL Balance & Adjusted Debt Paydown1,2 ($ Million) Liquidity3 ($ Million) 1. Paydown of $17 million is net of the $182 million that was borrowed to fund the Stronghold acquisition. 2. Paydown of $19 million is net of the $50 million that was borrowed to fund the Founders acquisition. 3. Liquidity is defined as cash and cash equivalents plus available borrowings under Ring’s credit agreement. Stronghold Acquisition final deferred payment Founders Acquisition2 Founders Acquisition Founders Acquisition final deferred payment FY Adv tax payment and other one-time cash items Adj. Debt Paydown ($MM) RBL Balance ($MM) Lime Rock Acquisition Lime Rock Acquisition $500 $450 $400 $3 50 $300 $2 50 $40 $20 $0 • . -- . i' -------------------$-3.W,;::,--- -- 0 1 '23 0 2 '23 0 3'23 04'23 01 '24 0 2 '24 0 3 '24 0 4'24 0 1 '25 __ ............................................................ ____ ............................................. . $3 $3 $7 -$20 · ... . -$7 ... . -$40 ................................ ...... .................................................... ....................................... ........... ..... ............................... ' -$60 -$80 01'23 02'23 03'23 04'23 01'24 02'24 03'24 04'24 01'25 - $240 $220 $200 $180 $160 $140 ... $120 $100 $80 $60 $40 $20 $0 $217 $204 $208 $194 $179 $171 $175 $179 $141 01'23 02'23 03'23 04'23 01'24 02'24 03'24 04'24 01'25
Ring Energy, Inc. Competitive Value for Stockholders 21 Track Record of 3 Consecutive Years of Corporate Returns Above 15% Despite Drop in Commodity Prices Cash Return on Capital Employed1 (CROCE) % Strong CROCE % • Disciplined and successful capital program driving returns • Shallow decline production base contributes to higher returns • High quality inventory together with operating proficiency and efficient execution on capital program led to increased profitability • Multiple asset core areas in NWS & CBP with existing infrastructure provide diverse inventory of high return, low cost horizontals and verticals providing flexibility to react to volatile market conditions and ability to maximize AFCF generation 1. The Company defines “CROCE” as Adjusted Cash Flow from Operations divided by average debt and shareholder equity for the period. 2022 – ‘24 CROCE Avg of 17.9% Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Avg WTI $/Bbl & Avg Realized $/Boe 25.0% $100.00 $94.90 ~ Avg Realized $/Boe Avg WTI Price 20.0% $90.00 $/Bbl $77.58 15.0% $80.00 $76.95 $76.63 10.0% $70.00 5.0% $60.00 0.0% $50.00 2022 2023 2024 2022 2023 2024 -
www.ringenergy.com ASSET OVERVIEW VALUE FOCUSED PROVEN STRATEGY | MAY 8, 2025 | NYSE AMERICAN: REI
Ring Energy, Inc. Committed to Sustainable Success 23 2024 Sustainability Report Progressing our ESG Journey A Target Zero Day is a Day that Results in: Zero Company or Contractor OSHA Recordable Injury, and Zero Agency Reportable Spill or Release as Defined by TRRC, EPA, TCEQ, etc., and Zero Preventable Vehicle Incidents, and Zero H2S Alarms of 10PPM or Greater Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI • Created ESG Task Force and established Target Zero 365 (TZ-365) Safety & Environmental Initiative in 2021to monitor and guide company’s adherence to ESG standards. – Designed to protect the workforce, environment, communities and financial sustainability. – Focused on Safety-first environment and achieving high percentage of Target Zero Days. • 2024 YoY reduction of methane emissions by ~25% • Q1 2025 Continued focus on improving internal processes and minimizing environmental impact. – Completed implementation of contractor management program and initiated contractor orientation process to support and ensure safe work practices within our contract work force. – Initiated implementation of enhanced facility maintenance program to proactively eliminate leaks and spills. • 2025 Capital Program includes Emission Reduction plans with: – Continued upgrades of Tank Vent Control Systems including High and Low pressure Flares. – Continued upgrades of vessel controls to eliminate pneumatic devices and/or convert to non-vent controls. – Migrating Leak Detection and Repair program in-house to increase quality and reduce costs. Download Report PDF -
Ring Energy, Inc. Assets Overview 24 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Deep Inventory of High-Return Drilling and Re-Completion Locations Select Recent New Drill Vertical Well Results – Central Basin Platform 1. Vertical completion no lateral length noted. 2. Peak IP 60 (Boepd) based on best rolling 60-day average. 3. Peak IP 30 (Boepd) based on best continuous rolling 30-day average, due to lack of 60 day production data. 4. Peak IP 15 (Boepd) based on best continuous rolling 15-day average, due to lack of 60 day production data. Select Recent Re-Completion Well Results – Central Basin Platform Select Recent New Drill Horizontal Well Results – Northwest Shelf Select Recent New Drill Horizontal Well Results – Central Basin Platform Includes operated & NonOP Peak IP Geological Area Well Name 30 / 60 Region (Soepd) CSP PJ Lea PJ Lea #4008M 1' 2 210 CSP PJ Lea PJ Lea #3909M 1' 2 287 CSP PJ Lea PJ Lea #3912M 1' 2 275 ... CSP PJ Lea PJ Lea 4703M 1' 2 224 N 0 Scharbauer C NW #103 1' 2 N CSP Penwell 342 CSP Penwell M illard D #104 1' 2 299 CSP Penwell Millard E 105 1' 2 236 CSP Penwell Scharbauer C 103 1•2 273 CSP PJ Lea PJ Lea #4704M 1' 3 287 "' N CSP Penwell M illard D 1061' 3 332 0 N CSP Penwell Scharbauer C 302 1' 3 308 Peak IP Geological Area Well Name 60 Region (Soepd) ... CSP Henderson Henderson M F 05603G ' ·' 211 N 0 CSP Henderson Henderson M F 1901'3 172 N - Basin Northwest Shelf Delaware Oi l (%) WI(%) CSP Midland 81% 100% 81% 100% 80% 100% 77% 100% 76% 100% 86% 100% 80% 100% 86% 100% 84% 100% 80% 100% 89% 100% 'ING w Oil(%) WI(%) 86% 100% 88% 100% WARD TERRY L) .. .............. KLER ♦ ~ 'f"r. GAINES ... ANDREWS 1A ECTOR \ ~ . . --· ~. ., : ~ : = .. , .. . ..... : DAWSC MARTII\ MIDLAND UPTON Peak IP Lateral Geological Area Well Name 30 / 60 Oil(%) Length WI(%) Region (Soepd) (ft) NWS Platang Matador 646 B #4H2 450 90% 5048 100% ... N NWS Platang Matador 646 C #2H2 326 91% 5064 100% 0 N NWS Platang Cougar 726 2H 2 334 85% 5076 100% NWS Platang Red Raider 663 SH 2 574 88% 5053 75% "' NWS Platang Red Raider 663 A 6H 2 541 89% 5043 75% N 0 N NWS Platang Red Raider 663 B 7H2 554 89% 5059 75% NWS Platang Red Raider 663 C 8H 2 659 89% 6402 75% Peak IP lateral Geological Area Well Name 30 I 60 Oil(%) Length WI(%) Region (Soepd) (ft) CBP Shafter Lake University Block 14 Cons. #2401H 2 336 95% 5056 100% ... CBP Shafter Lake University 14S #1402H2 411 97% 5074 100% N CBP Shafter Lake Homer 1H 2 313 93% 5039 100% 0 N CBP Shafter Lake Savage 1H2 428 97% 4998 100% CBP Shafter Lake Harmonia 1H2 263 97% 5039 100%
Ring Energy, Inc. Assets Overview 25 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI New Drill Inventory Performance Consistent HZ Well Performance San Andres Horizontal Play EUR (MBoe) per 1000’ Lateral Feet Enhanced Vertical Well Performance CBP Vertical Multi-Stacked Play 2 D&C Capex $ per Effective Lateral Foot Vertical D&C Capex1 $ per Frac Stage ($M) 87-91% Oil - l Reduced by 11% Reduced by 3% 1. PJ Lea new drills are 6 frac stages and Penwell new drills are 7 frac stages. ~70% Oil ~81% Oil ~100 ~ 20,000 ~ w 0 m C i::: ~15,000 ~ 75 ai :r; 10,000 >, CV C I 0 en 5,000 E ::, 0 50 0 2023 2024 2023 2024 $ 600 $ 275 $ 550 $ 500 $ 250 $ 450 $ 400 $ 225 2023 2024 2023 2024 -
Ring Energy, Inc. Impact of Founders Acquisition 26 Net Sept. 2023 Sept 2024 % Diff Boe/d 1,887 2,654 41% Bo/d 1,497 1,821 22% Lift Cost $/Boe $14.84 $12.27 -17% (MMBoe) YE 2023 Q3 2024 % Diff YE'23 1P 7.9 8 1% Sales Prod. 0.9 PDP 4.2 5.3 26% # of Wells Drilled 0 12 # Locations Remaining1 ~50 ~50 Reduced Capex by 28% Performance Exceeded Initial Expectations Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Founders Acquisition $75MM REI Net Prod. (MBoe/d) 1 REI Net Debt $MM Production (G) Boe/d 2 LOE $/Boe D&C $MM 90 Day Cum MBoe 2 Proved Reserves MMBoe 3 Close date Aug 15, 2023 17.3 REI Standalone REI Pro Forma 20.1 16% growth to PF company REI Standalone $397 $392 Net Debt reduced over 5 qtrs Reduced LOE by 20% Founders Penwell Asset in Ector County – Post Closing Performance REI Pro Forma – Post Closing Performance Increased Gross Prod by 38% Increased 1P Reserves by 46%Increased Performance by 24% 1. 3-stream net production 2. 2-stream gross production as reported to Texas RRC 3. CGA Proved reserves for Penwell Field REI Pro Forma A Active Rigs • AcquisitionAcreage 1------,------------- -l • Exist ing Acreage 4,000 3,000 2,000 1,000 0 Winkler Ce ntral Basin Platform Sep-23 - Ector .... ·· - -· \ A -. , • ~ Crane ~ .. Sep-24 $25 $20 $15 $10 $5 $0 $100 $75 $50 $25 $0 Cash Due @ Close Eff date (Post Adj Close) Deferred Payment 04 2023 FY 2024 $3.0 $2.0 $1 .0 $0.0 15%@month 4 18% adjust 67% cash 21 .0 20.0 19.0 18.0 17.0 16.0 Founders 2022-23 $450 $425 $400 11 $375 $350 02'23 03'23 04'23 01'24 02'24 03'24 02'23 03'23 04'23 01 '24 02'24 03'24 25 15.0 20 10.0 15 10 5.0 5 0 0.0 Pre 2023 Post 2023 YE 23 REI 2024
Ring Energy, Inc. San Andres Horizontal Play Characteristics 27 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Proven, Conventional, Top Tier Returns San Andres Hz Delaware Hz Midland Hz High ROR Oil Play ü ü ü Low D&C Costs ü Lower 1st Year Decline ü Low Lease Acquisition Cost ü Long life wells ü Oil IPs >750 Bbl/d ü ü Multiple Benches ü ü > 85% Oil ü $30-35/Bbl D&C Break-even2 ü 1. D&C capex range is for CBP & NWS 1.0 & 1.5 mile laterals in 2024. 2. Break-even costs is for core inventory in NWS & CBP horizontal asset areas. The range in break-even based on YTD capex spend and depends on lateral length, asset area, completion and artificial lift type. • Permian Basin has produced >30 BBbl — San Andres accounts for ~40% • Low D&C costs1 $2.3 - $3.4 MM per Hz 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 CO2 flood I I I -
Ring Energy, Inc. Vertical Multi-Stacked Pay Characteristics 28 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Proven, Conventional, Top Tier Returns CBP Vt Stack & Frac Delaware Hz Midland Hz High ROR Oil Play ü ü ü Low D&C Costs ü Lower 1st Year Decline ü Low Lease Acquisition Cost ü Long life wells ü Oil IPs >750 Bbl/d ü ü Multiple Benches ü ü ü High NRI’s ü $35-$40/Bbl D&C Break-even2 ü • Central Basin Platform has produced >15 BBboe — Vertical multi-stage fracs targeting legacy reservoirs that have been productive throughout the basin (Clearfork to Wolfcamp) • Low D&C costs1 $1.0 - $1.9 MM per well • Targeted Vertical completion depths of ~4,000-7,000’ • Typical oil column of 1,000-1,500’ • Life >30+ years • Initial peak oil rates of 150 - 400 Bbl/d • Higher primary recovery than shales • Potential for waterflood and CO2 flood 1. D&C capex range for verticals include all CBP-S inventory. 2. Break-even costs is for core inventory in NWS & CBP horizontal asset areas. The range in break-even based on YTD capex spend and depends on lateral length, asset area, completion and artificial lift type.-
www.ringenergy.com VALUE FOCUSED PROVEN STRATEGY | MAY 8, 2025 | NYSE AMERICAN: REI THANK YOU Company Contact Al Petrie (281) 975-2146 apetrie@ringenergy.com Wes Harris (281) 975-2146 wharris@ringenergy.com Analyst Coverage ROTH Capital Partners John M. White (949) 720-7115 jwhite@roth.com Tuohy Bothers Investment Noel Parks (215) 913-7320 nparks@tuohybrothers.com Water Tower Research Jeff Robertson (469) 343-9962 jeff@watertowerresearch.com Ring Headquarters 1725 Hughes Landing Blvd Ste 900 The Woodlands, TX 77830 Phone: 281-397-3699
www.ringenergy.com APPENDIX VALUE FOCUSED PROVEN STRATEGY | MAY 8, 2025 | NYSE AMERICAN: REI
Ring Energy, Inc. REI Historical Price Performance1 31 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Price Performance Since January 1, 2022 (1) Sources Factset as of 5/2/2025 Stronghold Announcement Founders Announcement 6.5 MM warrants exercised 3.0 MM warrants exercised 4.5 MM warrants exercised 14.5 MM warrants exercised Warburg Pincus sell down 12.6 MM shares Warburg Pincus sell down 4.4 MM shares Warburg Pincus sell down 6.2 MM shares Warburg Pincus sell down 6.6 MM shares 5.5 5.0 4.5 4.0 3.5 3.0 2.5 2.0 1.5 1.0 0.5 Jan 22 - Apr22 Jul22 Oct22 140.00 120.00 100.00 80.00 60.00 40.00 0.00 Jan 23 Apr 23 Jul 23 Oct 23 Jan 24 Apr 24 Jul 24 Oct24 Jan 25 Apr25 - Ring Energy, Inc. - Price (Left) - WTI Crude Oil ($/bbl) - Price (Right)
Ring Energy, Inc. Financial Overview 32 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI (1) The oil basis swap hedges are calculated as the fixed price (weighted average spread price above) less the difference between WTI Midland and WTI Cushing, in the issue of Argus Americas Crude. Derivative Summary as of March 31, 2025 (2) The gas basis swap hedges are calculated as the Henry Hub natural gas price less the fixed amount specified as the weighted average spread price above. The Company has hedged: 2025: ~1.7 million barrels of oil at avg downside price of $64.44 2026: ~1.8 million barrels of oil at avg downside price of $66.89 2025: ~2.0 BCF of natural gas at avg downside price of $3.43 2026: ~2.6 BCF of natural gas at avg downside price of $3.56 Oil Hedges (WTI) Gas Hedges (Henry Hub) Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 Q1 2027 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 Q1 2027 Swaps: NYMEX Swaps: Hedged volume (Bbl) 151,763 351,917 141 ,755 477,350 457,101 59,400 423,000 381,500 Hedged volume (MMBtu) 513,900 455,250 128,400 140,600 662,300 121,400 613,300 Weighted average swap price $ 68.53 $ 71.41 $ 69.13 $ 70.16 $ 69.38 $ 66.70 $ 66.70 $ 63.80 Weighted average swap $ 3.60 $ 3.88 $ 4.25 $ 4.20 $ 3.54 $ 4.22 $ 3.83 $ price Two-way collars: Two-way collars: Hedged volume (Bbl) 464,100 225,400 404,800 379,685 Hedged volume (MMBtu) 18,300 308,200 598,000 553,500 515,728 700,000 Weighted average put price $ 60.00 $ 65.00 $ 60.00 $ $ $ 60.00 $ $ Weighted average put price $ 3.00 $ 3.00 $ 3.00 $ 3.50 $ $ 3.00 $ $ 4.00 Weighted average call price $ 69.85 $ 78.91 $ 75.68 $ $ $ 72 .50 $ $ Weighted average call price $ 4.15 $ 4.75 $ 4.15 $ 5.03 $ $ 3.93 $ $ 5.20 Oil Hedges (basis differential) Gas Hedges (Basis Differential) Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 Q1 2027 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 Q1 2027 Argus basis swaps: El Paso Permian Basin basis swaps: Hedged volume (Bbl) 183,000 276,000 276,000 Hedged volume (MMBtu) 700,000 Weighted average spread price <1> $ 1.00 $ 1.00 $ 1.00 $ $ $ $ $ Weighted average spread price <2> $ $ $ $ $ $ $ $ 0.74 -
Ring Energy, Inc. Income Statement and Operational Stats 33 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Income Statement Operational Stats (1) 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. (Unaudited) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Oil, Natural Gas, and Natural Gas Liquids Revenues $ 79,091,207 $ 83,440,546 $ 94,503,136 Costs and Operating Expenses Lease operating expenses 19,677,552 20,326,216 18,360,434 Gathering, transportation and processing costs 203,612 130,230 166,054 Ad valorem taxes 1,532,108 2,421,595 2,145,631 Oil and natural gas production taxes 3,584,455 3,857,147 4,428,303 Depreciation, depletion and amortization 22,615,983 24,548,849 23,792,450 Asset retirement obligation accretion 326,549 323,085 350,834 Operating lease expense 175,091 175,090 175,091 General and administrative expense (including share-based compensation) 8,619,976 8,035,977 7,469,222 Total Costs and Operating Expenses 56,735,326 59,818,189 56,888,019 Income from Operations 22,355,881 23,622,357 37,615,117 Other Income (Expense) Interest income 90,058 124,765 78,544 Interest (expense) (9,498,786) (10,112,496) (11,498,944) Gain (loss) on derivative contracts (928,790) (6,254,448) (19,014,495) Gain (loss) on disposal of assets 124,610 — 38,355 Other income 8,942 80,970 25,686 Net Other Income (Expense) (10,203,966) (16,161,209) (30,370,854) Income Before Benefit from (Provision for) Income Taxes 12,151,915 7,461,148 7,244,263 Benefit from (Provision for) Income Taxes (3,041,177) (1,803,629) (1,728,886) Net Income (Loss) $ 9,110,738 $ 5,657,519 $ 5,515,377 Basic Earnings (Loss) per Share $ 0.05 $ 0.03 $ 0.03 Diluted Earnings (Loss) per Share $ 0.05 $ 0.03 $ 0.03 Basic Weighted-Average Shares Outstanding 199,314,182 198,166,543 197,389,782 Diluted Weighted-Average Shares Outstanding 201,072,594 200,886,010 199,305,150 (Unaudited) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Net sales volumes: Oil (Bbls) 1,086,694 1,188,272 1,218,837 Natural gas (Mcf) 1,615,196 1,683,793 1,496,507 Natural gas liquids (Bbls) 299,366 339,589 263,802 Total oil, natural gas and natural gas liquids (Boe)(1) 1,655,259 1,808,493 1,732,057 % Oil 66 % 66 % 70 % % Natural Gas 16 % 15 % 15 % % Natural Gas Liquids 18 % 19 % 15 % Average daily sales volumes: Oil (Bbls/d) 12,074 12,916 13,394 Natural gas (Mcf/d) 17,947 18,302 16,445 Natural gas liquids (Bbls/d) 3,326 3,691 2,899 Average daily equivalent sales (Boe/d) 18,392 19,658 19,034 Average realized sales prices: Oil ($/Bbl) $ 70.40 $ 68.98 $ 75.72 Natural gas ($/Mcf) (0.19) (0.96) (0.55) Natural gas liquids ($/Bbls) 9.65 9.08 11.47 Barrel of oil equivalent ($/Boe) $ 47.78 $ 46.14 $ 54.56 Average costs and expenses per Boe ($/Boe): Lease operating expenses $ 11.89 $ 11.24 $ 10.60 Gathering, transportation and processing costs 0.12 0.07 0.10 Ad valorem taxes 0.93 1.34 1.24 Oil and natural gas production taxes 2.17 2.13 2.56 Depreciation, depletion and amortization 13.66 13.57 13.74 Asset retirement obligation accretion 0.20 0.18 0.20 Operating lease expense 0.11 0.10 0.10 G&A (including share-based compensation) 5.21 4.44 4.31 G&A (excluding share-based compensation) 4.19 3.52 3.32 G&A (excluding share-based compensation and transaction costs) 4.18 3.51 3.32 -
Ring Energy, Inc.34 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Statements of Cash FlowsBalance Sheet (Unaudited) March 31, 2025 December 31, 2024 ASSETS Current Assets Cash and cash equivalents $ 1,100,851 $ 1,866,395 Accounts receivable 35,680,686 36,172,316 Joint interest billing receivables, net 2,121,035 1,083,164 Derivative assets 5,309,892 5,497,057 Inventory 3,300,755 4,047,819 Prepaid expenses and other assets 1,156,529 1,781,341 Total Current Assets 48,669,748 50,448,092 Properties and Equipment Oil and natural gas properties, full cost method 1,932,616,777 1,809,309,848 Financing lease asset subject to depreciation 4,272,259 4,634,556 Fixed assets subject to depreciation 3,359,292 3,389,907 Total Properties and Equipment 1,940,248,328 1,817,334,311 Accumulated depreciation, depletion and amortization (496,993,139) (475,212,325) Net Properties and Equipment 1,443,255,189 1,342,121,986 Operating lease asset 1,753,693 1,906,264 Derivative assets 5,020,380 5,473,375 Deferred financing costs 6,911,264 8,149,757 Total Assets $ 1,505,610,274 $ 1,408,099,474 LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities Accounts payable $ 86,417,436 $ 95,729,261 Income tax liability 537,591 328,985 Financing lease liability 846,380 906,119 Operating lease liability 661,487 648,204 Derivative liabilities 5,426,195 6,410,547 Notes payable — 496,397 Deferred cash payment 9,415,066 — Asset retirement obligations 441,611 517,674 Total Current Liabilities 103,745,766 105,037,187 Non-current Liabilities Deferred income taxes 31,496,585 28,591,802 Revolving line of credit 460,000,000 385,000,000 Financing lease liability, less current portion 708,304 647,078 Operating lease liability, less current portion 1,234,690 1,405,837 Derivative liabilities 3,632,133 2,912,745 Asset retirement obligations 28,826,738 25,864,843 Total Liabilities 629,644,216 549,459,492 Commitments and contingencies Stockholders' Equity Preferred stock - $0.001 par value; 50,000,000 shares authorized; no shares issued or outstanding — — Common stock - $0.001 par value; 450,000,000 shares authorized; 206,509,126 shares and 198,561,378 shares issued and outstanding, respectively 206,509 198,561 Additional paid-in capital 808,627,109 800,419,719 Retained earnings (Accumulated deficit) 67,132,440 58,021,702 Total Stockholders’ Equity 875,966,058 858,639,982 Total Liabilities and Stockholders' Equity $ 1,505,610,274 $ 1,408,099,474 (Unaudited) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Cash Flows From Operating Activities Net income $ 9,110,738 $ 5,657,519 $ 5,515,377 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization 22,615,983 24,548,849 23,792,450 Asset retirement obligation accretion 326,549 323,085 350,834 Amortization of deferred financing costs 1,238,493 1,299,078 1,221,607 Share-based compensation 1,690,958 1,672,320 1,723,832 Credit loss expense 17,917 (26,747) 163,840 (Gain) loss on disposal of assets (124,610) — — Deferred income tax expense (benefit) 2,805,346 1,723,338 1,585,445 Excess tax expense (benefit) related to share-based compensation 99,437 9,011 40,808 (Gain) loss on derivative contracts 928,790 6,254,448 19,014,495 Cash received (paid) for derivative settlements, net (553,594) 745,104 (1,461,515) Changes in operating assets and liabilities: Accounts receivable (564,158) 349,474 (5,240,487) Inventory 747,064 580,161 171,416 Prepaid expenses and other assets 624,812 295,555 503,704 Accounts payable (10,385,137) 4,462,089 (1,601,276) Settlement of asset retirement obligation (207,580) (613,603) (591,361) Net Cash Provided by Operating Activities 28,371,008 47,279,681 45,189,169 Cash Flows From Investing Activities Payments for the Lime Rock Acquisition (70,859,769) — — Payments to purchase oil and natural gas properties (647,106) (1,423,483) (475,858) Payments to develop oil and natural gas properties (31,083,507) (36,386,055) (38,904,808) Payments to acquire or improve fixed assets subject to depreciation (34,275) — (124,937) Proceeds from sale of fixed assets subject to depreciation 17,360 — — Proceeds from divestiture of equipment for oil and natural gas properties — 121,232 — Net Cash Used in Investing Activities (102,607,297) (37,688,306) (39,505,603) Cash Flows From Financing Activities Proceeds from revolving line of credit 114,000,000 22,000,000 51,500,000 Payments on revolving line of credit (39,000,000) (29,000,000) (54,500,000) Payments for taxes withheld on vested restricted shares, net (896,431) — (814,985) Proceeds from notes payable — 58,774 — Payments on notes payable (496,397) (475,196) (533,734) Payment of deferred financing costs — (42,746) — Reduction of financing lease liabilities (136,427) (265,812) (255,156) Net Cash Provided by (Used in) Financing Activities 73,470,745 (7,724,980) (4,603,875) Net Increase (Decrease) in Cash (765,544) 1,866,395 1,079,691 Cash at Beginning of Period 1,866,395 — 296,384 Cash at End of Period $ 1,100,851 $ 1,866,395 $ 1,376,075 1111
Ring Energy, Inc. “PV-10” is a non-GAAP financial measure that differs from a financial 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 measure of the Company’s oil and natural gas properties is relevant and useful to investors because it presents the estimated discounted future net cash flows attributable to its estimated proved reserves independent of its income tax attributes, thereby isolating the intrinsic value of the estimated future cash flows attributable to its reserves. Management believes 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 on 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 considered in isolation or as a substitute for the standardized measure of discounted future net cash flows as defined under GAAP. The Company defines “Cash Return on Capital Employed” or “CROCE” as Adjusted Cash Flow from Operations divided by average debt and shareholder equity for the period. The Company defines “All-In Cash Operating Costs,” a non-GAAP financial measure, as “all in cash” costs which includes lease operating expenses, G&A costs excluding share-based compensation, net interest expense (including interest income and expense, excluding amortization of deferred financing costs), workovers and other operating expenses, production taxes, ad valorem taxes, and gathering/transportation costs. Management believes that this metric provides useful additional information to investors to assess the Company’s operating costs in comparison to its peers, which may vary from company to company. The Company defines “Cash Operating Margin,” a non-GAAP financial measure, as realized revenues per Boe less all-in cash operating costs per Boe. Management believes that this metric provides useful additional information to investors to assess the Company’s operating margins in comparison to its peers, which may vary from company to company. The “Current Ratio” is calculated under our existing senior revolving credit facility and means as of any date, the ratio of (i) our Current Assets as of such date to (ii) our Current Liabilities as of such date. Based on its credit agreement, the Company defines Current Assets as all current assets, excluding non-cash assets under Accounting Standards Codification (“ASC”) 815, plus the unused line of credit. The Company’s non-cash current assets include the derivative asset marked to market value. Based on its credit agreement, the Company defines Current Liabilities as all liabilities, in accordance with GAAP, which are classified as current liabilities, including all indebtedness payable on demand or within one year, all accruals for federal or other taxes payable within such year, but excluding current portion of long-term debt required to be paid within one year, the aggregate outstanding principal balance and non-cash obligations under ASC 815. Non-GAAP Disclosure 35 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Certain financial information included in this Presentation are not measures of financial performance recognized by accounting principles generally accepted in the United States (“GAAP”). These non-GAAP financial measures are “Adjusted Net Income,” “Adjusted EBITDA,” “Adjusted Free Cash Flow” or “AFCF,” “Adjusted Cash Flow from Operations” or “ACFFO,” “Cash Return on Capital Employed” or “CROCE,” “PV-10,” “Leverage Ratio,” “All-in Cash Operating Costs,” and "Cash Operating Margin." Management uses these non-GAAP financial measures in its analysis of performance. In addition, CROCE is a key metric used to determine a portion of the Company’s incentive compensation awards. These disclosures may not be viewed as a substitute for results determined in accordance with GAAP and are not necessarily comparable to non-GAAP performance measures which may be reported by other companies. “Adjusted Net Income” is calculated as net income minus the estimated after-tax impact of share-based compensation, ceiling test impairment, unrealized gains and losses on changes in the fair value of derivatives, and transaction costs for executed acquisitions and divestitures (“A&D”). Adjusted Net Income is presented because the timing and amount of these items cannot be reasonably estimated and affect the comparability of operating results from period to period, and current period to prior periods. The Company believes that the presentation of Adjusted Net Income provides useful information to investors as it is one of the metrics management uses to assess the Company’s ongoing operating and financial performance, and also is a useful metric for investors to compare Ring’s results with its peers. The Company defines “Adjusted EBITDA” as net income plus net interest expense (including interest income and expense),unrealized loss (gain) on change in fair value of derivatives, ceiling test impairment, income tax (benefit) expense, depreciation, depletion and amortization, asset retirement obligation accretion, transaction costs for executed A&D, share-based compensation, loss (gain) on disposal of assets, and backing out the effect of other income. Company management believes Adjusted EBITDA is relevant and useful because it helps investors understand Ring’s operating performance and makes it easier to compare its results with those 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 operating 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 discretionary use. The Company defines “Adjusted Free Cash Flow” or “AFCF” as Net Cash Provided by Operating Activities less changes in operating assets and liabilities (as reflected on Ring’s Condensed Statements of Cash Flows), plus transaction costs for executed acquisitions and divestitures (A&D), current income tax expense (benefit), proceeds from divestitures of equipment for oil and natural gas properties, loss (gain) on disposal of assets, and less capital expenditures, credit loss expense, and other income. For this purpose, Ring’s definition of capital expenditures includes costs incurred related to oil and natural gas properties (such as drilling and infrastructure costs and the lease maintenance costs) but excludes acquisition costs of oil and gas properties from third parties that are not included in Ring’s capital expenditures guidance provided to investors. Management believes that Adjusted Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of Ring’s current operating activities after the impact of capital expenditures and net interest expense (including interest income and expense, excluding amortization of deferred financing costs) and without being impacted by items such as changes associated with working capital, which can vary substantially from one period to another. Other companies may use different definitions of Adjusted Free Cash Flow. The Company defines “Adjusted Cash Flow from Operations” or “ACFFO” as Net Cash Provided by Operating Activities, as reflected in Ring’s Condensed Statements of Cash Flows, less the changes in operating assets and liabilities, which includes accounts receivable, inventory, prepaid expenses and other assets, accounts payable, and settlement of asset retirement obligations, which are subject to variation due to the nature of the Company’s operations. Accordingly, the Company believes this non-GAAP measure is useful to investors because it is used often in its industry and allows investors to compare this metric to other companies in its peer group as well as the E&P sector. “Leverage” or the “Leverage Ratio” is calculated under Ring’s existing senior revolving credit facility and means as of any date, the ratio of (i) consolidated total debt as of such date to (ii) Consolidated EBITDAX for the four consecutive fiscal quarters ending on or immediately prior to such date for which financial statements are required to have been delivered under Ring’s existing senior revolving credit facility. The Company defines “Consolidated EBITDAX” in accordance with its existing senior revolving credit facility that means for any period an amount equal to the sum of (i) consolidated net income (loss) for such period plus (ii) to the extent deducted in determining consolidated net income for such period, and without duplication, (A) consolidated interest expense, (B) income tax expense determined on a consolidated basis in accordance with GAAP, (C) depreciation, depletion and amortization determined on a consolidated basis in accordance with GAAP, (D) exploration expenses determined on a consolidated basis in accordance with GAAP, and (E) all other non-cash charges acceptable to Ring’s senior revolving credit facility administrative agent determined on a consolidated basis in accordance with GAAP, in each case for such period minus (iii) all noncash income added to consolidated net income (loss) for such period; provided that, for purposes of calculating compliance with the financial covenants, to the extent that during such period the Company shall have consummated an acquisition permitted by the credit facility or any sale, transfer or other disposition of any property or assets permitted by the senior revolving credit facility, Consolidated EBITDAX will be calculated on a pro forma basis with respect to the property or assets so acquired or disposed of. Also set forth in Ring’s existing senior revolving credit facility is the maximum permitted Leverage Ratio of 3.00. The table below provides detail of PV-10 to the standardized measure of discounted future net cash flows as of December 31, 2024. ($ in 000’s) Present value of estimated future net revenues (PV-10) $1,462,827 Future income taxes, discounted at 10% 229,891 Standardized measure of discounted future net cash flows $1,232,936 -
Ring Energy, Inc. (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Net income $ 9,110,738 $ 5,657,519 $ 5,515,377 Interest expense, net 9,408,728 9,987,731 11,420,400 Unrealized loss (gain) on change in fair value of derivatives 375,196 6,999,552 17,552,980 Income tax (benefit) expense 3,041,177 1,803,629 1,728,886 Depreciation, depletion and amortization 22,615,983 24,548,849 23,792,450 Asset retirement obligation accretion 326,549 323,085 350,834 Transaction costs - executed A&D 1,776 21,017 3,539 Share-based compensation 1,690,958 1,672,320 1,723,832 Loss (gain) on disposal of assets (124,610) — (38,355) Other income (8,942) (80,970) (25,686) Adjusted EBITDA $ 46,437,553 $ 50,932,732 $ 62,024,257 Adjusted EBITDA Margin 59 % 61 % 66 % Non-GAAP Reconciliations 36 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Adjusted Net Income Adjusted EBITDA 1. Adjusted EBITDA Margin is Adj. EBITDA divided by oil, natural gas, and natural gas liquids revenue. 1 (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Total Per share - diluted Total Per share - diluted Total Per share - diluted Net income $ 9,110,738 $ 0.05 $ 5,657,519 $ 0.03 $ 5,515,377 $ 0.03 Share-based compensation 1,690,958 0.01 1,672,320 0.01 1,723,832 0.01 Unrealized loss (gain) on change in fair value of derivatives 375,196 — 6,999,552 0.03 17,552,980 0.08 Transaction costs - executed A&D 1,776 — 21,017 — 3,539 — Tax impact on adjusted items (500,646) (0.01) (2,008,740) (0.01) (4,447,977) (0.02) Adjusted Net Income 10,678,022 $ 0.05 12,341,668 $ 0.06 20,347,751 $ 0.10 Diluted Weighted-Average Shares Outstanding 201,072,594 200,886,010 199,305,150 Adjusted Net Income per Diluted Share $ 0.05 $ 0.06 $ 0.10 -
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 37 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Adjusted Free Cash Flow (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Net Cash Provided by Operating Activities $ 28,371,008 $ 47,279,681 $ 45,189,169 Adjustments - Condensed Statements of Cash Flows Changes in operating assets and liabilities 9,784,999 (5,073,676) 6,758,004 Transaction costs - executed A&D 1,776 21,017 3,539 Income tax expense (benefit) - current 136,393 71,280 102,633 Capital expenditures (32,451,531) (37,633,168) (36,261,008) Proceeds from divestiture of equipment for oil and natural gas properties — 121,232 — Credit loss expense (17,917) 26,747 (163,840) Loss (gain) on disposal of assets — — (38,355) Other income (8,942) (80,970) (25,686) Adjusted Free Cash Flow $ 5,815,786 $ 4,732,143 $ 15,564,456 (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Adjusted EBITDA $ 46,437,553 $ 50,932,732 $ 62,024,257 Net interest expense (excluding amortization of deferred financing costs) (8,170,235) (8,688,653) (10,198,793) Capital expenditures (32,451,531) (37,633,168) (36,261,008) Proceeds from divestiture of equipment for oil and natural gas properties — 121,232 — Adjusted Free Cash Flow $ 5,815,787 $ 4,732,143 $ 15,564,456 -
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 38 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Leverage Ratio (Comparative Period End)Leverage Ratio (Current Period End) (Unaudited) Three Months Ended Last Four QuartersJune 30, September 30, December 31, March 31, 2024 2024 2024 2025 Consolidated EBITDAX Calculation: Net Income (Loss) $ 22,418,994 $ 33,878,424 $ 5,657,519 $ 9,110,738 $ 71,065,675 Plus: Consolidated interest expense 10,801,194 10,610,539 9,987,731 9,408,728 40,808,192 Plus: Income tax provision (benefit) 6,820,485 10,087,954 1,803,629 3,041,177 21,753,245 Plus: Depreciation, depletion and amortization 24,699,421 25,662,123 24,548,849 22,615,983 97,526,376 Plus: non-cash charges acceptable to Administrative Agent 1,664,064 (26,228,108) 8,994,957 2,392,703 (13,176,384) Consolidated EBITDAX $ 66,404,158 $ 54,010,932 $ 50,992,685 $ 46,569,329 $ 217,977,104 Plus: Pro Forma Acquired Consolidated EBITDAX 10,329,116 7,838,163 5,244,078 7,392,359 30,803,716 Less: Pro Forma Divested Consolidated EBITDAX (469,376) (600,460) 77,819 8,855 (983,162) Pro Forma Consolidated EBITDAX $ 76,263,898 $ 61,248,635 $ 56,314,582 $ 53,970,543 $ 247,797,658 Non-cash charges acceptable to Administrative Agent: Asset retirement obligation accretion $ 352,184 $ 354,195 $ 323,085 $ 326,549 Unrealized loss (gain) on derivative assets (765,898) (26,614,390) 6,999,552 375,196 Share-based compensation 2,077,778 32,087 1,672,320 1,690,958 Total non-cash charges acceptable to Administrative Agent $ 1,664,064 $ (26,228,108) $ 8,994,957 $ 2,392,703 As of March 31, Corresponding 2025 Leverage Ratio Leverage Ratio Covenant: Revolving line of credit $ 460,000,000 1.86 Lime Rock deferred payment 10,000,000 0.04 Consolidated Total Debt 470,000,000 1.90 Pro Forma Consolidated EBITDAX 247,797,658 Leverage Ratio 1.9 Maximum Allowed ≤ 3.00x (Unaudited) Three Months Ended Last Four QuartersJune 30, September 30, December 31, March 31, 2023 2023 2023 2024 Consolidated EBITDAX Calculation: Net Income (Loss) $ 28,791,605 $ (7,539,222) $ 50,896,479 $ 5,515,377 $ 77,664,239 Plus: Consolidated interest expense 10,471,062 11,301,328 11,506,908 11,420,400 44,699,698 Plus: Income tax provision (benefit) (6,356,295) (3,411,336) 7,862,930 1,728,886 (175,815) Plus: Depreciation, depletion and amortization 20,792,932 21,989,034 24,556,654 23,792,450 91,131,070 Plus: non-cash charges acceptable to Administrative Agent (470,875) 36,396,867 (29,695,076) 19,627,646 25,858,562 Consolidated EBITDAX $ 53,228,429 $ 58,736,671 $ 65,127,895 $ 62,084,759 $ 239,177,754 Plus: Pro Forma Acquired Consolidated EBITDAX 9,542,529 4,810,123 — — 14,352,652 Less: Pro Forma Divested Consolidated EBITDAX (357,122) (672,113) (66,463) 40,474 (1,055,224) Pro Forma Consolidated EBITDAX $ 62,413,836 $ 62,874,681 $ 65,061,432 $ 62,125,233 $ 252,475,182 Non-cash charges acceptable to Administrative Agent: Asset retirement obligation accretion $ 353,878 $ 354,175 $ 351,786 $ 350,834 Unrealized loss (gain) on derivative assets (3,085,065) 33,871,957 (32,505,544) 17,552,980 Share-based compensation 2,260,312 2,170,735 2,458,682 1,723,832 Total non-cash charges acceptable to Administrative Agent $ (470,875) $ 36,396,867 $ (29,695,076) $ 19,627,646 As of March 31, 2024 Leverage Ratio Covenant: Revolving line of credit $ 422,000,000 Pro Forma Consolidated EBITDAX 252,475,182 Leverage Ratio 1.67 Maximum Allowed ≤ 3.00x -
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 39 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI Adjusted Cash Flow from Operations (ACFFO) Cash Return on Capital Employed (CROCE) G&A Reconciliations PV-10 (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Net Cash Provided by Operating Activities $ 28,371,008 $ 47,279,681 $ 45,189,169 Changes in operating assets and liabilities 9,784,999 $ (5,073,676) 6,758,004 Adjusted Cash Flow from Operations $ 38,156,007 $ 42,206,005 $ 51,947,173 As of and for the twelve months ended December 31, December 31, December 31, 2024 2023 2022 Total long term debt (i.e. revolving line of credit) $385,000,000 $425,000,000 $415,000,000 Total stockholders' equity 858,639,982 786,582,900 661,103,391 Average debt 405,000,000 420,000,000 352,500,000 Average stockholders' equity 822,611,441 723,843,146 480,863,799 Average debt and stockholders' equity $1,227,611,441 $1,143,843,146 $833,363,799 Net Cash Provided by Operating Activities $194,423,712 $198,170,459 $196,976,729 Less change in WC (Working Capital) (888,089) 1,180,748 24,091,577 Adjusted Cash Flows From Operations (ACFFO) $195,311,801 $196,989,711 $172,885,152 CROCE (ACFFO)/(Average D+E) 15.9 % 17.2 % 20.7 % (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 General and administrative expense (G&A) $ 8,619,976 $ 8,035,977 $ 7,469,222 Shared-based compensation 1,690,958 1,672,320 1,723,832 G&A excluding share-based compensation 6,929,018 6,363,657 5,745,390 Transaction costs - executed A&D 1,776 21,017 3,539 G&A excluding share-based compensation and transaction costs $ 6,927,242 $ 6,342,640 $ 5,741,851 Oil (Bbl) Gas (Mcf) Natural Gas Liquids (Bbl) Net (Boe) PV-10 Balance, December 31, 2023 82,141,277 146,396,322 23,218,564 129,759,229 $ 1,647,031,127 Purchase of minerals in place — — — — Extensions, discoveries and improved recovery 11,495,236 10,630,769 2,738,451 16,005,482 Sales of minerals in place (1,140,568) (56,020) (16,361) (1,166,266) Production (4,861,628) (6,423,674) (1,258,814) (7,191,054) Revisions of previous quantity estimates (6,730,246) (730,235) 3,621,245 (3,230,707) Balance, December 31, 2024 $ 80,904,071 149,817,16 2 28,303,085 $ 134,176,684 $ 1,462,827,136 -
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 40 Value Focused Proven Strategy | May 8, 2025 | NYSE American: REI All-In Cash Operating Costs Cash Operating Margin (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 All-In Cash Operating Costs: Lease operating expenses (including workovers) $ 19,677,552 $ 20,326,216 $ 18,360,434 G&A excluding share-based compensation 6,929,018 6,363,657 5,745,390 Net interest expense (excluding amortization of deferred financing costs) 8,170,235 8,688,653 10,198,793 Operating lease expense 175,091 175,090 175,091 Oil and natural gas production taxes 3,584,455 3,857,147 4,428,303 Ad valorem taxes 1,532,108 2,421,595 2,145,631 Gathering, transportation and processing costs 203,612 130,230 166,054 All-in cash operating costs $ 40,272,071 $ 41,962,588 $ 41,219,696 Boe 1,655,259 1,808,493 1,732,057 All-in cash operating costs per Boe $ 24.33 $ 23.20 $ 23.80 (Unaudited for All Periods) Three Months Ended March 31, December 31, March 31, 2025 2024 2024 Cash Operating Margin Realized revenues per Boe $ 47.78 $ 46.14 $ 54.56 All-in cash operating costs per Boe 24.33 23.20 23.80 Cash Operating Margin per Boe $ 23.45 22.94 30.76 -