Ring Energy Announces Fourth Quarter and Full Year 2024 Results, Year-End 2024 Proved Reserves, and 2025 Guidance

Rhea-AI Summary

Ring Energy (NYSE: REI) reported strong operational and financial results for Q4 and full year 2024. The company achieved net income of $67.5 million ($0.34 per share) for FY2024, with record sales volumes of 19,648 Boe/d, representing an 8% year-over-year increase.

Key 2024 highlights include:

• Generated Adjusted EBITDA of $233.3 million
• Reduced year-over-year operating costs by 2%
• Maintained capital spending at $151.9 million while improving efficiency
• Paid down $40 million in debt
• Grew proved reserves by 4.4 MMBoe to 134.2 MMBoe

For 2025, Ring Energy projects:

• Average annual sales of 21,000 Boe/d (7% increase)
• Capital spending of $154 million
• Approximately 49 wells to be drilled, completed and brought online

Positive

• Record production volumes: 19,648 Boe/d (+8% YoY)
• Generated $233.3M Adjusted EBITDA
• Reduced operating costs by 2% YoY
• Improved horizontal well capital efficiency by 11%
• Grew proved reserves by 4.4 MMBoe
• Maintained positive free cash flow for 21 consecutive quarters

Negative

• 7% reduction in realized prices
• Natural gas sales price negative at -$1.44 per Mcf
• Increased G&A expenses to $4.44 per Boe in Q4 from $3.47 in Q3
• $6.3M net loss on commodity derivative contracts in Q4

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THE WOODLANDS, Texas, March 05, 2025 (GLOBE NEWSWIRE) -- Ring Energy, Inc. (NYSE American: REI) (“Ring” or the “Company”) today reported operational and financial results for the fourth quarter and full year 2024, year-end 2024 proved reserves and provided 2025 operational and financial guidance.

Fourth Quarter 2024 Highlights

• Recorded net income of $5.7 million, or $0.03 per diluted share;
• Reported Adjusted Net Income¹ of $12.3 million, or $0.06 per diluted share;
• Sold 19,658 barrels of oil equivalent per day (“Boe/d”), exceeding midpoint of guidance and 12,916 barrels of oil per day (“Bo/d”);
• Held all-in cash operating costs¹ (on a Boe basis) substantially flat with Q3 2024;
• Reduced total capital expenditures by 12% to $37.6 million as compared to Q3 2024;
• Recorded Adjusted Cash Flow from Operations¹ of $42.2 million and delivered Adjusted Free Cash Flow¹ of $4.7 million, remaining cash flow positive for 21 consecutive quarters; and
• Strengthened balance sheet by an additional $7.0 million in debt reduction.
  

Full Year 2024 Highlights

• Recorded net income of $67.5 million, or $0.34 per diluted share;
• Reported Adjusted Net Income¹ of $69.5 million, or $0.35 per diluted share;
• Grew sales volumes year-over-year (“Y-O-Y”) by 8% to a record 19,648 Boe/d and oil sales by 6% to a record 13,283 Bo/d;
• Reduced Y-O-Y all-in cash operating costs¹ (on a Boe basis) by 2%;
• Generated Adjusted EBITDA¹ of $233.3 million despite a 7% reduction in realized prices;
• Maintained capital spending essentially flat at $151.9 million while improving capital efficiency on horizontal (“Hz”) wells by 11% to ~$492 per foot and vertical wells by ~3% on a per completed interval basis;
• Generated a Cash Return on Capital Employed (“CROCE”)¹ of 15.9% despite lower commodity pricing, which is the third consecutive year that Ring has achieved a CROCE in excess of 15%;
• Recorded Adjusted Cash Flow from Operations¹ of $195.3 million and delivered Adjusted Free Cash Flow¹ of $43.6 million, remaining cash flow positive for over 5 years;
• Divested non-core vertical wells with high operating cost for $5.5 million;
• Paid down $40.0 million in debt and $70.0 million since closing the Founders acquisition in August 2023;
• Reaffirmed the borrowing base at $600 million, exited 2024 with ~$217 million of liquidity, borrowings of $385 million, and a Leverage Ratio¹ of 1.66x; and
• Organically grew proved reserves by 4.4 MMBoe, or 3%, to 134.2 MMBoe.

2025 Outlook²

• Average annual sales midpoint of 21,000 Boe/d and 13,900 Bo/d, a 7% and 5% increase, respectively;
• Annual capital spending midpoint of $154 million, essentially flat with the prior year;
• Total wells drilled, completed and online (midpoint) of ~49 wells; and
• Assumes nine months of Lime Rock asset operations without the benefit of anticipated synergies and cost reductions.

Mr. Paul D. McKinney, Chairman of the Board and Chief Executive Officer, commented, “We finished 2024 delivering on our promises during the fourth quarter, in a year in which the Ring Team enhanced nearly every controllable metric. We grew our sales by 8% over the prior year to a record 19,648 Boe/d and our oil sales by 6% to a record 13,283 Bo/d. We reduced our all-in cash operating costs per Boe by 2% and drilled 13 more wells for slightly less capital than the previous year representing a substantial increase in capital efficiency for both our horizontal and vertical wells. We paid down debt by $40 million and exited the year with $385 million borrowings and approximately $217 million of liquidity. During the fourth quarter of 2024, we reduced our capital expenditures in anticipation of seeking and completing a meaningful acquisition of producing properties, while achieving the midpoint of our guidance on a Boe basis. As we have previously stated, we intend to maintain or slightly grow our production through our organic drilling program and grow through accretive, balance sheet enhancing acquisitions of assets that meet specific criteria. Our strategy retains the flexibility to respond to changing conditions to ensure we continue to make progress profitably growing the Company, achieving the size and scale to earn more attractive market metrics, and build long term shareholder value. Looking forward to 2025, we intend to continue a reduced capital spending program in the first quarter to help us achieve a satisfactory leverage ratio upon closing the Lime Rock transaction. The rest of the year will be consistent with our past. We will continue our focus on maximizing cash flow generation and intend to allocate a portion of our cash flow from operations to maintain production and liquidity and allocate the balance to paying down debt. With the potential added benefit of the proposed Lime Rock production beginning in the second quarter and our historically successful capital spending program, we anticipate ending 2025 stronger than ever.”

Mr. McKinney concluded, “I would like to thank the Ring Team for the hard work and dedication it took to deliver our 2024 results. I also want to express our gratitude for the continued support of our shareholders. Despite an environment of lower realized commodity prices, being a member of a market segment where investor interest has waned, and other market conditions beyond our control, our shareholders continued to support us as we pursue our value focused proven strategy to build long-term value.”

Summary Results

	Quarter							Year
	Q4 2024	Q3 2024	Q4 2024 to Q3 2024 % Change		Q4 2023	Q4 2024 to Q4 2023 % Change		FY 2024	FY 2023	FY % Change
Average Daily Sales Volumes (Boe/d)	19,658	20,108	(2	)%	19,397	1	%	19,648	18,119	8	%
Crude Oil (Bo/d)	12,916	13,204	(2	)%	13,637	(5	)%	13,283	12,548	6	%
Net Sales (MBoe)	1,808.5	1,849.9	(2	)%	1,784.5	1	%	7,191.1	6,613.3	9	%
Realized Price - All Products ($/Boe)	$46.14	$48.24	(4	)%	$56.01	(18	)%	$50.94	$54.60	(7	)%
Realized Price - Crude Oil ($/Bo)	$68.98	$74.43	(7	)%	$77.33	(11	)%	$74.87	$76.21	(2	)%
Revenues ($MM)	$83.4	$89.2	(7	)%	$99.9	(17	)%	$366.3	$361.1	1	%
Net Income/Loss ($MM)	$5.7	$33.9	(83	)%	$50.9	(89	)%	$67.5	$104.9	(36	)%
Adjusted Net Income1 ($MM)	$12.3	$13.4	(8	)%	$21.2	(42	)%	$69.5	$100.5	(31	)%
Adjusted EBITDA1 ($MM)	$50.9	$54.0	(6	)%	$65.4	(22	)%	$233.3	$236.0	(1	)%
Capital Expenditures ($MM)	$37.6	$42.7	(12	)%	$38.8	(3	)%	$151.9	$152.0	—	%
Adjusted Free Cash Flow1 ($MM)	$4.7	$1.9	144	%	$16.3	(71	)%	$43.6	$45.3	(4	)%

Adjusted Net Income, Adjusted EBITDA, Adjusted Free Cash Flow, Adjusted Cash Flow from Operations, Cash Return on Capital Employed and PV-10 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.”

Sales Volumes, Prices and Revenues: Sales volumes for the fourth quarter of 2024 are shown in the table above.

For the fourth quarter of 2024, realized average sales prices were $68.98 per barrel of crude oil, $(0.96) per Mcf of natural gas and $9.08 per barrel of NGLs. The realized natural gas and NGL prices are impacted by a fee reduction to the value received. For the fourth quarter of 2024, the weighted average natural gas price per Mcf was $0.87 offset by a weighted average fee value per Mcf of $(1.83), and the weighted average NGL price per barrel was $20.96 partially offset by a weighted average fee of $(11.88) per barrel. The combined average realized sales price for the period was $46.14 per Boe, down 4% versus $48.24 per Boe for the third quarter of 2024, and down 18% from $56.01 per Boe in the fourth quarter of 2023. The average oil price differential the Company experienced from WTI NYMEX futures pricing in the fourth quarter of 2024 was a negative $1.42 per barrel of crude oil, while the average natural gas price differential from NYMEX futures pricing was a negative $3.83 per Mcf.

Revenues were $83.4 million for the fourth quarter of 2024 compared to $89.2 million for the third quarter of 2024 and $99.9 million for the fourth quarter of 2023. The 7% decrease in fourth quarter 2024 revenues from the third quarter was driven by a ($3.8MM) price variance and a ($2.0MM) volume variance.

Lease Operating Expense (“LOE”): LOE, which includes expensed workovers and facilities maintenance, was $20.3 million, or $11.24 per Boe, in the fourth quarter of 2024 versus $20.3 million, or $10.98 per Boe, in the third quarter of 2024 and $18.7 million, or $10.50 per Boe, for the fourth quarter of 2023. Fourth quarter 2024 LOE per Boe was within the Company’s guidance range, and the Company remains focused on further improving the efficiencies of its operations.

Gathering, Transportation and Processing (“GTP”) Costs: As previously disclosed, due to a contractual change effective May 1, 2022, the Company no longer maintains ownership and control of the majority of its natural gas through processing. As a result, GTP costs are now substantially reflected as a reduction to the natural gas sales price and not as an expense item. There remains only one contract in place with a natural gas processing entity where the point of control of gas dictates requiring the fees to be recorded as an expense.

Ad Valorem Taxes: Ad valorem taxes, inclusive of an accrual for methane taxes of $527,687, were $1.34 per Boe for the fourth quarter of 2024, compared to $1.17 per Boe in the third quarter of 2024 and $0.92 per Boe for the fourth quarter of 2023.

Production Taxes: Production taxes were $2.13 per Boe in the fourth quarter of 2024 compared to $2.27 per Boe in the third quarter of 2024 and $2.78 per Boe in fourth quarter of 2023. Production taxes ranged between 4.6% to 5.0% of revenue for all three periods.

Depreciation, Depletion and Amortization (“DD&A”) and Asset Retirement Obligation Accretion: DD&A was $13.57 per Boe in the fourth quarter of 2024 versus $13.87 per Boe for the third quarter of 2024 and $13.76 per Boe in the fourth quarter of 2023. Asset retirement obligation accretion was $0.18 per Boe in the fourth quarter of 2024 compared to $0.19 per Boe for the third quarter of 2024 and $0.20 per Boe in the fourth quarter of 2023.

General and Administrative Expenses (“G&A”): G&A was $8.0 million ($4.44 per Boe) for the fourth quarter of 2024 versus $6.4 million ($3.47 per Boe) for the third quarter of 2024 and $8.2 million ($4.58 per Boe) in the fourth quarter of 2023. G&A, excluding share-based compensation¹, was $6.4 million for the fourth quarter of 2024 ($3.52 per Boe) versus $6.4 million for the third quarter of 2024 ($3.45 per Boe) and $5.7 million in the fourth quarter of 2023 ($3.20 per Boe). The fourth quarter of 2024 included $21,017 of Transaction Costs. Excluding these costs and share-based compensation, G&A was $3.51 per Boe for the period.

Interest Expense: Interest expense was $10.1 million in the fourth quarter of 2024 versus $10.8 million for the third quarter of 2024 and $11.6 million for the fourth quarter of 2023.

Derivative (Loss) Gain: In the fourth quarter of 2024, Ring recorded a net loss of $6.3 million on its commodity derivative contracts, including a realized $0.7 million cash commodity derivative gain and an unrealized $7.0 million non-cash commodity derivative loss. This compared to a net gain of $24.7 million in the third quarter of 2024, including a realized $1.9 million cash commodity derivative loss and an unrealized $26.6 million non-cash commodity derivative gain, and a net gain of $29.3 million in the fourth quarter of 2023, including a realized $3.3 million cash commodity derivative loss and an unrealized $32.5 million non-cash commodity derivative gain.

A summary listing of the Company’s outstanding derivative positions at December 31, 2024 is included in the tables shown later in this release. A quarterly breakout is provided in the Company’s investor presentation.

For full year 2025, the Company currently has approximately 2.4 million barrels of oil (48% of oil sales guidance midpoint) hedged and 2.4 billion cubic feet of natural gas (33% of natural gas sales guidance midpoint) hedged.

Income Tax: The Company recorded a non-cash income tax provision of $1.8 million in the fourth quarter of 2024, $10.1 million in the third quarter of 2024, and $7.9 million for fourth quarter 2023.

Balance Sheet and Liquidity: Total liquidity at December 31, 2024 was $216.8 million, a 4% increase from September 30, 2024 and a 24% increase from December 31, 2023. Liquidity at December 31, 2024 consisted of cash and cash equivalents of $1.9 million and $215.0 million of availability under Ring’s revolving credit facility, which includes a reduction of $35 thousand for letters of credit. On December 31, 2024, the Company had $385.0 million in borrowings outstanding on its revolving credit facility that has a current borrowing base of $600.0 million. Ring paid down $7 million of debt during the fourth quarter of 2024 and $70.0 million since the closing of the Founders Transaction in August 2023. The Company is targeting further debt pay down during 2025 dependent on market conditions, the timing of capital spending, and other considerations.

During the fourth quarter of 2024, the Company’s borrowing base of $600 million under its revolving credit facility was reaffirmed. The next regularly scheduled bank redetermination is scheduled to occur during May 2025. Ring is currently in compliance with all applicable covenants under its revolving credit facility.

Capital Expenditures: During the fourth quarter of 2024, capital expenditures on an accrual basis were $37.6 million, which was near the midpoint of Ring’s guidance of $33 million to $41 million. The Company drilled five Hz and four vertical wells, and completed ten wells — with all drilling and completion activity occurring in the Central Basin Platform (“CBP”). Also included in fourth quarter 2024 capital spending were costs for capital workovers, infrastructure upgrades, recompletions, leasing costs, and ESG improvements.

For the year ended December 31, 2024, capital expenditures on an accrual basis were $151.9 million — substantially flat with full year 2023 despite more than a 40% increase in drilling and completion activity in 2024. Capital spending in 2024 included costs to drill, complete and place on production 21 Hz wells (five in the NWS and 16 in the CBP) and 22 vertical wells in the CBP, as well as costs for capital workovers, infrastructure upgrades, recompletions, leasing costs, and ESG improvements.

The table below sets forth Ring’s drilling and completions activities by quarter for 2024:

Quarter		Area		Wells Drilled		Wells Completed		Drilled Uncompleted ("DUC") (2)
1Q 2024		Northwest Shelf (Horizontal)		2		2		—
		Central Basin Platform (Horizontal)		3		3		—
		Central Basin Platform (Vertical)		6		6		—
		Total (1)		11		11		—
2Q 2024		Northwest Shelf (Horizontal)		—		—		—
		Central Basin Platform (Horizontal)		5		5		—
		Central Basin Platform (Vertical)		6		6		—
		Total		11		11		—
3Q 2024		Northwest Shelf (Horizontal)		3		3		—
		Central Basin Platform (Horizontal)		4		2		2
		Central Basin Platform (Vertical)		6		6		—
		Total		13		11		2
4Q 2024		Northwest Shelf (Horizontal)		—		—		—
		Central Basin Platform (Horizontal)		5		6		1
		Central Basin Platform (Vertical)		4		4		—
		Total		9		10		1
FY 2024		Northwest Shelf (Horizontal)		5		5		—
		Central Basin Platform (Horizontal)		17		16		1
		Central Basin Platform (Vertical)		22		22		—
		Total		44		43		1

⁽¹⁾ First quarter total and full year total do not include one salt water disposal (“SWD”) well completed in the Central Basin Platform
⁽²⁾ Note that the DUC wells represent period-end counts rather than period-to-date totals.

Full Year 2024 Summary Financial Review

The Company reported net income for full year 2024 of $67.5 million, or $0.34 per diluted share, and Adjusted Net Income of $69.5 million, or $0.35 per diluted share. For full year 2023, Ring reported net income of $104.9 million, or $0.54 per diluted share, and Adjusted Net Income of $100.5 million, or $0.51 per diluted share.

In full year 2024, the Company generated Adjusted EBITDA of $233.3 million, Adjusted Free Cash Flow of $43.6 million, and Adjusted Cash Flow from Operations of $195.3 million — representing a four percent or less decline in all three metrics from full year 2023, despite an almost seven percent decrease in overall realized commodity pricing.

Revenues totaled $366.3 million for 2024 compared to $361.1 million in 2023, with the increase driven by higher sales volumes partially offset by lower overall realized commodity prices.

Net sales for full year 2024 were a record 19,648 Boe/d, or 7,191,054 Boe, comprised of 4,861,628 Bbls of oil, 6,423,674 Mcf of natural gas, and 1,258,814 Bbls of NGLs. Full year 2023 net sales averaged 18,119 Boe/d, or 6,613,321 Boe, which included 4,579,942 Bbls of oil, 6,339,158 Mcf of natural gas, and 976,852 Bbls of NGLs. The increase in sales volumes was primarily associated with a full year of production from the Founders Acquisition that closed in August 2023, as well as strong organic growth from the Company’s targeted capital spending program.

For full year 2024, the Company’s realized crude oil sales price was $74.87 per barrel, the natural gas sales price was $(1.44) per Mcf, and the NGLs sales price was $9.23 per barrel. The combined average sales price for full year 2024 was $50.94 per Boe compared to $54.60 per Boe for full year 2023.

For the full year 2024, LOE was $78.3 million, or $10.89 per Boe (substantially at the midpoint of guidance of $10.70 to $11.00 per Boe). The increase in LOE on an absolute basis from full year 2023 was primarily due to the full year of expenses from the assets acquired with the Founders Acquisition (closed in August 2023) which contributed to the previously discussed 9% increase in production. Also affecting absolute LOE were higher activity levels, partially offset by the Company’s ongoing cost reduction and increased efficiency initiatives.

For the full year 2024, G&A was $29.6 million, or $4.12 per Boe, compared to $29.2 million, or $4.41 per Boe for full year 2023. G&A, excluding share-based compensation, was $24.1 million, or $3.36 per Boe, compared to $20.4 million, or $3.08 per Boe for full year 2023. Excluding Transaction Costs, full year 2024 G&A, net of share-based compensation, was $3.35 per Boe. The increase from full year 2023 was primarily associated with higher total compensation levels driven by higher activity levels in 2024 and a non-recurring employee retention tax credit in 2023, with the overall net increase partially offset by a $3.3 million year-over-year reduction in share-based compensation.

Recently Announced Proposed Accretive Bolt-On Acquisition

On February 25, 2025, the Company entered into an agreement to acquire Lime Rock’s CBP assets for $90 million in cash with $80 million due at closing and $10 million due on the nine month anniversary of closing, and approximately 7.4 million shares of our common stock. The purchase price is subject to customary purchase price adjustments. The transaction has an effective date of October 1, 2024, and is expected to close by the end of the first quarter of 2025.

Lime Rock’s CBP acreage is in Andrews County, Texas, where the majority of the acreage directly offsets Ring’s core Shafter Lake operations, and the remaining acreage is prospective for multiple horizontal targets and exposes the Company to new active plays. The transaction represents another opportunity for the Company to seamlessly integrate strategic, high-quality assets with Ring’s existing operations and create shareholder value through improved operations and synergy capture.

The Lime Rock position has been a key target for Ring as the Company has historically sought to consolidate producing assets in core counties in the CBP defined by shallow declines, high margin production and undeveloped inventory that immediately competes for capital. Additionally, these assets add significant near-term opportunities for field level optimization and cost savings that are core competencies of Ring’s operating team.

2025 Capital Investment, Sales Volumes, and Operating Expense Guidance

In January, the Company commenced its 2025 development program with one rig drilling horizontal wells followed by another rig drilling vertical wells. During the first quarter, this disciplined capital program is intended to achieve a satisfactory leverage ratio upon the closing of the Lime Rock transaction. The Company intends to utilize a phased (versus continuous) capital drilling program to maximize free cash flow and retain the flexibility to respond to changes in commodity prices and other market conditions.

For full year 2025, Ring expects total capital spending of $138 million to $170 million that includes a balanced and capital efficient combination of drilling, completing and placing on production 27 to 32 Hz and 15 to 22 vertical wells across the Company’s asset portfolio. Additionally, the full year capital spending program includes funds for the drilling of targeted well recompletions, capital workovers, infrastructure upgrades, reactivations, leasing costs, ESG improvements, and the drilling of approximately three SWD wells, in addition to the Company’s pro-rata capital spending for non-operated drilling, completion, and capital workover activities.

All projects and estimates are based on assumed WTI oil prices of $65 to $75 per barrel and Henry Hub prices of $2.00 to $4.00 per Mcf.

Based on the $154 million midpoint of spending guidance, the Company expects the following estimated allocation of capital investment:

• 73% for drilling, completion, and related infrastructure;
• 19% for recompletions and capital workovers;
• 5% for environmental and emission reducing facility upgrades; and
• 3% for land and non-operated capital.

The Company remains focused on continuing to generate Adjusted Free Cash Flow. All 2025 planned capital expenditures will be fully funded by cash on hand and cash from operations, and excess Adjusted Free Cash Flow is currently targeted for further debt reduction.

The Company currently forecasts full year 2025 oil sales volumes of 13,600 to 14,200 Bo/d compared with full year 2024 oil sales volumes of 13,283 Bo/d, with the midpoint of guidance reflecting almost a 5% increase from last year.

The guidance in the table below represents the Company's current good faith estimate of the range of likely future results for the first quarter and full year of 2025 and assumes the closing of the Lime Rock transaction at the end of the first quarter of 2025. Guidance could be affected by the factors discussed below in the "Safe Harbor Statement" section. LOE per Boe assumes the full operating costs of the Lime Rock assets before anticipated synergies and cost reductions after the assets are integrated.

		Q1 2025		Q2 2025		Q3 2025		Q4 2025		FY 2025
Sales Volumes:
Total Oil (Bo/d)		11,700 – 12,000		13,700 – 14,700		14,000 – 15,000		14,400 – 15,400		13,600 – 14,200
Midpoint (Bo/d)		11,850		14,200		14,500		14,900		13,900
Total (Boe/d)		18,000-18,500		20,500 – 22,500		20,700 – 22,700		21,000 – 23,000		20,000 - 22,000
Midpoint (Boe/d)		18,250		21,500		21,700		22,000		21,000
Oil (%)		65%		66%		67%		68%		66%
NGLs (%)		19%		18%		18%		18%		18%
Gas (%)		16%		16%		15%		14%		16%
Capital Program:
Capital spending(1) (millions)		$26 - $34		$34 - $42		$46 - $54		$32 - $40		$138 - $170
Midpoint (millions)		$30		$38		$50		$36		$154
New Hz wells drilled		4 - 5		8 - 9		11 - 13		4 - 5		27 - 32
New Vertical wells drilled		3 - 4		3 - 5		4 - 6		5 - 7		15 - 22
Completion of DUC wells		0		1		0		0		1
Wells completed and online		7 - 9		12 - 15		15 - 19		9 - 12		43 - 55
Operating Expenses:
LOE (per Boe)		$11.75 - $12.25		$11.50 - $12.50		$11.25 - $12.25		$11.00 - $12.00		$11.25 - $12.25
Midpoint (per Boe)		$12.00		$12.00		$11.75		$11.50		$11.75

⁽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 ESG improvements.

Year-End 2024 Proved Reserves

The Company's year-end 2024 SEC proved reserves were 134.2 MMBoe, up 3% compared to 129.8 MMBoe at year-end 2023. During 2024, Ring recorded reserve additions of 16.0 MMBoe for extensions, discoveries and improved recovery. Offsetting these additions were 1.2 MMBoe related to the sale of non-core assets, 7.2 MMBoe of production, and 3.2 MMBoe of revisions related to changes in pricing and performance.

The SEC twelve-month first day of the month average prices used for year-end 2024 were $71.96 per barrel of crude oil and $2.130 per MMBtu of natural gas, both before adjustment for quality, transportation, fees, energy content, and regional price differentials, while for year-end 2023 they were $74.70 per barrel of crude oil and $2.637 per MMBtu of natural gas — a decrease of four percent and two percent, respectively.

Year-end 2024 SEC proved reserves were comprised of approximately 60% crude oil, 19% natural gas, and 21% natural gas liquids. At year end, approximately 69% of 2024 proved reserves were classified as proved developed and 31% as proved undeveloped. This is compared to year-end 2023 when approximately 68% of proved reserves were classified as proved developed and 32% were classified as proved undeveloped. The Company’s year-end 2024 proved reserves were prepared by Cawley, Gillespie & Associates, Inc., and independent petroleum engineering firm.

The PV-10 value at year-end 2024 was $1,462.8 million versus $1,647.0 million at the end of 2023.

		Oil (Bbl)			Gas (Mcf)			Natural Gas Liquids (Bbl)			Net (Boe)			PV-10(1)
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			149,817,162			28,303,085			134,176,684			$	1,462,827,136

⁽¹⁾ PV-10 is a non-GAAP financial measure and is derived from the Standardized Measure of Discounted Futures Net Cash Flows, which is the most directly comparable generally accepted accounting principles (“GAAP”) measure.

In accordance with guidelines established by the SEC, estimated proved reserves as of December 31, 2024 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average commodity price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the year ended December 31, 2024. The SEC average prices used for year-end 2024 were $71.96 per barrel of crude oil (WTI) and $2.130 per MMBtu of natural gas (Henry Hub), both before adjustment for quality, transportation, fees, energy content, and regional price differentials. Such prices were held constant throughout the estimated lives of the reserves. Future production and development costs are based on year-end costs with no escalations.

Standardized Measure of Discounted Future Net Cash Flows

Ring’s standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves and changes in the standardized measure as described below were prepared in accordance with GAAP.

As of December 31,			2024				2023
Future cash inflows		$	6,165,487,616			$	6,622,410,752
Future production costs			(2,432,555,200	)			(2,413,303,488	)
Future development costs (1)			(536,825,664	)			(562,063,424	)
Future income taxes			(465,768,645	)			(548,664,988	)
Future net cash flows			2,730,338,107				3,098,378,852
10% annual discount for estimated timing of cash flows			(1,497,401,764	)			(1,699,193,661	)
Standardized Measure of Discounted Future Net Cash Flows		$	1,232,936,343			$	1,399,185,191

(1) Future development costs include not only development costs but also future asset retirement costs.

Reconciliation of PV-10 to Standardized Measure

PV-10 is derived from the Standardized Measure of Discounted Future Net Cash Flows (“Standardized Measure”), which is the most directly comparable GAAP financial measure for proved reserves calculated using SEC pricing. PV-10 is a computation of the Standardized Measure on a pre-tax basis. PV-10 is equal to the Standardized Measure at the applicable date, before deducting future income taxes, discounted at 10 percent. We believe that the presentation of PV-10 is relevant and useful to investors because it presents the discounted future net cash flows attributable to our estimated net proved reserves prior to taking into account future corporate income taxes, and it is a useful measure for evaluating the relative monetary significance of our oil and natural gas properties. Further, investors may utilize the measure as a basis for comparison of the relative size and value of our reserves to other companies without regard to the specific tax characteristics of such entities. Moreover, GAAP does not provide a measure of estimated future net cash flows for reserves other than proved reserves or for reserves calculated using prices other than SEC prices. We use this measure when assessing the potential return on investment related to our oil and natural gas properties. PV-10, however, is not a substitute for the Standardized Measure. Our PV-10 measure and the Standardized Measure do not purport to represent the fair value of our oil and natural gas reserves.

The following table reconciles the PV-10 value of the Company’s estimated proved reserves as of December 31, 2024 to the Standardized Measure:

SEC Pricing Proved Reserves
Standardized Measure Reconciliation
Present Value of Estimated Future Net Revenues (PV-10)		$	1,462,827,136
Future Income Taxes, Discounted at 10%			229,890,793
Standardized Measure of Discounted Future Net Cash Flows		$	1,232,936,343

Conference Call Information

Ring will hold a conference call on Thursday, March 6, 2025 at 11:00 a.m. ET (10:00 a.m. CT) to discuss its fourth quarter and full year 2024 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 2024 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. All statements, other than statements of historical fact included in this release, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. Additionally, forward-looking statements include statements about the expected benefits to the Company and its shareholders from the proposed Lime Rock acquisition and the anticipated completion of the Lime Rock acquisition or the timing thereof. When used in this release, the words “could,” “may,” “will,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “guidance,” “project,” “goal,” “plan,” “target” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. 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; 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; 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 SEC, including its Form 10-K for the fiscal year ended December 31, 2024, and its other filings with the SEC. Readers and investors are cautioned that the Company’s actual results may differ materially from those described in the forward-looking statements due to a number of factors, including, but not limited to, the Company’s ability to acquire productive oil and/or gas properties or to successfully drill and complete oil and/or gas wells on such properties, general economic conditions both domestically and abroad, and the conduct of business by the Company, and other factors that may be more fully described in additional documents set forth by the Company. Should one or more of the risks or uncertainties described in this release occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, expressed or implied, included in this release are expressly qualified in their entirety by this safe harbor statement. This safe harbor statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. 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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
Oil, Natural Gas, and Natural Gas Liquids Revenues	$	83,440,546			$	89,244,383			$	99,942,718			$	366,327,414			$	361,056,001
Costs and Operating Expenses
Lease operating expenses		20,326,216				20,315,282				18,732,082				78,310,949				70,158,227
Gathering, transportation and processing costs		130,230				102,420				464,558				506,333				457,573
Ad valorem taxes		2,421,595				2,164,562				1,637,722				8,069,064				6,757,841
Oil and natural gas production taxes		3,857,147				4,203,851				4,961,768				16,116,565				18,135,336
Depreciation, depletion and amortization		24,548,849				25,662,123				24,556,654				98,702,843				88,610,291
Asset retirement obligation accretion		323,085				354,195				351,786				1,380,298				1,425,686
Operating lease expense		175,090				175,091				175,090				700,362				541,801
General and administrative expense		8,035,977				6,421,567				8,164,799				29,640,300				29,188,755
Total Costs and Operating Expenses		59,818,189				59,399,091				59,044,459				233,426,714				215,275,510
Income from Operations		23,622,357				29,845,292				40,898,259				132,900,700				145,780,491
Other Income (Expense)
Interest income		124,765				143,704				96,984				491,946				257,155
Interest (expense)		(10,112,496	)			(10,754,243	)			(11,603,892	)			(43,311,810	)			(43,926,732	)
Gain (loss) on derivative contracts		(6,254,448	)			24,731,625				29,250,352				(2,365,917	)			2,767,162
Gain (loss) on disposal of assets		—				—				44,981				89,693				(87,128	)
Other income		80,970				—				72,725				106,656				198,935
Net Other Income (Expense)		(16,161,209	)			14,121,086				17,861,150				(44,989,432	)			(40,790,608	)
Income Before Provision for Income Taxes		7,461,148				43,966,378				58,759,409				87,911,268				104,989,883
Provision for Income Taxes		(1,803,629	)			(10,087,954	)			(7,862,930	)			(20,440,954	)			(125,242	)
Net Income	$	5,657,519			$	33,878,424			$	50,896,479			$	67,470,314			$	104,864,641
Basic Earnings per Share	$	0.03			$	0.17			$	0.26			$	0.34			$	0.55
Diluted Earnings per Share	$	0.03			$	0.17			$	0.26			$	0.34			$	0.54
Basic Weighted-Average Shares Outstanding		198,166,543				198,177,046				195,687,725				197,937,683				190,589,143
Diluted Weighted-Average Shares Outstanding		200,886,010				200,723,863				197,848,812				200,277,380				195,364,850

RING ENERGY, INC. Condensed Operating Data (Unaudited)
	Three Months Ended									Twelve Months Ended
	December 31,			September 30,			December 31,			December 31,			December 31,
	2024			2024			2023			2024			2023
Net sales volumes:
Oil (Bbls)	1,188,272			1,214,788			1,254,619			4,861,628			4,579,942
Natural gas (Mcf)	1,683,793			1,705,027			1,613,102			6,423,674			6,339,158
Natural gas liquids (Bbls)	339,589			350,975			261,020			1,258,814			976,852
Total oil, natural gas and natural gas liquids (Boe)(1)	1,808,493			1,849,934			1,784,490			7,191,054			6,613,321
% Oil	66	%		66	%		70	%		68	%		69	%
% Natural gas	15	%		15	%		15	%		15	%		16	%
% Natural gas liquids	19	%		19	%		15	%		17	%		15	%
Average daily sales volumes:
Oil (Bbls/d)	12,916			13,204			13,637			13,283			12,548
Natural gas (Mcf/d)	18,302			18,533			17,534			17,551			17,368
Natural gas liquids (Bbls/d)	3,691			3,815			2,837			3,439			2,676
Average daily equivalent sales (Boe/d)	19,658			20,108			19,397			19,648			18,119
Average realized sales prices:
Oil ($/Bbl)	68.98			74.43			77.33			74.87			76.21
Natural gas ($/Mcf)	(0.96	)		(2.26	)		(0.12	)		(1.44	)		0.05
Natural gas liquids ($/Bbls)	9.08			7.66			11.92			9.23			11.95
Barrel of oil equivalent ($/Boe)	46.14			48.24			56.01			50.94			54.60
Average costs and expenses per Boe ($/Boe):
Lease operating expenses	11.24			10.98			10.50			10.89			10.61
Gathering, transportation and processing costs	0.07			0.06			0.26			0.07			0.07
Ad valorem taxes	1.34			1.17			0.92			1.12			1.02
Oil and natural gas production taxes	2.13			2.27			2.78			2.24			2.74
Depreciation, depletion and amortization	13.57			13.87			13.76			13.73			13.40
Asset retirement obligation accretion	0.18			0.19			0.20			0.19			0.22
Operating lease expense	0.10			0.09			0.10			0.10			0.08
G&A (including share-based compensation)	4.44			3.47			4.58			4.12			4.41
G&A (excluding share-based compensation)	3.52			3.45			3.20			3.36			3.08
G&A (excluding share-based compensation and transaction costs)	3.51			3.45			3.00			3.35			3.01

(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
As of December 31,			2024				2023
ASSETS
Current Assets
Cash and cash equivalents		$	1,866,395			$	296,384
Accounts receivable			36,172,316				38,965,002
Joint interest billing receivables, net			1,083,164				2,422,274
Derivative assets			5,497,057				6,215,374
Inventory			4,047,819				6,136,935
Prepaid expenses and other assets			1,781,341				1,874,850
Total Current Assets			50,448,092				55,910,819
Properties and Equipment
Oil and natural gas properties, full cost method			1,809,309,848				1,663,548,249
Financing lease asset subject to depreciation			4,634,556				3,896,316
Fixed assets subject to depreciation			3,389,907				3,228,793
Total Properties and Equipment			1,817,334,311				1,670,673,358
Accumulated depreciation, depletion and amortization			(475,212,325	)			(377,252,572	)
Net Properties and Equipment			1,342,121,986				1,293,420,786
Operating lease asset			1,906,264				2,499,592
Derivative assets			5,473,375				11,634,714
Deferred financing costs			8,149,757				13,030,481
Total Assets		$	1,408,099,474			$	1,376,496,392
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts payable		$	95,729,261			$	104,064,124
Income tax liability			328,985				—
Financing lease liability			906,119				956,254
Operating lease liability			648,204				568,176
Derivative liabilities			6,410,547				7,520,336
Notes payable			496,397				533,734
Asset retirement obligations			517,674				165,642
Total Current Liabilities			105,037,187				113,808,266
Non-current Liabilities
Deferred income taxes			28,591,802				8,552,045
Revolving line of credit			385,000,000				425,000,000
Financing lease liability, less current portion			647,078				906,330
Operating lease liability, less current portion			1,405,837				2,054,041
Derivative liabilities			2,912,745				11,510,368
Asset retirement obligations			25,864,843				28,082,442
Total Liabilities			549,459,492				589,913,492
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; 198,561,378 shares and 196,837,001 shares issued and outstanding, respectively			198,561				196,837
Additional paid-in capital			800,419,719				795,834,675
Retained earnings (Accumulated deficit)			58,021,702				(9,448,612	)
Total Stockholders’ Equity			858,639,982				786,582,900
Total Liabilities and Stockholders' Equity		$	1,408,099,474			$	1,376,496,392

RING ENERGY, INC. Condensed Statements of Cash Flows
		(Unaudited)
		Three Months Ended												Twelve Months Ended
		December 31,				September 30,				December 31,				December 31,				December 31,
			2024				2024				2023				2024				2023
Cash Flows From Operating Activities
Net income		$	5,657,519			$	33,878,424			$	50,896,479			$	67,470,314			$	104,864,641
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization			24,548,849				25,662,123				24,556,654				98,702,843				88,610,291
Asset retirement obligation accretion			323,085				354,195				351,786				1,380,298				1,425,686
Amortization of deferred financing costs			1,299,078				1,226,881				1,221,479				4,969,174				4,920,714
Share-based compensation			1,672,320				32,087				2,458,682				5,506,017				8,833,425
Credit loss expense			(26,747	)			8,817				92,142				160,847				134,007
(Gain) loss on disposal of assets			—				—				—				(89,693	)			—
Deferred income tax expense (benefit)			1,723,338				10,005,502				7,735,437				19,935,413				(425,275	)
Excess tax expense (benefit) related to share-based compensation			9,011				7,553				319,541				104,344				478,304
(Gain) loss on derivative contracts			6,254,448				(24,731,625	)			(29,250,352	)			2,365,917				(2,767,162	)
Cash received (paid) for derivative settlements, net			745,104				(1,882,765	)			(3,255,192	)			(5,193,673	)			(9,084,920	)
Changes in operating assets and liabilities:
Accounts receivable			349,474				5,529,542				6,825,601				3,594,504				1,154,085
Inventory			580,161				1,148,418				(588,100	)			2,089,116				3,113,782
Prepaid expenses and other assets			295,555				545,529				158,163				93,509				226,688
Accounts payable			4,462,089				(225,196	)			(4,952,335	)			(5,076,738	)			(1,451,422	)
Asset retirement obligation			(613,603	)			(222,553	)			(836,778	)			(1,588,480	)			(1,862,385	)
Net Cash Provided by Operating Activities			47,279,681				51,336,932				55,733,207				194,423,712				198,170,459
Cash Flows From Investing Activities
Payments for the Stronghold Acquisition			—				—				—				—				(18,511,170	)
Payments for the Founders Acquisition			—				—				(12,324,388	)			—				(62,227,145	)
Payments to purchase oil and natural gas properties			(1,423,483	)			(164,481	)			(557,323	)			(2,210,826	)			(2,162,585	)
Payments to develop oil and natural gas properties			(36,386,055	)			(42,099,874	)			(39,563,282	)			(153,945,456	)			(152,559,314	)
Payments to acquire or improve fixed assets subject to depreciation			—				(33,938	)			(282,519	)			(185,524	)			(492,317	)
Proceeds from sale of fixed assets subject to depreciation			—				—				(1	)			10,605				332,229
Proceeds from divestiture of oil and natural gas properties			121,232				—				1,500,000				121,232				1,554,558
Proceeds from sale of Delaware properties			—				—				(7,993	)			—				7,600,699
Proceeds from sale of New Mexico properties			—				—				(420,745	)			(144,398	)			3,891,757
Proceeds from sale of CBP vertical wells			—				5,500,000				—				5,500,000				—
Net Cash Used in Investing Activities			(37,688,306	)			(36,798,293	)			(51,656,251	)			(150,854,367	)			(222,573,288	)
Cash Flows From Financing Activities
Proceeds from revolving line of credit			22,000,000				27,000,000				46,000,000				130,000,000				225,000,000
Payments on revolving line of credit			(29,000,000	)			(42,000,000	)			(49,000,000	)			(170,000,000	)			(215,000,000	)
Proceeds from issuance of common stock from warrant exercises			—				—				—				—				12,301,596
Payments for taxes withheld on vested restricted shares, net			—				(17,273	)			(225,788	)			(919,249	)			(520,153	)
Proceeds from notes payable			58,774				—				72,442				1,560,281				1,637,513
Payments on notes payable			(475,196	)			(442,976	)			(488,776	)			(1,597,618	)			(1,603,659	)
Payment of deferred financing costs			(42,746	)			—				(52,222	)			(88,450	)			(52,222	)
Reduction of financing lease liabilities			(265,812	)			(257,202	)			(224,809	)			(954,298	)			(776,388	)
Net Cash Provided by (Used in) Financing Activities			(7,724,980	)			(15,717,451	)			(3,919,153	)			(41,999,334	)			20,986,687
Net Increase (Decrease) in Cash			1,866,395				(1,178,812	)			157,803				1,570,011				(3,416,142	)
Cash at Beginning of Period			—				1,178,812				138,581				296,384				3,712,526
Cash at End of Period		$	1,866,395			$	—			$	296,384			$	1,866,395			$	296,384

RING ENERGY, INC.
Financial Commodity Derivative Positions
As of December 31, 2024

The following tables reflect the details of current derivative contracts as of December 31, 2024 (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)
	Q1 2025				Q2 2025				Q3 2025				Q4 2025				Q1 2026				Q2 2026				Q3 2026				Q4 2026
Swaps:
Hedged volume (Bbl)		193,397				151,763				351,917				141,755				477,350				457,101				59,400				423,000
Weighted average swap price	$	68.68			$	68.53			$	71.41			$	69.13			$	70.16			$	69.38			$	66.70			$	66.70
Two-way collars:
Hedged volume (Bbl)		474,750				464,100				225,400				404,800				—				—				379,685				—
Weighted average put price	$	57.06			$	60.00			$	65.00			$	60.00			$	—			$	—			$	60.00			$	—
Weighted average call price	$	75.82			$	69.85			$	78.91			$	75.68			$	—			$	—			$	72.50			$	—

	Gas Hedges (Henry Hub)
	Q1 2025				Q2 2025				Q3 2025				Q4 2025				Q1 2026				Q2 2026				Q3 2026				Q4 2026
NYMEX Swaps:
Hedged volume (MMBtu)		451,884				647,200				330,250				11,400				26,600				555,300				17,400				513,300
Weighted average swap price	$	3.77			$	3.46			$	3.72			$	3.74			$	3.74			$	3.39			$	3.74			$	3.74
Two-way collars:
Hedged volume (MMBtu)		22,016				27,300				308,200				598,000				553,500				—				515,728				—
Weighted average put price	$	3.00			$	3.00			$	3.00			$	3.00			$	3.50			$	—			$	3.00			$	—
Weighted average call price	$	4.40			$	4.15			$	4.75			$	4.15			$	5.03			$	—			$	3.93			$	—

	Oil Hedges (basis differential)
	Q1 2025				Q2 2025				Q3 2025				Q4 2025				Q1 2026				Q2 2026				Q3 2026				Q4 2026
Argus basis swaps:
Hedged volume (Bbl)		177,000				273,000				276,000				276,000				—				—				—				—
Weighted average spread price (1)	$	1.00			$	1.00			$	1.00			$	1.00			$	—			$	—			$	—			$	—

⁽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.

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,” “Current Ratio,” “Cash Return on Capital Employed” or “CROCE,” “All-In Cash Operating Costs,” and “Cash Operating Margin.” Management uses these non-GAAP financial measures in its analysis of performance. In addition, Adjusted EBITDA 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.

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 our results with our peers.

	(Unaudited for All Periods)
	Three Months Ended																								Twelve Months Ended
	December 31,								September 30,								December 31,								December 31,								December 31,
		2024								2024								2023								2024								2023
	Total				Per share - diluted				Total				Per share - diluted				Total				Per share - diluted				Total				Per share - diluted				Total				Per share - diluted
Net Income	$	5,657,519			$	0.03			$	33,878,424			$	0.17			$	50,896,479			$	0.26			$	67,470,314			$	0.34			$	104,864,641			$	0.54
Share-based compensation		1,672,320				0.01				32,087				—				2,458,682				0.01				5,506,017				0.03				8,833,425				0.05
Unrealized loss (gain) on change in fair value of derivatives		6,999,552				0.03				(26,614,390	)			(0.13	)			(32,505,544	)			(0.16	)			(2,827,756	)			(0.02	)			(11,852,082	)			(0.07	)
Transaction costs - executed A&D		21,017				—				—				—				354,616				—				24,556				—				417,166				—
Tax impact on adjusted items		(2,008,740	)			(0.01	)			6,132,537				0.03				(35,631	)			—				(628,405	)			—				(1,788,248	)			(0.01	)
Adjusted Net Income	$	12,341,668			$	0.06			$	13,428,658			$	0.07			$	21,168,602			$	0.11			$	69,544,726			$	0.35			$	100,474,902			$	0.51
Diluted Weighted-Average Shares Outstanding		200,886,010								200,723,863								197,848,812								200,277,380								195,364,850
Adjusted Net Income per Diluted Share	$	0.06							$	0.07							$	0.11							$	0.35							$	0.51

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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
Net Income	$	5,657,519			$	33,878,424			$	50,896,479			$	67,470,314			$	104,864,641
Interest expense, net		9,987,731				10,610,539				11,506,908				42,819,864				43,669,577
Unrealized loss (gain) on change in fair value of derivatives		6,999,552				(26,614,390	)			(32,505,544	)			(2,827,756	)			(11,852,082	)
Income tax (benefit) expense		1,803,629				10,087,954				7,862,930				20,440,954				125,242
Depreciation, depletion and amortization		24,548,849				25,662,123				24,556,654				98,702,843				88,610,291
Asset retirement obligation accretion		323,085				354,195				351,786				1,380,298				1,425,686
Transaction costs - executed A&D		21,017				—				354,616				24,556				417,166
Share-based compensation		1,672,320				32,087				2,458,682				5,506,017				8,833,425
Loss (gain) on disposal of assets		—				—				(44,981	)			(89,693	)			87,128
Other income		(80,970	)			—				(72,725	)			(106,656	)			(198,935	)
Adjusted EBITDA	$	50,932,732			$	54,010,932			$	65,364,805			$	233,320,741			$	235,982,139
Adjusted EBITDA Margin		61	%			61	%			65	%			64	%			65	%

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 our 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, our 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 our capital expenditures guidance provided to investors. Our management believes that Adjusted Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of our 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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
Net Cash Provided by Operating Activities	$	47,279,681			$	51,336,932			$	55,733,207			$	194,423,712			$	198,170,459
Adjustments - Statements of Cash Flows
Changes in operating assets and liabilities		(5,073,676	)			(6,775,740	)			(606,551	)			888,089				(1,180,748	)
Transaction costs - executed A&D		21,017				—				354,616				24,556				417,166
Income tax expense (benefit) - current		71,280				74,899				(192,048	)			401,197				72,213
Capital expenditures		(37,633,168	)			(42,691,163	)			(38,817,080	)			(151,946,171	)			(151,969,735	)
Proceeds from divestiture of equipment for oil and natural gas properties		121,232				—				—				121,232				54,558
Credit loss expense		26,747				(8,817	)			(92,142	)			(160,847	)			(134,007	)
Loss (gain) on disposal of assets		—				—				(44,981	)			—				87,128
Other income		(80,970	)			—				(72,725	)			(106,656	)			(198,935	)
Adjusted Free Cash Flow	$	4,732,143			$	1,936,111			$	16,262,296			$	43,645,112			$	45,318,099

	(Unaudited for All Periods)
	Three Months Ended												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
Adjusted EBITDA	$	50,932,732			$	54,010,932			$	65,364,805			$	233,320,741			$	235,982,139
Net interest expense (excluding amortization of deferred financing costs)		(8,688,653	)			(9,383,658	)			(10,285,429	)			(37,850,690	)			(38,748,863	)
Capital expenditures		(37,633,168	)			(42,691,163	)			(38,817,080	)			(151,946,171	)			(151,969,735	)
Proceeds from divestiture of equipment for oil and natural gas properties		121,232				—				—				121,232				54,558
Adjusted Free Cash Flow	$	4,732,143			$	1,936,111			$	16,262,296			$	43,645,112			$	45,318,099

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 our 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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
Net Cash Provided by Operating Activities	$	47,279,681			$	51,336,932			$	55,733,207			$	194,423,712			$	198,170,459
Changes in operating assets and liabilities		(5,073,676	)			(6,775,740	)			(606,551	)			888,089				(1,180,748	)
Adjusted Cash Flow from Operations	$	42,206,005			$	44,561,192			$	55,126,656			$	195,311,801			$	196,989,711

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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
General and administrative expense (G&A)	$	8,035,977			$	6,421,567			$	8,164,799			$	29,640,300			$	29,188,755
Shared-based compensation		1,672,320				32,087				2,458,682				5,506,017				8,833,425
G&A excluding share-based compensation		6,363,657				6,389,480				5,706,117				24,134,283				20,355,330
Transaction costs - executed A&D		21,017				—				354,616				24,556				417,166
G&A excluding share-based compensation and transaction costs	$	6,342,640			$	6,389,480			$	5,351,501			$	24,109,727			$	19,938,164

Calculation of Leverage Ratio

“Leverage” or the “Leverage Ratio” is calculated under our existing senior revolving credit facility and means as of any date, the ratio of (i) our consolidated total debt as of such date to (ii) our 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 our existing senior revolving credit facility.

The Company defines “Consolidated EBITDAX” in accordance with our 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 our 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 we 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 our existing senior revolving credit facility is the maximum permitted Leverage Ratio of 3.00. The following table shows the leverage ratio calculation for the Company’s most recent fiscal quarter.

	(Unaudited)
	Three Months Ended
	March 31,				June 30,				September 30,				December 31,				Last Four Quarters
		2024				2024				2024				2024
Consolidated EBITDAX Calculation:
Net Income (Loss)	$	5,515,377			$	22,418,994			$	33,878,424			$	5,657,519			$	67,470,314
Plus: Consolidated interest expense		11,420,400				10,801,194				10,610,539				9,987,731				42,819,864
Plus: Income tax provision (benefit)		1,728,886				6,820,485				10,087,954				1,803,629				20,440,954
Plus: Depreciation, depletion and amortization		23,792,450				24,699,421				25,662,123				24,548,849				98,702,843
Plus: non-cash charges acceptable to Administrative Agent		19,627,646				1,664,064				(26,228,108	)			8,994,957				4,058,559
Consolidated EBITDAX	$	62,084,759			$	66,404,158			$	54,010,932			$	50,992,685			$	233,492,534
Plus: Pro Forma Acquired Consolidated EBITDAX	$	—			$	—			$	—			$	—			$	—
Less: Pro Forma Divested Consolidated EBITDAX		(124,084	)			(469,376	)			(600,460	)			77,819				(1,116,101	)
Pro Forma Consolidated EBITDAX	$	61,960,675			$	65,934,782			$	53,410,472			$	51,070,504			$	232,376,433
Non-cash charges acceptable to Administrative Agent:
Asset retirement obligation accretion	$	350,834			$	352,184			$	354,195			$	323,085
Unrealized loss (gain) on derivative assets		17,552,980				(765,898	)			(26,614,390	)			6,999,552
Share-based compensation		1,723,832				2,077,778				32,087				1,672,320
Total non-cash charges acceptable to Administrative Agent	$	19,627,646			$	1,664,064			$	(26,228,108	)		$	8,994,957
	As of
	December 31,
		2024
Leverage Ratio Covenant:
Revolving line of credit	$	385,000,000
Pro Forma Consolidated EBITDAX		232,376,433
Leverage Ratio		1.66
Maximum Allowed		≤ 3.00	x

Calculation of Current Ratio

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.

Also set forth in our existing senior revolving credit facility is the minimum permitted Current Ratio of 1.00. The following table shows the current ratio calculation for the Company’s most recent fiscal quarter.

		As of
		December 31,
		2024
Current Assets		50,448,092
Less: Current derivative assets		5,497,057
Current Assets per Covenant		44,951,035
Revolver Availability (Facility less debt less LCs)		214,965,000
Current Assets per Covenant		259,916,035
Current Liabilities		105,037,187
Less: Current financing lease liability		906,119
Less: Current operating lease liability		648,204
Less: Current derivative liabilities		6,410,547
Current Liabilities per Covenant		97,072,317
Current Ratio		2.68
Minimum Allowed		> or = 1.00	x

Calculation of Cash Return on Capital Employed

The Company defines “Return on Capital Employed” or “CROCE” as Adjusted Cash Flow from Operations divided by average debt and shareholder equity for the period. Management believes that CROCE is useful to investors as a performance measure when comparing our profitability and the efficiency with which management has employed capital over time relative to other companies. CROCE is not considered to be an alternative to net income reported in accordance with GAAP.

CROCE (Cash Return on Capital Employed):	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	%

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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
All-In Cash Operating Costs:
Lease operating expenses (including workovers)		20,326,216				20,315,282				18,732,082				78,310,949				70,158,227
G&A excluding share-based compensation		6,363,657				6,389,480				5,706,117				24,134,283				20,355,330
Net interest expense (excluding amortization of deferred financing costs)		8,688,653				9,383,658				10,285,429				37,850,690				38,748,863
Operating lease expense		175,090				175,091				175,090				700,362				541,801
Oil and natural gas production taxes		3,857,147				4,203,851				4,961,768				16,116,565				18,135,336
Ad valorem taxes		2,421,595				2,164,562				1,637,722				8,069,064				6,757,841
Gathering, transportation and processing costs		130,230				102,420				464,558				506,333				457,573
All-in cash operating costs		41,962,588				42,734,344				41,962,766				165,688,246				155,154,971
Boe		1,808,493				1,849,934				1,784,490				7,191,054				6,613,321
All-in cash operating costs per Boe	$	23.20			$	23.10			$	23.52			$	23.04			$	23.46

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												Twelve Months Ended
	December 31,				September 30,				December 31,				December 31,				December 31,
		2024				2024				2023				2024				2023
Cash Operating Margin
Realized revenues per Boe	$	46.14			$	48.24			$	56.01			$	50.94			$	54.60
All-in cash operating costs per Boe	$	23.20			$	23.10			$	23.52			$	23.04			$	23.46
Cash Operating Margin per Boe	$	22.94			$	25.14			$	32.49			$	27.90			$	31.14

---

¹ Non-GAAP financial measure. Please see “Non-GAAP Information” at the end of this release for details and reconciliations of GAAP to Non-GAAP.
² 2025 outlook includes the assets to be acquired in the Lime Rock Acquisition, with an anticipated closing date before the end of Q1 2025.

FAQ

What were Ring Energy's (REI) production volumes for Q4 2024?

Ring Energy sold 19,658 barrels of oil equivalent per day (Boe/d) and 12,916 barrels of oil per day (Bo/d) in Q4 2024.

How much debt did Ring Energy (REI) reduce in 2024?

Ring Energy reduced debt by $40 million in 2024 and $70 million since closing the Founders acquisition in August 2023.

What is Ring Energy's (REI) production guidance for 2025?

Ring Energy projects average annual sales of 21,000 Boe/d and 13,900 Bo/d for 2025, representing 7% and 5% increases respectively.

How much were Ring Energy's (REI) proved reserves at the end of 2024?

Ring Energy grew proved reserves by 4.4 MMBoe to reach 134.2 MMBoe by the end of 2024, representing a 3% increase.

What was Ring Energy's (REI) capital expenditure in Q4 2024?

Ring Energy reduced total capital expenditures by 12% to $37.6 million in Q4 2024 compared to Q3 2024.