This article first appeared on GuruFocus .
Release Date: August 06, 2026
For the complete transcript of the earnings call, please refer to the full earnings call transcript .
Positive Points
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Ring Energy Inc ( REI ) reported a 3% sequential increase in total BOE sales volumes, averaging 19,990 BOE per day in Q2 2026.
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Realized oil prices surged 38% quarter-over-quarter, boosting overall realized price by 36% to $57.55 per BOE.
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The company completed a $65 million equity offering, using proceeds to reduce revolver borrowings and improve liquidity to $226 million.
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Leverage improved to approximately 1.7 times, with a clear path to achieving the 1.25 times target by early 2027.
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Ring Energy Inc ( REI ) raised its 2026 oil sales guidance midpoint by 2% and provided initial 2027 guidance with 10% BOE growth.
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The company expects 2027 capital spending to decrease by 10% from 2026, while infrastructure investments are projected to cut future drilling costs by at least $7.5 million.
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Operational efficiency improved, with LOE per BOE down 3% sequentially to $10.12, and cash costs reduced by $1.50 per BOE annually.
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The company is transitioning to longer laterals and codevelopment, which is expected to enhance capital efficiency and returns.
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Ring Energy Inc ( REI ) has a growing inventory of over 10 years, with plans to expand further through leasing and acquisitions.
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The company maintains a disciplined hedging strategy, with 30% of oil production unhedged to capture upside in higher price environments.
Negative Points
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Ring Energy Inc ( REI )'s hedge portfolio limited participation in the significant oil price upside during Q2 2026.
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Natural gas pricing remains pressured due to ongoing takeaway and processing constraints, with a differential of -$8.14 per MCF.
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The company's 2026 capital spending plan was increased to $158-$178 million, up from initial guidance, due to accelerated infrastructure investments.
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The equity offering diluted existing shareholders, though proceeds were used for debt reduction.
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The company faces uncertainty in the commodity market, with management noting the forward strip implies a surplus that may not materialize.
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Asset sales are still in early stages, with no clear timeline or expected proceeds, limiting near-term balance sheet flexibility.
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The transition to longer laterals and codevelopment requires significant upfront infrastructure investments, which may pressure near-term free cash flow.
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The company's leverage ratio remains above its 1.25 times target, though improving, and hedging requirements are still elevated.
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Geopolitical risks, such as the Iran conflict and Strait of Hormuz disruptions, create volatility in oil prices and operational uncertainty.
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The 2027 production growth outlook is dependent on successful execution of the development plan and commodity prices, with stress tests at $60 oil showing only marginal free cash flow.
Q & A Highlights
Q: Can you talk about where you stand with respect to evaluating the asset base and identifying incremental drilling opportunities, maybe versus where you were at the beginning of 2026? A: Paul McKinney, Chairman and CEO: We have spent considerable time over the last several years evaluating our operated land for untapped opportunities and leasing additional acreage to extend those areas. We are testing new zones in our stacked pay areas, which are conventional in nature with higher porosity and permeabilities. The application of horizontal drilling, especially longer laterals, and codevelopment significantly reduces costs. We believe we see opportunities up and down the Central Basin Platform, and by the end of the year, our inventory will be significantly higher, exceeding 10 years. With continued efforts from our geoscience and land teams, we believe this will significantly exceed that in 2027.
Q: You started 2026 with a capital plan pinned on a $60 or low $60s price deck. Can you share what you're pinning the 2027 plan on? A: Paul McKinney, Chairman and CEO: The 2027 plan will be a higher capital spending plan. At the beginning of the year, we had a modest program anticipating a price environment that could test $50 oil. We layered in hedges to strengthen our floor to guarantee at least $60 at the wellhead. With higher oil prices and the equity raise, we are making infrastructure investments earlier to improve capital efficiency. Next year, we plan to spend around $160 million, which will deliver more barrels per day and more reserves per dollar spent, positioning the company for accelerated organic production growth we have not delivered in the 5-6 years I've been here. We are running $75 in the near term, and even at $60 oil in 2027, the economics still work and we can marginally generate free cash flow.
Q: The equity offering clearly impacted your CapEx. Are you going to be in a better position to capture the upside if commodity prices are higher, given the revolver has historically limited your ability to capture higher prices? A: Paul McKinney, Chairman and CEO: Our credit facility requires hedging 50% of oil and gas production for the first 24 months when leverage is above 1.25 times and the draw against the borrowing base is greater than 50%. We are focused on getting leverage below 1.25 times, which would reduce longer-term hedging requirements by 50%. The majority of historical hedge losses were associated with months 13-24. We are rapidly dropping our leverage ratio and anticipate qualifying for reduced hedging requirements as early as the first quarter of next year. Currently, 30% of our oil production is exposed to higher prices in Q3-Q4 2026, but that increases to 60-64% in 2027, demonstrating meaningful upside to adjusted free cash flow.
Q: Now that you have a runway for the horizontal play, does that simplify what you can pay in bonuses in a given area, or does it complicate the land equation? A: Paul McKinney, Chairman and CEO: It doesn't complicate things; it's the same type of business. The real challenge is finding opportunities in the mature Central Basin Platform where most acreage is held by others. There are overlooked areas because historical porosity and permeabilities were low and technology wasn't advanced. We believe the Central Basin Platform still has tremendous opportunity. Lands owned by larger companies are not core to them, and they've shown willingness to sell. We have allocated more money to land acquisitions this year, but we are not disclosing where we're buying to avoid increased competition. We are making progress and look forward to disclosing it as the year progresses.
Q: Can you get your thoughts on crude oil macro and why we don't have more strength in the 2027 strip and beyond, considering the unresolved situation with Iran? A: Paul McKinney, Chairman and CEO: The forward strip does not reflect current fundamentals. Production curtailed through the Strait of Hormuz has been offset by alternative routes and strategic petroleum reserves, but those reserves are being depleted. Global storage has been consumed. Emerging economies with growing middle classes will drive continued demand. The world has not been investing at a rate necessary to replace decline since the last major price shocks. I believe this disruption may have accelerated the crossing of the world's ability to deliver oil versus demand. A flat $80-$85 strip would incentivize the capital investments needed. As we go into 2027 and 2028, the likelihood of seeing $50 or $60 oil becomes less. We want to position Ring Energy to deliver organic growth to take advantage of what I believe will be a stronger market environment.
Q: With respect to the horizontal wells in the second half plan and next year, is the lateral length being dictated by the shape of the leases or other reservoir issues? A: Paul McKinney, Chairman and CEO: In most areas, lateral length is dictated by the unit and land position. Over the last two years, we have focused land acquisition efforts to ensure we can unitize and develop longer laterals. In the South, where we historically drilled verticals, there are still areas that prevent longer laterals due to unit development, but our land department is working on solutions. Our goal is to convert all units to drill long laterals and take advantage of increased capital efficiency. Alex Dyers, EVP and Chief Operations Officer, added that the infrastructure dollars spent on facilities, frac pits, and disposal wells are necessary to support the 1.5 and 2-mile wells in the South, which bring on more production and water.
Q: You mentioned asset sales in your prepared comments. How much could you generate from asset sales and what is the timing? A: Paul McKinney, Chairman and CEO: That's a challenging question to answer. Some ideas are in their infancy, while others are a bit further along, but it's premature to discuss amounts. Looking at our history, we have routinely optimized our portfolio, making acquisitions and exiting positions that don't fit our criteria, such as our exit from New Mexico. This is another avenue to strengthen the balance sheet and put assets we value less into the hands of those who value them more. We will continue to do this, but giving a range today would be out of line.
Q: Can you talk about the impact of the equity offering on your ability to reduce hedging constraints and capture higher prices? A: Paul McKinney, Chairman and CEO: The offering helped strengthen the balance sheet, but we still need to grow production and capture higher prices to reach the point where hedging programs won't limit upside as much. The elevated price environment is rapidly dropping our leverage ratio, and we anticipate
For the complete transcript of the earnings call, please refer to the full earnings call transcript .
