SandRidge Energy, Inc. 2026 Q2 Earnings Call

Welcome everyone. With me today are Grayson Pranin, our CEO, Jonathan Frates, our CFO, Brandon Brown, our CAO, and Dean Parrish, our COO. We would like to remind you that today's call contains forward-looking statements and assumptions, which are subject to risk and uncertainty, and actual results may differ materially from those projected in these forward-looking statements. These statements are not guarantees of future performance, and our actual results may differ materially due to known and unknown risks and uncertainties as discussed in greater detail in our earnings release and our SEC filings. We may also refer to adjusted EBITDA and adjusted G&A and other non-GAAP financial measures. Reconciliations of these measures can be found on our website. With that, I'll turn the call over to Grayson.

Thank you. Good afternoon. I'm pleased to report on a strong quarter and first half for the company. We continue to grow year-over-year production and revenue, driven primarily by our operated development program and higher commodity prices. We also announced a bolt-on acquisition that expands our footprint in the Cherokee Play. Before getting into this and other highlights, I will turn things over to Jonathan for details on financial results.

Thanks, Grayson. During the quarter, the price of oil averaged roughly $95 per barrel, while the price of natural gas fell to just above $3. The company grew production to 19.7 MBOE per day, representing an increase of 11% year-over-year on a BOE basis, while oil increased to 22% over the same period. We generated revenues of just over $51 million, a 48% increase year-over-year, and adjusted EBITDA to $34 million, a 49% increase over the same period. As always, we continue to manage the business with the goal of maximizing long-term cash flow while growing production and utilizing our NOLs to shield us from income taxes. At the end of the quarter, cash, including restricted cash, was approximately $115 million, which represents roughly $3.09 per common share outstanding.

The company paid $10.6 million in dividends during the quarter, which included our regular quarterly dividend of $0.13 per share and the previously announced one-time special dividend of $0.20 per share. Including special dividends, SandRidge has now paid $5.05 per share in dividends since the beginning of 2023. On August 4th, 2026, the board of directors declared a $0.13 per share dividend payable on August 31st to shareholders of record on August 19th, 2026. Shareholders may elect to receive cash or additional shares of common stock through the company's dividend reinvestment plan. Commodity price realization for the quarter before considering the impact of hedges were $95.35 per barrel of oil, $1.36 per MCF of gas, and $21.68 per barrel of NGL. This compares to first quarter realizations of $71.11 per barrel of oil, $3.13 per MCF of gas, and $18.64 per barrel of NGL.

While oil prices rose during the quarter, the realized price of natural gas fell meaningfully, primarily due to widening regional price differentials. Our commitment to cost discipline continues to yield results with adjusted G&A for the quarter of approximately $2.7 million, or $1.52 per BOE, compared to $2.4 million or $1.48 per BOE in the second quarter of 2025. Net income was approximately $27 million for the quarter, or $0.72 per common share, and adjusted net income was approximately $21 million or $0.57 per share. This compares to $19.6 million or $0.53 per common share and $12.2 million or $0.33 per share, respectively, during the same period last year.

The company generated cash flow from operations of $42.4 million during the quarter, compared to $22.9 million during the same period last year, and adjusted operating cash flow of $34.6 million during the quarter, compared to $25.6 million in the same period of 2025. The company continues to have no debt and expects to fund all 2026 capital expenditures and capital returns with cash flows from operations during the year. Lastly, our production is hedged with a combination of swaps and collars, representing just under 30% of the midpoint for 2026 guidance. This includes 37% of natural gas production and 43% of oil. These hedges will help secure a portion of our cash flows and support our drilling program through the year. We continue to monitor prices to take advantage of favorable opportunities, but plan to maintain meaningful upside throughout the remainder of the year.

Before shifting to our outlook, we should note that our earnings release in 10-Q will provide further details on our financial and operational performance during the year. Now I will turn it over to Dean for an update on operations.

Thank you, Jonathan. I'll start with a review of the second quarter, then discuss recent drilling and completion results. Total capital spend for the quarter, excluding A&D, was $16.3 million, which is better than expected for the quarter, mostly due to activity timing. The rigorous bidding process Focus on driving, drilling, and completion costs down in the Cherokee Play and longer artificial lift run-life times from previous years of improvements also contributed.

We have been securing critical well components needed for the remainder of the year to minimize any supply or inflationary pressures that may affect our capital program. Lease operating expenses for the quarter were $10.3 million or $5.73 per BOE, which falls right in line with expectations. We are also securing the equipment and services that will be critical for production operations in 2026, similar to the capital program. We expect to continue to see pressure on diesel through fuel surcharges passed on through service providers that have strict internal protocol to reduce surcharges when diesel prices begin to decrease. During the quarter, the company successfully brought two wells online from our operated one-rig Cherokee drilling program.

We recently brought online two additional wells in July and are drilling the sixth out of 10 wells for the year. Our operations team continues to execute, with the fourth well that was drilled being the fastest, lowest well cost to date. In addition to Cherokee development, the operations team successfully recompleted a shut-in legacy well to an uphole zone with initial production rates of 1,400 Mcf per day and four barrels of oil per day, exceeding expectations. We will continue to focus on lower drilling and completion costs while looking for opportunities to extract additional value from legacy assets. Moving to our 2026 capital program. We plan to drill 10 operated Cherokee wells with one rig this year and complete nine wells. The remaining completion is anticipated to carry over to next year.

A majority of the remaining wells in our development program this year directly offset producing or in-progress wells in the area. We continue to monitor offsetting results. Gross well costs vary by depth but are estimated to be between approximately $9 million and $11 million. We intend to spend between $76 million and $97 million in our 2026 capital program, which is made up of $62 million-$80 million in drilling and completion activity and between $14 million and $17 million in capital workovers, production optimization, and selective leasing in the Cherokee Play. Our high-graded leasing is focused on further bolstering our interest, consolidating our position, and extending development into future years. I will turn things back over to Grayson.

Thank you, Dean. Let's begin with the recently announced Cherokee acquisition. On June 29th, we signed an agreement to acquire certain producing assets and leasehold interests in the Cherokee Play, expanding our efficient operations in the area with the addition of 7,000 net leasehold acres and interest in 21 wells to include interest in four SandRidge operated wells. The proven undeveloped leasehold includes four two-and-a-half mile wells and four two-mile wells, which immediately offset our core position in Roger Mills County. The average 30-day IP for the operated producing wells we are acquiring is more than 2,100 BOE per day with 58% oil. We view this as a very complementary bolt-on that expands our footprint in the Mid-Continent by adding quality oil-weighted production and bolstering our Cherokee inventory with acreage that immediately offsets our current drilling and leasing programs.

We anticipate closing this acquisition in the third quarter and will then focus on integrating the new assets, applying our low-cost know-how to operations. Currently, do not plan to add people as a result of the acquisition. Let's pivot over to the development program. As Dean discussed, we had first production on two wells this past quarter. One well targeted the Cherokee Shale in our core area, which had a peak 30-day average production rate of approximately 2,000 BOE per day, consistent with the surrounding wells in the area. The other well turned in line this quarter was a step out from our core area and tested a sub-member of the larger Cherokee formation immediately below the Cherokee Shale. This well had an initial 30-day average rate more than 10,000 Mcf per day and more than 100 barrels of oil per day on a two-stream basis.