Riley Exploration Permian Inc (REPX) Investment Analysis

1. Executive Summary

Riley Exploration Permian Inc. (REPX) operates as a highly specialized, growth-oriented independent oil and natural gas exploration and production (E&P) enterprise. Unlike the majority of modern Permian Basin operators that aggressively pursue the ultra-deep, highly pressurized unconventional shale layers within the central cores of the Delaware or Midland Basins, the company focuses its operational footprint strategically on the Northwest Shelf of the Permian Basin. This geographic and geological positioning is fundamental to the corporate identity and economic modeling of the firm. The operational strategy specifically targets horizontal drilling techniques applied to conventional, oil-saturated, and liquids-rich formations that yield shallower decline curves and produce long-term, sustainable cash flows. The company’s core acreage is consolidated into two primary hubs: the Champions field, located in Yoakum County, Texas, which extracts hydrocarbons predominantly from the legacy San Andres formation, and the Red Lake field in Eddy County, New Mexico, which targets the Abo and Yeso formations. At the close of 2024, prior to significant subsequent acquisitions, the operational footprint encompassed 58,270 net acres containing 612 net producing wells, establishing a highly contiguous land position that allows for extended lateral drilling and highly optimized, centralized infrastructure deployment.

Revenue generation is fundamentally driven by the upstream extraction, gathering, and sale of three primary hydrocarbon streams: crude oil, natural gas, and natural gas liquids (NGLs). Crude oil is the overwhelmingly dominant economic driver of the business. During the third quarter of 2025, the company averaged 32.3 thousand barrels of oil equivalent per day (MBoe/d) in total production, of which 18.4 thousand barrels per day (MBbls/d), or approximately 57%, was comprised of crude oil. Because global and domestic crude oil commands a significantly higher realized price per equivalent unit compared to the currently depressed Permian natural gas and NGL markets, crude oil accounts for the vast majority of top-line revenue and operating margins. The customer base for these upstream products primarily consists of large midstream aggregators, regional refiners, and pipeline operators who purchase the commodities at the wellhead or at centralized gathering points, subsequently transporting them to major pricing hubs in the Gulf Coast or Cushing, Oklahoma.

Beyond traditional upstream extraction operations, the company generates significant value, operational synergies, and risk mitigation through strategic ancillary business segments. Recognizing the severe infrastructure bottlenecks that chronically plague the Permian Basin, management proactively incubated two critical segments: midstream infrastructure and power generation. The midstream segment achieved a major monetization and strategic milestone in December 2025 through the sale of the Dovetail Midstream project in New Mexico to Targa Northern Delaware LLC. This transaction provided massive upfront capital while ensuring long-term flow assurance for the company's natural gas production. Concurrently, the power generation segment operates via RPC Power LLC, a 50/50 joint venture established with Conduit Power LLC. This joint venture constructs and operates thermal generation and battery energy storage facilities. RPC Power serves dual strategic functions: it significantly lowers the company's internal lease operating expenses (LOE) by providing reliable, behind-the-meter electricity for field operations, and it generates independent, counter-cyclical revenue by selling dispatchable electricity into the Texas ERCOT grid during periods of peak statewide demand.

2. Business Drivers & Strategic Overview

The operational and financial trajectory of Riley Exploration Permian is governed by three primary strategic pillars: the optimization and expansion of organic upstream drilling inventory, the execution of highly accretive regional mergers and acquisitions (M&A), and the relentless pursuit of infrastructure independence to circumvent basin-wide structural bottlenecks.

The primary catalyst for revenue generation remains the disciplined, technologically advanced development of the company’s delineated drilling inventory across Texas and New Mexico. The company utilizes advanced horizontal drilling and completions technology to extract maximum value from mature, conventional reservoirs. During the 2025 operational campaigns, the company routinely pushed the technical envelope, setting multiple records in Yoakum County. This included drilling the longest lateral ever recorded in the San Andres formation at 10,375 feet, as well as achieving the fastest spud-to-total-depth (TD) drilling times in the region's history. These operational efficiencies are not merely technical achievements; they translate directly into lower capital intensity per well, reduced days on location, and accelerated time-to-market. The company also employs a strategic batch completion methodology and maintains a dynamic inventory of drilled-but-uncompleted wells (DUCs). By completing wells in batches of 5 to 10 at a time, the company secures favorable pricing from pressure pumping service providers and achieves greater logistical efficiency, subsequently staggering the turn-to-sales dates to maintain a stable, predictable production profile rather than experiencing volatile production spikes and steep declines.

Growth is achieved through a dual mandate of this organic drilling alongside opportunistic M&A activity. In July 2025, the company successfully closed the acquisition of Silverback Exploration II, LLC. The transaction was finalized for an adjusted cash price of $120 million, plus minor contingent considerations of $3.1 million, reflecting a highly disciplined negotiation process given initial valuations closer to $142 million. This transaction was transformative, adding significant contiguous acreage in Eddy County, New Mexico, approximately 5 MBoe/d of immediate production, and over 300 gross undeveloped locations to the corporate inventory. The integration of the Silverback assets has been exceptionally swift and highly accretive. By September and October of 2025, proactive workover operations and the application of the company's proprietary operating methodologies resulted in production from the acquired assets exceeding original underwriting projections by more than 50%. This structural approach to M&A—acquiring under-optimized, contiguous assets from private operators and immediately applying superior operational techniques—represents a primary competitive advantage that allows the company to act as a highly effective regional consolidator on the Northwest Shelf.

A profound competitive advantage for the company lies in its approach to infrastructure. The Permian Basin is chronically constrained by pipeline takeaway capacity and electrical grid reliability. These macro-level deficits create severe choke points that frequently lead to involuntary production shut-ins or catastrophic localized price realizations, such as the negative spot prices frequently observed at the Waha natural gas hub. To circumvent the unreliability and high cost of the Texas electrical grid, the company established RPC Power LLC, backed by a $60 million senior secured credit facility coordinated by KeyBanc Capital Markets. By the third quarter of 2025, RPC Power successfully served approximately 70% of the massive electrical load required for the Champions field operations in Texas, effectively isolating these critical extraction operations from ERCOT grid volatility and rolling blackouts. Furthermore, the company is utilizing the joint venture to construct four 10-megawatt (MW) thermal generation facilities designed explicitly for commercial power sales into the ERCOT grid, alongside advanced battery energy storage systems. By utilizing field-produced natural gas—which often prices negatively at the wellhead, requiring producers to pay to have it taken away—as a virtually free feedstock to generate electricity, the company is executing a structural physical arbitrage. It transforms a localized liability into a high-margin revenue stream, selling dispatchable power during ERCOT scarcity events.

Simultaneously, the midstream infrastructure risk profile was fundamentally de-risked in late 2025. In December 2025, the company announced the sale of its wholly-owned Dovetail Midstream LLC subsidiary to Targa Northern Delaware LLC. The assets consisted primarily of natural gas gathering infrastructure serving Eddy County, New Mexico. The transaction secured an aggregate upfront cash purchase price of $111 million, with the right to earn up to an additional $60 million in volume-based contingent payments over a five-year period, alongside a subsequent $10 million sale of compressor station assets scheduled for early 2026. This strategic divestiture served two vital purposes: it provided immediate liquidity to rapidly deleverage the balance sheet following the Silverback acquisition, and it partnered the company with a best-in-class midstream operator, guaranteeing the flow assurance required to aggressively develop the newly acquired New Mexico acreage without the risk of future pipeline curtailments.

An additional long-term strategic growth initiative is the application of Carbon Dioxide Enhanced Oil Recovery (CO2 EOR). The company's Champions field in Yoakum County directly offsets the legacy Wasson field. The Wasson field has historically been one of the most prolific and successful CO2 EOR operational areas in the global oil industry, validating the geological receptiveness of the area. The San Andres formation contains substantial residual oil zones (ROZs) that are largely unresponsive to traditional primary depletion or secondary waterflooding, but are highly receptive to miscible CO2 flooding. The company has been executing a detailed CO2 EOR pilot program. If commercialized at scale, the injection of anthropogenic CO2 could increase the ultimate oil recovery factor of the acreage by an estimated 10% to 25%. This technology effectively converts vast quantities of unrecoverable resources into proved developed producing (PDP) reserves without the heavy capital intensity associated with continuously drilling new horizontal wells, offering a massive asymmetric upside to the long-term resource base.

3. Financial Performance & Valuation

The financial profile of the company demonstrates significant cash flow generation capabilities, stringent cost containment, and operational resilience, even amid the softening macroeconomic crude oil pricing environment that characterized much of 2025.

Recent Historical Performance

The 2025 fiscal year showcased a clear trajectory of acquisitive growth and cash flow optimization. During the first quarter of 2025, the company reported average total equivalent production of 24.4 MBoe/d (15.6 MBbls/d of oil), generating $102 million in revenues and $50 million in net cash provided by operating activities. Non-GAAP Adjusted EBITDAX for the first quarter stood at a robust $71 million, yielding a Total Free Cash Flow of $36 million. In the second quarter of 2025, facing a challenging oil market and regional infrastructure constraints, the company maintained production at 24.4 MBoe/d (15.2 MBbls/d of oil), generating $34 million in operating cash flow and $18 million in Total Free Cash Flow, while actively reducing capital expenditures in response to lower price realizations.

The third quarter of 2025, ending September 30, marked a structural step-change in the financial baseline due to the successful integration of the Silverback assets. The company reported total revenues of $107 million and a net income of $16 million, equating to $0.77 per diluted share. Average total equivalent production surged to 32.3 MBoe/d (18.4 MBbls/d of oil), representing a 33% quarter-over-quarter increase in total volumes and a 21% increase in oil volumes. Net cash provided by operating activities rebounded strongly to $64 million for the quarter. On a non-GAAP basis, Adjusted EBITDAX was $64 million, with Total Free Cash Flow reaching $25 million.

The company generated these third-quarter results despite a highly challenging pricing environment. Average realized prices before derivative settlements were $63.94 per barrel of oil, $(0.21) per Mcf of natural gas, and $(0.66) per barrel of NGLs. The negative realization on both gas and NGLs underscores the severe basin-wide constraints and perfectly highlights the critical strategic value of the RPC Power joint venture and the Dovetail Midstream sale, which directly mitigate these exact pricing pressures. Despite these top-line pricing headwinds, cost containment remained exemplary. Operating expenses during Q3 2025 included Lease Operating Expenses (LOE) of $27 million (equating to just $9.03 per Boe), administrative costs of $10 million ($3.34 per Boe), and production and ad valorem taxes of $8 million ($2.78 per Boe). The sub-$10/Boe LOE highlights the systemic efficiency of the company's shallow-decline, conventional reservoir base when compared to the highly pressurized, high-water-cut, and infrastructure-heavy shale wells in the deeper basin cores.

Capital Structure and Liquidity

As of September 30, 2025, the total outstanding debt principal was $375 million, consisting of $225 million drawn on the senior secured revolving credit facility and $150 million in senior unsecured notes. The debt profile increased by $91 million during the third quarter primarily to fund the $120 million Silverback acquisition. The senior notes require $5 million quarterly principal payments and feature optional redemption clauses prior to maturity in April 2026.

However, the balance sheet underwent a massive de-risking event subsequent to the Q3 reporting period. The December 2025 sale of the Dovetail Midstream asset provided $111 million in immediate upfront cash, the proceeds of which were explicitly earmarked by management to reduce borrowings on the credit facility. The company's underlying liquidity position is highly secure. In December 2024, the credit facility maturity was successfully extended to December 2028, and the borrowing base was expanded from $375 million to $400 million by a syndicate of nine lenders. With the aggressive paydown from the Targa transaction, the company operates with a highly conservative leverage profile. Assuming an annualized Q3 2025 Adjusted EBITDAX run-rate of approximately $256 million, and adjusting post-midstream sale debt levels down to approximately $264 million ($375M - $111M), the pro-forma debt-to-EBITDAX ratio sits at approximately 1.0x, a comfortable threshold that provides massive operational flexibility.

Valuation Multiples and Capital Returns

At current trading levels near $28.30 per share, and with 21.96 million shares outstanding as of late 2025, the equity market capitalization is approximately $621 million. Factoring in the pro-forma net debt position of roughly $264 million, the Enterprise Value (EV) stands at approximately $885 million. Trading at an EV/EBITDAX multiple of approximately 3.4x to 3.8x (based on annualized 2025 figures), the valuation represents a significant structural discount to broader market indices and large-cap energy peers, suggesting deep value.

Management aggressively returns capital to shareholders. The company has maintained a steady and growing dividend, declaring a quarterly payout of $0.40 per share in early 2026, up 5% from the $0.38 payouts earlier in 2025. This $1.60 annualized dividend results in a highly compelling and well-covered yield of approximately 5.6%. Furthermore, acting on the perceived valuation disconnect, the Board of Directors authorized a sweeping $100 million share repurchase program in December 2025, extending over 24 months. At current market prices, this program represents authorization to retire over 16% of the company's outstanding equity float, providing a massive psychological floor to the share price while increasing per-share metrics for long-term holders.

4. Risk Assessment & Macroeconomic Considerations

While the company is structurally sound, the upstream sector is inherently tethered to the macroeconomic volatility of global commodity markets and highly specific localized operational risks.

Macro Trends: Global Commodity Pricing

Heading into 2026, global industry outlooks forecast potential macroeconomic headwinds. Leading energy analytics firm Enverus projects a recalibration year, with Brent crude potentially averaging around $55 per barrel in 2026, driven by global supply adjustments, non-OPEC production growth, and softening macroeconomic demand conditions in China and Europe. Should West Texas Intermediate (WTI) crude remain persistently below $60 per barrel, the company’s unhedged operating margins will experience compression. However, the company rigorously mitigates this exposure via a highly active hedging program. Entering 2026, the company has hedged over 60% of its anticipated 2026 crude oil volumes at a weighted average downside protection price of $60 per barrel, utilizing a mix of swaps and collars to preserve upside optionality while strictly limiting downside cash flow destruction.

Basin Infrastructure and Natural Gas Dynamics

The Permian Basin is simultaneously experiencing a profound structural shift regarding natural gas and NGL takeaway capacity. Record-breaking basin-wide oil production has resulted in vast quantities of associated natural gas being produced simultaneously. This associated gas has overwhelmed existing pipeline infrastructure, frequently pushing spot prices at the Waha hub below zero, forcing operators to pay to have their gas transported or resort to flaring. While new massive pipeline projects, such as the Matterhorn Express and the upcoming Bahia NGL pipeline expansion, are coming online to alleviate this bottleneck, operators without secured, firm transportation agreements face the severe risk of involuntary production shut-ins. The company’s sale of its New Mexico midstream assets to Targa was executed specifically to achieve "flow assurance" for its natural gas production, effectively transferring the takeaway and regulatory risk to a dedicated, massive midstream operator.

Micro Risks: Produced Water Disposal and Regulatory Pressures

A highly localized, yet potentially existential operational risk involves produced water management. When oil and gas are extracted in the Permian Basin, massive quantities of salty, toxic "produced water" are brought to the surface simultaneously. Currently, approximately 85% of produced water in the Permian is eliminated via injection into deep subterranean disposal wells. This practice has been increasingly and scientifically linked to induced seismicity (earthquakes) across West Texas and southeastern New Mexico. Regulatory bodies, particularly in New Mexico where the company recently expanded its footprint via the Silverback acquisition, have intensified regulatory scrutiny and actively limited or banned injection volumes in designated seismic response areas. If disposal costs—currently ranging from $0.60 to $0.70 per barrel—spike due to hard capacity constraints, or if the company is forced by regulators to construct extensive, highly expensive recycling infrastructure to treat the water for reuse, well-level economics and corporate margins would be materially and negatively impacted.

Execution and Integration Risk

While the initial integration results from the Silverback acquisition exceed early expectations, scaling operations across a broadened, dual-state asset base introduces ongoing execution risk. The company deliberately builds an uncompleted well inventory (DUCs) to manage capital flows efficiently and insulate against service cost inflation. However, any failure in applied drilling and completion techniques, supply chain delays for specialized steel casing, or shortages in high-spec pressure pumping fleets could significantly delay production targets. Furthermore, the RPC Power joint venture, while highly promising, exposes the E&P company to the complex, highly regulated frameworks of the Texas ERCOT power market, requiring distinct operational competencies entirely outside traditional upstream oil and gas extraction.

5. 5-Year Scenario Analysis

To accurately project total return outcomes over a 5-year horizon (2026-2030), this analysis relies on maximally detailed financial modeling utilizing the company's current verified baseline data. The foundation parameters for Year 0 (2025 exit) include the Q3 2025 annualized Adjusted EBITDAX of $256 million, a starting pro-forma debt load of $264 million (accounting for the $111M Targa paydown), a cash balance of $16.5 million, and 21.96 million shares outstanding. 2025 baseline revenue is established at approximately $422 million. The analysis assumes a sustained minimum dividend payout of $1.60 annually, yielding cumulative cash returns to shareholders across the 5 years. Valuations are derived from an applied Enterprise Value to EBITDAX (EV/EBITDAX) multiple.

Base Case (Probability: 60%)

The Narrative & Fundamentals: The global oil market achieves a stable equilibrium, absorbing non-OPEC growth while OPEC+ manages spare capacity effectively. WTI crude oil averages $65 to $70 per barrel consistently through 2030. The company executes its core business plan with disciplined efficiency, achieving modest organic production growth of 3% to 5% annually from the combined Texas and New Mexico asset base. Five-year sales growth follows a steady 4% Compound Annual Growth Rate (CAGR), driving annual revenue from $422 million to approximately $513 million by 2030. The Targa midstream earnout targets are partially met as production grows steadily, yielding $30 million in contingent cash payments over the five years. The RPC Power joint venture scales successfully according to plan, isolating field power costs and contributing $20 million annually in pure free cash flow to the parent entity by 2028 as new 10MW thermal facilities come online. Total operating costs (LOE) experience mild inflation of 2% annually, offsetting efficiency gains.

Financial Assumptions & Outputs: By 2030, EBITDAX expands to $310 million. The company deploys the entirety of its $100 million buyback authorization systematically over the first three years, retiring approximately 3.5 million shares at an average price of $28.50, leaving 18.46 million shares outstanding. Sustained free cash flow generation easily covers the dividend and allows management to pay down gross debt to a highly conservative terminal level of $100 million.

Valuation & Price Outcome: The broader equity market rewards the company's steady yield, execution, and low leverage with a slightly expanded EV/EBITDAX multiple of 4.5x, reflecting standard valuations for healthy small-cap E&Ps.

• Projected Terminal EV: $1,395 million ($310M EBITDAX x 4.5).

• Projected Market Cap: $1,295 million (EV - $100M terminal debt; cash assumed $0 for conservatism).

• 2030 Share Price Outcome: $70.15 ($1,295M / 18.46M shares).

• Cumulative Dividends Paid: $8.00 per share.

High Case (Probability: 25%)

The Narrative & Fundamentals: Geopolitical tensions, prolonged supply chain disruptions, or a structural lack of global upstream capital investment drives WTI crude oil into a structural super-cycle, averaging above $80 per barrel. Revenue scales dramatically at an 8% CAGR, reaching $620 million by 2030. The company's non-core and experimental segments excel far beyond expectations: the CO2 EOR pilot at the Champions field demonstrates exceptional miscible sweep efficiency, allowing the company to book extensive, low-cost Proved Undeveloped Reserves (PUDs) without acquiring new land. Targa hits all aggressive volume thresholds, delivering the full $60 million maximum earnout. The RPC Power JV becomes a cash-printing asset amid severe ERCOT grid volatility and rolling blackouts, generating $40 million in annual EBITDA independently.

Financial Assumptions & Outputs: By 2030, EBITDAX scales massively to $420 million. The enormous influx of free cash flow covers the dividend, pays off all corporate debt entirely, and allows the company to authorize a secondary, larger buyback program. Across five years, the company retires a total of 5.5 million shares, leaving just 16.46 million shares outstanding. Terminal debt is $0.

Valuation & Price Outcome: Institutional investors flock to the pristine balance sheet, massive cash return profile, and the proven longevity of the CO2 EOR reserves. The multiple expands to a premium 5.5x EV/EBITDAX.

• Projected Terminal EV: $2,310 million ($420M EBITDAX x 5.5).

• Projected Market Cap: $2,310 million (EV - $0 debt).

• 2030 Share Price Outcome: $140.34 ($2,310M / 16.46M shares).

• Cumulative Dividends Paid: $12.00 per share (assuming significant dividend hikes).

Low Case (Probability: 15%)

The Narrative & Fundamentals: A severe global macroeconomic recession, accelerated EV adoption, or unchecked shale efficiency gains create a prolonged structural supply glut, suppressing WTI crude to an average of $45-$50 per barrel. Sales contract at a -3% CAGR as the company is forced to drop drilling rigs, harvest decline curves, and preserve capital, resulting in 2030 revenue of just $362 million. Permian water disposal costs escalate dramatically due to severe regulatory crackdowns on induced seismicity , pushing LOE margins above $12.00/Boe. The Targa earnouts are entirely missed due to drilling curtailments.

Financial Assumptions & Outputs: By 2030, EBITDAX shrinks drastically to $180 million. The company suspends the $100 million buyback program entirely to preserve liquidity, meaning the full 21.96 million shares remain outstanding. Debt reduction stalls completely; the company is forced to roll its senior notes and rely on the credit facility, leaving $300 million in outstanding principal. The dividend is slashed by 50% to $0.80 annually starting in 2027 to prevent covenant breaches.

Valuation & Price Outcome: The market severely punishes the levered balance sheet and shrinking production base, applying a distressed multiple of 3.0x EV/EBITDAX.

• Projected Terminal EV: $540 million ($180M EBITDAX x 3.0).

• Projected Market Cap: $240 million (EV - $300M debt).

• 2030 Share Price Outcome: $10.92 ($240M / 21.96M shares).

• Cumulative Dividends Paid: $4.80 per share.

5-Year Share Price Trajectory Table

Subjective Probability Weighted Outcome: (0.60 $70.15) + (0.25 $140.34) + (0.15 * $10.92) = $42.09 + $35.08 + $1.63 = $78.80 Probability Weighted Share Price Target.

VALUE UNLOCK IMMINENT

6. Qualitative Scorecard

• Management Alignment: 9/10 The executive suite and board operate with an intense owner-operator mentality that is exceedingly rare in the modern public E&P space. Insider ownership is exceptionally high, with insiders holding approximately 43.91% of outstanding shares (9,647,248 shares). CEO Bobby Riley personally holds over 349,000 shares, and other executives like Corey Riley continue to acquire shares on the open market. This deep equity concentration ensures that management’s wealth generation is intrinsically tied to long-term share price appreciation and dividend continuity rather than purely salary-based compensation or short-term bonus metrics. Furthermore, large institutional backers, including Yorktown Energy Partners and Bluescape Energy Partners, maintain substantial board-level influence, enforcing rigorous capital discipline.

• Revenue Quality: 7/10 While ultimately beholden to the cyclical whims of global commodity markets, the revenue quality is structurally enhanced by intelligent, defensive hedging. The company protects its downside risk comprehensively, boasting hedges on over 60% of its 2026 crude oil volumes at a weighted average downside price of $60 per barrel. Furthermore, the high oil weighting of the production mix (57% volume, ~90%+ revenue) shields the company from the devastatingly low realizations currently plaguing pure-play natural gas producers in the basin.

• Market Position: 6/10 The company remains a small-cap player in a massive basin dominated by supermajors like ExxonMobil and Chevron, and large-cap independents like Diamondback and Permian Resources. It lacks the economies of scale possessed by these behemoths. However, by operating specifically on the Northwest Shelf rather than attempting to compete in the hyper-expensive Midland and Delaware Basin cores, it secures a highly defensible niche. It acts as a regional consolidator, executing acquisitions (like Silverback) that are too small to attract the supermajors but highly accretive on a relative basis.

• Growth Outlook: 8/10 Organic production growth is explicitly targeted at a modest but highly sustainable pace to preserve high-tier inventory over the long term. Realized volume growth will be augmented heavily by the rapid integration of the Silverback acreage, which added over 300 gross undeveloped locations to the runway. However, the true asymmetric growth lever lies entirely outside traditional primary drilling: the ongoing CO2 EOR pilot program in the Champions field holds the potential to significantly augment long-term resource recovery, mirroring the success of the adjacent Wasson field, without the rapid, capital-intensive decline curves associated with primary shale production.

• Financial Health: 7/10 The absolute debt load requires continuous monitoring, but the trajectory is highly positive. A total debt burden of $375 million (pre-Targa sale) against a market capitalization of ~$621 million translates to a debt-to-equity ratio of nearly 65%, which screens as high for the sector. However, the debt is highly serviceable. Operational cash flow comprehensively covers interest expenses (over 5x interest coverage), and the maturity schedule is favorable, with the credit facility extended to December 2028. Most importantly, the recent midstream asset sale provided an immediate $111 million cash injection utilized specifically to deleverage, materially improving the pro-forma balance sheet entering 2026.

• Business Viability: 7/10 The upstream portfolio is exceptionally durable, characterized by the shallow decline curves inherent to conventional San Andres and Yeso reservoirs compared to unconventional shales. The primary choke point threatening long-term viability is produced water disposal and the associated regulatory risks regarding seismicity in New Mexico. However, management's foresight in countering power infrastructure choke points via the internal RPC Power joint venture acts as a vital mitigant to broader basin unreliability.

• Capital Allocation: 9/10 Management demonstrates premier capital allocation acumen across all phases of the commodity cycle. They routinely harvest non-core assets at premium valuations (e.g., the Targa midstream sale at $111 million upfront plus extensive earnouts for an asset built efficiently in-house). Instead of chasing unprofitable volume growth in a weak oil tape, they prioritize tangible shareholder returns via a 5.6% yielding dividend and an opportunistic $100 million share repurchase program authorized at a cyclical valuation low point.

• Analyst Sentiment: 8/10 Wall Street coverage, though relatively thin due to the company's sub-$1B market capitalization, is highly positive. The consensus rating among covering analysts is a "Strong Buy," with median price targets implying significant upside. Recent estimate revisions for 2025 and 2026 earnings per share have been actively revised upwards by 5.0% and 14.2% respectively, signaling deep institutional confidence in the company's cash flow durability and the rapid success of the recent acquisition integration.

• Profitability: 8/10 The company extracts robust margins from its mature asset base. Operating margins hover around 27%, supported by a remarkably low Lease Operating Expense (LOE) of just $9.03 per Boe. Capital efficiency is excellent, evidenced objectively by the fact that the Silverback acquisition assets were optimized to produce 50% above initial underwriting estimates within just months of closing.

• Track Record: 8/10 Since transitioning to the public markets, management has proven highly capable of compounding intrinsic value. They have successfully navigated severe commodity price cycles, aggressively built and monetized internal infrastructure, and continuously paid and grown a quarterly dividend—distributing 19 consecutive dividends as a public entity—rewarding long-term shareholders with tangible cash returns while simultaneously expanding the proved reserve base.

• Overall Blended Score: 7.7 / 10

RESILIENT BUT LEVERED

7. Conclusion & Investment Thesis

The fundamental macroeconomic and microeconomic outlook for Riley Exploration Permian Inc. presents a highly compelling case of a structurally undervalued, highly efficient upstream operator executing a deeply differentiated strategy. Rather than engaging in the capital-destructive treadmill of hyper-growth shale drilling that characterizes much of the Permian Basin, the company treats its Northwest Shelf assets as long-term, low-decline cash generation engines. By targeting shallow-decline conventional reservoirs, maintaining a rigorous operational focus on cost containment (sub-$10/Boe LOE), and hedging heavily against global price shocks, the company manufactures insulated, highly predictable free cash flow.

The investment thesis hinges on three primary structural catalysts. First, the successful monetization of the Dovetail Midstream assets to Targa not only rapidly de-risks the balance sheet by paying down the credit facility but also ensures absolute flow assurance, allowing unobstructed future development of the Eddy County acreage. Second, the RPC Power joint venture acts as a dual-threat asset: a structural cost advantage and an independent profit center, isolating the company from the notoriously fragile Texas ERCOT grid while turning flared associated gas into high-margin revenue. Third, the potential commercialization of the CO2 EOR pilot in the Champions field offers immense, asymmetric upside to book vast new reserves without heavy drilling capital intensity.

Risks are distinctly tied to macroeconomic oil pricing downturns, regulatory shifts regarding wastewater injection limits in New Mexico, and managing the absolute debt load if interest rates spike. However, backed by a management team with immense insider ownership, a $100 million buyback backstop, and a secure 5.6% dividend yield, the company offers investors a deep margin of safety. The firm is currently undervalued relative to its cash flow generation and infrastructure optionality.

ASYMMETRIC UPSIDE PROFILE

8. Technical Analysis, Price Action & Short-Term Outlook

Riley Exploration Permian shares are currently demonstrating structural bullish momentum within a broader volatile energy tape. The stock is trading at $28.30, which sits comfortably above the critical long-term 200-day simple moving average of $27.51 and the medium-term 50-day moving average of $27.09. The recent price action has absorbed sector-wide volatility effectively, heavily supported by recent institutional buying—including a massive 211% stake increase by Denali Advisors in late 2025—and the psychological floor provided by the active $100 million share repurchase program. With the fourth quarter and full-year 2025 earnings release scheduled for March 4, 2026, where the market highly anticipates positive commentary regarding the Silverback integration and midstream sale deleveraging, the short-term outlook strongly favors continued upward consolidation and trend continuation.

BULLISH TREND INTACT