APA: Value or Value Trap?

• APA Corporation screens as a value opportunity, with exploration upside, but its high leverage and commodity price exposure require a high tolerance for risk.
• APA’s areas of operation include the Permian Basin, Egypt, and the North Sea, with exploration upside in Alaska, Suriname, and Uruguay.
• Key risks include high leverage, unhedged commodity exposure, and dependence on the GranMorgu development in Suriname.
• A base case fair value target of $39.50 per share is derived from a five-year DCF model, with significant valuation variability based on commodity price assumptions.

Introduction

APA Corporation (NASDAQ: APA) screens as a value opportunity in an energy sector that remains out of favor. While my base case valuation for APA implies meaningful upside from current levels, the investment case depends on successful execution of high-impact exploration projects, navigating geopolitical risk, and weathering an uncertain near-term commodity environment. For investors with a higher risk tolerance, APA may offer the potential for asymmetric returns.

Company Overview

Originally founded as Apache Corporation in 1954, APA Corporation operated primarily in the United States for much of its early history before expanding internationally. In 2021, APA was reorganized as a holding company, with Apache becoming a wholly owned subsidiary. Today, APA produces approximately 488,000 BOE/D (barrels of oil equivalent per day), with a production mix of 54% oil, 29% natural gas, and 17% NGLs.

Areas of Operation: Permian, Egypt, and North Sea

APA’s largest asset is in the Permian Basin, which includes approximately 275,000 net acres in the Midland Basin and approximately 203,000 net acres in the Delaware Basin. The 2024 acquisition of Callon Petroleum expanded APA’s Delaware position by approximately 120,000 net acres. In the Midland Basin, APA targets the Wolfcamp and Spraberry formations, while in the Delaware Basin, it focuses on the Bone Spring and Wolfcamp formations.

APA holds a significant onshore position in Egypt’s Western Desert, established through its investment and eventual merger with Phoenix Resources in the mid-1990s. The company consolidated the majority of its acreage position in 2021 through a merged concession agreement with the Government of Egypt and the Egyptian General Petroleum Corporation (EGPC). This agreement extended development lease terms by 20 years and exploration leases by 5 years. APA’s subsidiary in Egypt is jointly owned (two-thirds by APA, one-third by Sinopec). It operates under a production-sharing contract with EGPC, and through this agreement, the contractor is entitled to a 40% cost recovery and a 30% profit-sharing rate. Approximately 67% of APA’s acreage remains undeveloped, offering exploration upside.

APA also maintains a legacy offshore position in the U.K. North Sea that was acquired from Exxon Mobil Corporation (XOM) in 2003. However, as a result of new regulations, tax implications, and operating expenses, the company announced that it will cease all production in the North Sea by 2030.

The following table shows APA’s regional breakdown of production and revenue (%):

Suriname: A Key Driver of Future Growth

Suriname is positioned to be a significant catalyst of future production growth for APA. This field is adjacent to Exxon Mobil’s prolific Stabroek Block in Guyana. APA made the initial discovery in Block 58 in offshore Suriname and entered into a joint venture agreement in which TotalEnergies SE (TTE) became the operator and each company obtained a 50% working interest. The GranMorgu development will have an initial production capacity of 220,000 barrels per day and is targeting the first oil in 2028. APA also holds a working interest in Block 53 in offshore Suriname, where evaluation of the area is ongoing.

Exploration: A Differentiated Strength

Beyond Suriname, APA also has potential exploration upside that sets it apart from many mid-sized peers that are expected to be pressured on reserve additions as U.S. shale continues to mature. In Alaska, APA holds a 50% operated working interest in approximately 163,000 net acres on the North Slope where the company announced a successful discovery at the Sockeye-2 well and subsequent successful well test in early 2025. This discovery could add production upside by the end of the decade, contingent on additional appraisal and a final investment decision. In addition, APA holds a working interest in offshore Uruguay, where it is currently acquiring seismic data ahead of planned exploration drilling.

Financial Commentary

Income Statement:

Given the current commodity price environment and the potential for near-term weakness in oil prices, APA’s corporate breakeven is an important metric to monitor.

The following chart illustrates APA’s corporate-level revenue and full-cycle breakeven costs on a per-BOE basis. The left bar represents corporate revenue, while the right stacked bar shows full-cycle costs, including sustaining costs, development spending, and the base dividend. A line graph shows the annual breakeven trend along with horizontal average lines for both revenue and cost metrics.

Breakeven prices vary by company-realized commodity prices and production mix, so benchmark oil and gas prices are included for context.

Based on historical data, APA appears to be set up to handle the current low-pricing environment with a small amount of contingency. However, the company does not maintain material hedge positions, meaning a further decline in oil prices could pressure its financials.

Balance Sheet

APA ended 2024 with a Net Debt-to-EBITDA (TTM) ratio of 1.9x, above the majority of its peer group. This comparatively higher leverage may be one factor contributing to its discounted valuation. By comparison, peers such as Chord Energy (0.4x), Coterra Energy (0.5x), Civitas Resources (1.2x), Matador Resources (1.4x), Devon Energy (1.1x), and Diamondback Energy (1.6x) all maintain more conservative leverage ratios.

APA recently received an upgrade to BBB- from S&P Global, achieving investment-grade status from all three major credit rating agencies. The company carries approximately $4.8 billion in fixed-rate debt with a weighted average interest rate of 5.34%. Its maturity profile is long-dated, with the majority of obligations due beyond 2030 and a weighted average maturity of approximately 17 years.

Cash Flow

The chart below illustrates APA’s sources and uses of cash flow. The left-stacked bar in each year reflects sources of cash, the right-stacked bar shows uses, and the black line represents free cash flow.

APA has continued to streamline its portfolio through a series of non-core asset divestitures, including the sale of producing properties in the Permian and Eagle Ford, mineral and royalty interests, and its remaining equity stake in Kinetik Holdings.

The company targets returning 60% of free cash flow to shareholders through a combination of dividends and share repurchases. APA pays a quarterly dividend of $0.25 per share and repurchased 9.2 million shares for $246 million in 2024. However, there has been some criticism of the effectiveness of continued buybacks relative to incremental debt reduction, given the persistent decline in APA’s stock price.

Capital expenditures rose in 2024, largely driven by increased drilling activity in the Permian Basin following the Callon acquisition. While the company has guided to lower capital spending in 2025, adjustments may be necessary if commodity prices remain under pressure.

Valuation

Energess Resources has a base case fair value target of $39.50 per share for APA Corporation that was determined using a five-year discounted cash flow (DCF) model. Production in 2025 is assumed to be the guidance value of 396,000 BOE/D and assumes a compound annual growth rate (CAGR) of 5% thereafter.

Production estimates were adjusted to reflect anticipated portfolio changes. North Sea volumes, starting at 27,000 BOE/D in 2025, are assumed to phase out entirely by the beginning of 2029 in line with APA’s planned exit. Suriname production will be introduced in 2028, assuming a ramp-up from 35,010 BOE/D to 67,485 BOE/D in 2029. These volumes represent approximately half of the floating production, storage, and offloading (FPSO) unit nameplate capacity in the first year and reflect full participation by Suriname under its contractual option. These adjustments resulted in 742 million BOE over the five-year period.

Revenue of $40.8 billion was derived using a regression analysis of APA’s historical realized prices against benchmark assumptions of $75/bbl for oil and $4.75/MMBtu for natural gas. Unit operating expenses were based on historically derived values from the table below.

These cost assumptions resulted in total cash operating expenses and income taxes of approximately $25.4 billion. Subtracting these from revenue results in an operating cash flow of $15.4 billion.

Capital expenditures were modeled at 35% of revenue, totaling $14.3 billion over the period, in line with APA’s historic reinvestment rates. Non-cash expenses totaled $11.9 billion and were added back for a free cash flow of $13.0 billion over five years.

These cash flows were discounted to present value using a 10% weighted average cost of capital (WACC), resulting in a present value of approximately $10.1 billion. A terminal value was calculated using a 4.0x EV/EBITDA exit multiple applied to EBITDA (TTM) of $4.5 billion in the final year, resulting in a terminal value of $17.9 billion. Discounting this to present value yielded $10.8 billion.

Summing the discounted five-year cash flows and the terminal value produced an enterprise value (EV) of $20.9 billion. After subtracting $6.3 billion in net debt, the resulting equity value of $14.6 billion equates to a fair value estimate of $39.50 per share, based on an assumed share count of 369.9 million.

To evaluate a broader range of outcomes, a low-case and high-case DCF were also calculated. The combined commodity price assumption for the low case was based on a regression of average benchmark pricing of $2.75/MMBtu (Million British Thermal units) for natural gas and $55/bbl for oil, while the high case regression used average benchmark pricing of $6.00/MMBtu and $90/bbl.

The list below summarizes key assumptions and valuation outcomes under different scenarios (low, base, and high cases). Energess Resources anticipates that the base case is the most likely outcome, while the low and high cases illustrate the potential valuation variability if commodity prices average either extreme over the forecast period.

Risks

E&P revenues are highly sensitive to commodity prices. This risk is elevated for APA, who had no material hedging as of the end of 2024.

The company also faces geopolitical risks due to its international operations. In Egypt, the company’s receivables balance from the EGPC has gradually increased, and a deterioration in economic conditions could lead to a risk of non-payment.

Regulatory risk is another consideration that can lead to increased costs or an interruption in operations. Hydraulic fracturing poses regulatory risks, but there are also risks associated with water usage rights, waste disposal restrictions, and seismicity.

Additionally, a significant portion of APA’s future production growth is expected to come from its non-operated interest in Suriname, where TotalEnergies is the operator.

Conclusion

APA Corporation presents a compelling case for value investors with a high tolerance for risk. With a base case fair value of $39.50 per share, APA offers significant upside from its current price. Unlike many of its mid-size peers that rely heavily on maturing U.S. shale basins, APA is differentiated by its exposure to high-impact exploration projects. However, its elevated leverage, unhedged commodity exposure, and geopolitical risks will require careful monitoring.