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The greatest opportunity lies in the commercial acceleration of the Utica shale oil play and Dorado natural gas field alongside expanding Gulf Coast LNG export feed-gas demand,.
WTI crude oil benchmark price falling and remaining below $55.00 per barrel, breaching management's three-year corporate planning range of $60.00 to $80.00 per barrel.
We rate EOG Resources Inc. as a Buy, reflecting an 18.82% upside from the report-date price of $140.35 on September 25, 2026 to our Fair value estimate of $166.77 per share,.3
We rate EOG Resources Inc. as a Buy. For an ordinary investor, this means the stock offers an attractive risk-adjusted opportunity to gain exposure to high-quality domestic energy assets at a favorable valuation discount.
The report was prepared at a price of $140.35 on September 25, 2026. This price represents an 18.82% upside to our Fair value estimate of $166.77 per share. It also trades at a substantial discount to our Potential value estimate of $284.99 per share.3
The primary risk to this thesis is a severe downturn in benchmark crude oil prices below management's planning threshold of $55.00 per barrel. If global oil demand softens or supply expands rapidly, realized prices would drop, compressing operating margins below 25.0% compared with 28.21% in 2025. An investor would see this risk materializing through sequential quarterly revenue declines, lower operating cash flows, and a slowdown in share repurchases under the company's capital return framework.45
The primary driver of upside is EOG's structural cost advantage across premier North American shale plays. By maintaining direct well completion costs under $700 per lateral foot and applying proprietary subsurface technology, EOG targets 14% total volume growth in 2026. This low break-even cost structure generates more than $10.0 billion in operating cash flow, funding steady share count reductions and lifting per-share value toward our Fair value of $166.77, with long-term Potential value reaching $284.99 as Utica and Dorado developments scale,.3456
EOG maintains direct well completion costs under $700 per lateral foot through self-sourced sand, high-spec rigs, and proprietary subsurface analytics, enabling sustainable economic returns across commodity cycles,.4
United States operations generate 98.4% of consolidated revenue ($22.27 billion in 2025), while dedicated infrastructure like the Verde pipeline captures a $0.50/Mcf netback uplift and insulates volumes from regional takeaway bottlenecks.46
With $3.40 billion in cash against $8.41 billion in total debt, EOG combines a 28-year unbroken dividend record with an active buyback program reducing shares outstanding to 524.5 million.3
We rate EOG Resources as a Buy because its low-cost premium drilling inventory and disciplined capital allocation generate superior cash returns and substantial per-share value accretion above the report-date market price,.5
EOG is focused on being among the highest return and lowest cost producers, committed to strong environmental performance and playing a significant role in the long-term future of energy. EOG operates under a consistent business and operational strategy that focuses on a comprehensive approach to developing acreage through industry cycles.
EOG evaluates rate of return, net present value, margins, payback period and other key metrics. As a consequence, the company may be at a competitive disadvantage in certain respects, such as in bidding for drilling rights or in accessing and retaining necessary services, facilities, equipment, materials and personnel.
Under a severe macroeconomic and hydrocarbon downturn, benchmark crude oil prices drop below management's $60 to $80/bbl WTI planning band to breach the $55/bbl threshold, inducing severe revenue contraction well past consensus expectations of -7.30% in FY2027. Operating EBIT margins compress below 25.0% as fixed operational costs and elevated FY2026 guided capex of $6.5B confront depressed realized prices. In this environment, annual free cash flow shrinks toward $2.0B, forcing management to curtail share buybacks under its 70% free cash flow return framework. However, EOG's strong liquidity cushion of $3.40B in liquid cash against $8.41B in total debt ensures complete debt serviceability without restructuring distress, grounding enterprise valuation near the downside anchor of $91.21.
EOG Resources possesses a narrow economic moat rooted in its structural cost advantages across tier-one North American shale basins and proprietary midstream connectivity. Unlike pure-play exploration peers that rely on purchased acreage and third-party engineering studies, EOG utilizes in-house subsurface geological intelligence and proprietary drilling technology to identify and capture high-return sweet spots before competitors inflate land values. This organic exploration strategy ensures that drilling locations satisfy strict hurdle rates of at least a 30% direct after-tax return under conservative commodity pricing assumptions ($40 oil / $2.50 gas), anchoring structural operational profitability.
The company's cost moat is reinforced by continuous operational innovations and significant domestic operational scale. Year-to-date direct well costs have declined by 7% year-over-year to less than $700 per lateral foot, driven by self-sourced frac sand, dedicated water recycling networks, and high-rate fracture fleets. Furthermore, countercyclical midstream investments, notably the Verde gas pipeline connecting South Texas gas plays to the Gulf Coast industrial corridor, generate an ongoing netback premium of $0.50 per Mcf. This midstream integration secures premium pricing points and insulates corporate realizations against regional basin egress bottlenecks.
A wide moat rating is precluded by the commodity-sensitive nature of upstream exploration and production. Because oil and natural gas are unhedged, fungible global commodities with zero customer switching costs, realized operating earnings fluctuate directly with international pricing benchmarks. This cyclical is demonstrated by FY2025 compressing to $6.39B from $8.08B in FY2024, alongside the plateauing of Delaware Basin oil output. Nevertheless, EOG's superior cost curve positioning, balance sheet liquidity ($3.40B cash), and organic reserve additions support an economic return profile that sustains a robust Narrow moat rating.
None of the valuation methods used to calculate Fair value relies on a separate assumption about how long the competitive advantage lasts.
The highlighted cell is Fair value when every assumption sits at its base level ($166.77). Each row and column shows what Fair value becomes when one assumption moves.
Free cash flow to the firm stays positive in the first projected year at $7.0B after modeled reinvestment of $1.8B, with terminal value at 76.9% of enterprise value. A sudden drop in free cash flow is not projected unless capital spending relative to , reinvestment, or resets materially.
An operational beat driven by organic inventory outperformance validates structural cost advantages, prompting an upgrade recommendation toward $284.99.
Results meeting baseline expectations confirm steady execution along the approved forecast schedule, maintaining our house rating and pathway toward $166.77.
The upstream exploration and production sector maintains moderate reinvestment discipline, characterized by an industry capex-to-revenue benchmark of 19.10% and an industry capex-to-depreciation ratio of 1.57x. EOG's FY2025 capex of $6.12B on revenue of $22.63B reflects a 27.02% capital reinvestment intensity, expanding to guided FY2026 capex of $6.50B to support organic growth in the Utica and Dorado plays without excessive debt accumulation.345
In an upstream expansionary cycle, robust global energy demand, expanding US liquefied natural gas export capacity, and persistent capital discipline among major producers support strong hydrocarbon realizations. EOG benefits from volume expansion toward consensus FY2026 revenue of $30.19B, guided by 14% total production volume growth. expand toward 37%, accelerating generation and funding enhanced share repurchases and regular dividend increases.
High-grade cyclical profile with structural cost advantages, peer-leading balance sheet liquidity ($3.40B cash), and 18.82% upside to Fair value of $166.77, balanced against macro commodity price volatility that warrants prudent exposure limits.5
Manage position risk by strictly capping portfolio allocation within the 4-6% recommended target band. Maintain awareness of global macroeconomic indicators, crude supply dynamics, and storage reports. EOG's strong liquidity cushion of $3.40B in liquid cash and total debt of $8.41B provides significant downside defense, ensuring dividend durability and capital flexibility throughout cyclical contractions.
Trading at $140.35 on September 25, 2026, the stock offers an 18.82% upside to our Fair value estimate of $166.77,. EOG's low-cost inventory, sub-$700/ft direct completion costs, and cash generation provide strong fundamental downside support.34
EOG supports an unbroken 28-year dividend track record backed by a formal commitment to return at least 70% of annual free cash flow through regular dividends and share repurchases. Pristine liquidity ($3.40B in cash) protects distributions across commodity dips.45
With forward consensus EPS reaching $17.01 in FY2026 and $14.91 in FY2027, EOG offers attractive cyclical torque to firm energy prices, guided 14% production growth, and potential long-term upside toward $284.99.
We recommend initiating or adding to positions in EOG Resources Inc. at the report-date price of $140.35 on September 25, 2026, targeting our Fair value estimate of $166.77 per share,. EOG's structural cost advantage, with direct completion costs under $700 per lateral foot and 14% guided production growth in 2026, provides high-quality exposure to North American upstream energy with strong return on capital.34
Capital discipline remains peer-leading, characterized by modest debt ($8.41 billion against $3.40 billion in cash,) and an ongoing commitment to return at least 70% of free cash flow to shareholders. This disciplined capital allocation shields equity value against severe cyclical drawdowns while driving per-share compounding through steady share retirements.
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The records this analysis drew on, as they stood when it was run.
The downside scenario reflects a severe commodity downcycle where benchmark crude and natural gas prices drop below corporate planning thresholds. Lower realized prices compress operating margins, restrict operating cash flows, and force reductions in discretionary shareholder capital returns while slowing drilling activity. This scenario would be disconfirmed by sustained global energy demand stability and disciplined supply management, verifiable through monthly global inventory and storage reports.
Reported operating margin compressed from 34.10% in FY2024 to 28.21% in FY2025, while gross margin deteriorated from 68.34% to 63.38%. FY2026 capex guidance expands to $6.5B while Delaware oil production is flat to decreasing. An operating margin below 25.0% realizes the operating_margin_minus_6pp replay shock, cutting enterprise DCF fair value by over 20%.45
The valuation model relies on a low computed Ke of 7.3821% based on a subdued adjusted beta of 0.5319. In contrast, sector beta is 0.7214 and industry beta is 0.72. Normalizing the cost of equity above 9.0% triggers the discount_rate_plus_2pp library shock, reducing discounted earnings fair value by 28.6% and FCFF DCF by 29.0%.2
The five developments that would weaken our investment case.
Operating margin dropping below 25.0% indicates that service cost inflation or well productivity depletion in mature basins is overwhelming price realizations, compressing operating income and cutting enterprise DCF fair value by over 20%.
Current:28.21% (FY2025)
Alert ifBelow 25.0%
Crude pricing breaching the $55.00/bbl floor compromises management's three-year planning assumptions, accelerating revenue contraction beyond consensus expectations of -7.30% in FY2027 and collapsing forward earnings toward the $33.06 low case.
Current:$60.00 - $80.00/bbl management planning range
Alert ifBelow $55.00/bbl
Capex exceeding $7.20B without production growth exceeding guided 14% signals capital intensity creep and plateauing well performance in the Delaware Basin, curtailing free cash flow.
Current:$6.50B guided for FY2026 (FY2025: $6.12B)
Alert ifAbove $7.20B without volume expansion above 14%
Direct well completion costs exceeding $750 per lateral foot indicates that operational efficiencies and self-sourced sand advantages are eroding against oilfield service inflation, compressing capital productivity and narrowing unit margins.
Current:Less than $700 per foot (H1 2026)
Alert ifAbove $750 per foot
EOG generates durable economic profit across commodity cycles, delivering a return on invested capital of 15.85% (and 16.46% trailing), comfortably exceeding its moderate cost of equity of 7.3821% and corporate WACC of 7.0929%. Even as FY2025 operating income compressed to $6.39B from $8.08B in FY2024 due to commodity price fluctuations, EOG generated $10.04B in operating cash flow and funded $6.12B in capital expenditures, generating $3.93B in free cash flow and maintaining a substantial spread over cost of capital.235
Each lens answers a different valuation question. Only included lenses set Fair value; floors and diagnostics provide context.
Project SBC-adjusted EPS, discount each year's earnings at cost of equity, then add a Gordon-growth terminal value.
Under the moderate discount rate, $106 comes from forecast-period earnings and $162 from the long-term value, totaling $269.
Apply a terminal P/E to the dated forward EPS path, then discount that future share value back to the analysis date.
Convert the revenue and margin path into after-tax free cash flow, discount the annual per-share amounts and at , then adjust for signed per current share.
Add depreciation to net income, subtract maintenance capex, divide by diluted shares, and apply a normalized valuation multiple.
Solve for the growth rate that makes the model value equal the report-date share price.
Under the Base scenario, the target reaches $166.77 representing a probability of 50.0% and an expected return of 18.8% from $140.35. This path is anchored on EOG delivering steady low single-digit volume expansion led by Utica development while Delaware Basin production holds stable. Operating margins remain normalized, supported by structural well cost discipline and countercyclical pipeline netback advantages. The path would be disconfirmed if realized hydrocarbon prices experience extended downturns or if unit development costs rise sharply, observable in upcoming quarterly filings.
Under the Bull scenario, the target reaches $284.99 with an estimated probability of 25.0% and an expected return of 103.1% relative to $140.35, aligning toward $284.99. This path materializes if Utica liquids production outperforms initial development targets and Dorado natural gas volumes capture growing Gulf Coast LNG demand premiums. Favorable commodity realizations expand operating margins and accelerate free cash flow generation, driving aggressive share count retirement. This case would be disconfirmed by takeaway bottlenecks or diminishing well productivity across new drilling benches, detectable through semi-annual production reports.
A fundamental miss indicating well productivity depletion or uncontrollable cost inflation would impair normalized operating earnings power, requiring a downgrade to preserve capital.
Earnings quality is exceptionally high, underpinned by clean GAAP operating cash flows that consistently exceed reported net income. Cash conversion remains robust with minimal working capital friction and no reliance on aggressive accounting accruals or non-operating gains. Low interest expense burden and conservative capitalization ensure reported operating profits translate directly into distributable surplus cash.
Tracking lateral foot completion costs reveals whether operational efficiencies and self-sourced materials continue to outpace oilfield service inflation, directly determining operating margin durability and returns on invested capital.
Midstream transportation netbacks reflect EOG's ability to bypass regional takeaway bottlenecks and capture premium Gulf Coast pricing, protecting cash flows from localized basis discounts.
Monitoring capital expenditure against guided ranges reveals whether reserve additions require escalating capital intensity, directly impacting free cash flow conversion.
Capital distribution adherence indicates management's commitment to returning excess cash via dividends and share buybacks rather than pursuing expensive corporate acquisitions.
Volume and product mix trends show whether high-margin oil expansion in the Utica offsets mature basin plateaus, driving top-line revenue and operating leverage.
| $18.64B |
| $25.70B |
| $24.19B |
| $23.70B |
| $22.63B |
| +5.0% |
| Gross profit | $14.32B | $24.62B | $18.24B | $17.70B | $15.37B | +1.8% |
| Operating income | $6.10B | $9.97B | $9.60B | $8.08B | $6.39B | +1.1% |
| Net income | $4.66B | $7.76B | $7.59B | $6.40B | $4.98B | +1.7% |
| EPS (diluted) | $7.99 | $13.22 | $13.00 | $11.25 | $9.12 | +3.4% |
| EBITDA | $9.76B | $13.62B | $13.33B | $12.46B | $11.30B | +3.7% |
| R&D | $154.0M | — | — | — | — | — |
| SG&A | $511.0M | $570.0M | $640.0M | $669.0M | $861.9M | +14.0% |
Cash flow generation is structurally robust. In FY2025, operating cash flow reached $10.04B, fully funding capital expenditures of $6.12B and generating $3.93B in free cash flow (following $5.77B generated in FY2024). Capital reinvestment rate is modeled at 20.0% of NOPAT in FY2026 and 19.0% in FY2027, supporting guided FY2026 capex of $6.50B while maintaining high cash conversion. Maintenance capex is estimated at 72.0% of total capex ($4.40B), closely matching annual depreciation of $4.46B, ensuring that organic reserve replenishment does not impair free cash flow conversion.3457
EOG maintains a disciplined, shareholder-aligned capital allocation framework funded entirely by organic cash flows. In Q2 2026 alone, the company returned $540M via regular dividends and $1.30B through share buybacks. The regular dividend has remained unbroken and unreduced for 28 consecutive years, serving as the cornerstone of shareholder distributions alongside an active share repurchase program supported by $11.7B in remaining authorization. Share count has retired steadily to 524,529,000 shares from 546M in FY2025 and 587M in FY2022. Total debt stood at $8.41B in FY2025 ($8.25B currently) against $3.40B in cash, sustaining a conservative debt weight of 9.94% that preserves maximum balance sheet strength.
EOG's return on invested capital remains structurally resilient at 15.85% (and 16.46% trailing), driven by disciplined capital allocation targeting drilling locations that provide >=30% direct after-tax return under conservative pricing thresholds ($40 oil / $2.50 gas). Although commodity price softness reduced operating income to $6.39B in FY2025 compared to FY2024 peak levels of $8.08B, capital discipline keeps economic returns stable near mid-cycle expectations.
EOG's ROIC of 15.85% significantly exceeds its corporate WACC of 7.0929% and moderate cost of equity of 7.3821% by over 850 basis points, affirming substantial economic value creation throughout commodity cycles.
EOG posted an operating margin of 28.21% in FY2025, exceeding the upstream industry benchmark of 25.80%, supported by direct well costs under $700 per foot.
Sub-industry cost structures protect corporate cash generation during commodity downturns, keeping cash flows positive across cyclical price contractions.
Management guides 14% total production growth in FY2026, driven predominantly by the Utica Encino development while Delaware Basin oil output plateaus.
Low-cost organic delineation in newer basins mitigates basinal exhaustion in legacy assets without requiring debt-heavy corporate M&A.
The Verde pipeline investment continues to deliver an ongoing netback uplift of $0.50 per Mcf on South Texas natural gas volumes.
Strategic midstream egress insulates realized gas revenue from localized basin price discounts, enhancing overall corporate netbacks.
| Revenue | $8,620,000,000 |
|---|---|
| Cost of revenue | $3,134,000,000 |
| Gross profit | $5,486,000,000 |
| Operating expenses | $1,958,000,000 |
| Operating income | $3,528,000,000 |
| Non-operating items and tax | -$804,000,000 |
| Net income | $2,724,000,000 |
| Total assets | $51,799,000,000 |
|---|---|
| Cash | $3,396,000,000 |
| Current assets | $7,656,000,000 |
| Total liabilities | $21,966,000,000 |
| Current liabilities | $4,691,000,000 |
| Shareholders’ equity | $29,833,000,000 |
| Net income | $4,980,000,000 |
|---|---|
| Operating inflow | $10,044,000,000 |
| Depreciation and amortization | $4,461,000,000 |
| Stock-based compensation | $216,000,000 |
| Other operating adjustments | $387,000,000 |
| Operating cash flow | $10,044,000,000 |
| Cash available | $17,136,000,000 |
| Beginning cash | $7,092,000,000 |
| Investing outflow | $10,936,000,000 |
| Capex | $6,115,000,000 |
| Other investing activities | $4,821,000,000 |
| Financing outflow | $2,804,000,000 |
| Net debt issuance | $1,923,000,000 |
| Share repurchases | $2,564,000,000 |
| Dividends paid | $2,161,000,000 |
| Other financing activities | $2,000,000 |
| Ending cash | $3,396,000,000 |
| Investing cash flow | -$10,936,000,000 |
| Financing cash flow | -$2,804,000,000 |
Source: SEC EDGAR · Filed 2026-02-24 · SEC EDGAR
| Revenue by operating segment | Revenue | Share | YoY |
|---|---|---|---|
| United States Of America | $22.3B | 98.4% | -4.8% |
| Trinidad | $359M | 1.6% | 15.4% |
| Other International | $4M | 0% | — |
Point-in-time financial data used in the 2026-09-27 analysis.
| Period | Revenue | EBITDA | Net income | Operating cash flow | Free cash flow | Capex | Depreciation and amortization | Stock-based compensation | Share repurchases | Dividends paid | Net debt issuance | Investing cash flow | Financing cash flow | Beginning cash | Ending cash | Cash and investments | Total debt | Operating margin | ROIC | WACC | ROIC − WACC spread |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 2016-12-31 | $7.7B | $2.3B | -$1.1B | $2.4B | -$223.7M | $2.6B | $3.6B | $128.1M | $82.1M | $372.8M | — | -$1.3B | -$242.7M | — | $1.6B | $1.6B | $7B | -16.0% | — | — | — |
| 2017-12-31 | $11.2B | $4.3B | $2.6B | $4.3B | $141.1M | $4.1B | $3.4B | $133.8M | $63.4M | $386.5M | — | -$4B | -$1B | $1.6B | $834.2M | $841.9M | $6.4B | 8.3% | — | 5.4% | — |
| 2018-12-31 | $17.3B | $7.9B | $3.4B | $7.8B | $1.7B | $6.1B | $3.4B | $155.3M | $63.5M | $438M | — | -$6.2B | -$839.1M | $834.2M | $1.6B | $1.6B | $6.1B | 25.9% | — | 6.0% | — |
| 2019-12-31 | $17.4B | $7.5B | $2.7B | $8.2B | $1.7B | $6.4B | $3.8B | $175M | $25M | $588.2M | — | -$6.2B | -$1.5B | $1.6B | $2B | $2B | $5.5B | 21.3% | — | 5.4% | — |
| 2020-12-31 | $11B | $2.9B | -$605M | $5B | $1.5B | $3.5B | $3.4B | $146M | $16M | $820.8M | — | -$3.3B | -$359M | $2B | $3.3B | $3.4B | $6.8B | -4.9% | — | — | — |
| 2021-12-31 | $18.6B | $9.8B | $4.7B | $8.8B | $4.9B | $3.9B | $3.7B | $152M | $41M | $2.7B | — | -$3.4B | -$3.5B | $3.3B | $5.2B | $5.2B | $5.9B | 32.7% | — | 6.1% | — |
| 2022-12-31 | $25.7B | $13.6B | $7.8B | $11.1B | $10.1B | $1B | $3.5B | $133M | $118M | $1.4B | -$35M | -$5.1B | -$5.3B | $5.2B | $6B | $6B | $6B | 38.8% | — | 7.8% | — |
| 2023-12-31 | $24.2B | $13.3B | $7.6B | $11.3B | $5.2B | $6.2B | $3.5B | $177M | $1B | $3.4B | -$1.3B | -$6.3B | -$5.7B | $6B | $5.3B | $5.3B | $4.2B | 39.7% | — | 7.6% | — |
| 2024-12-31 | $23.7B | $12.5B | $6.4B | $12.1B | $5.8B | $6.4B | $4.1B | $199M | $3.2B | $2.1B | $952M | -$6B | -$4.4B | $5.3B | $7.1B | $7.1B | $5.1B | 34.1% | — | 8.0% | — |
| 2025-12-31 | $22.6B | $11.3B | $5B | $10B | $3.9B | $6.1B | $4.5B | $216M | $2.6B | $2.2B | $1.9B | -$10.9B | -$2.8B | $7.1B | $3.4B | $3.4B | $8.4B | 28.2% | — | 5.6% | — |
EOG Resources Inc. (EOG) trades at 10.1x forward earnings against a peer median of 11.6x. Its EV/EBITDA of 5.3x compares with a peer median of 5.8x. The comparison uses 4 peers: Diamondback Energy Inc., ConocoPhillips, APA Corporation and Occidental Petroleum Corporation, as of 2026-09-27.
In a cyclical downswing, global macroeconomic deceleration, rising non-OPEC supply, or quota non-compliance depress global crude benchmark prices below $55/bbl. Realized commodity prices decline sharply, driving revenue contraction toward the consensus FY2027 estimate of $27.98B (-7.30% year-over-year) and squeezing upstream operating margins toward cyclical troughs. Capital expenditures are reduced across the sector, slowing reserve replacement and forcing operators to curtail discretionary share repurchases.
EOG is positioned in the premier tier of North American independent E&P companies, characterized by structural cost leadership and superior balance sheet liquidity. EOG's FY2025 operating margin of 28.21% outperforms the broader industry benchmark of 25.80%. Furthermore, EOG's conservative capital structure—evidenced by a modest debt weight of 9.94% and $3.40B in cash against total debt of $8.41B —contrasts sharply with debt-laden peers such as Occidental Petroleum and APA Corporation, providing strong countercyclical flexibility.235
| Why |
|---|
| $135.00 - $140.35 | Initial Position Establishment (Accumulate) | The September 25, 2026 price of $140.35 provides a 15.84% discount to Fair value ($166.77), offering an attractive entry point for high-grade cyclical exposure. |
| $120.00 - $125.00 | Secondary Tranche Accumulation | Cyclical pullback into this band increases margin of safety, lowering valuation to under 8.5x FY2027 consensus EPS ($14.91). |
| Below $110.00 | Opportunistic Value Addition | Approaching cyclical support and owner earnings baseline of $96.05, where dividend yield and buyback accretion accelerate. |
Not every cited input appears here: internal calculations and intermediate model outputs have no external record, and some citations could not be matched to one.
Alert ifAbove 1.50x
| ConocoPhillips |
| $152.9B |
| 13.2x |
| 2.4x |
| 6.3x |
| 14.2% |
| 31.5% |
| APA | APA Corporation | $15.0B | 9.6x | 1.7x | 3.4x | 26.7% | 56.3% |
| OXY | Occidental Petroleum Corporation | $56.8B | 14.1x | 2.4x | 5.6x | 10.6% | 45.4% |
