# EOG Resources (EOG) Financial Model

Free Excel 3-statement financial model and company analysis for EOG Resources.

- Canonical: https://finamodel.com/companies/eog-resources
- Industry: Oil and Gas
- Downloadable model: Yes
- Excel download: https://finamodel.com/company-models/EOG.xlsx

## Model Purpose

This model provides a comprehensive equity valuation and free cash flow forecast to determine whether EOG Resources' premium drilling strategy, strict capital discipline, and recent $4.48 billion acquisition of Encino Acquisition Partners justify its current market valuation.

## Company Overview

EOG Resources is one of the largest independent crude oil and natural gas exploration and production (E&P) companies in the United States. The company focuses on high-return, low-cost wells across multiple basins, primarily the Delaware Basin, Eagle Ford, and Bakken, while expanding into the Utica shale and international offshore plays.

- **Business segments:** United States (approx. 97% of revenue), Trinidad (approx. 2%), Other International (approx. 1%).
- **Key geographies:** United States (Texas, New Mexico, North Dakota, Ohio), Trinidad and Tobago, with exploration in Bahrain and the UAE.
- **Business model type:** Asset-heavy, depletion-based E&P operating under the successful efforts method of accounting.
- **Competitive position:** EOG is the leading oil producer and acreage holder in the Delaware Basin. It is renowned for its "Premium" drilling strategy, which targets a 30% direct after-tax rate of return at flat $40/Bbl oil and $2.50/Mcf natural gas.
- **Recent major events:** On 1 August 2025, EOG closed the $4.48 billion cash acquisition of Encino Acquisition Partners, expanding its footprint in the Utica basin. The company issued $3.47 billion in new senior notes to fund the transaction and retire Encino's existing debt.

## Revenue Deep Dive

EOG reports revenue primarily by commodity type rather than geographic segment.

- **Crude Oil and Condensate**
  - **Revenue driver formula:** `Crude Oil Volume (MBbld) x Days in Period x Realized Price ($/Bbl)`
  - **Historical growth rate:** 3-5% CAGR in volumes.
  - **Key growth levers and headwinds:** Delaware Basin well performance, rig count, WTI price fluctuations, and OPEC+ supply decisions.
  - **Pricing dynamics:** Spot pricing based on WTI Cushing plus/minus regional gathering and quality differentials.
  - **Seasonality:** Minimal volume seasonality, though winter weather can occasionally freeze off production in northern basins.

- **Natural Gas Liquids (NGLs)**
  - **Revenue driver formula:** `NGL Volume (MBbld) x Days in Period x Realized Price ($/Bbl)`
  - **Historical growth rate:** 5-8% CAGR (growing faster than crude due to associated gas in the Permian).
  - **Pricing dynamics:** Priced as a basket of liquids (ethane, propane, butane); typically correlates with crude oil but trades at a significant discount (historically $20-$25/Bbl realized).

- **Natural Gas**
  - **Revenue driver formula:** `Natural Gas Volume (MMcfd) x Days in Period x Realized Price ($/Mcf)`
  - **Historical growth rate:** 10-15% CAGR (boosted by the Dorado play and Utica acquisition).
  - **Pricing dynamics:** Based on Henry Hub plus/minus regional differentials. EOG has exposure to premium LNG markets which improves realized prices.

- **Gathering, Processing and Marketing**
  - **Revenue driver formula:** `Third-party volumes processed/marketed x Fee rate`
  - **Notes:** Primarily a margin business to optimize EOG's own production flow; revenues are largely offset by corresponding marketing costs.

## Cost Structure



### Variable Costs / COGS (Operating Expenses)

- **Lease and Well (LOE):** The direct cost of operating producing wells. Typically runs $3.50 to $4.50 per Boe. Scales directly with production volumes.
- **Gathering, Processing and Transportation (GP&T):** Effective 1 January 2024, EOG combined transportation and gathering into one line item. Typically runs $3.00 to $3.50 per Boe.
- **Production and Ad Valorem Taxes:** Severance taxes paid to states (e.g., Texas, New Mexico). Modeled as a strict percentage of wellhead revenue (typically 6.5% to 7.5%).
- **Purchases of Commodities:** Costs associated with the Gathering, Processing and Marketing revenue line.

### Operating Expenses

- **Depreciation, Depletion and Amortisation (DD&A):** The largest non-cash expense, driven by the depletion of oil and gas properties. Typically runs $10.00 to $11.00 per Boe.
- **General and Administrative (G&A):** Corporate overhead. Highly efficient, typically running $1.50 to $1.80 per Boe.
- **Exploration and Dry Hole Costs:** Costs of unproved leases and unsuccessful exploratory wells. Averages $150 million to $250 million per year.

### Margin Profile

- **Cash Operating Margin:** EOG focuses on cash operating costs (LOE + GP&T + G&A), which run approximately $10.00 to $10.50 per Boe.
- **EBITDA Margin:** Highly volatile depending on commodity prices, but typically ranges from 50% to 65%.
- **Net Margin:** Typically 20% to 30% in mid-cycle pricing environments.

## Balance Sheet Structure

- **Total assets:** Approximately $46 billion to $48 billion.
- **Key asset categories:** Oil and Gas Properties (Successful Efforts Method) make up over 80% of total assets.
- **Working capital profile:**
  - **DSO:** 30-45 days (receivables from oil purchasers).
  - **DPO:** 45-60 days (payables to service companies).
  - **Net working capital:** Typically negative, providing a slight source of cash as the company grows. EOG does not require significant working capital to fund growth.
- **PP&E:** Dominated by proved and unproved leasehold costs, well equipment, and gathering infrastructure. Useful life is tied to the proved reserves life index (unit-of-production method).

## Capital Expenditure & Investment

- **Capex as % of revenue:** 25% to 35% (highly dependent on the denominator/commodity prices).
- **Absolute Capex:** $6.3 billion to $6.7 billion guided for 2026.
- **Maintenance vs. Growth:** Approximately 70% maintenance (to hold production flat) and 30% growth.
- **M&A pattern:** Historically an organic grower, but the 2025 Encino acquisition ($4.48 billion) marks a strategic shift to acquire tier-1 inventory in the Utica shale.

## Debt & Capital Structure

- **Total debt:** Approximately $7.66 billion following the Encino acquisition.
- **Cash and equivalents:** Approximately $3.53 billion.
- **Net debt:** Approximately $4.1 billion (EOG frequently operates with near-zero or negative net debt prior to major acquisitions).
- **Key debt instruments:** Unsecured senior notes. EOG issued $3.47 billion in new notes in 2025 to fund the Encino deal.
- **Revolving credit facility:** Undrawn, used for liquidity backup.
- **Share repurchase programme:** Highly active. Repurchased $2.5 billion (21.7 million shares) in 2025.
- **Dividend policy:** $1.02 per quarter ($4.08 annualized), representing a sustainable base dividend that EOG has never cut in 28 years.

## Cash Flow Characteristics

- **Operating cash flow (OCF):** $10.0 billion to $11.0 billion annually.
- **Free cash flow (FCF):** $4.5 billion to $4.7 billion annually.
- **FCF payout ratio:** EOG targets returning 70% to 100% of FCF to shareholders via base dividends and buybacks.
- **Major non-cash items:** DD&A is the primary bridge between Net Income and OCF, often adding back $4.5 billion to $5.0 billion annually.
- **Cash tax rate:** Effective tax rate is typically 21% to 22%. Cash taxes closely mirror GAAP taxes due to the exhaustion of historical NOLs.

## Sheet Structure

1. **Assumptions**: Hardcoded drivers for macro pricing (WTI, Henry Hub), differentials, production volumes by commodity, and unit costs ($/Boe).
2. **Production & Pricing**: Calculates daily volumes (MBbld, MMcfd), converts to total MBoed, applies realized pricing, and calculates total hydrocarbon revenues.
3. **Income Statement**: Revenue lines driven by the Production sheet. Operating expenses calculated using $/Boe metrics. Includes the 2024 GP&T consolidation.
4. **Balance Sheet**: Driven by PP&E schedules. Oil & Gas properties depleted via DD&A. Debt balances linked to the Debt Schedule.
5. **Cash Flow Statement**: Standard indirect method. Net income plus DD&A, deferred taxes, and working capital changes. Capex deducted in investing activities.
6. **Debt & Interest**: Tranches of senior notes, including the $3.47 billion issued in 2025. Calculates interest expense and tracks the undrawn revolver.
7. **Returns & Valuation**: DCF using unlevered free cash flow, NAV (Net Asset Value) based on reserve life, and a dividend/buyback tracking schedule.

## Key Financial Relationships

1. `Total Production (MBoed) = Crude Oil (MBbld) + NGLs (MBbld) + (Natural Gas (MMcfd) / 6)`
2. `Crude Oil Revenue = Crude Oil Volume (MBbld) x 1,000 x Days in Period x Realized Crude Price ($/Bbl)`
3. `Natural Gas Revenue = Natural Gas Volume (MMcfd) x 1,000 x Days in Period x Realized Gas Price ($/Mcf)`
4. `Realized Crude Price ($/Bbl) = WTI Benchmark Price + EOG Specific Differential`
5. `Lease and Well (LOE) Expense = Total Production (MBoed) x 1,000 x Days in Period x LOE Rate ($/Boe)`
6. `Gathering, Processing and Transportation (GP&T) Expense = Total Production (MBoed) x 1,000 x Days in Period x GP&T Rate ($/Boe)`
7. `Production and Ad Valorem Taxes = (Crude Revenue + NGL Revenue + Natural Gas Revenue) x Production Tax Rate (%)`
8. `DD&A Expense = Total Production (MBoed) x 1,000 x Days in Period x DD&A Rate ($/Boe)`
9. `Free Cash Flow = Cash from Operations - Capital Expenditures`
10. `Shareholder Returns = Common Dividends Paid + Share Repurchases`

## Cross-Sheet Dependencies

- **Assumptions** feeds **Production & Pricing** (volumes, macro prices, differentials).
- **Production & Pricing** feeds the **Income Statement** (Revenues) and acts as the volume multiplier for unit costs (LOE, GP&T, DD&A).
- **Income Statement** feeds the **Cash Flow Statement** (Net Income, Deferred Taxes) and **Balance Sheet** (Retained Earnings).
- **Cash Flow Statement** feeds the **Balance Sheet** (Cash balance) and **Debt & Interest** (Revolver draw/paydown if cash is negative).
- **Debt & Interest** feeds the **Income Statement** (Interest Expense), creating a potential circularity if interest expense drives net income, which drives cash flow, which drives debt balances. A circuit breaker toggle must be included.

## Sign Convention

- **Income Statement:** Revenues are positive. Expenses (LOE, GP&T, DD&A, Taxes) are negative.
- **Balance Sheet:** Assets are positive. Liabilities and Equity are positive.
- **Cash Flow Statement:** Net Income is positive. Non-cash add-backs (DD&A) are positive. Cash outflows (Capex, Dividends, Buybacks) are negative. Increases in assets (use of cash) are negative; increases in liabilities (source of cash) are positive.

## Things Most Likely to Go Wrong

1. "Failing to divide Natural Gas MMcfd by 6 when calculating total MBoed; this will massively overstate total equivalent production."
2. "Ignoring the 1 January 2024 accounting change where EOG combined Transportation Costs and Gathering/Processing into a single GP&T line; historical data must be pro-forma adjusted to match."
3. "Applying the production tax rate to total revenue instead of wellhead hydrocarbon revenue (excluding marketing/midstream revenue)."
4. "Missing the stub-period impact of the Encino acquisition in Q3/Q4 2025; production jumps artificially in August 2025 and must be modelled as a step-function, not organic growth."
5. "Overestimating realized natural gas prices; EOG's realized price is typically higher than peers due to premium market access, but still trades at a differential to Henry Hub."
6. "Failing to account for the $3.47 billion in new senior notes issued in Q3 2025, which permanently steps up the run-rate interest expense."
7. "Treating Gathering, Processing and Marketing revenue as pure profit; it has an almost 1:1 offsetting expense line (Purchases of Commodities)."
8. "Modelling share count as static; EOG aggressively repurchases shares ($2.5B in 2025), which significantly impacts per-share valuation metrics."

## Validation Checks

1. "Total equivalent production (MBoed) must exactly equal Crude + NGLs + (Gas/6)."
2. "Cash operating costs (LOE + GP&T + G&A) should sum to between $10.00 and $10.50 per Boe; flag if outside this band."
3. "Production and ad valorem taxes must be between 6.5% and 7.5% of wellhead revenue."
4. "Capex must align with the $6.3B to $6.7B guidance for 2026."
5. "Free cash flow conversion (FCF / OCF) should be roughly 40% to 50%."
6. "Balance sheet must balance: Total Assets = Total Liabilities + Equity in every period."
7. "Dividend payout must cover the $4.08 annualized per share rate."
8. "Total debt should step up by approximately $3.47 billion in Q3 2025 to reflect the Encino acquisition financing."

## Key Assumptions (Default Values)

| Assumption | Default Value | Unit | Rationale |
|---|---|---|---|
| WTI Crude Oil Price | 75.00 | $/Bbl | Base case macro assumption for 2026 |
| Henry Hub Natural Gas Price | 3.00 | $/Mcf | Base case macro assumption for 2026 |
| Crude Oil Differential to WTI | 1.50 | $/Bbl | EOG typically realizes a slight premium/tight differential |
| Natural Gas Differential to HH | (0.20) | $/Mcf | Typical realization discount to Henry Hub |
| NGL Realized Price | 23.50 | $/Bbl | Based on 2024/2025 actual realizations |
| Crude Oil Production | 510.0 | MBbld | Reflects 2026 guidance including Encino |
| NGL Production | 250.0 | MBbld | Reflects 2026 guidance |
| Natural Gas Production | 2,350 | MMcfd | Reflects 2026 guidance and Utica growth |
| Lease and Well (LOE) Rate | 4.10 | $/Boe | Based on recent historical averages |
| GP&T Rate | 3.20 | $/Boe | Based on consolidated 2024/2025 reporting |
| G&A Rate | 1.65 | $/Boe | Highly efficient corporate structure |
| Production Tax Rate | 7.2 | % | % of wellhead revenue |
| DD&A Rate | 10.50 | $/Boe | Based on recent depletion trends |
| Capital Expenditures | 6,500 | $MM | Midpoint of 2026 guidance ($6.3B - $6.7B) |
| Effective Tax Rate | 21.7 | % | Based on 2025 actuals |
| Annual Dividend per Share | 4.08 | $ | Declared rate as of early 2026 |
| Share Repurchases | 2,500 | $MM | Assumes continuation of 2025 buyback pace |
| WACC | 9.5 | % | Standard E&P discount rate |

## Data Sources & Benchmarks

- **SEC Filings:** EOG Resources Investor Relations page (investors.eogresources.com) for 10-K, 10-Q, and 8-K filings.
- **Key Peers:** Diamondback Energy (FANG), Devon Energy (DVN), Occidental Petroleum (OXY), ConocoPhillips (COP).
- **Industry Data:** Rystad Energy (ShaleWellCube) for basin-level breakeven data; EIA (Energy Information Administration) for macro inventory and pricing trends.
- **Consensus Estimates:** FactSet or Bloomberg for forward commodity curves and consensus EPS/FCF estimates.

## Sources

- EOG Resources Q4 and Full-Year 2025 Earnings Release and Call Transcript (February 2026)
- EOG Resources Q3 2025 Earnings Release (November 2025)
- EOG Resources Q2 2025 Earnings Release (August 2025)
- EOG Resources 2024 Form 10-K (February 2025)
- EOG Resources Investor Presentations (2025/2026) detailing the "Premium" strategy and Encino acquisition

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## Frequently asked questions

### What does EOG Resources do, and where does it operate?

EOG Resources is one of the largest independent crude oil and natural gas exploration and production (E&P) companies in the United States. It focuses on high-return, low-cost wells primarily in the Delaware Basin, Eagle Ford, and Bakken, with operations also in Trinidad and other international areas.

### How does EOG Resources generate its revenue?

EOG Resources generates revenue primarily from the sale of crude oil and condensate, natural gas liquids (NGLs), and natural gas. Revenue for each commodity is driven by the volume produced and the realized market price per barrel or per thousand cubic feet.

### What is EOG Resources' capital expenditure strategy?

EOG Resources guides capital expenditure between $6.3 billion and $6.7 billion for 2026, with approximately 70% allocated to maintenance and 30% to growth. While historically an organic grower, the company recently made a significant $4.48 billion acquisition of Encino Acquisition Partners.

### What are the key assumptions for EOG Resources' financial model regarding growth and costs?

The financial model assumes a revenue growth rate of approximately 8.6% and projects COGS as 55% of revenue. Selling, General, and Administrative (SGA) expenses are modeled at about 3% of revenue, with depreciation and amortization at 20% of revenue.

### What is the purpose of the EOG Resources financial model, and what is its forecast horizon?

The EOG Resources financial model provides a comprehensive equity valuation and free cash flow forecast. Its main purpose is to assess whether the company's premium drilling strategy and recent acquisition justify its current market valuation, with a forecast horizon from FY2026 to FY2030.

### Can I download an Excel financial model for EOG Resources?

Yes, an Excel financial model for EOG Resources is available for download. This model offers detailed forecasts and assumptions for the company's financial performance, including revenue drivers and cost structures.

[Interactive forecast calculator](https://finamodel.com/companies/eog-resources/forecast)