# Diamondback Energy (FANG) Financial Model

Free Excel 3-statement financial model and company analysis for Diamondback Energy.

- Canonical: https://finamodel.com/companies/diamondback-energy
- Industry: Oil and Gas
- Downloadable model: Yes
- Excel download: https://finamodel.com/company-models/FANG.xlsx

## Model Purpose

This model provides a comprehensive equity valuation and cash flow forecast to determine the intrinsic value, debt paydown trajectory, and shareholder return capacity of Diamondback Energy following its transformational acquisition of Endeavor Energy Resources.

## Company Overview

Diamondback Energy (NASDAQ: FANG) is a premier independent oil and natural gas company focused exclusively on the acquisition, development, and exploration of unconventional onshore reserves in the Permian Basin in West Texas. The company extracts hydrocarbons primarily from the Wolfcamp and Spraberry formations.

The business operates as a single reportable segment but generates revenue across three distinct product streams: Oil (approximately 75% of revenue), Natural Gas Liquids (15% of revenue), and Natural Gas (10% of revenue). All operations are geographically concentrated in the Midland and Delaware Basins of the United States. Diamondback operates an asset-heavy exploration and production (E&P) business model that requires significant upfront capital expenditure to drill and complete wells, followed by a steep initial production decline curve that levels out over time.

Competitively, Diamondback is one of the largest pure-play Permian operators, boasting a highly competitive corporate breakeven of approximately $37 per barrel. The company recently underwent a massive transformation by closing the $26 billion acquisition of Endeavor Energy Resources on 10 September 2024, which significantly expanded its Midland Basin footprint. Furthermore, in late 2025, the company sold its Environmental Disposal Systems business to Deep Blue for $694 million, a move that generated upfront cash but structurally increased ongoing lease operating expenses.

## Revenue Deep Dive



### Oil

- **Segment name:** Oil Sales
- **Revenue driver formula:** Oil Production Volume (MBbls) x Realised Oil Price per Bbl
- **Historical growth rate:** 15-20% CAGR, heavily distorted by the 2024 Endeavor acquisition which nearly doubled production capacity.
- **Key growth levers and headwinds:** Driven by the number of gross horizontal wells drilled and completed, lateral length extensions (targeting over 15,000 feet in the Barnett shale), and multi-well pad efficiencies. Headwinds include natural reservoir depletion and supply chain constraints for drilling equipment.
- **Pricing dynamics:** Spot pricing linked to WTI Midland and WTI Houston benchmarks. The company uses derivative contracts to hedge a portion of production, but unhedged realised prices dictate baseline revenue.
- **Revenue recognition notes:** Recognised when control passes to the purchaser at the delivery point.
- **Seasonality:** Minimal operational seasonality, though extreme winter weather in Texas can occasionally freeze off production for brief periods.

### Natural Gas Liquids (NGLs)

- **Segment name:** Natural Gas Liquids Sales
- **Revenue driver formula:** NGL Production Volume (MBbls) x Realised NGL Price per Bbl
- **Historical growth rate:** 15-20% CAGR, tracking alongside oil production as NGLs are extracted from the same raw gas stream.
- **Key growth levers and headwinds:** Dependent on processing plant capacity and the liquids-rich nature of the specific acreage being drilled.
- **Pricing dynamics:** Priced as a basket of liquids (ethane, propane, butane) typically trading at a structural discount to WTI crude.
- **Revenue recognition notes:** Recognised upon delivery to midstream processing partners.
- **Seasonality:** Propane components see slight seasonal demand spikes in winter, but overall impact is muted.

### Natural Gas

- **Segment name:** Natural Gas Sales
- **Revenue driver formula:** Natural Gas Production Volume (MMcf) x Realised Gas Price per Mcf
- **Historical growth rate:** 20%+ CAGR due to rising gas-to-oil ratios as Permian wells mature.
- **Key growth levers and headwinds:** Associated gas production increases as oil wells age. A major headwind is the lack of takeaway pipeline capacity in the Permian Basin.
- **Pricing dynamics:** Highly volatile. Permian gas often trades at a severe discount to the Henry Hub benchmark (Waha hub pricing), occasionally dropping below zero during pipeline maintenance events.
- **Revenue recognition notes:** Recognised upon delivery to the pipeline interconnect.
- **Seasonality:** Higher pricing during peak summer cooling and peak winter heating months.

## Cost Structure



### Variable Costs / COGS

- **Line-by-line breakdown:** Lease Operating Expense (LOE), Gathering, Processing and Transportation (GP&T), and Production and Ad Valorem Taxes.
- **Gross margin range:** E&P companies typically measure unhedged realised cash margins rather than traditional gross margin. This cash margin has historically ranged from 65% to 75%.
- **Key input costs and commodity exposures:** Steel (tubulars), frac sand, pumping services, and electricity for artificial lift.
- **How COGS scales with revenue:** Production taxes scale linearly with revenue (typically 6-8%). LOE and GP&T scale with production volumes rather than commodity prices, creating massive operating leverage when oil prices rise.

### Operating Expenses

- **R&D:** Not applicable for this E&P company.
- **SG&A:** Reported as General and Administrative (G&A) expense. It includes cash compensation, office leases, and IT. It is largely fixed and scales with headcount rather than production.
- **Depreciation & Amortisation:** Reported as Depreciation, Depletion, and Amortisation (DD&A). Calculated using the unit-of-production method. It typically runs at 20-25% of revenue but fluctuates based on reserve revisions.
- **Stock-Based Compensation:** Included within G&A, typically running at 1-2% of revenue.
- **Restructuring / one-time charges:** Frequent non-cash ceiling test impairments under full-cost accounting rules. For example, the company recorded a $3.7 billion non-cash impairment in Q4 2025 due to lower trailing twelve-month commodity prices.

### Margin Profile

- **EBITDA margin:** 65-75% over the last 5 years.
- **Operating margin:** 40-55%, heavily dependent on DD&A rates and impairment charges.
- **Net margin:** 25-35% in mid-cycle environments, but can turn negative during impairment cycles (as seen in Q4 2025).
- **Margin trend:** Cash margins remain robust due to the low $37/Bbl corporate breakeven, but GAAP margins are highly volatile due to commodity price swings.

## Balance Sheet Structure

- **Total assets:** Approximately $35-40 billion following the Endeavor acquisition.
- **Key asset categories:** Proved oil and natural gas properties dominate the balance sheet.
- **Goodwill & intangibles:** Material goodwill exists from historical corporate acquisitions (Endeavor, FireBird, Lario), representing roughly 10-15% of total assets.
- **Working capital profile:**
  - **Days Sales Outstanding (DSO):** 30-45 days.
  - **Days Inventory Outstanding (DIO):** Not material (hydrocarbons are sold as produced).
  - **Days Payable Outstanding (DPO):** 60-90 days.
  - **Net working capital as % of revenue:** Typically negative.
  - **Working capital dynamic:** The company runs a working capital deficit. Payables for drilling and completion activities consistently exceed receivables from oil purchasers, meaning growth is partially funded by the supply chain.
- **PP&E:** Consists almost entirely of oil and natural gas properties subject to depletion.
- **Right-of-use assets / operating leases:** Present for office space and certain field equipment, but immaterial relative to the reserve base.

## Capital Expenditure & Investment

- **Capex as % of revenue:** 35-45% depending on the commodity price environment.
- **Maintenance capex vs. growth capex:** Approximately 80% is maintenance capex required to offset the steep decline rates of shale wells, with 20% dedicated to low-single-digit production growth.
- **Major capex programmes underway:** The 2026 capital budget is set at $3.75 billion, heavily focused on the Midland Basin and the new Barnett shale multi-well pad developments.
- **Capitalised software / development costs:** Immaterial.
- **M&A pattern:** Transformational acquirer. The company routinely executes multi-billion dollar deals to consolidate the Permian Basin, followed by divestitures of non-core infrastructure (such as the EDS water business and EPIC Crude pipeline stakes in 2025).
- **Typical acquisition multiple paid:** Typically pays $30,000 to $50,000 per flowing BOE, or $10,000 to $20,000 per undeveloped acre.

## Debt & Capital Structure

- **Total debt:** Approximately $12-14 billion, having increased significantly to fund the $8 billion cash portion of the Endeavor acquisition.
- **Debt/EBITDA ratio:** Management targets below 1.5x.
- **Credit rating:** Investment grade (Baa3/BBB- equivalent).
- **Key debt instruments:** A series of senior unsecured notes with maturities ranging from 2026 to 2064, alongside a revolving credit facility.
- **Maturity profile:** Well-laddered, with average maturities exceeding 10 years.
- **Interest rate profile:** Primarily fixed-rate senior notes with a weighted average cost of debt around 5.0-5.5%.
- **Covenants:** Standard investment-grade covenants limiting priority debt and requiring minimum interest coverage.
- **Share repurchase programme:** Highly active. The company repurchased 13.84 million shares for $2.0 billion in 2025 and has an $8.0 billion total authorisation.
- **Dividend policy:** The company pays a base dividend of $4.20 per share annually ($1.05 per quarter as of Q4 2025). It also pays variable dividends to ensure total return of capital meets a minimum of 50% of Free Cash Flow.

## Cash Flow Characteristics

- **Operating cash flow conversion:** OCF to Net Income is highly distorted by non-cash impairments. OCF typically runs at 50-60% of total revenue.
- **Free cash flow margin:** FCF to Revenue typically ranges from 15% to 25%.
- **Major non-cash items:** DD&A, deferred income taxes, and full-cost ceiling test impairments.
- **Working capital cash flow impact:** Changes in working capital can swing OCF by hundreds of millions of dollars quarter-to-quarter based on the timing of drilling completions.
- **Capex intensity:** Extremely high. The company must reinvest billions annually just to keep production flat.
- **Cash tax rate vs. GAAP effective tax rate:** Cash taxes are generally lower than the GAAP rate due to the immediate expensing of intangible drilling costs (IDCs) for tax purposes, though this gap is narrowing as historical net operating losses are consumed.

## Sheet Structure

1. **Assumptions**: Hardcoded inputs for macro pricing (WTI, Henry Hub), basis differentials, production volumes by product, LOE per BOE, and the annual capex budget.
2. **Production & Pricing**: Build-up of daily production (MBO/d, MMcf/d, MNGL/d) converted to annual volumes, multiplied by realised prices net of basis differentials.
3. **Income Statement**: Revenue broken out by Oil, Natural Gas, and NGLs. Expenses detailed by LOE, Production Taxes, GP&T, G&A, DD&A, Impairments, Interest Expense, and Income Taxes.
4. **Cash Flow Statement**: Net Income reconciled to OCF by adding back DD&A and impairments. Includes Cash Capex, FCF calculation, Dividends, Share Repurchases, and Debt issuance or repayment.
5. **Balance Sheet**: Cash, Receivables, PP&E (Oil & Gas Properties), Payables, Long-Term Debt, and Stockholders' Equity.
6. **Debt Schedule**: Tranches of Senior Notes, Revolver balance, and Interest expense calculation.
7. **Return of Capital**: Tracking of base dividends, variable dividends, and share repurchases against the management target of returning at least 50% of Free Cash Flow.
8. **DCF Valuation**: Unlevered free cash flow projection, WACC calculation, and terminal value based on an EV/EBITDA multiple.

## Key Financial Relationships

1. Total Production (MBOE/d) = Oil Production (MBO/d) + (Natural Gas Production (MMcf/d) / 6) + NGL Production (MBbls/d)
2. Oil Revenue = Annual Oil Production (MBbls) x (WTI Benchmark Price - Oil Basis Differential)
3. Natural Gas Revenue = Annual Gas Production (MMcf) x (Henry Hub Benchmark Price - Gas Basis Differential)
4. Lease Operating Expense (LOE) = Annual Total Production (MBOE) x LOE per BOE
5. Production Taxes = Total Revenue x Production Tax Rate
6. DD&A Expense = Annual Total Production (MBOE) x DD&A Rate per BOE
7. Free Cash Flow (FCF) = Operating Cash Flow Before Working Capital Changes - Cash Capital Expenditures
8. Base Dividend Paid = Shares Outstanding x Base Dividend per Share
9. Target Return of Capital = Free Cash Flow x 50%
10. Share Repurchases = Target Return of Capital - Base Dividend Paid - Variable Dividend Paid

## Cross-Sheet Dependencies

The **Assumptions** sheet dictates the volume and pricing metrics on the **Production & Pricing** sheet. The **Production & Pricing** sheet calculates total revenue, which feeds the top line of the **Income Statement**. Net income from the **Income Statement** flows to the **Cash Flow Statement**, where non-cash items are added back to determine Free Cash Flow. Free Cash Flow feeds the **Return of Capital** sheet to calculate allowable dividends and buybacks. These capital returns reduce the cash balance on the **Balance Sheet** and lower the share count on the **Assumptions** sheet for future per-share calculations. A circularity exists between the **Debt Schedule** and the **Income Statement** if the revolving credit facility is used to balance cash shortfalls, as interest expense impacts net income and operating cash flow.

## Sign Convention

- Revenue, production volumes, and realised prices are positive.
- Expenses on the Income Statement (LOE, G&A, Taxes, Interest) are entered as positive numbers and subtracted in aggregate margin formulas.
- On the Cash Flow Statement, cash inflows are positive. Cash outflows (Capital Expenditures, Dividends, Share Repurchases) are negative.
- Balance Sheet items (Assets, Liabilities, Equity) are positive.

## Things Most Likely to Go Wrong

- Failing to account for the structural increase in LOE (up $0.30/BOE to a range of $5.90 to $6.40) following the late-2025 sale of the Environmental Disposal Systems water business.
- Miscalculating BOE conversions. The model must divide natural gas volumes (Mcf) by six to convert them to barrels of oil equivalent (BOE).
- Ignoring the massive step-up in share count and debt from the September 2024 Endeavor acquisition when comparing future projections to historical pre-2024 data.
- Modelling full-cost ceiling test impairments as cash expenses. These are strictly non-cash and must be added back to Operating Cash Flow.
- Overestimating realised gas prices. Permian gas often trades at a severe discount to Henry Hub and can occasionally price below zero.
- Double-counting Viper Energy (VNOM) distributions. Diamondback consolidates VNOM but must back out non-controlling interests.
- Forgetting that aggressive share repurchases dynamically reduce the total cash burden of the base dividend in future periods.
- Misaligning the capex budget. The $3.75 billion budget for 2026 is designed to hold production relatively flat; modelling high growth on this budget will overstate capital efficiency.

## Validation Checks

- Total production should align with 2026 guidance of approximately 920 to 930 MBOE/d.
- LOE per BOE must stay within the guided $5.90 to $6.40 range.
- Free Cash Flow yield (FCF divided by Market Capitalisation) should be benchmarked against peers, typically landing between 8% and 12% in mid-cycle pricing.
- Total Return of Capital must equal at least 50% of Free Cash Flow in every projected period.
- The Balance Sheet must balance perfectly: Total Assets = Total Liabilities + Equity.
- Base dividend payout should not exceed Free Cash Flow in stress-test scenarios (e.g., WTI dropping to $50/Bbl).
- Debt/EBITDA should remain below 1.5x to reflect the company's commitment to its investment-grade rating.

## Key Assumptions (Default Values)

| Assumption | Default Value | Unit | Rationale |
|---|---|---|---|
| 2026 Total Production | 925 | MBOE/d | Midpoint of post-Endeavor run-rate guidance |
| 2026 Oil Production | 505 | MBO/d | Midpoint of oil mix guidance |
| WTI Oil Price | 75.00 | $/Bbl | Base case macro assumption for mid-cycle pricing |
| Realised Oil Price Differential | (1.50) | $/Bbl | Historical discount to WTI benchmark |
| LOE per BOE | 6.15 | $/BOE | Midpoint of new $5.90-$6.40 guidance post-EDS sale |
| Production & Ad Valorem Taxes | 7.0 | % of Rev | Historical average |
| 2026 Cash Capex | 3,750 | $MM | 2026 Management guidance |
| Base Dividend (Annual) | 4.20 | $/Share | Q4 2025 declared rate ($1.05 per quarter) |
| Target Return of Capital | 50 | % of FCF | Stated management framework minimum |
| Effective Tax Rate | 22.0 | % | Standard corporate rate plus state taxes |
| WACC | 9.5 | % | Standard E&P cost of capital |

## Data Sources & Benchmarks

- **Filings:** SEC EDGAR for Diamondback Energy (FANG) 10-K, 10-Q, and 8-K filings.
- **Presentations:** Diamondback Investor Relations page for the Q4 2025 Earnings Release and February 2026 Investor Presentation.
- **Peers for Benchmarking:** EOG Resources (EOG), Permian Resources (PR), Devon Energy (DVN), and ExxonMobil (XOM) following its acquisition of Pioneer Natural Resources.
- **Industry Data:** Energy Information Administration (EIA) for macro inventory data and Baker Hughes for Permian rig counts.

## Sources

- Diamondback Energy Q4 2025 Earnings Release (23 February 2026)
- Diamondback Energy February 2026 Investor Presentation
- Diamondback Energy Letter to Stockholders (23 February 2026)
- SEC Form 10-K for the year ended 31 December 2025

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## Frequently asked questions

### What does Diamondback Energy do?

Diamondback Energy is an independent oil and natural gas company focused on acquiring, developing, and exploring unconventional onshore reserves in the Permian Basin of West Texas. It extracts hydrocarbons primarily from the Wolfcamp and Spraberry formations, operating an asset-heavy exploration and production business model.

### How does Diamondback Energy generate revenue?

Diamondback Energy generates revenue across three distinct product streams: Oil, Natural Gas Liquids, and Natural Gas. Oil accounts for approximately 75% of revenue, Natural Gas Liquids for 15%, and Natural Gas for 10%, with all operations concentrated in the Midland and Delaware Basins.

### What is Diamondback Energy's capital expenditure strategy?

Diamondback Energy's capital expenditure typically ranges from 35-45% of revenue, influenced by the commodity price environment. Approximately 80% of this capex is dedicated to maintenance to offset the steep decline rates of shale wells, while 20% supports low-single-digit production growth.

### What is the purpose of the Diamondback Energy financial model?

The financial model for Diamondback Energy provides a comprehensive equity valuation and cash flow forecast. Its primary purpose is to determine the intrinsic value, debt paydown trajectory, and shareholder return capacity of the company following its acquisition of Endeavor Energy Resources.

### Can I download an Excel financial model for Diamondback Energy?

Yes, a downloadable Excel financial model is available for Diamondback Energy. This model offers a forecast horizon from FY2026 to FY2030, providing detailed financial projections and assumptions for the company.

### What is Diamondback Energy's working capital profile?

Diamondback Energy typically operates with a negative net working capital position. This means that payables for drilling and completion activities consistently exceed receivables from oil purchasers, indicating that growth is partially funded by its supply chain.

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