# Oil Gas Upstream Model Build an upstream E&P cash flow and valuation model with decline curves, production scheduling, fiscal terms, and project economics. This is not a procurement or CAPEX cost-estimation database. - Canonical: https://finamodel.com/templates/oil-gas-upstream-model - Excel download: https://finamodel.com/templates/oil-gas-upstream.xlsx - Category: Energy - Model type: Project finance - Difficulty: Advanced - Audiences: Developers & sponsors, Investors & analysts, E&P analysts, Asset managers, Investors, Engineers - Tags: upstream, oil-gas, reserves, npv, commodity-pricing ## Overview Evaluate upstream oil and gas development and acquisition decisions with a production-to-cash integration model. This template forecasts crude oil, natural gas, and NGL production across legacy and new wells, models commodity price exposure via price decking, and calculates project economics including NPV, IRR, and payback. It handles reserve depletion via hyperbolic decline curves, applies government take and severance taxes, and tracks working interest versus net revenue interest - critical distinctions in E&P asset analysis. The workbook contains dedicated sheets for production decline curves, revenue by commodity type, lease operating expenses and per-BOE metrics, capex and depreciation using the unit-of-production method, debt schedules for reserve-based lending, and a full three-statement model with EBITDAX margins (the standard profitability metric). DSCR and debt/EBITDAX covenants monitor lender compliance throughout the projection. All calculations follow industry convention: production in BOE, pricing with basis differentials, and reserve assumptions tied to actual well economics rather than flat growth rates. Target users include petroleum engineers, project finance analysts, and deal teams at E&P operators, infrastructure funds, and independent producers evaluating assets in the $50M to $1B enterprise value range. ## What's included - Type curve modelling with hyperbolic and exponential decline profiles - Working interest, net revenue interest, and royalty calculations - Multi-well drilling and completion capital scheduling - Operating expense modelling with fixed and variable components - NPV, IRR, and payback analysis across price scenarios - Production schedules by well, field, and phase - Operating expense curves and cost inflation - Capital expenditure and drilling schedules - Commodity price decking and price case assumptions - Government take, royalties, and tax calculations - NPV, IRR, and payback period by scenario ## Oil Gas Upstream Model: How the Template Evaluates E&P Cash Flows This oil gas upstream model template supports decisions on whether to invest in, acquire, or develop an upstream oil and gas asset or portfolio. It connects production volumes, realised pricing, operating costs, capital spending, and financing into a structured cash flow and valuation framework, using decline curves, fiscal terms, and project economics rather than a cost-estimation database. ### Production and Revenue Drivers The model's operating engine starts with gross production split across crude oil, natural gas, and natural gas liquids. Crude and gas volumes follow a hyperbolic decline profile, where an initial production rate and a curvature factor determine how quickly output falls over time. - New wells are added through a drilling schedule, while legacy wells decline continuously, so reported volumes combine both. Net revenue interest then converts gross volumes into the net share the company actually sells. - Each commodity is priced separately. Realised prices begin with benchmark references such as WTI or Henry Hub, adjusted by basis differentials that reflect transportation and quality. NGLs are typically priced relative to crude or a composite barrel. This layered approach means small changes in drilling pace, decline assumptions, or differentials can materially shift the revenue outlook. ### Cost and Capital Structure Costs are modelled in two broad groups. Variable costs include lease operating expenses, gathering and transportation fees, and severance taxes, all of which scale with production or revenue. - Because much of LOE is fixed per well, unit costs tend to rise as wells age and volumes decline. G&A and exploration expenses sit at the corporate level. - On the capital side, drilling and completion spending drives the well schedule, with maintenance capex needed simply to hold production flat and growth capex adding incremental volumes. Depletion is handled through the unit-of-production method, tying DD&A to remaining reserves. The debt schedule captures reserve-based lending drawdowns, repayments, and interest, which feeds both the income statement and the cash flow statement. ### Cash Flow and Valuation Outputs The income statement moves from revenue through operating costs, DD&A, interest, and taxes to net income, with EBITDAX shown as a key industry metric. The cash flow statement then follows the indirect method, adjusting net income for non-cash items such as depletion and working capital changes, and separating operating, investing, and financing activities. - Free cash flow is simply operating cash flow less total capex. For valuation, the model calculates a net asset value using discounted cash flows over a defined horizon, with a terminal value annuity capturing the long tail of production beyond the explicit forecast. - Discounted at a specified rate, this yields a PV-10 style metric. A balance sheet and validation checks sit alongside, ensuring that assets equal liabilities and equity and that production reconciles to the sum of legacy and new wells. ### Practical Use and Key Relationships In practice, the template is used to test how commodity prices, drilling pace, and cost inflation interact over a five-year forecast and beyond. The multi-year price deck allows each year to carry its own benchmark price and basis differential, rather than assuming a flat price forever. - Key relationships worth noting: net production equals gross production times NRI; net revenue equals net production times realised price; DD&A equals net book value divided by remaining reserves, multiplied by period production; and debt-to-EBITDAX provides a leverage check against covenant limits. - These relationships make the model sensitive to assumptions about decline rates, capital efficiency, and fiscal terms, helping users evaluate whether an asset can generate sufficient cash flow to justify development or acquisition. ## Built for upstream asset evaluation Use this model when you need to value producing assets, plan field development, or size debt against reserve-based cash flows. ## Structured around E&P economics A useful upstream model needs decline curves, fiscal terms, and production scheduling that reflect how oil and gas assets are actually evaluated and financed. ## Better for A&D and project finance This gives you a proper E&P framework instead of forcing generic DCF logic onto an asset class that requires well-level production modelling. ## Built for upstream asset evaluation Use this model when you need to value producing assets, plan field development, or size debt against reserve-based cash flows. ## Structured around E&P economics A useful upstream model needs decline curves, fiscal terms, and production scheduling that reflect how oil and gas assets are actually evaluated and financed. ## Better for A&D and project finance This gives you a proper E&P framework instead of forcing generic DCF logic onto an asset class that requires well-level production modelling. ## Features - **Production-to-cash integration:** Maps reserve estimates, well performance, and production decay curves to operating cash flows with realistic decline rates. - **Commodity price sensitivity:** Price-linked revenue model supports oil, gas, and NGL pricing with hedging assumptions and forward curve inputs. - **Government economics modeling:** Includes royalties, production taxes, and profit-sharing regimes to show after-tax cash flows and project competitiveness. ## Use cases - **Prospect evaluation and bid decisions:** Assess exploration upside, commerciality thresholds, and bid economics for acreage acquisition. - **Acquisition valuation and due diligence:** Build a standardized model for comparing multiple fields and assessing reserve replacement cost. - **Portfolio returns analysis:** Aggregate project IRRs, PV10, and cash flow timing across a portfolio to optimize capex allocation. ## Frequently asked questions ### What is an upstream oil and gas model? It is a financial model used to evaluate exploration and production assets by forecasting production, revenue, costs, and project returns over the life of the field. ### What should an upstream model include? A strong upstream model should include decline curve analysis, CAPEX and OPEX schedules, fiscal regime calculations, and NPV/IRR outputs. ### Who uses upstream oil and gas models? E&P companies, project finance lenders, private equity energy funds, and A&D advisory teams use them for asset valuation and investment decisions. ### What is decline curve analysis? Decline curve analysis forecasts future production by fitting historical output to mathematical decline profiles, typically using Arps hyperbolic or exponential methods. ### Can I model different commodity price scenarios? Yes. The model is designed to test project economics under various oil and gas price assumptions, including WTI, Brent, and Henry Hub benchmarks. ## Related templates - [Mining Operations Model](https://finamodel.com/templates/mining-model) - [Hydrogen Production and Storage Model](https://finamodel.com/templates/hydrogen-model) - [LNG Terminal Model](https://finamodel.com/templates/lng-terminal-model)