# LNG Terminal Model Model LNG terminal throughput, margins between spot and contract prices, regulatory compliance costs, and debt serviceability to determine project viability. Separate contract-backed volume from spot market balancing and stress-test DSCR under different utilization and price scenarios. - Canonical: https://finamodel.com/templates/lng-terminal-model - Excel download: https://finamodel.com/templates/lng-terminal.xlsx - Category: Energy - Model type: Project finance - Difficulty: Advanced - Audiences: Developers & sponsors, Investors & analysts, Energy Finance, Project Finance Teams, Utilities, Infrastructure Investors - Tags: lng, energy, terminal, project-finance, infrastructure ## Overview An LNG Terminal Model evaluates the project finance viability of a liquefied natural gas import or export terminal with ship-or-pay tolling contracts. The model captures capacity reservation fees (fixed, regardless of volume), variable throughput fees, and ancillary revenue (berthing, truck loading) to project 20-30 year cash flows. A typical 3 MTPA terminal generates $300-500M revenue annually at full utilization, with 75-90% gross margin because the variable cost (gas shrinkage, power, water) is minimal and the capacity fee is largely decoupled from operational costs. EBITDA margins of 55-75% support 5.0-7.0x debt-to-EBITDA leverage, requiring strict DSCR covenants (minimum 1.20-1.35x) and loan-life coverage ratios (minimum 1.30x). The workbook models a 3-5 year construction phase with capex draws, capitalized interest, and IDC (interest during construction). Commercial operations begin at a defined COD (Commercial Operations Date), gating all revenue and opex. Revenue derives from contracted capacity × tariff (fixed, inflation-escalated) for contracted shippers, plus variable volume × tariff on spot cargoes. Capex is split by component: jetty/marine ($60-80M), LNG tanks ($75-100M), vaporizers ($45-60M), and balance of plant. Maintenance capex (1-2% of initial capex annually) sustains operations; major turnarounds every 4-5 years add step-up costs. The Debt Schedule models construction period drawdowns and interest capitalization, then post-COD amortizing repayments sculpted to maintain target DSCR (typically 1.25-1.30x). A Debt Service Reserve Account (6 months forward) ensures covenant cushion. This model applies to infrastructure funds, sponsors, lenders, and NOCs evaluating terminal investments or expansions. Typical equity IRR targets 10-15%; project IRR 7-12%. Key sensitivities are LNG spreads (contracted vs. spot prices), utilization rates, and commodity price pass-through mechanisms embedded in contracts. ## What's included - Terminal capacity and utilization assumptions by ship and storage cycle - Fixed throughput fees and commodity-based pricing - Regasification, vaporization, and processing costs - Long-term supply contracts and spot market balancing volumes - Debt service schedule and liquidity reserve requirements - Terminal capacity and utilization assumptions by ship and storage - LNG carrier scheduling and queue management - Long-term supply contracts and spot market balancing - Debt service and liquidity requirements ## How the LNG Terminal Model Evaluates Contracted Throughput and Debt Service This lng terminal model shows how a regasification project earns money from long-term ship-or-pay tolling agreements, layered with variable throughput fees and smaller ancillary income. It walks through contracted versus spot capacity, construction funding, operating costs and project-finance debt service, so you can see how utilization and tariff assumptions translate into coverage ratios and investor returns. ### Contracted Capacity and the Revenue Build Revenue starts with capacity reservation fees under ship-or-pay tolling agreements, where shippers pay for reserved capacity whether or not they actually deliver cargoes. The model tracks five anchor contract tranches, each with its own volume, tariff, escalator and active window; as tranches expire, contracted capacity steps down and the blended tariff re-weights toward the remaining live agreements. - A nomination rate sets physical send-out as a share of reserved capacity, ramping over several years and floored by a take-or-pay threshold. Expired tranches can renew at a fraction of their prior volume and tariff, with the residual space sold into the spot market at a separate utilization assumption. - Physical throughput then drives variable and ancillary fees, and everything is gated to start at commercial operation. ### Where Costs and Capital Come From On the cost side, variable expenses scale with throughput, mainly fuel gas consumed in regasification, electricity for sendout and water for vaporizers, leaving a high gross margin typical of a tolling business. - Fixed operating costs cover staff, maintenance and turnarounds, insurance, land or concession fees, overhead and regulatory compliance, with major overhauls arriving on a multi-year cycle. - Capital spending is split across site and marine works, storage tanks, regasification equipment, pipeline interconnection, utilities and contingency, and it draws down over a multi-year construction profile. - Interest during construction and commitment fees on undrawn debt are capitalized into the asset base rather than expensed, and the resulting project cost sizes the senior debt facility at a fixed share of total funded cost. ### Debt Service, Coverage Ratios and Distributions Debt draws during construction, then runs interest-only before converting to a re-amortizing annuity over the remaining tenor. Cash flow available for debt service is built from EBITDA less tax, working capital movement and maintenance capex, which is a stricter base than EBITDA alone. - DSCR, LLCR and PLCR are all measured against that same figure, and the checks compare them to target thresholds and confirm the loan repays before the concession ends. Cash sweep, if switched on, prepays from surplus cash and re-amortizes scheduled principal. - Distributions are released only when coverage stays above a lock-up level while debt is outstanding, so equity cash flow responds directly to utilization and tariff outcomes. ### Timing, Terminal Value and How to Use It The model follows a full concession sequence: construction years with negative free cash flow, an operating period where contracted revenue covers costs and debt service, and a final-year terminal value of net book value at a salvage percentage less decommissioning cost. - Depreciation runs across several asset classes from commercial operation, including a pool for capitalized maintenance capex, and a no-loss carry-forward block handles tax in downside cases. Use it to test whether the contracted book, tariff escalation and utilization assumptions support the required coverage ratios and returns. - The public download is a values-only preview, so the sheet structure and driver relationships are shown without live formulas. ## Capacity utilization modeling Forecast ship arrivals, storage cycles, and daily regasification volumes to determine average capacity utilization and revenue per unit of throughput. ## Commodity price exposure Model revenue from fixed fees and commodity spreads, and show the P&L impact of LNG price volatility and hedging effectiveness across scenarios. ## Long-term contract stacking Segment revenue into contract-backed throughput and spot market sales, with separate pricing and volume risk assumptions for each category. ## Capacity utilization modeling Forecast ship arrivals, storage cycles, and daily regasification volumes to determine average capacity utilization and revenue per unit of throughput. ## Commodity price exposure Model revenue from fixed fees and commodity spreads, and show the P&L impact of LNG price volatility and hedging effectiveness across scenarios. ## Long-term contract stacking Segment revenue into contract-backed throughput and spot market sales, with separate pricing and volume risk assumptions for each category. ## Features - **Capacity utilization modeling:** Forecast ship arrivals, storage cycles, and daily regasification to determine average capacity use and revenue per unit. - **Commodity price exposure:** Model revenue from both fixed fees and commodity spreads; show P&L impact of LNG price volatility and hedging effectiveness. - **Long-term contract stacking:** Segment revenue into contract-backed throughput and spot market, with separate pricing and volume risk for each. ## Use cases - **Project sanctioning:** Demonstrate project economics and debt service capacity to satisfy lenders and equity investors during the investment decision. - **Contract negotiation:** Model the financial impact of different contract lengths, take-or-pay clauses, and pricing mechanisms on overall NPV. - **Operational optimization:** Forecast optimal mix of contract vs. spot market sales and berth utilization to maximize throughput and margin. ## Frequently asked questions ### What is throughput in an LNG terminal model? Throughput is the volume of LNG flowing through the terminal from ship unloading through regasification. It is measured in mmBtu or tonnes per year and determines revenue when pricing is set on a fixed-per-unit basis. ### What are the main cost drivers for an LNG terminal? Regasification costs including energy and compression, storage losses, operating labor, maintenance, and utilities are the primary drivers. Floating or import terminals also carry capacity rental, demurrage, and shipping costs. ### How do long-term contracts affect returns? Long-term contracts provide revenue certainty and reduce leverage ratios, making debt financing cheaper. However, they cap upside when commodity prices spike. Spot market sales offer flexibility and higher potential margins but add cash flow volatility. ### Who uses LNG terminal financial models? Energy finance teams, project finance advisors, utilities, and infrastructure investors use these models for project sanctioning, contract negotiation, and operational optimization decisions. ### What is a take-or-pay clause and how does it affect the model? A take-or-pay clause requires the customer to pay a minimum fee whether or not they take delivery of the gas. This provides a revenue floor that supports debt service and reduces demand risk in the financial model. ## Related templates - [Oil & Gas Upstream Model](https://finamodel.com/templates/oil-gas-upstream-model) - [Hydrogen Production and Storage Model](https://finamodel.com/templates/hydrogen-model) - [Electric Utility Tariff Model](https://finamodel.com/templates/utility-model)