The Features of Financing Oil and Gas Upstream Projects

The effect of reserve classification on financing

Reserves are classified by degree of certainty (proved, probable, possible); lenders typically give full weight in their collateral valuation only to proved developed producing reserves.

This conservative approach usually keeps borrowing capacity at a level far below the total estimated reserves.

The logic of reserve-based lending (RBL) structures

Reserve-based lending ties the credit limit directly to an independent valuation of reserves, and that limit is typically recalculated every six months (redetermination); if reserve estimates fall, the credit limit falls too.

This redetermination mechanism keeps the lender's risk continuously up to date, but it also brings the risk of the sponsor facing an unexpected contraction in credit availability.

The requirement to hedge price risk

Reserve-based loans typically require the sponsor to fix a significant portion of production (usually fifty to seventy-five percent) with price hedge contracts for a defined period.

This requirement aims to prevent a sudden drop in oil or gas prices from wiping out the lender's debt service capacity.

The financial impact of decommissioning obligations

At the end of an upstream asset's economic life, decommissioning and abandonment costs can reach significant levels; these obligations need to be provided for early in the financial model.

In some jurisdictions, regulators require a separate security fund or letter of guarantee to cover these costs, which increases the project's total financing need.

Pricing geopolitical and regulatory risk

Upstream projects typically operate under production sharing agreements or concession regimes; the stability of these regimes, together with country risk, directly affects the cost of financing.

Political risk insurance provided by multilateral development banks or export credit agencies is a commonly used tool to reduce this risk.

Frequently asked questions