A study was initiated to evaluate the potential for oil recovery at Schrader Bluff, Alaska, using gas injection processes. The purpose of the study was to determine which gas or gas mixtures are likely to produce oil via miscible recovery mechanisms at reservoir conditions, and to estimate the recovery potential. A laboratory study was conducted to measure the swelling and miscible phase behavior properties. A simulation study was conducted to estimate the ultimate oil recovery potential at Schrader Bluff. Based on the laboratory study, Prudhoe Bay MI and CO2/NGL mixtures reduce Schrader Bluff crude oil viscosity by up to 70%; viscosities were reduced from 65 cP (down hole conditions) to about 20 cP. All solvents tested were soluble with the crude oil up to 60 mol%, but formed separate layers at higher solvent concentrations and led to potential asphaltene precipitation problems. Displacement efficiencies exceeded 990/0 for 77.5% C02/22.S% NGL mixture in a standard slimtube test. Based on the simulation study, incremental recovery potential varied from 2% OOIP for Schrader Bluff lean gas, to 11 % OOIP for Prudhoe Bay MI, to 21.6% for 20% CO2/80% NGL. All studies were conducted with 1: 1 WAG? injection scheme. Recovery would be further improved with better throughput in the lower permeable N sands. It appeared that sufficient CO2 would be available for injection if captured from Prudhoe Bay operations (flue gas, separator gas, etc.). Benefits to reduce global warming via reduction in C02 emissions from North Slope operations are also discussed.