Preliminary Results From a Solvent Gas Injection Field Test in a Depleted Heavy Oil Reservoir

Abstract

A field test was run during 1997 and 1998 to collect preliminary data on a solvent gas injection process. The site selected for the test was a "typical" Frog Lake, Alberta, Cummings formation reservoir that had been depleted using PC pump-based cold production methods on both 4 hectare (10 acre) and 8.1 hectare (20 acre) spacing. At the time of solvent injection, area average recovery from the test location was 9.5%, and the existence of wormholes in the reservoir was strongly suggested by regional well-to-well water migration and production of reservoir sand at high initial rates and cumulative volumes. A solvent containing 33 volume % propane and 67 volume % methane was injected at two converted central producers until cumulative volumes of 2 million m3 and 4 million m3 were achieved. This paper discusses field observations during the injection, soak, and production periods. A number of circumstances contributed to a poor economic result, but the operational and technical information obtained should prove helpful to operators considering application of solvent injection processes. Introduction Cold Production in Western Canadian Regional Heavy Oil Sands PC pump-based cold production has expanded rapidly following initial development in the 1980s. This exploitation methodology provides a large percentage of the produced oil volume for most Western Canadian heavy oil producers. Some producers use only this method. Despite continued efforts to improve PC pump-based cold production technology, current methods generally leave 80 to 95% of the OOIP behind at economic limit. While this is a large oil-inplace target for follow-up EOR processes, the cold production process appears to have strongly altered reservoir conditions. Wormhole channels have been implied and described on the basis of observed high produced sand volumes and rapid migration of edge water and injected fluids and tracers(1–3). The reservoirs are generally pressure depleted. Solution gas, which appears to help power production through mechanisms described as either foamy oil flow(4–6) or more recently as extremely low gas mobility(7), often appears to "blow down" at the end of a well's life. Water influx, likely through wormhole networks, sometimes occurs at wells distant from the original oil/water contact. Thermal Production in Western Canadian Regional Heavy Oil Sands During the 1960s, operators attempted steam processes in selected heavy oil regional sands to recover a higher fraction of OOIP. It was soon determined that the typical H-40 casings with non-thermal cement would not withstand the resulting thermal stresses. Insulated tubing strings with or without packers were tried, but these strings were expensive, fragile, and often did not achieve theoretical performance in the field. Thermal completions in newer wells avoided wellbore failure due to the use of premium tubulars and collars, but other problems occurred. Often the steam had to be injected at pressures exceeding the formation parting (fracture) pressure to achieve acceptable heat transfer rates to the reservoir. This resulted in rapid steam channeling to neighboring wells, or to neighboring formations.

Interplay of Capillarity, Drainage Height, and Aqueous Phase Saturation on Mass Transfer Rate of Solvent Vapor into Heavy Oil

“…Vapor extraction has been the subject of extensive experimental and numerical studies to investigate various aspects of this process. In addition to these laboratory studies, there are reported cases of field trials of solvent-aided processes in western Canada (Miller et al 2003;Gupta and Gittins, 2005). Despite relatively extensive literature on the vapor extraction process since 1989, the estimation of the efficiency of mass transfer phenomenon in porous media with characteristics of typical heavy oil reservoirs has not been fully investigated.…”

Post-Cold Production Solvent Vapor Extraction (SVX) Process Performance Evaluation by Numerical Simulation

“…Without considering the change in initial conditions provided by primary or secondary production techniques, the results of the studies only reflected the performance of solvent injection. However, it is expected that SVX processes will be used in the field as a post-cold production enhanced oil recovery method (1,8) . Generally the mechanisms of cold production are divided into two main categories: development of wormholes and foamy oil flow.…”

A Post–Cold Production Solvent Vapor Extraction (SVX) Process Performance Evaluation by Numerical Simulation

“…This is mainly because the wormholed well allows the solvent to spread out over the reservoir more efficiently. However, in a real field situation, because of the complicated wormhole structure and possible thief zones, using the wormholed well as an injector may cause solvent loses outside the pattern area (Miller et al, 2003).…”

“…Without considering the change in initial conditions provided by primary or secondary production techniques, the results of the studies only reflected the performance of solvent injection. However, it is expected that SVX processes will be used in the field as a post-cold production enhanced oil recovery method (Miller et al, 2003;Knorr, 2006). Generally the mechanisms of cold production are divided into two main categories: development of wormholes and foamy oil flow.…”