History Matching Field Results from a SAGD / Light Hydrocarbon Process (SAGD+ TM)
Abstract
Connacher Oil & Gas Limited is presently operating two SAGD projects at its Pod One and Algar sites, about 80 km southwest of Fort McMurray, Alberta, Canada. The total approved steam injection capacity is 57,000 barrels per day. Connacher is committed to enhance the performance of its current projects and future expansion sites by developing drilling, lifting and recovery technologies. Amongst these, SAGD with light hydrocarbon co-injection (SAGD+TM) is one of the most promising methods.
In July 2011, Connacher initiated the first field trial at two Algar well pairs. Shortly after the light hydrocarbon (or solvent) co-injection, increases in bitumen production and solvent recovery were observed. In mid-November, the solvent injection was suspended and the well pairs reverted to the normal SAGD operating mode. The residual effects of solvent injection was monitored until February 2012.
This paper describes the selection of the well pairs, the modifications to the injection and production facilities and the design of the monitoring program. It also describes how the geological, wellbore and production information was used in a thermal simulation model to simulate the recovery behavior. By matching the production history, Connacher gained significant insights into the reservoir recovery and well flow mechanisms. Furthermore, Connacher was able to identify areas of improvement and applied them in the subsequent SAGD+TM field trials.