Data-Driven Decision-Making Strategy for Thermal Well Completion

Abstract

Various wellbore completion strategies have been developed for thermal wells in Western Canada. The idea in this paper is estimating the improvement of oil production and steam injection if flow control devices (FCDs) will be installed for the next wells to be drilled, or if FCDs were installed at a particular well-pad that has not yet been completed with any FCDs. The approach is based on labeled real data for 68 well-pads from seven major thermal projects in Western Canada. Three phases make up the paper's methodology. The first phase compares wells with and without FCDs to evaluate the performance of the FCDs based on normalized oil production and cumulative steam oil ratio (cSOR). The second phase involves clustering well-pads using an unsupervised incremental-dynamic algorithm. An estimation of FCD contribution to enhancing oil production and cSOR is also performed for test well-pads based on their most similar cluster. In the third phase, cross-validation is employed to ensure that the estimation is trustworthy, and that the procedure is generalizable. To evaluate the performance of FCDs, a reliable comparison was made using normalized oil production and cSOR. Based on our analysis from October 2002 to March 2022, successful FCD deployment resulted 42% more normalized oil and a 37% reduction in cSOR. Among these, liner deployed (LD) FCDs increased oil production by 44% while decreasing cSOR by 58%. Although tubing deployed (TD) FCDs are installed in problematic wells, they produced 40% more oil while decreasing cSOR by 21% in successful cases. Successful inflow control devices (ICDs) increased oil production by 40% while lowering cSOR by 45%. Successful outflow control devices (OCDs) increased oil production by 82% while reducing cSOR by 22%. The clustering algorithm separates the database into four clusters that will be utilized in the estimating phase. In the estimation phase, ten well-pads (15% of the database) are presumed to be new well-pads to be drilled (test data). Based on the estimation results, the root mean square errors (RMSEs) for FCDs contribution to enhancing oil production and cSOR for the test well-pads are 12%. Cross-validation was also performed to assess the approach's predictability for new data, to verify that our technique is generalizable. The findings indicate that FCDs might result in lower capital expenditures (CapEx) and greenhouse gas (GHG) emissions intensity for SAGD well-pad developments, allowing them to reduce emissions. The conclusions of this research will aid production engineers in their knowledge of relative production performance. The findings may be used to examine paradigm shifts in the development of heavy oil deposits as technology advances while keeping economic constraints in mind.

Impact of Inflow and Outflow Rate Control to Minimize Freshwater Usage: Historical Canadian Steam-Assisted Gravity Drainage Operations versus Numerical Simulations

“…In the data-driven analysis performed in this study and results reported by ref , LDICDs performed better in increasing oil production and lowering cSOR than TDICDs. One reason could be the risk of failure associated with TDICD completion as a result of sand production if the well completed by TDICDs is run by the same subcool and production rate as that completed by LDICDs . In this paper, the subcool and good operational parameters remained the same for both cases with LDICDs and TDICDs, and still, the case with LDICDs performed better than the case with TDICDs.…”

“…One reason could be the risk of failure associated with TDICD completion as a result of sand production if the well completed by TDICDs is run by the same subcool and production rate as that completed by LDICDs. 51 In this paper, the subcool and good operational parameters remained the same for both cases with LDICDs and TDICDs, and still, the case with LDICDs performed better than the case with TDICDs. We concluded that this is because LDICDs are in direct contact with the sand face; therefore, they can provide the pressure drop more efficiently, resulting in a more equalized fluid rate entering the well (Figure 31).…”