A 3D earth model has, rapidly and successfully, detailed a map of the reservoir for horizontal drilling. The designed trajectory was closely followed, resulting in a successful well with early cleanup oil flow rates prior to injection test of 89 m3/d (600 BOPD) and a stable water injection rate of 230 m3/d (1450 BWPD).
The prediction capability of the 3D mapping and characterization provides a viable method for reducing risk while optimizing well placement.
The reservoir was closely mapped and characterized for the dual purpose of a horizontal well placement for a potential waterflood, as well as up scaling of results for the purpose of flow simulation.
Location The subject reservoir is located about 400 Km to the Northwest of Edmonton near the town of Grande Prairie, Alberta, Canada. (Figures 1 and 2) Figure 3 Well Planning in S.M.A.R.T.
Horizontal Injector The proposed well at 3-3-72-5W6M has since been drilled using the study proposed spatial coordinates (Figure 3) (Rig Release Date: 99- 01-02), meeting its objective of placement within the sweet spot of rock properties for optimal injection results (Figure 4).
Figure 4 3D porosity model with proposed and actual trajectories Using the 3D model of porosity, GR, Permeability and Water Saturation and the Figures 1 & 2, Location Maps proposed designation of the top view of the 310 A Case Study: Successful Horizontal Well Trajectory Planning Using 3D Visualization horizontal well, the proposed trajectory was include Porosity, Gamma Ray, Permeability digitized on the screen and exported to the and Water Saturation. he images here are visualization environment. (Figure 16, at the using 3D seismic structure as a constrained end of this paper) surface. For type logs and cross plot samples refer to Figures 6 and 7.
Initial Results The well has open hole completion from a well length 1905m to 2685m. On cleanup flow prior to injection test the well flowed 89 m3 of oil in 22 hours (97 m3/dor 610 BOPD). Since then it has been converted to a water injector with a stable injection of 230 m3/d (1450 BWPD) at 12000 KPa.
General Reservoir Background -7 Oil Wells and one Horizontal Injector. -Producing on Primary Recovery until the recent waterflood. -Current production 200m3/d oil (1250 BOPD) (Figure 5).
Figure 6 Type logs Figure 5 Reservoir production history -Injection rates at 3-3: stable 230 m3/d (1450 BWPD) at 12000 KPa. On cleanup flow prior to injection test the well flowed 89 m3 of oil in 22 hours (97 m3/dor 610 BOPD). Injection capacity of this horizontal is 3 to 4 times a vertical well. -Original Oil in Place (OOIP): 1774 E3m3 (11.1 MMBO) of 40 AP
