Faster back to production; rate +90%

Challenge

The client chose Well #4 on a particular pad for treatment with symptoms that included a DP of over 1 MPa, 40% plugging on the steam-throttle-joint (STJ) curve and poor gross production vs DI performance compared to the average. BLUESPARK® was chosen for the treatment as there would be no damage to any completion equipment, maintaining well integrity.

Well Conditions

• Measured depth: 2000 m (6600 ft)
• Clearwater shale

Solution

Improve connectivity to the reservoir by removing CaCO3 scale and clearing out blockages using electro-hydraulic stimulation technology

• Well #4 was cooled by pumping warm water down the liner to cool the wellbore to below 130 °C
• BLUESPARK® 275 tool was conveyed on third-party e-Coil to the toe of the wellbore
• There were 21 distinct intervals of 1.0 m treated as the toolstring was pulled up the wellbore towards the heel
• The field was then switched from CSS to steamflood, and Well #4 was monitored, along with 4 other wells on the same pad that were not treated with BLUESPARK®

Outcome

• Well #4 (BLUESPARK® treated well) achieved a quicker and higher ramp up in production (graphs on reverse side)
• After factoring in flush production and incremental fluid production due to reservoir pressure communication, the client calculated there was an additional 60 m3/d of sustained gross fluid production for Well #4 vs the other wells on the same pad
• Well #4 had a 90% higher rate in the first 3 months vs the other wells ^^, and a 79% higher rate in the 90-120 day post interwell communication established period

^^ Average, not including well #5