BSI was contracted to mitigate gas traveling through the cemented 13-3/8” x 9-5/8” annulus and up the wellbore via the milled 9-5/8” casing top. A region of poor cement was identified just below the 13-3/8” shoe at 1,600’. The well was prepared by perforating through the 9-5/8” casing at 1,600’, installing 4-1/2” drill pipe to the depth of the bottom perf, and setting a bridge plug just below that.

Two injection stages were run over a 36-hour period.

Pressure was raised incrementally in the 1st stage and reached 1,400 psi around 80 minutes into pumping. Pressure was held steady for the next 120 min, during which the flow rate steadily fell. The well was then shut in at pressure overnight to allow minerals to continue to grow, choking off leakage pathways from the outside in.

Injection resumed the next morning at 1,400 psi, the flow rate experiencing a steady and significant decrease, implying leaks had been successful sealed. Pumping concluded around mid day and the well was shut in at pressure for another 12 hours to ensure all leakage pathways were completely closed.

The flow rate began at 0.252 gpm in the 1st stage and ended at 0.025 gpm at the conclusion of the 2nd stage, with a total of 68 gal injected. This constituted a 90.1% decrease in injectivity, implying significant sealing.