Removed scale from the upper completion of the wellbore using the BLUESPARK®, treating a 7.5 m (25 ft) interval with an operating time of 6.25 hours.

BLUESPARK® reduced scale by 80 – 100% and saved up to 5 days of operating time and USD $200K. The treatment was completed in one run in less than 14 hours of operating time.

Improved connectivity to the reservoir. Injection zone takes water for the first time in years, a 350% increase in aquifer water production rate.

BLUESPARK® stimulation to improve connectivity to the reservoir by clearing out blockages resulted in a 3x increase in oil production with the job completed in less than 3 days.

A Tubing Retrievable Surface Controlled Subsurface Safety Valve (TRSCSV) was made operational with BLUESPARK® in 3.5 hours, eliminating the need to shut in the well.

Instantaneous reduction in injection pressure by 55%, and an injection rate increase by 1,260% after BlueSpark® treatment.

The mini FHUT was successful in holding a fluid column in the wellbore so that the pulsing was occurring in the required environment. A camera was run before and after the 1st BLUESPARK® run and it confirmed that scale was removed.

After only one treatment of the SPMs with BLUESPARK®, the tractor/stroker tool was able to retrieve both GLVs on the first attempt. For the lower SPM, this was due to the ability of BLUESPARK® to clear scale from the orientation sleeve and complex shapes like the GLV latch.

The aggregate oil production for the first 30-days averaged 324 BOPD, up 970% from the pre-BLUESPARK® aggregate of 30.3 BOPD, including one well (Well #4) that had zero production pre-treatment.

A 60% aggregate increase in oil production for two wells was completed in less than two days.

Well #4 (BLUESPARK® treated well) achieved a quicker and higher ramp up in production. 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.

An increase in control line returns was noted after the first BLUESPARK® run, indicating the flow tube and flapper were reactivated. A successful inflow test was performed on the SSSV after the 2nd run.

All wells saw an immediate increase in oil production. The total oil rate for all 4 wells increased 70% for the first 3 months, while the total water decreased by 25%.

Both wells saw an immediate drop in injection pressure resulting in an increase in injection rate. Step rate tests done immediately after the treatment and after several months confirmed lower pressures and higher injection rates than before the treatment were being maintained.

The 9 wells saw the aggregate oil rate increase from 739 b/d to 1071 b/d (45%). Water cut decreased by 0.5%. Gas increased from 13642 mcf/d to 23421 mcf/d (72%).

BLUESPARK® completely removed 40 ft of calcium carbonate (CaCO3) scale from the inside of tubing in less than 2 days, as confirmed by the caliper log.

The well saw an immediate increase in injectivity. The average 3-month injection rate went from 2.2 b/d to 73.9 b/d (3200% increase).

The SCSSV inflow tests were successful, making the SCSSV compliant and allowing the well to be put back on production. The production of the well was maintained at 3,500 bpd.

The BLUESPARK® tool was deployed through tubing on third-party E-Line and completed in 8 hours.

Blue Spark Energy successfully performed its first scale removal operation on a Side Pocket Mandrel (SPM) with Gas Lift Valve (GLV) in the North Sea using our innovative BLUESPARK® technology.