The Town of Lakeview’s geothermal district heating system had decreased 45% in flow rate, resulting in the shutdown of some buildings. The treatment resulted in a 134% increase in rate, allowing all buildings to be operational again.

The salt-water injection well was cleaned of formation damage due to fines and sludge, resulting in an increase in the injection rate of 175% while reducing CO2 emissions. The oil production of the field also increased.

The BaSO4 scale was removed from the sand screens by BLUESPARK®, resulting in an increase in oil production of 175%

The SCSSSV scale was removed by BLUESPARK®, resulting in a successful inflow test and no need for an insert valve

The injection rate increased to as much as 12x the rate before treatment

Removed CaCO3 scale from perforations in a deviated Malaysia well

Removed scale from the wellhead using BLUESPARK®, allowing access into the main wellbore.

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%.