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 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.

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%).

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

The well saw an immediate increase in gas production, which continually rose over the next 3 months. The average gas production increased from 17 MCF/d to 71 MCF/d in a 3-month comparison, an increase of over 300%.

The well saw an immediate increase in injection rates and a decrease in injection pressure. The average injection rate increased from a 3-month average of 97 b/d to 419 b/d for the first 3 months after BLUESPARK® + Acid.

The well saw an immediate increase in oil production. The average oil production for the first 3 months was 6.4 b/d, an 1180% increase.

Client data from the BLUESPARK® treated well showed over 20x increase in injection rate and 45% reduction in injection pressure. 6 months later this well injects between 60 to 90 bbl/d and pressure is at 4200 kPa.

The client ran back in the wellbore with tubing and discovered that the BLUESPARK® had created 11 feet of fill (in 7 inch casing). An analysis of the fill determined the presence of silica and clay, along with the BaSO4, confirming that the perf tunnels had been cleaned.

BLUESPARK® treated well showed a 52% injection increase 3 months post-stimulation, and 80% injection increase over the longterm.

Significant inflow of oil was produced after the remediation. Client data shows an average oil production of 36.7 b/d over a one-month period (716% increase).

The wells were immediately put back on production and rates, pressures and fluid levels were monitored. The total production for the 5 wells increased by 65% based on a 3-month comparison, while the water cut decreased by 5%.

The post-BLUESPARK® multi-finger caliper confirmed that 100% of scale was removed at a pulsing rate of 60 pulses/ft. Oil production increased from 4.8 b/d to 8.5 b/d when comparing the 3-month pre-BLUESPARK® to 3-month post-BLUESPARK® rates.

Oil production in 3 trial wells was over 4x greater after stimulation (3-month comparison).

The December 2013 well showed an average increase of 100% (17 BOPD) in oil production and 127% (19 MCF/d) in gas production over 5 months since treatment.