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.

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

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.

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 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%.

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.

Post BLUESPARK®, oil production increased 173% from 91.8 b/d to 250.9 b/d. Well uptime increased from 11.8% to 67.8%.

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.

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 wellbore was reconnected to the reservoir, as pressures decreased and injection rates increased. Public data from the BLUESPARK® treated well showed an average injection increase from 83 b/d to 289 b/d for 3-months post stimulation.

Oil production more than doubled after the remediation. Client data shows an average increase in oil production of more than 10 STB/ day over a 3- month period (163% increase).

The well immediately produced oil at a higher rate that before being shut-in, but water production was less. The oil production increased from 16.3 bbl/d to 26.9 b/d, comparing 3-month pre- to post-BLUESPARK®.

BLUESPARK® treated well showed an average increase in oil production of 96 b/d over a one month period.

Client data from the BLUESPARK® treated well showed an average production increase from 100m3/day (630 bbl/day) to 800m3/day (5,032 bbl/day) over a one-month period.