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.

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.

Blue Spark Energy successfully performed its first Sub-Surface Safety Valve (SSSV) re-activation in the Danish North Sea using our innovative BLUESPARK® technology.

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.

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).