Case Studies
Third Wave has been piloting the technology in Eagle Ford since 2020, and more recently in Midland.
Some of the projects and results are highlighted here.
Case Study 1
Project 1: Eagle Ford Declined Well
Objective: Prove technoeconomic viability
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Pumped 12,300 barrels surfactant solution
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Bullhead job with rods/tubing pulled
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Maintained injection below frac pressure
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30 day soak period then returned to production
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Incremental oil increased significantly after stimulation
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After 24 mo, oil rate was still 3x the rate expected from hyperbolic fit of pre-stim oil rate data
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Payout time: 7 months
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IRR > 100%
Project 2: Eagle Ford Declined Well
Objective: use diverter to increase matrix contact
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Successful injection with diverter
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Pumped 11,300 barrels surfactant solution
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Bullhead with rods/tubing pulled and 11 diverter stages
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Maintained injection below frac pressure
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30 day soak period then returned to production
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Less rapid response vs. without diverter
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2x oil rate vs. pre-stim
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Estimated IRR based on incremental production is 50%
Case Study 2
Case Study 3
Project 3: Six Eagle Ford Declined Well Stimulations in Six Days
Objective: Test lower volumes for cost optimization
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Pumped 2,500 barrels surfactant solution per well
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Bullhead job down annulus (tubing left in place)
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Maintained injection below frac pressure
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20 day soak period then returned to production
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Incremental oil increased significantly after stimulation on 5 of 6 wells
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Leveraged pressure impacts of nearby completions for 4 stimulated wells
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Economically attractive incremental recovery from 5 of 6 wells
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$22/bbl incremental cost
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Project 4: Midland Basin Declined Well
Objective: Prove technoeconomic viability in Permian & on 2 mi laterals​
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Bullhead with tubing pulled
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Maintained injection below frac pressure
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30 day soak period then returned to production
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Evidence for undertreatment, project economics not favorable​
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Other producers have published successful Permian pilots using a similar approach
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Case Study 4
Case Study 5
Project 5: Eagle Ford Multiwell Stimulation
Objective: Prove technoeconomic viability of injecting "few" and stimulating "neighbors"
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Injection into 2 wells, with intent to stimulate adjacent wells
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10 day soak period then returned to production
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Evidence for surfactant stimulation of 9 adjacent wells​
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Incremental economics after 8 months are outstanding, payout 2.5 mo, IRR > 200%
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