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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  

click here for SPE Journal Paper

Objective: Prove technoeconomic viability

  • Pumped 12,300 barrels surfactant solution

  • Bullhead job with rods/tubing pulled

  • Maintained injection below frac pressure

  • 30 day soak period then returned to production

  • Incremental oil increased significantly after stimulation

  • After 24 mo, oil rate is still 3x the rate expected from hyperbolic fit of pre-stim oil rate data

  • Payout time: 7 months

  • IRR assuming NO further incremental production is 90%

  • Estimated IRR based on fit of post-stim data is 130%

Project 2: Eagle Ford Declined Well 

(click here for Tulsa IOR2024 paper)

Objective: use diverter to increase matrix contact

  • Successful injection with diverter

  • Pumped 11,300 barrels surfactant solution

  • Bullhead with rods/tubing pulled and 11 diverter stages

  • Maintained injection below frac pressure

  • 30 day soak period then returned to production

  • Less rapid response vs. without diverter

  • 2x oil rate vs. pre-stim

  • Estimated IRR based on incremental production is 50%

Case Study 2

IMG_4897_edited.jpg

Case Study 3

Case Study 3 June 2022 EF injections.jpg

Project 3: Six Eagle Ford Declined Well Stimulations in Six Days

Objective:  Test lower volumes for cost optimization

  • Pumped 2,500 barrels surfactant solution per well

  • Bullhead job down annulus (tubing left in place)

  • Maintained injection below frac pressure

  • 20 day soak period then returned to production

  • Incremental oil increased significantly after stimulation on 5 of 6 wells

  • Leveraged pressure impacts of nearby completions for 4 stimulated wells

  • Economically attractive incremental recovery from 5 of 6 wells 

  • $22/bbl incremental cost

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Project 4: Midland Basin Declined Well

Objective: Prove technoeconomic viability in Permian & on 2 mi laterals

  • Pumped 20,000 barrels surfactant solution

  • Bullhead with tubing pulled 

  • Maintained injection below frac pressure

  • 30 day soak period then returned to production

  • Production and analysis in progress

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Other producers have published successful Permian pilots using a similar approach

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click here for successful Chevron study in Permian

Case Study 4

Case Study 4 Midland Basin INjection Site night_edited.jpg
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