Case Studies
Frac geometry control | ZERO H2S production
cost management | 1% variance between field estimate and actual
perforation optimization | + 96% cluster efficiency
Challenges: H2S sensitive reservoirs; low stress barrier in the upper Bakken shale to contain fractures
Approach: optimize completion design to control frac geometry in desired production zone
Results:
- 2017 project: no H2S production, 15% less water production, wells were in top 10 Bakken producers in 2017
- 2019 project: no H2S production, production outperformed type curves in both Bakken and Three Forks formations
- 2022 project: no H2S production YTD, pending evaluating production performance
perforation optimization | + 96% cluster efficiency
cost management | 1% variance between field estimate and actual
perforation optimization | + 96% cluster efficiency
Challenges: increase reservoir contact without near wellbore diversion; reduce completions cost due to low oil price
Approach: develop extreme limited entry perforation design
Results:
- Achieved more than 96% cluster efficiency, evidenced from radioactive (RA) tracer and Camera results
- Well production performance meets and exceeds type curve expectations
cost management | 1% variance between field estimate and actual
cost management | 1% variance between field estimate and actual
cost management | 1% variance between field estimate and actual
Challenges: variance between field estimate and actual invoice was more than 15% in 2019; low visibility of monthly spending
Approach: build a comprehensive cost model served multi purposes including AFE, budgeting, forecasting and accruing monthly; establish a cost reconciliation process to closely monitor field cost estimate after each pad
Results:
- Reduced the variance between field estimates and actuals in 2021 to less than 1%
- A cost model with high visibility of past, current and future project cost
completions best practices | reduce cycle time by 20%
Utilizing field gas to power the frac fleet in THE bakken
cost management | 1% variance between field estimate and actual
Challenge: reduce well cycle time and completions cost while delivering production performance
Approach: apply best completions practices to increase horsepower efficiency
Results:
- Improved horsepower efficiency by 23%
- Reduced well cycle time by 20%
- Saved $235,000/well completions cost
Utilizing field gas to power the frac fleet in THE bakken
Utilizing field gas to power the frac fleet in THE bakken
Utilizing field gas to power the frac fleet in THE bakken
Challenge: reduce carbon emission during completions phase
Approach: utilize field gas for completions activities
Results: after 11 months of FEED studies, the frac fleet was successfully power on a dual fuel system that combines up to 70% compressed natural gas and 30% diesel. The alternative fuel source is projected to reduce 10,500 tons of carbon emissions annually and save diesel cost significantly.
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Utilizing field gas to power the frac fleet in THE bakken
Utilizing field gas to power the frac fleet in THE bakken
For more detailed case studies of these projects and others, please contact us.