Improving Cementing Increases Production, Bakken Shale

Published: 10/07/2019

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Kinetix software simulations of the four isolation and fracturing fluid cases.
Kinetix software simulation for a Bakken Shale well shows that in wells with 70% of stages isolated (top), fracturing fluid migrates behind the casing, redistributing length and height growth for some fractures. This increases risks of reaching unproductive rock, water-saturated zones, or nearby wells as frac hits. Fracturing with 100% isolation (bottom) stimulates the reservoir as designed, improving 3-year oil production up to 22% for the crosslinked fracturing fluid case and 5% for the linear gel fluid case.
Bakken Formation, United States, North America, Onshore
Modeling Assumptions
Completion type Cemented sliding sleeves
Drilling fluid Nonaqueous fluid (NAF)
Distance between frac ports ~290 ft (slight variation across the lateral)
Stage isolation—conventional cementing 70%
Stage isolation—cemented with Fulcrum technology 100%
To assess the effect of stage-to-stage communication in a typical Bakken Shale well, Kinetix reservoir-centric stimulation-to-production software was used to simulate typical 3-year production performance after hydraulic fracturing with crosslinked or linear gel with 70% or 100% of stages isolated.
Products Used