Fracturing/pressure pumping
This paper focuses on a replicable, quantitative workflow using completions-process simulation software.
This paper presents a high-fidelity, reservoir-centric stimulation-to-production modeling workflow to prevent fracture-driven interactions.
This work elaborates on recommended practices for calibrating a numerical model to a set of available infill-well field observations.
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Openhole multistage (OHMS) systems are more cost-effective than the cemented casing plug-and-perf (CCPP) techniques for increasing production and reducing development costs. -
This paper presents results from the analysis of the effect of in-fill drilling on parent-well performance, and describes a simplistic approach to understanding the effect of the quest for operational efficiencies and economic cycles on development strategies.
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One of the biggest ways to lower the cost of production from shale would be to identify zones that are productive, or not, before fracturing them.
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A service using pressure data from a few nearby unconventional wells to map fracturing will soon be for sale.
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Two places that illustrate the mounting challenges facing the shale business are the Bakken Shale in North Dakota, where the number of working rigs is one-third what it was a year ago, and the Fayetteville Shale in Arkansas, where there are no more working rigs.
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What is observed when an unconventional well is fractured is often at odds with what was expected by those who planned the job.
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When it comes to hydraulic fracturing, steadiness may not be a virtue. That was the conclusion of a test to see if rapid pump rate variations would lead to greater production than conventionally fractured stages when the pressure was held steady.
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Understanding how much rock is being stimulated and propped is critical for unconventional producers. New imaging methods using electromagnetic energy or acoustic microemitters could represent a milestone in understanding what is left behind after fracturing.
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A refracturing campaign in the Permian yielded a production gain that allowed payback on the investment within 6–12 months.
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The integration of microseismic data with 3D seismic attributes, and well log and completions data is used to understand geomechanical rock properties.
