Fracturing/pressure pumping
In this third work in a series, the authors conduct transfer-learning validation with a robust real-field data set for hydraulic fracturing design.
This paper describes development of a high-temperature water-based reservoir drill-in fluid using a novel synthetic polymer and customized with optimal chemical concentrations and sized calcium carbonate.
The aim of this study is to incorporate detailed geological, petrophysical, and hydraulic fracturing models to better predict and mitigate the effects of interbench interactions.
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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. -
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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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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A new proppant exhibits a neutrally wet surface, which does not have a preferential affinity for oil, gas, or water and therefore will not promote the preferential entrapment of any phase within the proppant pack.
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Hydraulic fracturing exerts transient geomechanical forces near the wellbore, enabling a brief time interval in which a second hydraulic fracture can be created in a different direction.
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The oil-economy downturn will not affect the areas where research, development, and application of novel technologies are absolutely necessary for the commercialization of hydrocarbon.
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While many factors may influence fracture-height evolution in multilayer formations, the consensus is that the so-called “equilibrium height belonging to a certain treating pressure” provides an upper limit, at least for nonnaturally fractured media.
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A new unconventional proppant technology—a rod-shaped proppant—delivered 25% higher oil per net pay compared with offset wells using conventional proppant.
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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.
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A refracturing campaign in the Permian yielded a production gain that allowed payback on the investment within 6–12 months.
