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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The second major deal in the US proppant industry this year will see US Silica go forward as a private company. -
This paper explains how an operator’s projects in the Vaca Muerta have become more-efficient and cost-effective by increasing production and reducing well-delivery-cycle time while fostering the long-term sustainability of the project.
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Despite tens of thousands of potential candidates and the proven upsides, the unconventional industry has largely overlooked refracturing—possibly due to the way it’s discussed.
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The tie between US crude output and key indicators such as rig counts and the number of new wells has significantly weakened.
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High-pressure/high-temperature (HP/HT) resources continue to be a focus of efforts to apply new technologies that maximize productivity while addressing concerns related to capital expenditure, operating expenses, and high drilling costs. These cost-effective technologies will only grow in importance in exploiting HP/HT and ultra-HP/HT fields.
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The authors of this paper propose an artificial-intelligence-assisted work flow that uses machine-learning techniques to identify sweet spots in carbonate reservoirs.
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This paper describes an effort to use multiple technologies to better understand an Arkoma Basin reservoir and the interdisciplinary relationship between the reservoir’s subsurface hazards and a stimulation treatment.
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The main objective of this paper is to investigate the relationship between strain change and pressure change under various fractured reservoir conditions to better estimate conductive fractures and pressure profiles.
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Fracturing companies can’t connect to the electric grid fast enough as they seek to reduce emissions, save costs.
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Permian Basin oil wells produce a lot of water. Much of it is injected into disposal zones above and below the basin’s primary oil- and gas-producing zone. When water is injected into these disposal zones, the pressure increases, mainly because no fluid is concurrently removed. Is this increase in pressure a concern? The data would suggest yes.
