Completions
The supermajor would be the second to conduct a hydraulic fracturing pilot project in the country.
Ease of use and crowd-pleasing economics are driving US shale producers toward wet-sand completions. Chesapeake Energy is among the latest converts and explains why it wants to use wet sand on every new well.
The paper describes the operator’s first implementation of fishbone stimulation technology, establishing a precedent for other fishbone candidate wells.
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Is it possible to fracture a well using power off the grid? The answer is yes, but sharp electric engineers are required. -
The two-well stimulation approach is delivering big savings to first adopters. A new report from Rystad highlights how the development is taking shape.
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In striving to boost production of shale gas and tight oil, China is trying enhanced-hydraulic-fracturing technology and real-time data analysis in the Sichuan shale basin. In Daqing’s tight-oil fields, an alternative fracture-completion strategy and post-stimulation flowback technology has been tested.
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Murphy Oil has created a work flow to normalize the tags it uses when collecting data on its hydraulic fracturing stages. The work flow described here empowers decision makers, who no longer wait for hours to collect data or waste hours cleaning and preparing data for analysis.
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The all-stock deal doubled Liberty’s working pressure-pumping capacity without adding any debt to its balance sheet, while Schlumberger retains a 37% equity interest.
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A trio of field studies recently presented at the 2020 SPE Annual Technical Conference and Exhibition highlights in different ways how emerging technology and old-fashioned problem solving are moving the industry needle on proppant and conductivity control.
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An investigation of casing damage led Chesapeake Energy and Well Data Labs to identify patterns in the treating pressure data that are useful markers when trouble is likely.
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With only around 30 installations worldwide, ADNOC’s onshore team has seen enough results from its first “fishbone” stimulation to embark on a 10-well program that will decide a full development scheme.
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The average geothermal gradient in the subject deepwater field in Nigeria is 4.37°C/100 m, nearly twice the gradient in most fields. As a result, the magnitude of the expected annular pressure buildup (APB) during steady-state production is large enough to threaten well integrity.
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The complete paper describes the first implementation of a solution to control fracture height for conventional wells in the Pannonian Basin.
