Eagle Ford Case History: Evaluation of Diversion Techniques to Increase Stimulation Effectiveness

Evans, Shea; Holley, Eric; Dawson, Kirk; Garrison, Nicholas; Montes, Matthew; Preston, Greg; Hudson, Scott E.

doi:10.15530/urtec-2016-2459883

Cited by 20 publications

(2 citation statements)

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“…The Eagle Ford, a Late Cretaceous, marine, organic-rich shale located in the Western Gulf Basin in South Texas, is fossiliferous and interbedded with limestones, carbonaceous siltstones, and pyritic and phosphatic shale . Previous experimental analyses showed that Eagle Ford Shale samples used in this study are carbonate-rich shale with ∼66% calcite and contain quartz (∼26%), kaolinite (∼3%), pyrite (2%), gypsum (% not measured), and organic material (2%). , The images collected by SEM–EDS (Figure ) confirmed the presence of the components described above in the Eagle Ford samples we examined here.…”

Section: Discussionmentioning

confidence: 85%

Initial Laboratory Measurements Probing Hydrogen Interactions with Eagle Ford Shale and Pyrite: Potential Implications for Subsurface Hydrogen Storage

Kim,

Townsley,

Kutchko

et al. 2024

J. Phys. Chem. C

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Hydrogen (H 2 ) has the potential to be a transformative technology as an enabler of a low-carbon future and a promoter of renewable energy. When H 2 is injected and stored in the subsurface, it has the potential to interact with the caprock (usually shale), which overlies and seals the storage reservoir. This study examines the geochemical reactions or changes in surface morphology of Eagle Ford Shale, a proxy for caprock, upon exposure to H 2 at 50 °C and 10.3 MPa. Exposures were also performed with N 2 to provide an experimental control. Scanning electron microscopy with energy dispersive spectroscopy, atomic force microscopy, and optical photothermal-infrared spectroscopy were applied to quantify surface changes on the microscale and nanoscale level. Fluid chemistry changes were monitored by ion chromatography and inductively coupled plasma mass spectrometry. Exposure of Eagle Ford Shale to H 2 gas alone did not result in any chemical alterations to the shale or any changes in the surface morphology. Exposure of Eagle Ford Shale to both H 2 and water as well as N 2 and water resulted in changes to the surface morphology because of gypsum dissolution and reprecipitation, thus indicating that H 2 is not necessary to promote changes. Pure pyrite was the most reactive with H 2 possibly resulting in a reduction to pyrrhotite. These initial studies suggest that the extent of reactions activated by hydrogen with caprock is minor under the temperature and pressure conditions that would represent underground hydrogen storage.

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Section: Discussionmentioning

confidence: 85%

Initial Laboratory Measurements Probing Hydrogen Interactions with Eagle Ford Shale and Pyrite: Potential Implications for Subsurface Hydrogen Storage

Kim,

Townsley,

Kutchko

et al. 2024

J. Phys. Chem. C

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“…Mathieu et al [42] (2013) used DTS and DAS together for a field case study of cementplug-injection completions to analyze the ball-sequestration process and determine leakage between fractured sections based on DTS and DAS waterfall plots, with stronger DAS acoustic signals representing higher inflow during injection to calculate the distribution of fracturing fluid and proppant, and by providing graphs of real-time flow rates of fracture clusters to evaluate the effect of steering-agent application [43]; Sookprasong et al [35] (2014) jointly applied DTS and DAS to monitor different periods of fracture start, stop, dormancy and restart during the fracturing of tight gas wells, estimated the volume distribution of fracturing fluid and proppant in the fracture cluster based on DAS data and evaluated the current fracturing stage by DTS and DAS waterfall-graph bridge-plug-seal quality; however, this algorithm does not take into account the occurrence of fracturingfluid leakage and the calculated fluid distribution has errors. Wheaton et al [44] (2016) performed multi-stage hydraulic fracturing in horizontal shale wells in the Eagle Ford area and visualized the fracture geometry in a 3D fracture model with DTS and DAS data.…”

Section: Monitoring the Distribution Of Fracturing Fluid With Dasmentioning

confidence: 99%

Research Progress of Applying Distributed Fiber Optic Measurement Technology in Hydraulic Fracturing and Production Monitoring

Wang

2022

Energies

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With the exploration and development of unconventional oil and gas resources, downhole environmental monitoring and data-analysis technologies are becoming more and more important. Distributed fiber optic measurement technology, as a new monitoring technology to obtain accurate data, has a wide range of applications in hydraulic fracturing and production monitoring. It mainly includes: distributed fiber optic temperature sensors (DTSs) to monitor gas lift, identify in-flow fluid types, interpret flow profiles and monitor production enhancement operations; distributed fiber optic acoustic sensors (DASs) to monitor low frequency strain and microseismic and hydraulic fracturing operations; and distributed fiber optic stress sensors (DSSs) to characterize fractures in the near-well area, which have been well applied in the field. This paper describes the current application status of DASs and DSSs in hydraulic fracturing and production monitoring, respectively, from the principle of distributed fiber optic measurement technology. It also points out the limitations of these measurement technologies and the direction of future development. Distributed fiber optic measurement technology has been making technical breakthroughs in recent years, providing strong technical support for the development of unconventional oil and gas resources.

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A Literature Review

Li¹,

Karrenbach²,

Ajo‐Franklin³

2021

Geophysical Monograph Series

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Eagle Ford Case History: Evaluation of Diversion Techniques to Increase Stimulation Effectiveness

Cited by 20 publications

References 0 publications

Initial Laboratory Measurements Probing Hydrogen Interactions with Eagle Ford Shale and Pyrite: Potential Implications for Subsurface Hydrogen Storage

Initial Laboratory Measurements Probing Hydrogen Interactions with Eagle Ford Shale and Pyrite: Potential Implications for Subsurface Hydrogen Storage

Research Progress of Applying Distributed Fiber Optic Measurement Technology in Hydraulic Fracturing and Production Monitoring

A Literature Review

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