The Eagle Ford Shale Play, South Texas: Regional Variations in Fluid Types, Hydrocarbon Production and Reservoir Properties

Tian, Yao; Ayers, Walter B.; McCain, William D.

doi:10.2523/iptc-16808-ms

Cited by 28 publications

(20 citation statements)

References 3 publications

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“…The Eagle Ford Shale is one of the most prolific source rock plays in the US; it produces oil, gas condensate, and dry gas (Tian et al, 2013). According to Mullen et al (2010), the Eagle Ford Shale has long been known as the source rock for the Austin Chalk, and is currently being developed as a self-sourcing rock.…”

Section: Rock Samplesmentioning

confidence: 99%

Physicochemical Interactions of Source Rocks with Injected Water-Based Fluids

Abdulsattar

Agim

Lane

et al. 2015

Day 2 Tue, April 14, 2015

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Water-based fracturing fluids contain polymers to function either as fluid viscosifiers or friction-reduction agents. Whereas much work has been done on optimizing these functions, little or no published work focuses on their chemical interactions with the rock they are targeting. Co-polymers of polyacrylamide are used in slick-water fracturing, while Guar gum or one of its derivatives is used as a base for linear or cross-linked gels.This thesis reports studies on the adsorption behavior of some, primarily, guar-based polymers onto the surface of source rock outcrop samples in order to provide a better picture of the interactions of polymers with these rocks. Outcrop samples from the Barnett, Eagle Ford, and Marcellus were collected, analyzed for mineralogy and total organic carbon, and then exposed to different polymer solutions under elevated temperature and moderately elevated pressure. Viscosities of these polymer solutions were measured before and after exposing them to the rock in order to establish a correlation between polymer adsorption and the rock mineralogy and organic content. Results indicate that there is a significant correlation between the adsorption behavior of the polymer and the rock mineralogy and its organic carbon. Polymer adsorption is in agreement with cation exchange mechanisms as described in earlier work. Cationic polymers are more prone to be adsorbed on the surface of the rock than non-ionic polymers. The importance of polymer adsorption has not yet been determined. It is speculated that due to viscosity reduction resulting from polymer adsorption, wellbore clean-up could be enhanced through the use of this property. It could also have detrimental impacts on hydrocarbon iii production. This work also shows that oxidizing breakers might be spent on removing the organic content of the rock rather than being spent on breaking cross-linked gels, especially in rocks with high organic content. The results from this work point out that fluid-rock interactions are significant, and that further research regarding source-rock polymer interactions and its effects on hydrocarbon production is needed.iv DEDICATION This thesis is dedicated to my parents, friends, and all those who helped me through thick and thin for the past 26 ½ years.This thesis is also dedicated to my dog Luke, whose loving memory will always be beside me.This thesis is also dedicated to my dog Slash, who is a good boy. v ACKNOWLEDGEMENTS I would like to express my sincere gratitude to both my advisers, Dr. Robert Lane and Dr. Berna Hascakir. Without their constant support, endless revisions of this document, and direction to use specific scientific tools, this work would not have existed.Special thanks are also given to members of the Crisman Institute, whom without their generous funding, this project would not have existed.

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Section: Rock Samplesmentioning

confidence: 99%

Physicochemical Interactions of Source Rocks with Injected Water-Based Fluids

Abdulsattar

Agim

Lane

et al. 2015

Day 2 Tue, April 14, 2015

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“…Gas-condensate production has been reported from wells completed in Eagle Ford [79], Woodford [80], Duvernay [81], and Montney formations [82,83]. Flowback data from lean-gas wells completed in the Woodford formation have shown condensate production after about 10 days of flowback [80].…”

Section: On Phase Behaviors Of Gas-condensate Wellsmentioning

confidence: 99%

The Effect of Temperature on Flowback Data Analysis in Shale Gas Reservoirs: A Simulation-Based Study

Yang

Lai

et al. 2019

Energies

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During hydraulic fracturing, there is a temperature difference between the injected water and formation rock for shale gas wells. The objective of this study is to investigate how this temperature difference changes with time, and how it affects multiphase-flow modeling during the shut-in and flowback periods. We conducted numerical simulations to investigate the behaviors of fracture temperature in shale gas wells. The results show a significant increase in fracture temperature during the shut-in and flowback periods. Sensitivity analysis suggests that this temperature increase is strongly related to the thermal conductivity of formation rock, matrix permeability, and initial reservoir temperature. Simulation scenarios were further compared to investigate the effect of temperature on flowback data analysis. Without considering the thermal effect, flowback data analysis may yield an earlier fracture cleanup and overestimated fracture volume. In addition, this study suggests that the thermal effect may also have implications for optimizing flowback operations.

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“…Due to multistage fracture treatments in shale, natural fractures resource depletion trend is fairly complex. Also, adsorbed gas contributes a significant fraction of total original gas in place (Tian et al, 2013) and its effect on EUR isn't well understood.…”

Section: Decline Curve Analysismentioning

confidence: 99%