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Texas A&M University
1.
Morales Velasco, Carlos Armando.
Assessment of the Mexican Eagle Ford Shale Oil and Gas Resources.
Degree: MS, Petroleum Engineering, 2013, Texas A&M University
URL: http://hdl.handle.net/1969.1/151355 
► According to the 2011 Energy Information Agency (EIA) global assessment, Mexico ranks 4th in shale gas resources. The Eagle Ford shale is the formation with…
(more)
▼ According to the 2011 Energy Information Agency (EIA) global assessment, Mexico ranks 4th in shale gas resources. The
Eagle Ford shale is the formation with the greatest expectation in Mexico given the success it has had in the US and its liquids-rich zone. Accurate estimation of the resource size and future production, as well as the uncertainties associated with them, is critical for the decision-making process of developing shale oil and gas resources.
The complexity of the shale reservoirs and high variability in its properties generate large uncertainties in the long-term production and recovery factors of these plays. Another source of uncertainty is the limited production history. Given all these uncertainties, a probabilistic decline-curve analysis approach was chosen for this study, given that it is relatively simple, it enables performing a play-wide assessment with available production data and, more importantly, it quantifies the uncertainty in the resource size.
Analog areas in the US
Eagle Ford shale were defined based on available geologic information in both the US and Mexico. The Duong model coupled with a Markov Chain Monte Carlo (MCMC) methodology was used to analyze and forecast production of wells located in the previously defined analog sectors in the US
Eagle Ford shale. By combining the results of individual-well analyses, a type curve and estimated ultimate recovery (EUR) distribution for each of the defined analog sectors was obtained. These distributions were combined with well-spacing assumptions and sector areas to generate the prospective-resources estimates. Similar probabilistic decline-curve-analysis methodology was used to estimate the reserves and contingent resources of existing wells.
As of March 2013, the total prospective resources (P90-P50-P10) for the
Eagle Ford shale in Mexico (MX-EFS) are estimated to be 527-1,139-7,268 MMSTB of oil and 17- 37-217 TSCF of gas. To my knowledge, this is the first oil estimate published for this formation in Mexico. The most attractive sectors based on total estimated resources as well as individual-well type curves are located in the southeast of the Burgos Basin and east-west of the Sabinas basin. Because there has been very little development to date, estimates for reserves and contingent resources are much lower than those for prospective resources. Estimated reserves associated with existing wells and corresponding offset well locations are 18,375-34,722-59,667 MMSCF for gas and zero for oil. Estimated contingent resources are 14-64-228 MSTB of oil and 8,526-13,327- 25,983MMSCF of gas. The results of this work should provide a more reliable assessment of the size and uncertainties of the resources in the Mexican
Eagle Ford shale than previous estimates obtained with less objective methodologies.
Advisors/Committee Members: McVay, Duane (advisor), Lee, John (advisor), Sun, Yuefeng (committee member).
Subjects/Keywords: Eagle Ford shale; Mexico; resources
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APA (6th Edition):
Morales Velasco, C. A. (2013). Assessment of the Mexican Eagle Ford Shale Oil and Gas Resources. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/151355
Chicago Manual of Style (16th Edition):
Morales Velasco, Carlos Armando. “Assessment of the Mexican Eagle Ford Shale Oil and Gas Resources.” 2013. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/151355.
MLA Handbook (7th Edition):
Morales Velasco, Carlos Armando. “Assessment of the Mexican Eagle Ford Shale Oil and Gas Resources.” 2013. Web. 12 Apr 2021.
Vancouver:
Morales Velasco CA. Assessment of the Mexican Eagle Ford Shale Oil and Gas Resources. [Internet] [Masters thesis]. Texas A&M University; 2013. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/151355.
Council of Science Editors:
Morales Velasco CA. Assessment of the Mexican Eagle Ford Shale Oil and Gas Resources. [Masters Thesis]. Texas A&M University; 2013. Available from: http://hdl.handle.net/1969.1/151355
Texas A&M University
2.
Rider, April Marie.
Seismic Modeling of the Eagle Ford — How Do Changes of Geological Facies Affect the Seismic Response?.
Degree: MS, Geophysics, 2018, Texas A&M University
URL: http://hdl.handle.net/1969.1/174022
► This paper utilizes synthetic models of the Eagle Ford to identify how variation of lithological facies across the regional extent of the Eagle Ford affects…
(more)
▼ This paper utilizes synthetic models of the
Eagle Ford to identify how variation of lithological
facies across the regional extent of the
Eagle Ford affects its seismic response. I apply three different
modeling methods at seven different locations across the
Eagle Ford: 1) Linear regression of
petrophysical cross-plots that extrapolate velocity and density log values through calculated brightness
logs treated as gamma ray proxies, 2) synthetic seismograms convolved with 30Hz and 60Hz
Ricker wavelets, and 3) simplified upscaled models derived by an automated log blocking code
based on a Monte Carlo procedure. Results reveal acceptable synthetic seismograms representative
of the geology can be created using unconventional methods. The regional seismic responses
exhibit similar time duration and seismic characters, but the number of cycles within the
Eagle
Ford varies with respect to internal variation and the interpreted boundaries change with respect to
the facies distribution.
Advisors/Committee Members: Gibson , Richard (advisor), Laya , Juan Carlos (committee member), King, Mike (committee member).
Subjects/Keywords: Eagle Ford; Modeling; Upscaling; Synthetics
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APA (6th Edition):
Rider, A. M. (2018). Seismic Modeling of the Eagle Ford — How Do Changes of Geological Facies Affect the Seismic Response?. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/174022
Chicago Manual of Style (16th Edition):
Rider, April Marie. “Seismic Modeling of the Eagle Ford — How Do Changes of Geological Facies Affect the Seismic Response?.” 2018. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/174022.
MLA Handbook (7th Edition):
Rider, April Marie. “Seismic Modeling of the Eagle Ford — How Do Changes of Geological Facies Affect the Seismic Response?.” 2018. Web. 12 Apr 2021.
Vancouver:
Rider AM. Seismic Modeling of the Eagle Ford — How Do Changes of Geological Facies Affect the Seismic Response?. [Internet] [Masters thesis]. Texas A&M University; 2018. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/174022.
Council of Science Editors:
Rider AM. Seismic Modeling of the Eagle Ford — How Do Changes of Geological Facies Affect the Seismic Response?. [Masters Thesis]. Texas A&M University; 2018. Available from: http://hdl.handle.net/1969.1/174022
Texas A&M University
3.
Enriquez Tenorio, Omar.
A Comprehensive Study of the Eagle Ford Shale Fracture Conductivity.
Degree: MS, Petroleum Engineering, 2016, Texas A&M University
URL: http://hdl.handle.net/1969.1/158000
► The aim of this study was to develop an understanding of the Eagle Ford shale unpropped and propped fracture conductivity. Samples were collected at Antonio…
(more)
▼ The aim of this study was to develop an understanding of the
Eagle Ford shale unpropped and propped fracture conductivity. Samples were collected at Antonio Creek and Lozier Canyon. Both outcrops are several hundred feet thick and extend for a few thousand feet laterally. At these locations five different geological facies (A, B, C, D and E), each with distinct lithological characteristics and geochemical properties that can be correlated to the
Eagle Ford shale in the subsurface are accessible. The mineralogy of the collected samples was determined via x-ray diffraction which corroborates the relationship of the samples to the outcrops and hence to the
Eagle Ford shale in the subsurface.
After collected, the samples were cut into modify API conductivity cell dimensions. The fracture conductivity at different closure stresses was determined based on laboratory measurements of flow rate and pressure drops along the fracture. The fluid used in this work was nitrogen. The proppant concentration used is representative of what is commonly used in hydraulic fracturing treatments in the
Eagle Ford shale. The heterogeneity of the
Eagle Ford shale is addressed by obtaining conductivity samples in two different directions with respect to the bedding plane for the five geological facies. Three directions were obtained for facies B.
Fracture area and fracture roughness (surface attributes) were calculated from the data taken by a surface profilometer. The mechanical properties, namely Young’s modulus, Poisson’s ratio and Brinell hardness, were experimentally determined from core plugs acquired from the same rocks where the conductivity samples were obtained. The effect that the surfaces attributes, mechanical properties and geological facies (mineralogy) have on conductivity was analyzed and the major findings of this work are the following.
From this study, we found that fracture orientation has an impact on the fracture conductivity. It was also found that the geological characteristics (mineralogy) and mechanical properties (Poisson’s Ratio) impact the fracture conductivity. The geological facies (lithology) impact the fracture conductivity in
Eagle Ford shale. Facies A, B and C exhibit a good relationship between fracture conductivity and surface attributes (fracture roughness and area). This relationship is not present in facies D and E.
This work provides a foundation for future studies (damage mechanism) of the
Eagle Ford shale fracture conductivity and gives an insight into the relationship of fracture conductivity and geological facies.
Advisors/Committee Members: Zhu, Ding (advisor), Hill, Alfred D (committee member), Pope, Michael (committee member).
Subjects/Keywords: Eagle Ford; fracture conductivity
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APA (6th Edition):
Enriquez Tenorio, O. (2016). A Comprehensive Study of the Eagle Ford Shale Fracture Conductivity. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/158000
Chicago Manual of Style (16th Edition):
Enriquez Tenorio, Omar. “A Comprehensive Study of the Eagle Ford Shale Fracture Conductivity.” 2016. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/158000.
MLA Handbook (7th Edition):
Enriquez Tenorio, Omar. “A Comprehensive Study of the Eagle Ford Shale Fracture Conductivity.” 2016. Web. 12 Apr 2021.
Vancouver:
Enriquez Tenorio O. A Comprehensive Study of the Eagle Ford Shale Fracture Conductivity. [Internet] [Masters thesis]. Texas A&M University; 2016. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/158000.
Council of Science Editors:
Enriquez Tenorio O. A Comprehensive Study of the Eagle Ford Shale Fracture Conductivity. [Masters Thesis]. Texas A&M University; 2016. Available from: http://hdl.handle.net/1969.1/158000
Texas A&M University
4.
Hudson, Ann.
Stratigraphy and Depositional Controls on Source Rock Formation within the Upper Cretaceous (Lower Cemomanian) Maness Shale, Central Texas.
Degree: MS, Geology, 2014, Texas A&M University
URL: http://hdl.handle.net/1969.1/154002
► With the success of the prolific Eagle Ford Shale play in South Texas, there is increasing interest in the resource potential of its equivalent source…
(more)
▼ With the success of the prolific
Eagle Ford Shale play in South Texas, there is increasing interest in the resource potential of its equivalent source rock on the northeast side of the San Marcos Arch. The “
Eagle Ford Shale” northeast of the San Marcos arch is composed of the transgressive lower Cenomanian Maness Shale, which unconformably overlies the Buda Limestone, and the regressive upper Cenomanian Pepper Shale of the Woodbine Group which unconformably underlies the Austin Chalk. This succession has sourced multiple reservoirs within the western portion of the East Texas Basin and is now being evaluated as a potential self-sourced reservoir. In this study we will attempt to determine the depositional controls on the formation of organic-rich source rock within the Maness Shale and divide the interval into chemostratigraphic packages based on whole rock elemental data. The main goals are 1) to build a depositional model within a sequence stratigraphic framework that can be used as a predictive tool to locate the richest source rocks within the basin, and 2) to determine the distribution of source rock facies vertically and laterally across the basin.
The Maness Shale is a mixed carbonate and siliciclastic mudrock which contains overall high TOC and was deposited in an anoxic, low-energy environment. Maximum TOC and carbonate content are found within a condensed section located in the upper portion of the Maness Shale in association with a maximum flooding surface. Paleo-redox elements (Cu, Ni, V, Mo, and U) indicate that maximum levels of anoxia were reached within the condensed section. Carbonate content is thought to be biogenic in origin and is a result of increased productivity within the basin. Increases in productivity also lead to a high amount of organic material being deposited and preserved.
Advisors/Committee Members: Tice, Michael M (advisor), Herbert, Bruce (committee member), Laya, Juan Carlos (committee member).
Subjects/Keywords: statigraphy; paleoenvironment; Eagle Ford; anoxia
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APA (6th Edition):
Hudson, A. (2014). Stratigraphy and Depositional Controls on Source Rock Formation within the Upper Cretaceous (Lower Cemomanian) Maness Shale, Central Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/154002
Chicago Manual of Style (16th Edition):
Hudson, Ann. “Stratigraphy and Depositional Controls on Source Rock Formation within the Upper Cretaceous (Lower Cemomanian) Maness Shale, Central Texas.” 2014. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/154002.
MLA Handbook (7th Edition):
Hudson, Ann. “Stratigraphy and Depositional Controls on Source Rock Formation within the Upper Cretaceous (Lower Cemomanian) Maness Shale, Central Texas.” 2014. Web. 12 Apr 2021.
Vancouver:
Hudson A. Stratigraphy and Depositional Controls on Source Rock Formation within the Upper Cretaceous (Lower Cemomanian) Maness Shale, Central Texas. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/154002.
Council of Science Editors:
Hudson A. Stratigraphy and Depositional Controls on Source Rock Formation within the Upper Cretaceous (Lower Cemomanian) Maness Shale, Central Texas. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/154002
Texas A&M University
5.
Alotaibi, Basel Z S Z J.
Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil.
Degree: MS, Petroleum Engineering, 2014, Texas A&M University
URL: http://hdl.handle.net/1969.1/154009
► In previous works and published literature, production forecast and production decline of unconventional reservoirs were done on a single-well basis. The main objective of previous…
(more)
▼ In previous works and published literature, production forecast and production decline of unconventional reservoirs were done on a single-well basis. The main objective of previous works was to estimate the ultimate recovery of wells or to forecast the decline of wells in order to estimate how many years a well could produce and what the abandonment rate was. Other studies targeted production data analysis to evaluate the completion (hydraulic fracturing) of shale wells.
The purpose of this research is to generate field-wide production forecast of the
Eagle Ford Shale (EFS). This study considered oil production of the EFS only. More than 6 thousand oil wells were put online in the EFS basin between 2008 and December 2013. The method started by generating type curves of producing wells to understand their performance. Based on the type curves, a program was prepared to forecast the oil production of EFS based on different drilling schedules; drilling requirements can be calculated based on the desired production rate. To complement the research, analysis of daily production data from the basin was performed. Moreover, single-well simulations were done to compare results with the analyzed data.
Findings of this study depended on the proposed drilling and developing scenario of EFS. The field showed potential of producing high oil production rate for a long period of time. The three presented forecasted cases gave and indications of the expected field-wide rate that can be witnessed in the near future in EFS.
The method generated by this study is useful for predicting the performance of various unconventional reservoirs for both oil and gas. It can be used as a quick-look tool that can help if numerical reservoir simulations of the whole basin are not yet prepared. In conclusion, this tool can be used to prepare an optimized drilling schedule to reach the required rate of the whole basin.
Advisors/Committee Members: Schechter, David (advisor), Maggard, Bryan (committee member), Sun, Yuefeng (committee member).
Subjects/Keywords: Eagle Ford Shale; Forecast
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APA (6th Edition):
Alotaibi, B. Z. S. Z. J. (2014). Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/154009
Chicago Manual of Style (16th Edition):
Alotaibi, Basel Z S Z J. “Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil.” 2014. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/154009.
MLA Handbook (7th Edition):
Alotaibi, Basel Z S Z J. “Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil.” 2014. Web. 12 Apr 2021.
Vancouver:
Alotaibi BZSZJ. Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/154009.
Council of Science Editors:
Alotaibi BZSZJ. Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/154009
Texas A&M University
6.
Vallabhaneni, Sridharan.
Facies and Stratigraphic Interpretation of the Upper Cretaceous Woodbine-Eagle Ford Interval in Leon, Madison, Grimes and Brazos Counties, Texas.
Degree: MS, Geology, 2016, Texas A&M University
URL: http://hdl.handle.net/1969.1/156901
► The Upper Cretaceous in Texas is a proven prolific hydrocarbon system. The “Eaglebine” in Central Texas, which includes both the Eagle Ford and Woodbine intervals,…
(more)
▼ The Upper Cretaceous in Texas is a proven prolific hydrocarbon system. The “Eaglebine” in Central Texas, which includes both the
Eagle Ford and Woodbine intervals, is an emerging play with promising results. However, stratigraphic architecture in this region is poorly understood when compared to that of the Maverick Basin and East Texas Basin. The objective of this research is to narrow the stratigraphic uncertainties of Woodbine-
Eagle Ford correlation between the East Texas and Maverick Basins and to predict the distribution of sand bodies in the active “Eaglebine” interval in Leon, Madison, Grimes and Brazos Counties by integrating information from available wireline logs and cores. A new stratigraphic interpretation of this region is proposed, and estimates of the petrophysical properties for the potential hydrocarbon-bearing intervals in the study area are presented.
The Buda Limestone-Austin Chalk succession in this study area, which brackets the “Eaglebine”, thins westward due to uplift associated with the San Marcos Arch and erosion at the Base Austin Chalk (BAC) Unconformity. Wireline log interpretation suggests that Woodbine Group sediments, which are dominantly siliciclastic, are a little over 500 feet (152.5) thick updip in Leon County and thin dramatically to fifty feet (15.25 m) thick downdip in Brazos County. This transition records the Woodbine shelf break in Leon-Madison County area. The unconformably overlying Lower
Eagle Ford Formation is relatively thick in Brazos and Grimes Counties. The lower part of the Lower
Eagle Ford Formation is carbonate-rich shale with high gamma ray and formation resistivity. This unit has the potential to be a prolific play in Brazos and Madison Counties. The Upper
Eagle Ford Formation in this region is a mixture of siliciclastic and carbonate sediments. The proportion of carbonate sediments gradually increases upwards to the Base Austin Chalk Unconformity. The sandstones of Upper
Eagle Ford Formation have good hydrocarbon reservoir potential based on their non-shale porosity values and high sand percentage. This study resolves the stratigraphic architecture of the Upper Cretaceous Woodbine-
Eagle Ford interval in the study area and will be helpful in understanding the regional stratigraphy from the East Texas Basin to the Maverick Basin when integrated with seismic data.
Advisors/Committee Members: Olszewski, Thomas D (advisor), Pope, Michael C (advisor), Heidari, Zoya (committee member).
Subjects/Keywords: stratigraphy; Eaglebine; Eagle Ford; Woodbine
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APA (6th Edition):
Vallabhaneni, S. (2016). Facies and Stratigraphic Interpretation of the Upper Cretaceous Woodbine-Eagle Ford Interval in Leon, Madison, Grimes and Brazos Counties, Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/156901
Chicago Manual of Style (16th Edition):
Vallabhaneni, Sridharan. “Facies and Stratigraphic Interpretation of the Upper Cretaceous Woodbine-Eagle Ford Interval in Leon, Madison, Grimes and Brazos Counties, Texas.” 2016. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/156901.
MLA Handbook (7th Edition):
Vallabhaneni, Sridharan. “Facies and Stratigraphic Interpretation of the Upper Cretaceous Woodbine-Eagle Ford Interval in Leon, Madison, Grimes and Brazos Counties, Texas.” 2016. Web. 12 Apr 2021.
Vancouver:
Vallabhaneni S. Facies and Stratigraphic Interpretation of the Upper Cretaceous Woodbine-Eagle Ford Interval in Leon, Madison, Grimes and Brazos Counties, Texas. [Internet] [Masters thesis]. Texas A&M University; 2016. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/156901.
Council of Science Editors:
Vallabhaneni S. Facies and Stratigraphic Interpretation of the Upper Cretaceous Woodbine-Eagle Ford Interval in Leon, Madison, Grimes and Brazos Counties, Texas. [Masters Thesis]. Texas A&M University; 2016. Available from: http://hdl.handle.net/1969.1/156901
University of Manchester
7.
Mcallister, Richard.
Diagenetic modifications of the Eagle Ford Formation : implications on chemical and physical properties.
Degree: PhD, 2017, University of Manchester
URL: https://www.research.manchester.ac.uk/portal/en/theses/diagenetic-modifications-of-the-eagle-ford-formation-implications-on-chemical-and-physical-properties(d4f35b0c-1ee9-4466-8e26-16fd05289aca).html
;
https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.727964
► This thesis investigates the impacts of diagenesis on the Late-Cretaceous Eagle Ford Formation (Fmn) in south-west Texas. This was achieved utilising many techniques such as…
(more)
▼ This thesis investigates the impacts of diagenesis on the Late-Cretaceous Eagle Ford Formation (Fmn) in south-west Texas. This was achieved utilising many techniques such as of outcrop and core analysis, standard petrographic techniques (including cathodoluminescence [CL] and scanning electron microscopy [SEM]), and geochemical analysis (x-ray diffraction [XRD], stable isotope analysis of C and O within inorganic minerals and Rock Eval pyrolysis). The bulk of diagenetic products and textures were identified via petrographic techniques, with geochemical analysis confirming interpretations based on visual observations. This thesis shows the Eagle Ford Fmn is a calcareous, organic-rich mudstone containing eight distinct lithofacies, which have all been directly impacted by burial diagenesis. The Lower Eagle Ford Fmn mainly comprises of dark organic and clay-rich lithofacies which represent a classic source rock with interbedded carbonate rich lithofacies. The Upper Eagle Ford Fmn is organic and clay-poor, with the bulk of lithofacies carbonate dominated and heavily cemented. An initial anoxic, open marine depositional environment which transitions into an oxic deepening environment is inferred during deposition of the Eagle Ford Fmn. Early, microbial derived redox reactions have precipitated authigenic calcite and pyrite within the Eagle Ford Fmn. Authigenic calcite infills and preserves biogenic debris (mainly planktonic and benthic foraminifera), with pyrite framboids post-dating the carbonate cements. Kaolinite infilling biogenic debris is also a common occurrence indicating it is also an early diagenetic product. Smectite is converted to mixed layer I/Sand illite during deep burial processes at similar depths and temperatures to hydrocarbon generation and expulsion. Authigenic quartz cements precipitate within primary porosity and on top of carbonate cements. Chlorite is observed as the last mineral precipitated in the Eagle Ford Fmn, often pseudomorphed from kaolinite within the micritic matrix. Diagenesis has had the greatest impact on porosity distribution in the Eagle Ford Fmn. The organic, clay-rich lithofacies contain little intra/inter-crystalline porosity with the bulk observed as clay-held or organic porosity. Meanwhile the carbonate-rich lithofacies contain mainly intra-crystalline porosity. Concretions are a common feature observed in the Lower Eagle Ford Fmn outcrops. Four concretion types were identified and studied using a variety of petrological and geochemical techniques. Diagenesis plays a major role in all concretions types. However, primary factors such as sea level fluctuation, sediment input and tectonic activity also have key impacts on the formation of concretions.
Subjects/Keywords: 552; Eagle Ford Formation; Diagenesis
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APA (6th Edition):
Mcallister, R. (2017). Diagenetic modifications of the Eagle Ford Formation : implications on chemical and physical properties. (Doctoral Dissertation). University of Manchester. Retrieved from https://www.research.manchester.ac.uk/portal/en/theses/diagenetic-modifications-of-the-eagle-ford-formation-implications-on-chemical-and-physical-properties(d4f35b0c-1ee9-4466-8e26-16fd05289aca).html ; https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.727964
Chicago Manual of Style (16th Edition):
Mcallister, Richard. “Diagenetic modifications of the Eagle Ford Formation : implications on chemical and physical properties.” 2017. Doctoral Dissertation, University of Manchester. Accessed April 12, 2021.
https://www.research.manchester.ac.uk/portal/en/theses/diagenetic-modifications-of-the-eagle-ford-formation-implications-on-chemical-and-physical-properties(d4f35b0c-1ee9-4466-8e26-16fd05289aca).html ; https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.727964.
MLA Handbook (7th Edition):
Mcallister, Richard. “Diagenetic modifications of the Eagle Ford Formation : implications on chemical and physical properties.” 2017. Web. 12 Apr 2021.
Vancouver:
Mcallister R. Diagenetic modifications of the Eagle Ford Formation : implications on chemical and physical properties. [Internet] [Doctoral dissertation]. University of Manchester; 2017. [cited 2021 Apr 12].
Available from: https://www.research.manchester.ac.uk/portal/en/theses/diagenetic-modifications-of-the-eagle-ford-formation-implications-on-chemical-and-physical-properties(d4f35b0c-1ee9-4466-8e26-16fd05289aca).html ; https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.727964.
Council of Science Editors:
Mcallister R. Diagenetic modifications of the Eagle Ford Formation : implications on chemical and physical properties. [Doctoral Dissertation]. University of Manchester; 2017. Available from: https://www.research.manchester.ac.uk/portal/en/theses/diagenetic-modifications-of-the-eagle-ford-formation-implications-on-chemical-and-physical-properties(d4f35b0c-1ee9-4466-8e26-16fd05289aca).html ; https://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.727964
University of Manchester
8.
Mcallister, Richard Thomas.
Diagenetic Modifications of The Eagle Ford Formation:
Implications on Chemical and Physical Properties.
Degree: 2017, University of Manchester
URL: http://www.manchester.ac.uk/escholar/uk-ac-man-scw:307172
► This thesis investigates the impacts of diagenesis on the Late-Cretaceous Eagle FordFormation (Fmn) in south-west Texas. This was achieved utilising many techniques suchas of outcrop…
(more)
▼ This thesis investigates the impacts of diagenesis
on the Late-Cretaceous
Eagle FordFormation (Fmn) in south-west
Texas. This was achieved utilising many techniques suchas of
outcrop and core analysis, standard petrographic techniques
(includingcathodoluminescence [CL] and scanning electron microscopy
[SEM]), and geochemicalanalysis (x-ray diffraction [XRD], stable
isotope analysis of C and O within inorganicminerals and Rock Eval
pyrolysis). The bulk of diagenetic products and textures
wereidentified via petrographic techniques, with geochemical
analysis confirminginterpretations based on visual
observations.This thesis shows the
Eagle Ford Fmn is a calcareous,
organic-rich mudstone containingeight distinct lithofacies, which
have all been directly impacted by burial diagenesis. TheLower
Eagle Ford Fmn mainly comprises of dark organic and clay-rich
lithofacies whichrepresent a classic source rock with interbedded
carbonate rich lithofacies. The UpperEagle
Ford Fmn is organic and
clay-poor, with the bulk of lithofacies carbonate dominatedand
heavily cemented. An initial anoxic, open marine depositional
environment whichtransitions into an oxic deepening environment is
inferred during deposition of the EagleFord Fmn.Early, microbial
derived redox reactions have precipitated authigenic calcite and
pyritewithin the
Eagle Ford Fmn. Authigenic calcite infills and
preserves biogenic debris(mainly planktonic and benthic
foraminifera), with pyrite framboids post-dating thecarbonate
cements. Kaolinite infilling biogenic debris is also a common
occurrenceindicating it is also an early diagenetic product.
Smectite is converted to mixed layer I/Sand illite during deep
burial processes at similar depths and temperatures to
hydrocarbongeneration and expulsion. Authigenic quartz cements
precipitate within primary porosityand on top of carbonate cements.
Chlorite is observed as the last mineral precipitated in theEagle
Ford Fmn, often pseudomorphed from kaolinite within the micritic
matrix.Diagenesis has had the greatest impact on porosity
distribution in the
Eagle Ford Fmn. Theorganic, clay-rich
lithofacies contain little intra/inter-crystalline porosity with
the bulkobserved as clay-held or organic porosity. Meanwhile the
carbonate-rich lithofaciescontain mainly intra-crystalline
porosity.Concretions are a common feature observed in the Lower
Eagle Ford Fmn outcrops. Fourconcretion types were identified and
studied using a variety of petrological andgeochemical techniques.
Diagenesis plays a major role in all concretions types.
However,primary factors such as sea level fluctuation, sediment
input and tectonic activity also havekey impacts on the formation
of concretions.
Advisors/Committee Members: HOLLIS, CATHERINE C, Taylor, Kevin, Hollis, Catherine.
Subjects/Keywords: Eagle Ford Formation; Diagenesis
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APA (6th Edition):
Mcallister, R. T. (2017). Diagenetic Modifications of The Eagle Ford Formation:
Implications on Chemical and Physical Properties. (Doctoral Dissertation). University of Manchester. Retrieved from http://www.manchester.ac.uk/escholar/uk-ac-man-scw:307172
Chicago Manual of Style (16th Edition):
Mcallister, Richard Thomas. “Diagenetic Modifications of The Eagle Ford Formation:
Implications on Chemical and Physical Properties.” 2017. Doctoral Dissertation, University of Manchester. Accessed April 12, 2021.
http://www.manchester.ac.uk/escholar/uk-ac-man-scw:307172.
MLA Handbook (7th Edition):
Mcallister, Richard Thomas. “Diagenetic Modifications of The Eagle Ford Formation:
Implications on Chemical and Physical Properties.” 2017. Web. 12 Apr 2021.
Vancouver:
Mcallister RT. Diagenetic Modifications of The Eagle Ford Formation:
Implications on Chemical and Physical Properties. [Internet] [Doctoral dissertation]. University of Manchester; 2017. [cited 2021 Apr 12].
Available from: http://www.manchester.ac.uk/escholar/uk-ac-man-scw:307172.
Council of Science Editors:
Mcallister RT. Diagenetic Modifications of The Eagle Ford Formation:
Implications on Chemical and Physical Properties. [Doctoral Dissertation]. University of Manchester; 2017. Available from: http://www.manchester.ac.uk/escholar/uk-ac-man-scw:307172
University of Texas – Austin
9.
-5687-4917.
Lessons learned in the Eagle Ford play and applicability to Mexico.
Degree: MA, Energy and Earth Resources, 2015, University of Texas – Austin
URL: http://hdl.handle.net/2152/32872
► Mexico’s oil and gas production decline from conventional reservoirs calls for the assessment of their Late Cenomanian-Turonian shale resources. However, a geological screening of the…
(more)
▼ Mexico’s oil and gas production decline from conventional reservoirs calls for the assessment of their Late Cenomanian-Turonian shale resources. However, a geological screening of the Texas Gulf coast and east and northeast Mexico indicates that their distinct paleogeographic and tectonic development preclude a straightforward correlation between the Upper Cretaceous
Eagle Ford Group of Texas and equivalent formations in Mexico. In Texas, east of the Frio River Line, extensional tectonics prevailed during the Mesozoic-Cenozoic; while in Mexico compressional tectonics influenced sedimentation from the late Cenomanian through the Eocene. Late Cenomanian compression led to paleobathymetry variations that may have influenced the lithology, distribution, and thickness of the lower organic-rich interval of the
Eagle Ford Group, as well as the uplift of a western landmass that was a source of detrital argillaceous sediments. Laramide orogeny produced the exhumation of the late Cenomanian-Turonian section in most of the eastern part of Mexico, and its burial in foreland basins below Cenozoic sediments with contrasting thickness. Therefore, uplift and loading burial impacted critical depth-dependent factors such as thermal maturation, pore pressure, and viscosity. Hence, in east and northeast Mexico four areas have geological and geotechnical characteristics to be potential sweet spots in the
Eagle Ford trend. The areas are the Sabinas Coal Basin, the western part of the Burgos Basin, the southwestern part of the Maverick Basin, and the southwestern part of the Tampico-Misantla Basin. Each area may be an opportunity to ensure Mexico´s energy mix and offset the declining production; nevertheless, these areas present significant technical, operational, and public challenges such as water shortage or mismanagement, insufficient road and pipeline infrastructure, and the ability to deal with people with strong cultures and social roots. Once the geologic and engineering data extracted from the appraisal wells permit the understanding of the economic potential of the sweet spots, supply chains may develop around a Northeastern Hub embracing the Burgos, Maverick, and Sabinas Coal Basins, and an Eastern Hub, including the Tampico-Misantla Basin. High-quality project management and decision-making process based on economic and scientific facts may permit a fruitful learning curve.
Advisors/Committee Members: Tinker, Scott W. (Scott Wheeler) (advisor), Gülen, Gürcan (advisor), Hammes, Ursula (committee member).
Subjects/Keywords: Eagle Ford; Mexico; Shale resources
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APA (6th Edition):
-5687-4917. (2015). Lessons learned in the Eagle Ford play and applicability to Mexico. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/32872
Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete
Chicago Manual of Style (16th Edition):
-5687-4917. “Lessons learned in the Eagle Ford play and applicability to Mexico.” 2015. Masters Thesis, University of Texas – Austin. Accessed April 12, 2021.
http://hdl.handle.net/2152/32872.
Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete
MLA Handbook (7th Edition):
-5687-4917. “Lessons learned in the Eagle Ford play and applicability to Mexico.” 2015. Web. 12 Apr 2021.
Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete
Vancouver:
-5687-4917. Lessons learned in the Eagle Ford play and applicability to Mexico. [Internet] [Masters thesis]. University of Texas – Austin; 2015. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/2152/32872.
Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete
Council of Science Editors:
-5687-4917. Lessons learned in the Eagle Ford play and applicability to Mexico. [Masters Thesis]. University of Texas – Austin; 2015. Available from: http://hdl.handle.net/2152/32872
Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete
Texas A&M University
10.
Guzek, James J.
Fracture Conductivity of the Eagle Ford Shale.
Degree: MS, Petroleum Engineering, 2014, Texas A&M University
URL: http://hdl.handle.net/1969.1/153302
► Hydraulic fracturing is a well completions technique that induces a network of flow channels in a reservoir. These channels are characterized by fracture conductivity, a…
(more)
▼ Hydraulic fracturing is a well completions technique that induces a network of flow channels in a reservoir. These channels are characterized by fracture conductivity, a measure of how easily a liquid or gas flows through the fracture. Fracture conductivity is influenced by several variables including fracture surface roughness, fracture closure stress, proppant size, and proppant concentration. The proppant concentration within a fracture can significantly affect the magnitude of fracture conductivity, which enhances the productivity of a hydraulically fractured well. Therefore, understanding the relationship between proppant concentration and fracture conductivity is critical to the successful development of unconventional reservoirs such as the
Eagle Ford Shale.
This work investigates the fracture conductivities of seven
Eagle Ford Shale samples collected from an outcrop of facies B. Rough fractures were induced in the samples and laboratory experiments that closely followed the API RP-61 procedure were conducted on the samples to measure the unpropped and propped conductivities. Propped experiments were performed with 30/50 mesh white sand at two different areal concentrations within the fracture, 0.1 lb/ft^(2) and 0.2 lb/ft^(2). Assuming a cubical packing arrangement, the proppant pack is calculated to be a partial monolayer of 0.8 layers at 0.1 lb/ft^(2) and a pack of 1.6 layers at 0.2 lb/ft^(2).
The results show that when the fractures are propped with 0.1 lb/ft^(2) or 0.2 lb/ft^(2), fracture conductivity values are approximately two orders of magnitude greater than unpropped conductivity values. Therefore, even low areal concentrations of proppant in a fracture can significantly enhance conductivity in the
Eagle Ford Shale. Comparing the results of the two propped experiment types, conductivity values at 0.1 lb/ft^(2) proppant concentration are on average 49% higher than conductivity values at 0.2 lb/ft^(2). This difference is attributed to the partial monolayer pack at 0.1 lb/ft^(2) and proppant pack of 1.6 layers at 0.2 lb/ft^(2). However as closure stress increases from 1,000 psi to 6,000 psi, fracture conductivity at 0.2 lb/ft^(2) decreases more slowly than conductivity at 0.1 lb/ft^(2). These results suggest that the conductivity of the denser proppant pack at 0.2 lb/ft^(2) is more resistant to the flow inhibiting effects caused by proppant embedment and proppant crushing.
Advisors/Committee Members: Hill, A. Daniel (advisor), Zhu, Ding (committee member), Pope, Michael C (committee member).
Subjects/Keywords: Eagle Ford Shale; fracture conductivity; proppant
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APA (6th Edition):
Guzek, J. J. (2014). Fracture Conductivity of the Eagle Ford Shale. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/153302
Chicago Manual of Style (16th Edition):
Guzek, James J. “Fracture Conductivity of the Eagle Ford Shale.” 2014. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/153302.
MLA Handbook (7th Edition):
Guzek, James J. “Fracture Conductivity of the Eagle Ford Shale.” 2014. Web. 12 Apr 2021.
Vancouver:
Guzek JJ. Fracture Conductivity of the Eagle Ford Shale. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/153302.
Council of Science Editors:
Guzek JJ. Fracture Conductivity of the Eagle Ford Shale. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/153302
Texas A&M University
11.
Jansen, Timothy A.
The Effect of Rock Properties on Hydraulic Fracture Conductivity in the Eagle Ford and Fayetteville Shales.
Degree: MS, Petroleum Engineering, 2014, Texas A&M University
URL: http://hdl.handle.net/1969.1/153882
► Hydraulic fracture treatments are used in low permeability shale reservoirs in order to provide highly conductive pathways from the reservoir to the wellbore. The success…
(more)
▼ Hydraulic fracture treatments are used in low permeability shale reservoirs in order to provide highly conductive pathways from the reservoir to the wellbore. The success of these treatments is highly reliant on the created fracture conductivity. Optimizing fracture designs to improve well performance requires knowledge of how fracture conductivity is affected by rock and proppant characteristics.
This study investigates the relationship between rock characteristics and laboratory measurements of propped and unpropped fracture conductivity of outcrop samples. These samples are from the
Eagle Ford shale and the Fayetteville shale. Triaxial compression tests were performed on core specimens in order to determine the Young’s Modulus and Poisson’s Ratio of the outcrop samples. A combination of X-ray diffraction and Fourier transform infrared spectroscopy was used to determine the mineralogy. Profilometer surface scans were also performed to characterize the fracture topography.
The results from this study show that the main factors affecting fracture conductivity are closure stress and proppant characteristics (concentration, size, and strength). For unpropped fractures, the fracture topography is the main factor in determining fracture conductivity. The topography interaction of the two surfaces determines the fracture width. A higher Young’s Modulus helps maintain this fracture width by resisting deformation as closure stress increases. For propped fractures, the most influential factor in determining fracture conductivity is proppant characteristics (concentration, size, and strength). At a proppant monolayer
placement, the major mechanism for conductivity loss is proppant embedment, leading to decreased fracture width. A higher Young’s Modulus reduces the proppant embedment and better maintains fracture conductivity as closure stress increases. For a multilayer proppant
pack concentration, the effect of rock characteristics is negligible compared to the effect of proppant pack characteristics.
Advisors/Committee Members: Zhu, Ding (advisor), Hill, A. Daniel (committee member), Chester, Fredrick M (committee member).
Subjects/Keywords: Fracture Conductivity; Eagle Ford; Fayetteville; Hydraulic Fracturing
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APA ·
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Export
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APA (6th Edition):
Jansen, T. A. (2014). The Effect of Rock Properties on Hydraulic Fracture Conductivity in the Eagle Ford and Fayetteville Shales. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/153882
Chicago Manual of Style (16th Edition):
Jansen, Timothy A. “The Effect of Rock Properties on Hydraulic Fracture Conductivity in the Eagle Ford and Fayetteville Shales.” 2014. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/153882.
MLA Handbook (7th Edition):
Jansen, Timothy A. “The Effect of Rock Properties on Hydraulic Fracture Conductivity in the Eagle Ford and Fayetteville Shales.” 2014. Web. 12 Apr 2021.
Vancouver:
Jansen TA. The Effect of Rock Properties on Hydraulic Fracture Conductivity in the Eagle Ford and Fayetteville Shales. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/153882.
Council of Science Editors:
Jansen TA. The Effect of Rock Properties on Hydraulic Fracture Conductivity in the Eagle Ford and Fayetteville Shales. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/153882
Colorado School of Mines
12.
Schaiberger, Allison.
Diagenesis in the Upper Cretaceous Eagle Ford shale, south Texas.
Degree: MS(M.S.), Geology and Geological Engineering, 2016, Colorado School of Mines
URL: http://hdl.handle.net/11124/170437
► This study utilizes three cores provided by Devon Energy from LaVaca and Dewitt Counties, TX, which were analyzed with a focus on diagenetic fabrics within…
(more)
▼ This study utilizes three cores provided by Devon Energy from LaVaca and Dewitt Counties, TX, which were analyzed with a focus on diagenetic fabrics within the Lower
Eagle Ford. A better understanding of paragenesis within the organic-rich Lower
Eagle Ford was developed with the use of XRF and XRD measurements, thin section samples, stable isotope analysis, and CL analysis. The majority of diagenetic alteration occurred early at shallow depths within anoxic/suboxic environments and slightly sulfate-reducing conditions from diagenetic fluids with varying isotopic composition. Diagenetic expression variation is most influenced by the depositional facies in which alteration occurs. Within the study area, four identified depositional facies (A-D), and five diagenetic facies (1-5) were identified within the Lower
Eagle Ford study area based on recrystallization, crystalline growth pattern, and elemental composition. Four of these facies were determined to significantly alter the character of the rock through recrystallization. The majority of recrystallized forms within the Lower
Eagle Ford are expressions of pervasive growth recrystallization occurring within foraminifera-rich layers. Elemental analyses of these pervasive forms indicates that foraminifera-rich beds that underwent recrystallization contain abundant clays (indicated by relatively high Al) that can be correlated to the diagenetic expression. Early diagenesis preserved foraminifera tests, but multiple phases of diagenesis are apparent in these recrystallized forms where clays served as the conduit for diagenetic fluids. Stable isotope values ranging from δ
13 C (-7 to+2 ‰) and δ
18 O ranges of (-5.25 to -2.25 ‰), depleted from organic carbon in samples, indicate a range of isotopic composition with possible mixed marine influence and varying degrees of water-rock interaction. Other diagenetic facies that occurred predominantly within the Pepper Formation exhibit dense recrystallized calcite seams identified as calcite beef, and cone-in-cone structures. Crystalline structures within these digenetic facies exhibit cone-in-cone and fibrous form where clays and organic matter occur adjacent to seams and at rims of calcite blades. Clay positioning could indicate clay was mobile during recrystallization. Stable isotopes for calcite beef and cone-in-cone structures range from δ
13 C of (-3 to 1 ‰) and δ
18 O of (-4.40 to -3.35 ‰). These values indicate a different diagenetic history from pervasive recrystallized forms. The cone-in-cone and calcite beef diagenetic fabrics may have formed through a physical diagenetic process occurring either during early or late diagenesis including displacive recrystallization, or crack-seal/ parallel expansion seams.
Advisors/Committee Members: Sonnenberg, Stephen A. (advisor), French, Marsha (committee member), Hull, David (committee member).
Subjects/Keywords: Lower Eagle Ford; diagenesis; Upper Cretaceous
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Export
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APA (6th Edition):
Schaiberger, A. (2016). Diagenesis in the Upper Cretaceous Eagle Ford shale, south Texas. (Masters Thesis). Colorado School of Mines. Retrieved from http://hdl.handle.net/11124/170437
Chicago Manual of Style (16th Edition):
Schaiberger, Allison. “Diagenesis in the Upper Cretaceous Eagle Ford shale, south Texas.” 2016. Masters Thesis, Colorado School of Mines. Accessed April 12, 2021.
http://hdl.handle.net/11124/170437.
MLA Handbook (7th Edition):
Schaiberger, Allison. “Diagenesis in the Upper Cretaceous Eagle Ford shale, south Texas.” 2016. Web. 12 Apr 2021.
Vancouver:
Schaiberger A. Diagenesis in the Upper Cretaceous Eagle Ford shale, south Texas. [Internet] [Masters thesis]. Colorado School of Mines; 2016. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/11124/170437.
Council of Science Editors:
Schaiberger A. Diagenesis in the Upper Cretaceous Eagle Ford shale, south Texas. [Masters Thesis]. Colorado School of Mines; 2016. Available from: http://hdl.handle.net/11124/170437
Colorado School of Mines
13.
Tuppen, Charles Adam.
Nine-component seismic amplitude inversion: a case study in the Eagle Ford shale.
Degree: MS(M.S.), Geophysics, 2019, Colorado School of Mines
URL: http://hdl.handle.net/11124/173298
► Over the last decade, unconventional hydrocarbon resources have led the United States to a spot atop the list of largest oil producers in the world.…
(more)
▼ Over the last decade, unconventional hydrocarbon resources have led the United States to a spot atop the list of largest oil producers in the world. During this time, major improvements in both technology and the general knowledge of shale reservoirs have driven down production costs while improving oil and gas recovery rates. The Reservoir Characterization Project (RCP) Phase XVII work seeks to further these advancements through a study of the value of time-lapse datasets and advanced reservoir characterization methods in the
Eagle Ford Shale of South Texas, one of the most prolific unconventional plays in the world. RCP's project involves the analysis of various geophysical, geological, and engineering datasets sampling an approximately 50-square-mile study area of the
Eagle Ford play. The available geophysical data includes time-lapse, multicomponent seismic data and vertical seismic profiles, along with microseismic event monitoring during hydraulic fracturing. The work presented in this thesis seeks to study the value of the nine-component surface seismic data for seismic amplitude variation with offset/angle (AVO/AVA) inversion and reservoir characterization. The vast majority of seismic datasets utilized in the oil and gas industry are single-component P-wave (PP) surveys. Nine-component surveys, which include converted wave (PS) data and pure-shear (SS) data, are rarely acquired due to the added costs and complexity of acquisition, processing, and interpretation. However, a better understanding of the additional information available in these datasets could be useful for determining whether or not these acquisitions are worthwhile. My analysis begins with their theoretical value for seismic inversion, which aims to recover P-impedance, S-impedance, and density models from recorded seismic amplitudes. Based on linearized approximations of the Zoeppritz equations, which describe the AVA of each data type, I determine that the PP data alone can provide accurate estimates of P-impedance; however, S-impedance and density are poorly constrained. The AVA equations suggest that PS data should improve estimates of S-impedance, but that SS data are likely necessary to obtain the critically important density term. These hypotheses are tested and confirmed through inversions of synthetic seismograms modeled from well log values, but with varying elastic parameters within the reservoir. The synthetic data are also used for comparison and quality control of the field data. After conditioning the field data, most notably through the removal of unrealistic lateral amplitude variations, four inversion methods are applied using a commercial software package: poststack PP, poststack SS (TT component), prestack PP, and joint prestack PP-PS. Inversion parameters are extensively tested to optimize results, and their effects are discussed along with some of the potential drawbacks of the methods applied. Comparing the inversion outputs shows that the joint inversion method produces the best results to utilize for further analysis…
Advisors/Committee Members: Simmons, James (advisor), Shragge, Jeffrey (committee member), Tura, Ali (committee member), Prasad, Manika (committee member).
Subjects/Keywords: Eagle Ford; multicomponent; SS; inversion; AVO; seismic
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Export
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APA (6th Edition):
Tuppen, C. A. (2019). Nine-component seismic amplitude inversion: a case study in the Eagle Ford shale. (Masters Thesis). Colorado School of Mines. Retrieved from http://hdl.handle.net/11124/173298
Chicago Manual of Style (16th Edition):
Tuppen, Charles Adam. “Nine-component seismic amplitude inversion: a case study in the Eagle Ford shale.” 2019. Masters Thesis, Colorado School of Mines. Accessed April 12, 2021.
http://hdl.handle.net/11124/173298.
MLA Handbook (7th Edition):
Tuppen, Charles Adam. “Nine-component seismic amplitude inversion: a case study in the Eagle Ford shale.” 2019. Web. 12 Apr 2021.
Vancouver:
Tuppen CA. Nine-component seismic amplitude inversion: a case study in the Eagle Ford shale. [Internet] [Masters thesis]. Colorado School of Mines; 2019. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/11124/173298.
Council of Science Editors:
Tuppen CA. Nine-component seismic amplitude inversion: a case study in the Eagle Ford shale. [Masters Thesis]. Colorado School of Mines; 2019. Available from: http://hdl.handle.net/11124/173298
14.
Wenzel, Cortney.
A Case Study - Hydraulic Fracturing Geography: The case of the Eagle Ford Shale, TX, USA.
Degree: 2013
URL: http://hdl.handle.net/2249.1/62601
Subjects/Keywords: Hydraulic Fracturing; Eagle Ford Shale
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APA ·
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Export
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APA (6th Edition):
Wenzel, C. (2013). A Case Study - Hydraulic Fracturing Geography: The case of the Eagle Ford Shale, TX, USA. (Thesis). [No school.] Retrieved from http://hdl.handle.net/2249.1/62601
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
No school.
Chicago Manual of Style (16th Edition):
Wenzel, Cortney. “A Case Study - Hydraulic Fracturing Geography: The case of the Eagle Ford Shale, TX, USA.” 2013. Thesis, [No school]. Accessed April 12, 2021.
http://hdl.handle.net/2249.1/62601.
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
No school.
MLA Handbook (7th Edition):
Wenzel, Cortney. “A Case Study - Hydraulic Fracturing Geography: The case of the Eagle Ford Shale, TX, USA.” 2013. Web. 12 Apr 2021.
Vancouver:
Wenzel C. A Case Study - Hydraulic Fracturing Geography: The case of the Eagle Ford Shale, TX, USA. [Internet] [Thesis]. [No school]; 2013. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/2249.1/62601.
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
No school.
Council of Science Editors:
Wenzel C. A Case Study - Hydraulic Fracturing Geography: The case of the Eagle Ford Shale, TX, USA. [Thesis]. [No school]; 2013. Available from: http://hdl.handle.net/2249.1/62601
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
No school.
Texas A&M University
15.
Gardner, Rand D.
Lateral Continuity of the Eagle Ford Group Strata in Lozier Canyon and Antonio Creek, Terrell County, Texas.
Degree: MS, Geology, 2013, Texas A&M University
URL: http://hdl.handle.net/1969.1/151670
► Understanding of the local lateral heterogeneity within the Eagle Ford Group, a prolific mudstone reservoir on the Texas Gulf Coast, is hindered by a lack…
(more)
▼ Understanding of the local lateral heterogeneity within the
Eagle Ford Group, a prolific mudstone reservoir on the Texas Gulf Coast, is hindered by a lack of well-preserved outcrops in close proximity to one another. Misinformation or over simplistic assumptions about relevant horizontal reservoir heterogeneities can lead to sub-optimal or uneconomical exploitation. High-resolution correlation of individual beds in the
Eagle Ford Group over several miles in Lozier Canyon and Antonio Creek in Terrell County, West Texas, was used to document lateral variation in thickness, composition, sedimentary structures, and gamma ray response of these strata on a local scale. Physical tracing of the beds on outcrops and within Gigapan photomosaics, hand-held spectral gamma-ray scintillometer profiles, and examination of polished hand samples and thin sections were used to correlate
Eagle Ford Group strata across Lozier Canyon and Antonio Creek. The results add value by increasing the understanding of local horizontal heterogeneities and the depositional environments of
Eagle Ford Group strata and potentially influencing how and where wells are drilled and completed.
Five distinct lithostratigraphic units, termed A-E from the base up, and their subunits, are laterally continuous over several miles in terms of thickness, lithology, and spectral gamma ray response. However, there are notable differences in thickness and sedimentary structures in units A and B. Unit A has the largest difference in thickness (7%), suggesting higher accommodation in the southeast part of the study area. Moreover, sedimentary structures and bed morphology of skeletal packstone beds in unit B, the primary target of horizontal wells in the subsurface, vary over a 4-mi interval from discontinuous lenses to laterally continuous stacked beds. Simulated wireline logs obtained from outcrop exposures suggest that spectral gamma ray data is superior to total gamma ray data in correctly identifying the most desirable sub units for completion. Geochemical data and trace fossil abundance suggest primarily anoxic bottom water conditions during deposition of the Lower
Eagle Ford Formation and oxic conditions during deposition of the Upper
Eagle Ford Formation. Widespread zones of deformed bedding within the
Eagle Ford Group strata typify certain units and were likely caused by paleoseismicity. Laterally extensive bedding plane exposures in Antonio Creek provide three-dimensional views of macrofossils and the bedform morphology that were previously only described from two-dimensional outcrops. Sedimentary structures suggest that units A, C, D, and E were deposited above storm wave base; and deposition of unit B was episodically above storm wave base.
Advisors/Committee Members: Pope, Michael C (advisor), Donovan, Arthur (committee member), Ayers, Walter B (committee member).
Subjects/Keywords: Lozier; Canyon; Antonio; Creek; Eagle; Ford; Group; Texas; Boquillas
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APA (6th Edition):
Gardner, R. D. (2013). Lateral Continuity of the Eagle Ford Group Strata in Lozier Canyon and Antonio Creek, Terrell County, Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/151670
Chicago Manual of Style (16th Edition):
Gardner, Rand D. “Lateral Continuity of the Eagle Ford Group Strata in Lozier Canyon and Antonio Creek, Terrell County, Texas.” 2013. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/151670.
MLA Handbook (7th Edition):
Gardner, Rand D. “Lateral Continuity of the Eagle Ford Group Strata in Lozier Canyon and Antonio Creek, Terrell County, Texas.” 2013. Web. 12 Apr 2021.
Vancouver:
Gardner RD. Lateral Continuity of the Eagle Ford Group Strata in Lozier Canyon and Antonio Creek, Terrell County, Texas. [Internet] [Masters thesis]. Texas A&M University; 2013. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/151670.
Council of Science Editors:
Gardner RD. Lateral Continuity of the Eagle Ford Group Strata in Lozier Canyon and Antonio Creek, Terrell County, Texas. [Masters Thesis]. Texas A&M University; 2013. Available from: http://hdl.handle.net/1969.1/151670
Texas A&M University
16.
Knorr, Ashley Faye.
The Effect of Rock Properties on Fracture Conductivity in the Eagle Ford.
Degree: MS, Petroleum Engineering, 2016, Texas A&M University
URL: http://hdl.handle.net/1969.1/157114
► Unconventional reservoirs have become increasingly possible and economical due to the advances of hydraulic fracturing, a stimulation technique that creates highly conductive fractures that serve…
(more)
▼ Unconventional reservoirs have become increasingly possible and economical due to the advances of hydraulic fracturing, a stimulation technique that creates highly conductive fractures that serve as pathways for hydrocarbons from the reservoir to the wellbore. This technique’s success is determined by the rock’s capability to fracture and the ability to sustain fracture conductivity. Several parameters, including formation properties, proppant type, and proppant concentration, affect the efficiency of fracture conductivity and should be taken into account for an optimal treatment.
The purpose of this study was to investigate the relationship between unpropped and propped fracture conductivity and the rock properties of outcrop samples from each of the facies of the
Eagle Ford formation. Multiple samples were collected from each zone and mechanical properties were tested in both the z-direction and x-direction of the bedding planes. Compressive triaxial tests were performed on core samples of the outcrops in order to determine the elastic rock properties of Young’s Modulus and Poisson’s Ratio. Additionally, Brinell hardness tests were completed to determine the resistance of plastic deformation of the outcrop samples. Lastly, mineral composition was obtained by X-Ray Diffraction analysis.
The results of this study were compared to fracture conductivity data performed on the
Eagle Ford formation. Within facies B1, the oil producing zone, the effect of anisotropy was present and revealed that the parallel (x-direction) samples had higher conductivity and higher Young’s Modulus than samples perpendicular (z-direction) to the bedding planes. Throughout all the facies, unpropped conductivity was predominantly influenced by the surface roughness. The propped fractures are more affected by proppant characteristics for fracture conductivity. At monolayer proppant concentration, proppant embedment is the main cause of conductivity loss due to permanent deformation. Fracture conductivity is influenced by several rock mechanical properties. Slower decline rates for propped conductivity were associated with higher surface roughness. Furthermore, the proppant pack characteristics dominate over the rock’s mechanical properties when multilayer proppant concentration is applied.
Advisors/Committee Members: Hill, A. Daniel (advisor), Zhu, Ding (committee member), Chester, Judith (committee member).
Subjects/Keywords: petroleum; shale; rock mechanics; fracture conductivity; eagle ford
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APA (6th Edition):
Knorr, A. F. (2016). The Effect of Rock Properties on Fracture Conductivity in the Eagle Ford. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/157114
Chicago Manual of Style (16th Edition):
Knorr, Ashley Faye. “The Effect of Rock Properties on Fracture Conductivity in the Eagle Ford.” 2016. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/157114.
MLA Handbook (7th Edition):
Knorr, Ashley Faye. “The Effect of Rock Properties on Fracture Conductivity in the Eagle Ford.” 2016. Web. 12 Apr 2021.
Vancouver:
Knorr AF. The Effect of Rock Properties on Fracture Conductivity in the Eagle Ford. [Internet] [Masters thesis]. Texas A&M University; 2016. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/157114.
Council of Science Editors:
Knorr AF. The Effect of Rock Properties on Fracture Conductivity in the Eagle Ford. [Masters Thesis]. Texas A&M University; 2016. Available from: http://hdl.handle.net/1969.1/157114
Texas A&M University
17.
Zhukovsky, Isaac David.
Uncertainty in Eagle Ford Shale Wells Production Quantified using Probabilistic Analysis with a Novel Decline-Curve Model.
Degree: MS, Petroleum Engineering, 2017, Texas A&M University
URL: http://hdl.handle.net/1969.1/161413
► This thesis proposes a Bayesian decline curve methodology, using Markov Chain Monte Carlo (MCMC) simulation and a novel empirical decline curve equation to better quantify…
(more)
▼ This thesis proposes a Bayesian decline curve methodology, using Markov Chain Monte Carlo (MCMC) simulation and a novel empirical decline curve equation to better quantify uncertainty in estimated ultimate recovery (EUR) for oil shales. The methodology is calibrated using hindcasting of production data from an area of the
Eagle Ford oil window. Hindcasting on an areal basis with 254 wells has demonstrated good results, with a coverage rate of true reserves of 78% for an 80% confidence interval (P90-P10), or 199 of the 254 wells tested. The novelty of the new model is in the implementation of the empirical decline curve equation for shale wells in Bayesian decline curve analysis with fast per well solution time on typical engineering computers
This method offers many benefits. Principally, the method quantitatively assesses uncertainty and avoids subjective estimates of uncertainty. The results the method generates are accurate for shale wells because the decline curve equation was empirically designed for such wells. Furthermore, it generates replicable results for given wells regardless of the forecasting engineer and offers a fast calculation time of 5-10 seconds per well in the data set.
The novel decline curve equation used in this methodology accommodates both early steep rate decline and later shallower decline with a smooth transition. Coupled with a Bayesian decline curve analysis process, the decline behavior of shale wells is assessed probabilistically with accuracy. The decline curve parameters are random variables with defined prior distributions. A MCMC simulation is performed to obtain the posterior distribution of well EURs. Wells in the sample set had >36 months of production with the first 12 months used as simulation input. The method is calibrated (hindcasted) on an areal basis by measuring the coverage rate of true reserves. The method, when applied to the
Eagle Ford oil shale production data, demonstrates good convergence to stationary posterior distributions of the parameters. This is important because field development of the
Eagle Ford and other shale plays is improved when uncertainty is accurately quantified. By quantifying uncertainty and moving away from deterministic decline curve analysis using equations designed for conventional reservoirs, a better understanding of shale well EUR and behavior throughout a play is obtained.
Advisors/Committee Members: King, Michael J (advisor), Datta-Gupta, Akhil (advisor), Everett, Mark (committee member).
Subjects/Keywords: decline curve analysis; probabilistic analysis; Eagle Ford shale
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APA (6th Edition):
Zhukovsky, I. D. (2017). Uncertainty in Eagle Ford Shale Wells Production Quantified using Probabilistic Analysis with a Novel Decline-Curve Model. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/161413
Chicago Manual of Style (16th Edition):
Zhukovsky, Isaac David. “Uncertainty in Eagle Ford Shale Wells Production Quantified using Probabilistic Analysis with a Novel Decline-Curve Model.” 2017. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/161413.
MLA Handbook (7th Edition):
Zhukovsky, Isaac David. “Uncertainty in Eagle Ford Shale Wells Production Quantified using Probabilistic Analysis with a Novel Decline-Curve Model.” 2017. Web. 12 Apr 2021.
Vancouver:
Zhukovsky ID. Uncertainty in Eagle Ford Shale Wells Production Quantified using Probabilistic Analysis with a Novel Decline-Curve Model. [Internet] [Masters thesis]. Texas A&M University; 2017. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/161413.
Council of Science Editors:
Zhukovsky ID. Uncertainty in Eagle Ford Shale Wells Production Quantified using Probabilistic Analysis with a Novel Decline-Curve Model. [Masters Thesis]. Texas A&M University; 2017. Available from: http://hdl.handle.net/1969.1/161413
Texas A&M University
18.
Peavey, Eric James.
A New Chronostratigraphic Framework for Eagle Ford- and Austin Chalk-equivalent Strata in west Texas: Implications for Basin Evolution and Diachroneity in Unconventional Reservoirs.
Degree: MS, Geology, 2017, Texas A&M University
URL: http://hdl.handle.net/1969.1/165848
► The Ernst Member within Big Bend National Park (BBNP), Brewster County, Texas provides unique opportunities for high-resolution chronostratigraphic study of Eagle Ford-equivalent strata across west…
(more)
▼ The Ernst Member within Big Bend National Park (BBNP), Brewster County, Texas provides unique opportunities for high-resolution chronostratigraphic study of
Eagle Ford-equivalent strata across west Texas and northeastern Mexico, and is partially equivalent to the
Eagle Ford Group in south and central Texas where it is a prolific, unconventional shale play.
A new chronostratigraphic framework integrating three U-Pb Chemical Abrasion-Isotope Dilution Thermal Ionization Mass Spectrometry (CA-IDTIMS) bentonite ages from the Ernst Member and six bentonite ages from the
Eagle Ford Group at Lozier Canyon with biostratigraphic proxies, hand-held spectral gamma ray (HHSGR), hand-held X-Ray Fluorescence (HHXRF) and δ¹³Ccarb measurements constraining (spatially and temporally) stratal surfaces, isotopic events and biozones in west Texas is presented. New ages for the Ernst Member type section in Ernst Tinaja, BBNP include 97.49 ± 0.12 Ma at 0.3 m (0.9 ft), 95.99 ± 0.15 Ma at 7.5 m (24.6 ft) and 91.16 ± 0.16 Ma at 52.1 m (171 ft) above the Buda Limestone/Ernst Member contact.
In BBNP, the Ernst Member preserves neither the OAE2 positive carbon isotope excursion (CIE) nor the Cenomanian/Turonian (C/T) boundary. Chemostratigraphic analysis of U, Mo, V, Zr, Ti, Ca, Sr, K, Al and Si/Ti identify a low-TOC, carbonate-rich interval (0–4.8 m; 0–15 ft), a high-TOC interval (4.8–27.4 m; 15–90 ft), the OAE2 recovery period (27.4–33 m; 90–108 ft), Langtry Member-equivalent deposits (33–52.7 m; 108–173 ft) and, bounded by the Early Coniacian Allocrioceras hazzardi Zone above and bentonite age of 91.16 ± 0.16 Ma at 52.1 m (171 ft) below, a Late Turonian Austin Chalk-equivalent section (52.7–84.6 m; 173–277.5 ft) at Ernst Tinaja. Averaged correlation (COR)-derived sedimentation rate estimates range from 0.34–2.3 cm/kyr for Lower
Eagle Ford-equivalent strata, 0.75–2.24 cm/kyr for Upper
Eagle Ford-equivalent strata and 1.8–3.64 cm/kyr for Austin Chalk-equivalent strata.
Advisors/Committee Members: Pope, Michael C (advisor), Miller, Brent V (advisor), Thomas, Debbie J (committee member).
Subjects/Keywords: Unconventional Reservoirs; Eagle Ford Group; Chronostratigraphy; Chemostratigraphy; Sequence Stratigraphy
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APA (6th Edition):
Peavey, E. J. (2017). A New Chronostratigraphic Framework for Eagle Ford- and Austin Chalk-equivalent Strata in west Texas: Implications for Basin Evolution and Diachroneity in Unconventional Reservoirs. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/165848
Chicago Manual of Style (16th Edition):
Peavey, Eric James. “A New Chronostratigraphic Framework for Eagle Ford- and Austin Chalk-equivalent Strata in west Texas: Implications for Basin Evolution and Diachroneity in Unconventional Reservoirs.” 2017. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/165848.
MLA Handbook (7th Edition):
Peavey, Eric James. “A New Chronostratigraphic Framework for Eagle Ford- and Austin Chalk-equivalent Strata in west Texas: Implications for Basin Evolution and Diachroneity in Unconventional Reservoirs.” 2017. Web. 12 Apr 2021.
Vancouver:
Peavey EJ. A New Chronostratigraphic Framework for Eagle Ford- and Austin Chalk-equivalent Strata in west Texas: Implications for Basin Evolution and Diachroneity in Unconventional Reservoirs. [Internet] [Masters thesis]. Texas A&M University; 2017. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/165848.
Council of Science Editors:
Peavey EJ. A New Chronostratigraphic Framework for Eagle Ford- and Austin Chalk-equivalent Strata in west Texas: Implications for Basin Evolution and Diachroneity in Unconventional Reservoirs. [Masters Thesis]. Texas A&M University; 2017. Available from: http://hdl.handle.net/1969.1/165848
Texas A&M University
19.
Meyer, Melissa J.
High-Resolution Chemostratigraphy of the Woodbine and Eagle Ford Groups, Brazos Basin, Texas.
Degree: MS, Geology, 2018, Texas A&M University
URL: http://hdl.handle.net/1969.1/173386
► Whole-rock elemental data is a useful tool for sub-dividing and characterizing mudrock variability across a shale basin. The chemostratigraphy of the Cenomanian-Turonian the Woodbine and…
(more)
▼ Whole-rock elemental data is a useful tool for sub-dividing and characterizing mudrock variability across a shale basin. The chemostratigraphy of the Cenomanian-Turonian the Woodbine and
Eagle Ford Groups in the Brazos basin—a western sub-basin of the East Texas basin—contains five distinct chemofacies within five regionally correlative chemozones, EB 1 through EB 5. Chemozones are characterized by variations in geochemical data and coincide with major sequence stratigraphic surfaces determined from gamma-ray and deep-resistivity wireline logs. Chemostratigraphic correlations of high-resolution XRF measurements (1.2 to 2.4-inch spacing; 12,282 total data points), integrated with 623 XRD mineralogy and 708 core-derived TOC measurements, highlight significant vertical and lateral elemental heterogeneities in a shale that otherwise appears to be homogenous.
In the Woodbine and
Eagle Ford Groups, several key elements are identified and correlated to depositional conditions: Ca concentrations indicate carbonate input; Si, Al, K, and Ti concentrations indicate clay input; Mo and Mn concentrations indicate redox conditions; and Ni enrichment indicates paleoproductivity. These key elemental proxies characterize chemofacies and chemozones. Average concentrations of key elements were mapped across chemozones to quantify their regional variability across the basin. This chemostratigraphic framework highlights major changes in: sedimentation type (i.e. siliclastic versus carbonate), sea level, redox conditions, paleoproductivity, and organic-matter enrichment in source rock plays. This assessment ultimately aids identifying horizontal landing zones and understanding their spatial variation in source rock plays.
Advisors/Committee Members: Pope, Michael (advisor), Donovan, Arthur (committee member), Schubert, Jerome (committee member).
Subjects/Keywords: chemostratigraphy; XRF; Woodbine; Eagle Ford; shale; source rock
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APA (6th Edition):
Meyer, M. J. (2018). High-Resolution Chemostratigraphy of the Woodbine and Eagle Ford Groups, Brazos Basin, Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/173386
Chicago Manual of Style (16th Edition):
Meyer, Melissa J. “High-Resolution Chemostratigraphy of the Woodbine and Eagle Ford Groups, Brazos Basin, Texas.” 2018. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/173386.
MLA Handbook (7th Edition):
Meyer, Melissa J. “High-Resolution Chemostratigraphy of the Woodbine and Eagle Ford Groups, Brazos Basin, Texas.” 2018. Web. 12 Apr 2021.
Vancouver:
Meyer MJ. High-Resolution Chemostratigraphy of the Woodbine and Eagle Ford Groups, Brazos Basin, Texas. [Internet] [Masters thesis]. Texas A&M University; 2018. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/173386.
Council of Science Editors:
Meyer MJ. High-Resolution Chemostratigraphy of the Woodbine and Eagle Ford Groups, Brazos Basin, Texas. [Masters Thesis]. Texas A&M University; 2018. Available from: http://hdl.handle.net/1969.1/173386
Texas A&M University
20.
Davis, Drew Edward.
Digital Outcrop Models of the Eagle Ford Group in Lozier Canyon, Terrell County, Texas.
Degree: MS, Geology, 2017, Texas A&M University
URL: http://hdl.handle.net/1969.1/161634
► The Eagle Ford group was a prolific producer of unconventional oil and gas in south Texas during the last decade. Operators typically target the Lower…
(more)
▼ The
Eagle Ford group was a prolific producer of unconventional oil and gas in south Texas during the last decade. Operators typically target the Lower
Eagle Ford formation to drill horizontal wells with lateral lengths averaging nearly 1 mi (1.61 km). Geologic variability can be significant at these distances, thus an understanding of lateral variability of reservoir thicknesses, facies distributions, and fractures paired with geochemical and petrophysical data is valuable in characterizing unconventional reservoirs.
High-resolution digital outcrop models (DOMs) using photogrammetry techniques provide a unique tool to study variability of
Eagle Ford group strata in outcrops in Lozier Canyon in Terrell County, West Texas. Stratigraphic variability within the
Eagle Ford group is well documented; however, lateral variability of
Eagle Ford strata is minimally understood and is fundamental to developing this productive unconventional play. This project focuses on world-class outcrops that expose complete vertical sections of the
Eagle Ford group. The study area covers a north-to-south straight line distance of 6.2 mi (10 km) allowing analysis at reservoir-scale.
The average gross stratigraphic thickness of the
Eagle Ford group increases by approximately 27.8 ft (8.47 m), a 13.59% increase, from the Scott Ranch site in north Lozier Canyon to south Lozier Canyon. Each
Eagle Ford facies increases in thickness from north-to-south Lozier Canyon with Facies C exhibiting the largest percent change in thickness at 20.18%. Skeletal packstone-grainstone bedforms in Facies B are less laterally continuous up-section from the base of the Sub-facies B2 – B3 contact into the mud-dominated uppermost Facies B (B5). A characterization of fractures traced in 2-D orthomosaics is related to bedding features in Facies B and Facies C. Fractures are generally shorter (vertically and laterally), more closely spaced, and have higher intensities in Facies B than in Facies C at each respective study site. Furthermore, our findings indicate that, as apparent fracture spacing decreases, apparent fracture dip increases. This inverse relationship between apparent fracture spacing and apparent fracture dip is related to outcrop strike and used to estimate the orientation of dominant fracture sets in Lozier Canyon.
This study highlights the practicality of using unmanned aerial vehicles (UAVs) and photogrammetry techniques to study vast areas of largely inaccessible outcrop. DOMs were interpreted and imported into Schlumberger’s Petrel 2014 and will be used to construct improved reservoir models of the
Eagle Ford group in future studies. These models may have application in helping to predict subsurface reservoir variability in the
Eagle Ford group and may be valuable for improving our understanding of other unconventional carbonate mudstone reservoirs, such as the Haynesville and Utica shales.
Advisors/Committee Members: Laya, Juan Carlos (advisor), Pope, Michael (committee member), Ayers, Walter (committee member).
Subjects/Keywords: Eagle Ford; Unconventional; Lozier Canyon; Digital Outcrop Model; Stratigraphic Variability; Photogrammetry
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APA (6th Edition):
Davis, D. E. (2017). Digital Outcrop Models of the Eagle Ford Group in Lozier Canyon, Terrell County, Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/161634
Chicago Manual of Style (16th Edition):
Davis, Drew Edward. “Digital Outcrop Models of the Eagle Ford Group in Lozier Canyon, Terrell County, Texas.” 2017. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/161634.
MLA Handbook (7th Edition):
Davis, Drew Edward. “Digital Outcrop Models of the Eagle Ford Group in Lozier Canyon, Terrell County, Texas.” 2017. Web. 12 Apr 2021.
Vancouver:
Davis DE. Digital Outcrop Models of the Eagle Ford Group in Lozier Canyon, Terrell County, Texas. [Internet] [Masters thesis]. Texas A&M University; 2017. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/161634.
Council of Science Editors:
Davis DE. Digital Outcrop Models of the Eagle Ford Group in Lozier Canyon, Terrell County, Texas. [Masters Thesis]. Texas A&M University; 2017. Available from: http://hdl.handle.net/1969.1/161634
Texas A&M University
21.
Del Busto Pinzon, Andres Mauricio.
Key Economic Drivers Impacting Eagle Ford Development from Resource to Reserves.
Degree: MS, Petroleum Engineering, 2013, Texas A&M University
URL: http://hdl.handle.net/1969.1/151888
► The Eagle Ford shale of South Texas has become one of the most active and most important shale plays in the U.S. This success has…
(more)
▼ The
Eagle Ford shale of South Texas has become one of the most active and most important shale plays in the U.S. This success has been possible because of the unique geology and richness of the play, allowing significant production of natural gas, condensate liquids, and oil; the rapid improvement of long horizontal lateral drilling and multi-stage hydraulic fracturing completion technologies; and a long-term period of sustained high oil prices.
This study develops a probabilistic before-tax economic model to estimate the reserves of the
Eagle Ford shale, under different stochastic parameters and scenarios usually not considered by evaluators. The model is used to assess impact and sensitivity on reserves and economic yardsticks considering the variability and uncertainty of project inputs such as production streams, commodity prices, capital investments, and operational costs.
We use existing probabilistic methodologies for production and price forecasting and use public and private sources to develop statistical distributions for additional parameters, including differentials for commodity prices, natural gas content for the different production regions, and water/gas and water/oil ratios.
We consider three evaluation scenarios–single-well, 100-well, and Full-well–in each of the proposed production regions of the
Eagle Ford shale, with calibrated probabilistic inputs for each region. Single-well results show how it is hard to produce complete distributions of reserves all across the play, although production regions with better productivity are identified. Results from the scenarios with multiple wells, show how the commerciality of the considered development projects is achievable in liquid-rich production regions and with moderate to high price forecasts.
This study provides useful information and results to oil and gas professionals about key areas that influence the commercial development of
Eagle Ford shale. The methodology to perform evaluations with probabilistic components enables better project development and investment decisions and can be applied to other shale plays.
Advisors/Committee Members: Ehlig-Economides, Christine (advisor), Voneiff, George (committee member), Barrufet, Maria A (committee member).
Subjects/Keywords: Oil and gas; Reserves evaluation; Eagle Ford Shale; Shale play
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APA (6th Edition):
Del Busto Pinzon, A. M. (2013). Key Economic Drivers Impacting Eagle Ford Development from Resource to Reserves. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/151888
Chicago Manual of Style (16th Edition):
Del Busto Pinzon, Andres Mauricio. “Key Economic Drivers Impacting Eagle Ford Development from Resource to Reserves.” 2013. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/151888.
MLA Handbook (7th Edition):
Del Busto Pinzon, Andres Mauricio. “Key Economic Drivers Impacting Eagle Ford Development from Resource to Reserves.” 2013. Web. 12 Apr 2021.
Vancouver:
Del Busto Pinzon AM. Key Economic Drivers Impacting Eagle Ford Development from Resource to Reserves. [Internet] [Masters thesis]. Texas A&M University; 2013. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/151888.
Council of Science Editors:
Del Busto Pinzon AM. Key Economic Drivers Impacting Eagle Ford Development from Resource to Reserves. [Masters Thesis]. Texas A&M University; 2013. Available from: http://hdl.handle.net/1969.1/151888
Texas A&M University
22.
Indras, Purvi.
Applying Decline Curve Analysis in the Liquid-rich Shales: Eagle Ford Shale Study.
Degree: MS, Petroleum Engineering, 2014, Texas A&M University
URL: http://hdl.handle.net/1969.1/152507
► With the emergence of liquid rich shale (LRS) plays like Eagle Ford and Northern Barnett, the petroleum industry needs a simple, easily applied technique that…
(more)
▼ With the emergence of liquid rich shale (LRS) plays like
Eagle Ford and Northern Barnett, the petroleum industry needs a simple, easily applied technique that provides reliable estimates of future production rates in this kind of reservoir. There is no guarantee that methodology that has proved to work in gas reservoirs will necessarily be appropriate in LRS reservoirs. In this work, we found that without corrections of early data, the Stretched Exponential Production Decline (SEPD) model, designed for transient flow, usually produces pessimistic forecasts of future production. The Duong method, another transient model, may be reasonable during long term transient linear flow, but notably optimistic after boundary-dominated flow (BDF) appears. For wells in BDF, the Arps model provides reasonable forecasts, but the Arps model may not be accurate when applied to transient data. A hybrid of early transient and later BDF models proves to be a reasonable solution to the forecasting problem in LRS.
In addition, use of diagnostic plots (like log-log rate-time and log-log rate-material balance time plots) improves confidence in flow regime identification and production forecasting. In some LRS’s, BDF is observed within 12 months. In any case, it is essential to identify or to estimate the time to reach BDF and to discontinue use of transient flow models after BDF appears or is expected.
We validated our methodology using “hindcast analysis”; that is, matching the first half of production history to determine model parameters, then forecasting the second half of history and comparing to observed production data.
We also found that application of pressure-corrected rates in decline curve analysis (DCA) may substantially improve the interpretation of data from unconventional oil wells flowing under unstable operating conditions. Fetkovich (hydraulically fractured well) type curve analysis can be added to improve confidence in flow regime identification from diagnostic plots and to estimate the Arps hyperbolic exponent b from the matching b stem on the type curve, which can then be extrapolated to determine estimated ultimate recovery.
Advisors/Committee Members: Lee, John W. (advisor), Ayers, Walter B. (committee member), Sun, Yuefeng (committee member).
Subjects/Keywords: Eagle Ford; Barnett; liquid rich shale; unconventional reservoirs; DCA
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APA (6th Edition):
Indras, P. (2014). Applying Decline Curve Analysis in the Liquid-rich Shales: Eagle Ford Shale Study. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/152507
Chicago Manual of Style (16th Edition):
Indras, Purvi. “Applying Decline Curve Analysis in the Liquid-rich Shales: Eagle Ford Shale Study.” 2014. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/152507.
MLA Handbook (7th Edition):
Indras, Purvi. “Applying Decline Curve Analysis in the Liquid-rich Shales: Eagle Ford Shale Study.” 2014. Web. 12 Apr 2021.
Vancouver:
Indras P. Applying Decline Curve Analysis in the Liquid-rich Shales: Eagle Ford Shale Study. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/152507.
Council of Science Editors:
Indras P. Applying Decline Curve Analysis in the Liquid-rich Shales: Eagle Ford Shale Study. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/152507
Texas A&M University
23.
Hancock, Travis A.
Sedimentary and Diagenetic Controls on Petroleum System Characteristics of the Upper Cretaceous Eagle Ford Group, South Texas.
Degree: MS, Geology, 2014, Texas A&M University
URL: http://hdl.handle.net/1969.1/152863
► Early diagenetic carbonate cements can affect brittleness and total organic content in shale reservoirs. Predicting these effects could potentially improve recovery efficiency and field development…
(more)
▼ Early diagenetic carbonate cements can affect brittleness and total organic
content in shale reservoirs. Predicting these effects could potentially improve recovery
efficiency and field development costs, and decrease the environmental impact of
developing the field. In this study, an X-ray fluorescence spectroscopic technique was
used to test for correlations between primary depositional features, diagenetic carbonate
cements, and organic content and fracture distributions in core samples from the
Eagle
Ford Group in McMullen County, Texas. Organic content varies significantly between
diagenetic facies, with the least organic matter present in coarsely mineralized shales.
This result is consistent with the hypothesis that diagenetic carbonate cementation that
was early relative to compaction diluted primary organic matter. In contrast, total
fracture length varies significantly between depositional facies, with the lowest total
fracture length per length of core present in massive shales. Carbonate diagenesis
therefore likely did not exert a significant control on the formation of the bedding-parallel
fractures observed in this study; instead, laminated fabrics provided planes of
weakness along which stress release fractures or hydrocarbon generation-induced
fractures could develop. The suggested target reservoir facies for similar
Eagle Ford
wells is a finely to moderately mineralized laminated shale because of the likelihood of
finding high organic content and horizontal fractures that would increase the effective
rock volume in communication with primary hydraulically induced fractures.
Advisors/Committee Members: Tice, Michael M (advisor), Mancini, Ernest A (advisor), Ayers, Walt B (committee member).
Subjects/Keywords: Eagle Ford Shale; Unconventional Petroleum Systems; Shale Gas
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APA (6th Edition):
Hancock, T. A. (2014). Sedimentary and Diagenetic Controls on Petroleum System Characteristics of the Upper Cretaceous Eagle Ford Group, South Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/152863
Chicago Manual of Style (16th Edition):
Hancock, Travis A. “Sedimentary and Diagenetic Controls on Petroleum System Characteristics of the Upper Cretaceous Eagle Ford Group, South Texas.” 2014. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/152863.
MLA Handbook (7th Edition):
Hancock, Travis A. “Sedimentary and Diagenetic Controls on Petroleum System Characteristics of the Upper Cretaceous Eagle Ford Group, South Texas.” 2014. Web. 12 Apr 2021.
Vancouver:
Hancock TA. Sedimentary and Diagenetic Controls on Petroleum System Characteristics of the Upper Cretaceous Eagle Ford Group, South Texas. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/152863.
Council of Science Editors:
Hancock TA. Sedimentary and Diagenetic Controls on Petroleum System Characteristics of the Upper Cretaceous Eagle Ford Group, South Texas. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/152863
Texas A&M University
24.
Deluca, Michael James.
Ash Bed Analysis of the Cretaceous Eagle Ford Shale Using ID-TIMS U/Pb Methods: Implications for Biostratigraphic Refinement and Correlations Within the Western Interior Seaway.
Degree: MS, Geology, 2016, Texas A&M University
URL: http://hdl.handle.net/1969.1/157869
► The Cenomanian-Turonian Eagle Ford Group was deposited within the Southern Cretaceous Western Interior Seaway (KWIS) and records the onset and duration of the Oceanic Anoxic…
(more)
▼ The Cenomanian-Turonian
Eagle Ford Group was deposited within the Southern Cretaceous Western Interior Seaway (KWIS) and records the onset and duration of the Oceanic Anoxic Event 2 (OAE2). Lozier Canyon in Val Verde country, Texas provides a unique opportunity to integrate subsurface data and core with a laterally continuous and exposed outcrop section. This study provides U/Pb ID-TIMS (Isotope dilution thermal mass spectrometry) zircon ages for ash beds within the
Eagle Ford Group. These high precision age markers are utilized for detailed regional correlations as well as calibration of globally recognizable isotopic events. Astrochronologic age models provide an estimate for the duration of the hiatus observed near the C/T boundary across much of North America, as well as reasonable estimates of significant isotopic events, biostratigrahic datums, and regionally identifiable stratigraphic surfaces. A minimum age constraint of the Buda/
Eagle Ford contact is 97.14 ± 0.36 Ma, and a maximum age constraint for the
Eagle Ford/Austin contact is 91.23 ± 0.13 Ma. ASM derived rock accumulation rates range from 0.599-0.794 cm/ka for the Lower
Eagle Ford and from 0.866-0.876 cm/ka for the Upper
Eagle Ford. Integration of bandpass short eccentricity signals, bulk δ
13C isotope data, and zircon age constraint from directly below the C/T unconformity suggests an overall duration of ~0.71 Ma for OAE2, which is similar with other duration estimates of this event throughout the KWIS. This suggests that Lozier Canyon contains a relatively complete OAE2 record, and potentially records the C-T boundary. Biostratigraphy and δ
13C suggest moderate (10’s-100’s ky) amount of time missing at the C-T unconformity.
Advisors/Committee Members: Miller, Brent V (advisor), Pope, Michael (advisor), Thomas, Debbie (committee member).
Subjects/Keywords: Geochronology; Eagle Ford Shale; Western Interior Seaway; Zircon; ID-TIMS; Astrochronology
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APA (6th Edition):
Deluca, M. J. (2016). Ash Bed Analysis of the Cretaceous Eagle Ford Shale Using ID-TIMS U/Pb Methods: Implications for Biostratigraphic Refinement and Correlations Within the Western Interior Seaway. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/157869
Chicago Manual of Style (16th Edition):
Deluca, Michael James. “Ash Bed Analysis of the Cretaceous Eagle Ford Shale Using ID-TIMS U/Pb Methods: Implications for Biostratigraphic Refinement and Correlations Within the Western Interior Seaway.” 2016. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/157869.
MLA Handbook (7th Edition):
Deluca, Michael James. “Ash Bed Analysis of the Cretaceous Eagle Ford Shale Using ID-TIMS U/Pb Methods: Implications for Biostratigraphic Refinement and Correlations Within the Western Interior Seaway.” 2016. Web. 12 Apr 2021.
Vancouver:
Deluca MJ. Ash Bed Analysis of the Cretaceous Eagle Ford Shale Using ID-TIMS U/Pb Methods: Implications for Biostratigraphic Refinement and Correlations Within the Western Interior Seaway. [Internet] [Masters thesis]. Texas A&M University; 2016. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/157869.
Council of Science Editors:
Deluca MJ. Ash Bed Analysis of the Cretaceous Eagle Ford Shale Using ID-TIMS U/Pb Methods: Implications for Biostratigraphic Refinement and Correlations Within the Western Interior Seaway. [Masters Thesis]. Texas A&M University; 2016. Available from: http://hdl.handle.net/1969.1/157869
Texas A&M University
25.
Murphy, Trey Daniel-Aaron.
"It All Depends on the Price of Oil!": Eagle Ford Shale Economic Development Outcomes in a Boom-Bust Milieu.
Degree: MS, Geography, 2016, Texas A&M University
URL: http://hdl.handle.net/1969.1/157060
► In October 2008, Petrohawk Energy drilled the first modern fracking well into the Eagle Ford Shale, sparking an oil and gas boom in what is…
(more)
▼ In October 2008, Petrohawk Energy drilled the first modern fracking well into the
Eagle Ford Shale, sparking an oil and gas boom in what is now one of the world’s most productive shale plays, responsible for 1.087 million barrels of oil per day. Large investments in production infrastructure and commercial developments have brought economic opportunities to one of the poorest areas in Texas. Notwithstanding multiple reports on economic activity, there have not been any studies examining how this development is experienced on the
Eagle Ford Shale and the amount of local policymaker economic governance. I therefore ask: Does a resource curse exist on the
Eagle Ford Shale? In framing this question, this study evaluates if social disruption and worsening economic inequality are present on the shale play. This thesis employs two methods: semi-structured interviews with 15 economic development officials from August 2014 to March 2015 and a spatial assessment of relative mineral wealth using 2010-2015 public tax data as a proxy for actual mineral wealth from Live Oak County, a core
Eagle Ford oil and gas production county.
The interviews indicated that economic development officials are most concerned about the deterioration of roads, the high demand for housing, and ramifications of skyrocketing wages. Findings from the Live Oak County mineral wealth analysis demonstrate that only 1.95% remains local to the county. This absentee mineral wealth is concentrated with major energy firms in the Texas metropolitan regions. The implications from these results indicate that a traditional core-periphery relationship has developed on the
Eagle Ford Shale, economic development officials remain optimistic about development despite receiving few benefits in an apparent royalty paradox, and social relations are changing possibly due to absentee mineral ownership. I answer the research question by noting that there are indications that the resource curse is present. As one respondent describes it,
Eagle Ford “[economic development] all depends on the price of oil!” and not on policymaker actions.
Advisors/Committee Members: Brannstrom, Christian (advisor), Ewers, Michael (committee member), Mjelde, James (committee member).
Subjects/Keywords: South Texas; Eagle Ford Shale; mineral appraisal data; resource curse; boomtowns
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APA (6th Edition):
Murphy, T. D. (2016). "It All Depends on the Price of Oil!": Eagle Ford Shale Economic Development Outcomes in a Boom-Bust Milieu. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/157060
Chicago Manual of Style (16th Edition):
Murphy, Trey Daniel-Aaron. “"It All Depends on the Price of Oil!": Eagle Ford Shale Economic Development Outcomes in a Boom-Bust Milieu.” 2016. Masters Thesis, Texas A&M University. Accessed April 12, 2021.
http://hdl.handle.net/1969.1/157060.
MLA Handbook (7th Edition):
Murphy, Trey Daniel-Aaron. “"It All Depends on the Price of Oil!": Eagle Ford Shale Economic Development Outcomes in a Boom-Bust Milieu.” 2016. Web. 12 Apr 2021.
Vancouver:
Murphy TD. "It All Depends on the Price of Oil!": Eagle Ford Shale Economic Development Outcomes in a Boom-Bust Milieu. [Internet] [Masters thesis]. Texas A&M University; 2016. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/1969.1/157060.
Council of Science Editors:
Murphy TD. "It All Depends on the Price of Oil!": Eagle Ford Shale Economic Development Outcomes in a Boom-Bust Milieu. [Masters Thesis]. Texas A&M University; 2016. Available from: http://hdl.handle.net/1969.1/157060
Uppsala University
26.
Lund, Linnea.
Decline Curve Analysis of Shale Oil Production : The Case of Eagle Ford.
Degree: Natural Resources and Sustainable Development, 2014, Uppsala University
URL: http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-235816
► Production of oil and gas from shale is often described as a revolution to energyproduction in North America. Since the beginning of this century…
(more)
▼ Production of oil and gas from shale is often described as a revolution to energyproduction in North America. Since the beginning of this century the shale oilproduction has increased from practically zero to currently supply almost half of theU.S. oil production. This development is made possible by the technology ofhorizontal drilling and hydraulic fracturing. Since the production has not been ongoingfor that long, production data is still fairly limited in length and there are still largeuncertainties in many parameters, for instance production decline, lifespan, drainagearea, geographical extent and future technological development. More research isneeded to be able to estimate future production and resources with more certainty. At the moment shale oil is extracted only in North America but around the worldinvestigations are starting to assess if the conditions are suitable from shale oilextraction elsewhere. The global technically recoverable resource has been estimatedto 345 Gb, 10% of all global technically recoverable resources. Health andenvironmental aspects of shale oil and gas production have not yet been investigatedthoroughly and there is a risk that these parameters may slow down or limit thespreading of shale development. This report aims to examine production patterns of shale oil wells by applying declinecurve analysis. This analysis comprises of analyzing historical production data toinvestigate how the future production may develop. The area of the study is the EagleFord shale play in Texas, U.S. The goal is to fit decline curves to production data andthen use them for making estimates of future production in the Eagle Ford. The production in the shale oil wells included in the study reach their peak already within a few months after production starts. After this point, production is declining.After one year, production has decreased by 75% and after two years the productionis 87% of the peak production. The hyperbolic decline curve has a good fit toproduction data and in many cases the curve is close to harmonic. It is too early todetermine whether the alternative decline curve that is tested, the scaling declinecurve, has a better fit in the long term. The report also investigates how the density of the petroleum affects the declinecurve. The result is that lighter products decline faster than heavier. A sensitivity analysis is performed to illustrate how different parameters affect thefuture production development. In addition to the wells’ decline rate, the assumptionson the maximum number of wells, the maximal production and the rate at which newwells are added affect the ultimately recoverable resource. These parameters all havelarge uncertainties and makes resource estimations more difficult.
Subjects/Keywords: shale oil; unconventional oil; shale; decline curve analysis; DCA; eagle ford
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APA (6th Edition):
Lund, L. (2014). Decline Curve Analysis of Shale Oil Production : The Case of Eagle Ford. (Thesis). Uppsala University. Retrieved from http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-235816
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
Chicago Manual of Style (16th Edition):
Lund, Linnea. “Decline Curve Analysis of Shale Oil Production : The Case of Eagle Ford.” 2014. Thesis, Uppsala University. Accessed April 12, 2021.
http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-235816.
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
MLA Handbook (7th Edition):
Lund, Linnea. “Decline Curve Analysis of Shale Oil Production : The Case of Eagle Ford.” 2014. Web. 12 Apr 2021.
Vancouver:
Lund L. Decline Curve Analysis of Shale Oil Production : The Case of Eagle Ford. [Internet] [Thesis]. Uppsala University; 2014. [cited 2021 Apr 12].
Available from: http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-235816.
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
Council of Science Editors:
Lund L. Decline Curve Analysis of Shale Oil Production : The Case of Eagle Ford. [Thesis]. Uppsala University; 2014. Available from: http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-235816
Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation
University of Texas – Austin
27.
Shultz, James Marion.
Pore network variation identified through NMR analysis : Eagle Ford Group, South Texas, USA.
Degree: MSin Energy and Earth Resources, Energy and Earth Resources, 2015, University of Texas – Austin
URL: http://hdl.handle.net/2152/32583
► Mudrock porosity is associated with both organic and inorganic matter, and hydrocarbons are found in both. The upper Eagle Ford Group is dominated by inorganic…
(more)
▼ Mudrock porosity is associated with both organic and inorganic matter, and hydrocarbons are found in both. The upper
Eagle Ford Group is dominated by inorganic porosity, while the lower
Eagle Ford Group is considered to have more organic-hosted porosity related to its high organic content. The differences in organic and inorganic pore types play a large role in the effectiveness of pore networks. This study investigates
Eagle Ford Group mudrock pores through the use of nuclear magnetic resonance (NMR) in order to more accurately describe porosity. Laboratory-based NMR has been used to measure the fluid content and pore volume of mudrocks affordably and nondestructively. Although NMR is versatile, it has limitations, in that pore-throats and pores must be fluid filled in order to be detected. However, calibration to Mercury Injection Capillary Pressure (MICP) measurements yields interpretable and valuable results. Using a total of 28 core samples from three wells in Karnes and Maverick Counties, South Texas, this study examines how pore networks differ vertically within the succession. The lithology and facies vary vertically within each well and laterally between wells. The facies groups defined with visual core examination were then modeled with wireline logs. While the facies groups show significant overlap in petrophysical character measured by NMR, scanning electron microscopy (SEM), total organic carbon (TOC), x-ray fluorescence (XRF), and x-ray diffraction (XRD), the samples taken from the same facies group nonetheless have similar MICP intrusion corrected porosities. When samples are compared without regard to facies groups, both MICP and TOC strongly correlate with NMR. While NMR detects differences in the pore network including the relative amount of porosity associated with clay sized particles between the upper and lower
Eagle Ford; and SEM shows that much of the upper
Eagle Ford organic porosity appears to be associated with migrated organic matter. Vertically segregating the
Eagle Ford by facies groups that can be modeled by wireline log, while difficult, with further sampling, may prove useful to play-wide mapping.
Advisors/Committee Members: Tinker, Scott W. (Scott Wheeler) (advisor), Hammes, Ursula (advisor), Smye, Katie (committee member), Fisher, William (committee member).
Subjects/Keywords: Mudrock porosity; Nuclear magnetic resonance; Eagle Ford Group; Texas
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APA (6th Edition):
Shultz, J. M. (2015). Pore network variation identified through NMR analysis : Eagle Ford Group, South Texas, USA. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/32583
Chicago Manual of Style (16th Edition):
Shultz, James Marion. “Pore network variation identified through NMR analysis : Eagle Ford Group, South Texas, USA.” 2015. Masters Thesis, University of Texas – Austin. Accessed April 12, 2021.
http://hdl.handle.net/2152/32583.
MLA Handbook (7th Edition):
Shultz, James Marion. “Pore network variation identified through NMR analysis : Eagle Ford Group, South Texas, USA.” 2015. Web. 12 Apr 2021.
Vancouver:
Shultz JM. Pore network variation identified through NMR analysis : Eagle Ford Group, South Texas, USA. [Internet] [Masters thesis]. University of Texas – Austin; 2015. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/2152/32583.
Council of Science Editors:
Shultz JM. Pore network variation identified through NMR analysis : Eagle Ford Group, South Texas, USA. [Masters Thesis]. University of Texas – Austin; 2015. Available from: http://hdl.handle.net/2152/32583
University of Texas – Austin
28.
Alnahwi, Ahmed Wasel.
Stratigraphic architecture and associated sedimentological and geochemical variability in the Upper Cretaceous Eagle Ford Group, south Texas.
Degree: PhD, Geological Sciences, 2018, University of Texas – Austin
URL: http://dx.doi.org/10.26153/tsw/10008
► A detailed, rock-based investigation of three Upper Cretaceous Eagle Ford Group cores situated behind (L1), at (L2), and downdip (L3) of the Lower Cretaceous Stuart…
(more)
▼ A detailed, rock-based investigation of three Upper Cretaceous
Eagle Ford Group cores situated behind (L1), at (L2), and downdip (L3) of the Lower Cretaceous Stuart City paleoreef-shelf margin in south Texas was conducted to understand stratigraphic, sedimentological, and geochemical relationships. An understanding of stratigraphic, sedimentological, and geochemical variability across the ancestral shelf margin is currently lacking. The Cenomanian–Turonian
Eagle Ford Group is composed predominantly of calcareous mudstones that were deposited below storm-wave base on the drowned South Texas Shelf. The Lower to Upper
Eagle Ford contact approximates the Cenomanian–Turonian boundary, at which the OAE-2 occurred and was identified in all three cores. The low-relief raised rim of the paleoshelf margin may have acted as a barrier, dividing the
Eagle Ford Group into two sedimentological systems: (1) a restricted drowned shelf to the north and (2) an open-marine basinal setting to the south. Pre-OAE-2
Eagle Ford strata on the drowned shelf are cyclic and enriched in molybdenum, suggesting anoxic to euxinic water masses. Anoxic basinward strata are less cyclical and have a lower molybdenum content.
The cores were investigated to quantify mineralogical composition and TOC. Machine learning of XRF dataset was conducted using neural-network analysis to predict mineralogies and TOC. Quantitative laboratory-measured XRD mineralogies and TOC were used to conduct the training and develop high-resolution quantitative models. Derived mineralogic and organic matter quantitative models represent continuous relative abundances. This method allows for the utilization of the relatively inexpensive and nondestructive XRF analysis that requires minimal sample preparation to construct high-resolution mineral abundances and TOC content.
Hyperspectral imagery was used to generate mineral maps of the L1 core. The used hyperspectral imaging system uses the SWIR (shortwave infrared) and LWIR (longwave infrared) spectrometers. The introduction of the LWIR made it possible to identify minerals that were not detected by previous SWIR systems such as quartz and feldspars. Hyperspectral imaging facilitates the study of textural and fabric relationships. The diagnostic cyclicity of the Lower
Eagle Ford is closely related to calcite compositional variations and coccolithophore productivity. Strontium-rich calcite indicates smaller allochem size dominance as well as lower sedimentation rates.
Advisors/Committee Members: Loucks, R. G. (advisor), Fisher, W. L. (William Lawrence), 1932- (advisor), Kerans, Charles (committee member), Steel, Ronald J (committee member), Larson, Toti E (committee member).
Subjects/Keywords: Eagle Ford; Stratigraphy; Sedimentology; Geochemistry; XRF; Machine learning; Hyperspectral imaging
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APA (6th Edition):
Alnahwi, A. W. (2018). Stratigraphic architecture and associated sedimentological and geochemical variability in the Upper Cretaceous Eagle Ford Group, south Texas. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/10008
Chicago Manual of Style (16th Edition):
Alnahwi, Ahmed Wasel. “Stratigraphic architecture and associated sedimentological and geochemical variability in the Upper Cretaceous Eagle Ford Group, south Texas.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed April 12, 2021.
http://dx.doi.org/10.26153/tsw/10008.
MLA Handbook (7th Edition):
Alnahwi, Ahmed Wasel. “Stratigraphic architecture and associated sedimentological and geochemical variability in the Upper Cretaceous Eagle Ford Group, south Texas.” 2018. Web. 12 Apr 2021.
Vancouver:
Alnahwi AW. Stratigraphic architecture and associated sedimentological and geochemical variability in the Upper Cretaceous Eagle Ford Group, south Texas. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2021 Apr 12].
Available from: http://dx.doi.org/10.26153/tsw/10008.
Council of Science Editors:
Alnahwi AW. Stratigraphic architecture and associated sedimentological and geochemical variability in the Upper Cretaceous Eagle Ford Group, south Texas. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://dx.doi.org/10.26153/tsw/10008
University of Texas – Austin
29.
Harbor, Ryan Lee.
Facies characterization and stratigraphic architecture of organic-rich mudrocks, Upper Cretaceous Eagle Ford Formation, South Texas.
Degree: MSin Geological Sciences, Geological Sciences, 2011, University of Texas – Austin
URL: http://hdl.handle.net/2152/ETD-UT-2011-08-3892
► The Eagle Ford is a well-known source rock for both sandstone (Woodbine) and carbonate (Austin and Buda) hydrocarbon reservoirs in East and South Texas. Recent…
(more)
▼ The
Eagle Ford is a well-known source rock for both sandstone (Woodbine) and carbonate (Austin and Buda) hydrocarbon reservoirs in East and South Texas. Recent discoveries have demonstrated that source rocks, such as the
Eagle Ford, are capable of producing significant volumes of gas and oil. At the same time, variations in well producibility indicate that these rocks, like conventional reservoirs, display considerable geological heterogeneity. Yet, only limited research has been published on the subsurface stratigraphy and character of
Eagle Ford facies. Understanding the types, controls, and distribution of these heterogeneities requires in-depth rock-based studies.
In order to characterize
Eagle Ford facies, 27 cores from 13 counties were investigated for rock textures, fabrics, sedimentary structures, and fossil assemblages. These studies were supported by light and electron microscopy as well as analysis of elemental chemistry and mineralogy. Regional subsurface stratigraphic correlations and facies distributions were defined using wireline logs calibrated from core studies.
In South Texas, the
Eagle Ford Formation was deposited during a second-order transgressive/regressive cycle on the flooded, oxygen-restricted Comanche Shelf. Nine depositional facies consisting predominately of organic-rich, fine-grained (5.0 % TOC) to coarser-grained (3.05 % TOC) fabrics were identified. Facies developed in low-energy environments episodically interrupted by higher-energy, event sedimentation (current winnowing, cohesive and non-cohesive density flows, and turbidity flows). Locally, these rocks show evidence of early diagenetic recrystallization of calcite.
Concurrent water anoxia and organic matter preservation persisted locally into later Austin deposition, resulting in formation of a three-fold division of the Cenomanian-Coniacian
Eagle Ford Formation. Common facies of lower and upper
Eagle Ford members include (1) unlaminated, fissile, clay- and silica-rich, organic-rich mudrocks, (2) laminated, calcareous, organic-rich mudrocks, and (3) laminated, foraminifera- and peloid-rich, organic-rich packstones. The transitional
Eagle Ford member consists of highly-cyclic (1) ripple-laminated, organic-rich wackestone (cycle base) and (2) burrowed, organic-lean lime wackestones (cycle top). Transitional
Eagle Ford facies developed in oxygen-restricted, basinal depositional environments as distal equivalents to burrowed, foraminiferal lime wackestones of the Austin Formation.
Facies complexities in the
Eagle Ford stem from complicated and interrelated processes of sediment production and distribution, diagenesis, and water column chemistry. Integrated core studies shed light on both controls of facies formation and their spatial distribution. These findings provide a framework for upscaling the fine-scale, heterogeneous character of shelfal
Eagle Ford mudrocks; thus allowing development of predictive models into the distribution of key reservoir properties in the subsurface.
Advisors/Committee Members: Ruppel, Stephen C. (advisor), Fisher, W. L. (William Lawrence), 1932- (advisor), Steel, Ronald J. (committee member).
Subjects/Keywords: Eagle Ford; Sedimentology; OAE 2; Upper Cretaceous; Unconventional resources; Oil shale
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APA (6th Edition):
Harbor, R. L. (2011). Facies characterization and stratigraphic architecture of organic-rich mudrocks, Upper Cretaceous Eagle Ford Formation, South Texas. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/ETD-UT-2011-08-3892
Chicago Manual of Style (16th Edition):
Harbor, Ryan Lee. “Facies characterization and stratigraphic architecture of organic-rich mudrocks, Upper Cretaceous Eagle Ford Formation, South Texas.” 2011. Masters Thesis, University of Texas – Austin. Accessed April 12, 2021.
http://hdl.handle.net/2152/ETD-UT-2011-08-3892.
MLA Handbook (7th Edition):
Harbor, Ryan Lee. “Facies characterization and stratigraphic architecture of organic-rich mudrocks, Upper Cretaceous Eagle Ford Formation, South Texas.” 2011. Web. 12 Apr 2021.
Vancouver:
Harbor RL. Facies characterization and stratigraphic architecture of organic-rich mudrocks, Upper Cretaceous Eagle Ford Formation, South Texas. [Internet] [Masters thesis]. University of Texas – Austin; 2011. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/2152/ETD-UT-2011-08-3892.
Council of Science Editors:
Harbor RL. Facies characterization and stratigraphic architecture of organic-rich mudrocks, Upper Cretaceous Eagle Ford Formation, South Texas. [Masters Thesis]. University of Texas – Austin; 2011. Available from: http://hdl.handle.net/2152/ETD-UT-2011-08-3892
University of Texas – Austin
30.
Khan, Abdul Muqtadir.
Multi-frac treatments in tight oil and shale gas reservoirs : effect of hydraulic fracture geometry on production and rate transient.
Degree: MSin Engineering, Petroleum Engineering, 2013, University of Texas – Austin
URL: http://hdl.handle.net/2152/22367
► The vast shale gas and tight oil reservoirs in North America cannot be economically developed without multi-stage hydraulic fracture treatments. Owing to the disparity in…
(more)
▼ The vast shale gas and tight oil reservoirs in North America cannot be economically developed without multi-stage hydraulic fracture treatments. Owing to the disparity in the density of natural fractures in addition to the disparate in-situ stress conditions in these kinds of formations, microseismic fracture mapping has shown that hydraulic fracture treatments develop a range of large-scale fracture networks in the shale plays.
In this thesis, an approach is presented, where the fracture networks approximated with microseismic mapping are integrated with a commercial numerical production simulator that discretely models the network structure in both vertical and horizontal wells. A novel approach for reservoir simulation is used, where porosity (instead of permeability) is used as a scaling parameter for the fracture width. Two different fracture geometries have been broadly proposed for a multi stage horizontal well, orthogonal and transverse. The orthogonal pattern represents a complex network with cross cutting fractures orthogonal to each other; whereas transverse pattern maps uninterrupted fractures achieving maximum depth of penetration into the reservoir. The response for a
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single-stage fracture is further investigated by comparing the propagation of the stage to be dendritic versus planar. A dendritic propagation is bifurcation of the hydraulic fracture due to intersection with the natural fracture (failure along the plane of weakness).
The impact of fracture spacing to optimize these fracture geometries is studied. A systematic optimization for designing the fracture length and width is also presented. The simulation is motivated by the oil window of
Eagle Ford shale formation and the results of this work illustrate how different fracture network geometries impact well performance, which is critical for improving future horizontal well completions and fracturing strategies in low permeability shale and tight oil reservoirs.
A rate transient analysis (RTA) technique employing a rate normalized pressure (RNP) vs. superposition time function (STF) plot is used for the linear flow analysis. The parameters that influence linear flow are analytically derived. It is found that picking a straight line on this curve can lead to erroneous results because multiple solutions exist. A new technique for linear flow analysis is used. The ratio of derivative of inverse production and derivative of square root time is plotted against square root time and the constant derivative region is seen to be indicative of linear flow. The analysis is found to be robust because different simulation cases are modeled and permeability and fracture half-length are estimated.
Advisors/Committee Members: Olson, Jon E. (advisor).
Subjects/Keywords: Hydraulic fracturing; Shale gas; Eagle Ford; Simulation; Production; Linear flow
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APA (6th Edition):
Khan, A. M. (2013). Multi-frac treatments in tight oil and shale gas reservoirs : effect of hydraulic fracture geometry on production and rate transient. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/22367
Chicago Manual of Style (16th Edition):
Khan, Abdul Muqtadir. “Multi-frac treatments in tight oil and shale gas reservoirs : effect of hydraulic fracture geometry on production and rate transient.” 2013. Masters Thesis, University of Texas – Austin. Accessed April 12, 2021.
http://hdl.handle.net/2152/22367.
MLA Handbook (7th Edition):
Khan, Abdul Muqtadir. “Multi-frac treatments in tight oil and shale gas reservoirs : effect of hydraulic fracture geometry on production and rate transient.” 2013. Web. 12 Apr 2021.
Vancouver:
Khan AM. Multi-frac treatments in tight oil and shale gas reservoirs : effect of hydraulic fracture geometry on production and rate transient. [Internet] [Masters thesis]. University of Texas – Austin; 2013. [cited 2021 Apr 12].
Available from: http://hdl.handle.net/2152/22367.
Council of Science Editors:
Khan AM. Multi-frac treatments in tight oil and shale gas reservoirs : effect of hydraulic fracture geometry on production and rate transient. [Masters Thesis]. University of Texas – Austin; 2013. Available from: http://hdl.handle.net/2152/22367
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