subject:(Coalbed methane)

University of Alberta

1. Al-hawaree, Mohamad. Geomechanics of CO₂ sequestration in coalbed methane reservoirs.

Degree: MS, Department of Civil and Environmental Engineering, 1999, University of Alberta

URL: https://era.library.ualberta.ca/files/fj236452s

Subjects/Keywords: Coalbed methane.

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APA (6^th Edition):

Al-hawaree, M. (1999). Geomechanics of CO₂ sequestration in coalbed methane reservoirs. (Masters Thesis). University of Alberta. Retrieved from https://era.library.ualberta.ca/files/fj236452s

Chicago Manual of Style (16^th Edition):

Al-hawaree, Mohamad. “Geomechanics of CO₂ sequestration in coalbed methane reservoirs.” 1999. Masters Thesis, University of Alberta. Accessed April 21, 2021. https://era.library.ualberta.ca/files/fj236452s.

MLA Handbook (7^th Edition):

Al-hawaree, Mohamad. “Geomechanics of CO₂ sequestration in coalbed methane reservoirs.” 1999. Web. 21 Apr 2021.

Vancouver:

Al-hawaree M. Geomechanics of CO₂ sequestration in coalbed methane reservoirs. [Internet] [Masters thesis]. University of Alberta; 1999. [cited 2021 Apr 21]. Available from: https://era.library.ualberta.ca/files/fj236452s.

Council of Science Editors:

Al-hawaree M. Geomechanics of CO₂ sequestration in coalbed methane reservoirs. [Masters Thesis]. University of Alberta; 1999. Available from: https://era.library.ualberta.ca/files/fj236452s

Texas A&M University

2. Martynova, Elena. Single-well Modeling of Coalbed Methane Production.

Degree: MS, Petroleum Engineering, 2014, Texas A&M University

URL: http://hdl.handle.net/1969.1/152465

► The presented study concerns the unconventional coal bed methane (CBM) fields that imply peculiarity of their evaluation. The theoretical basis of the CBM field development… (more)

Subjects/Keywords: Coalbed Methane; Permeability; Modeling

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APA (6^th Edition):

Martynova, E. (2014). Single-well Modeling of Coalbed Methane Production. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/152465

Chicago Manual of Style (16^th Edition):

Martynova, Elena. “Single-well Modeling of Coalbed Methane Production.” 2014. Masters Thesis, Texas A&M University. Accessed April 21, 2021. http://hdl.handle.net/1969.1/152465.

MLA Handbook (7^th Edition):

Martynova, Elena. “Single-well Modeling of Coalbed Methane Production.” 2014. Web. 21 Apr 2021.

Vancouver:

Martynova E. Single-well Modeling of Coalbed Methane Production. [Internet] [Masters thesis]. Texas A&M University; 2014. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/1969.1/152465.

Council of Science Editors:

Martynova E. Single-well Modeling of Coalbed Methane Production. [Masters Thesis]. Texas A&M University; 2014. Available from: http://hdl.handle.net/1969.1/152465

Texas A&M University

3. Okeke, Amarachukwu Ngozi. Sensitivity analysis of modeling parameters that affect the dual peaking behaviour in coalbed methane reservoirs.

Degree: MS, Petroleum Engineering, 2006, Texas A&M University

URL: http://hdl.handle.net/1969.1/4196

► Coalbed methane reservoir (CBM) performance is controlled by a complex set of reservoir, geologic, completion and operational parameters and the inter-relationships between those parameters. Therefore… (more)

Subjects/Keywords: Coalbed Methane

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APA (6^th Edition):

Okeke, A. N. (2006). Sensitivity analysis of modeling parameters that affect the dual peaking behaviour in coalbed methane reservoirs. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/4196

Chicago Manual of Style (16^th Edition):

Okeke, Amarachukwu Ngozi. “Sensitivity analysis of modeling parameters that affect the dual peaking behaviour in coalbed methane reservoirs.” 2006. Masters Thesis, Texas A&M University. Accessed April 21, 2021. http://hdl.handle.net/1969.1/4196.

MLA Handbook (7^th Edition):

Okeke, Amarachukwu Ngozi. “Sensitivity analysis of modeling parameters that affect the dual peaking behaviour in coalbed methane reservoirs.” 2006. Web. 21 Apr 2021.

Vancouver:

Okeke AN. Sensitivity analysis of modeling parameters that affect the dual peaking behaviour in coalbed methane reservoirs. [Internet] [Masters thesis]. Texas A&M University; 2006. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/1969.1/4196.

Council of Science Editors:

Okeke AN. Sensitivity analysis of modeling parameters that affect the dual peaking behaviour in coalbed methane reservoirs. [Masters Thesis]. Texas A&M University; 2006. Available from: http://hdl.handle.net/1969.1/4196

Texas Tech University

4. Pang, Yu. CO2 Sequestration Enhances Coalbed Methane Production.

Degree: 2013, Texas Tech University

URL: http://hdl.handle.net/2346/48869

► Since 1980s, petroleum engineers and geologists have conducted researches on Enhanced Coalbed Methane Recovery (ECBM). During this period, many methods are introduced to enhance the… (more)

▼ Since 1980s, petroleum engineers and geologists have conducted researches on Enhanced Coalbed Methane Recovery (ECBM). During this period, many methods are introduced to enhance the production of coalbed methane. One of the methods called CO2-ECBM, which is injecting CO2 into the coal seam to replace the coalbed methane adsorbed on the surface of coal matrix, attracted attention of many engineers. Injecting CO2 into coalbed formation serves a dual-purpose of enhancing production while sequestrating CO2. Nowadays, CO2 emission has been identified as major contributor to global warming effect which results in climate change. Therefore, in order to eliminate the detrimental effect of global warming, finding a way to permanently store venting CO2, at the meanwhile, to enhance the coalbed methane production thereby offset the cost of CO2 sequestration may be the best strategy for both environmental protection and petroleum industry. Researches for improving methane production by gas flooding, such as performance of CO2, N2 and fuel gas injection, changes in permeability and porosity caused by gas injection due to effects of swelling and shrinkage of coal and influence of coal rank have been done. Published papers had illustrated that CO2 sequestration to enhance coalbed methane production is feasible and practical. However, well completion is seldom taken in account. Thus, this thesis not only analyzes the effects of CO2 sequestration, but also focuses on determining the efficiency of CO2-ECBM, when applying hydraulic fracturing and horizontal well techniques as well completion. Through simulation works, the thesis evaluates production of coalbed methane from the reservoir applied CO2 sequestration and provides efficient and commercial well completion alternatives for production enhancement under CO2 sequestration condition. Advisors/Committee Members: Soliman, Mohamed Y. (Committee Chair), Sheng, James (committee member), Menouar, Habib K. (committee member), House, Waylon V. (committee member).

Subjects/Keywords: Coalbed; Methane; CO2 Sequestration

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APA (6^th Edition):

Pang, Y. (2013). CO2 Sequestration Enhances Coalbed Methane Production. (Thesis). Texas Tech University. Retrieved from http://hdl.handle.net/2346/48869

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Pang, Yu. “CO2 Sequestration Enhances Coalbed Methane Production.” 2013. Thesis, Texas Tech University. Accessed April 21, 2021. http://hdl.handle.net/2346/48869.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Pang, Yu. “CO2 Sequestration Enhances Coalbed Methane Production.” 2013. Web. 21 Apr 2021.

Vancouver:

Pang Y. CO2 Sequestration Enhances Coalbed Methane Production. [Internet] [Thesis]. Texas Tech University; 2013. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/2346/48869.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Pang Y. CO2 Sequestration Enhances Coalbed Methane Production. [Thesis]. Texas Tech University; 2013. Available from: http://hdl.handle.net/2346/48869

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of New South Wales

5. Karimi, Kaveh. Coal bed methane reservoir simulation studies.

Degree: Petroleum Engineering, 2005, University of New South Wales

URL: http://handle.unsw.edu.au/1959.4/22449 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:765/SOURCE02?view=true

► The purpose of this study is to perform simulation studies for a specific coal bedmethane reservoir. First, the theory and reservoir engineering aspects of coalbed… (more)

▼ The purpose of this study is to perform simulation studies for a specific coal bedmethane reservoir. First, the theory and reservoir engineering aspects of coalbed methane reservoirs, such as dual porosity concept, permeabilitycharacteristics of CBM reservoirs and mechanism of gas storage and gastransportation in CBM reservoir have been discussed. Next, simulation results forthe CBM reservoir presented. Simulation studies were carried out by using theCBM reservoir simulator, SIMED II. Injection/fall-off test pressure data wereinterpreted based on the pressure history matching method. The interpretationresults include the determination of reservoir permeability and identification ofthe reservoir altered zone. Also available production histories were used tosimulate the reservoir production behavior. Then the production model was usedto predict the reservoir future production and to carry out sensitivity analysis onreservoir performance.For natural pressure depletion, methane recovery was increased significantly asreservoir permeability was increased. Well-bore fracturing creates a fracturedzone with higher permeability. This increases methane production rate duringearly time of reservoir life. Reservoir matrix porosity has a significant effect onthe reservoir performance. Higher production peak rate and also higher methanerecovery was obtained for the reservoir with lower porosity values. Any increasein the reservoir compressibility causes greater reduction in reservoir absolutepermeability as well as relative permeability to gas throughout the reservoir.Therefore, methane recovery decreased as the reservoir compressibilityincreased. The reservoir production behavior was strongly affected by changes inreservoir size. The production peak rate was significantly postponed and loweredas reservoir size was increased. The effect of reservoir initial pressure wasinvestigated and the results show that higher initial reservoir pressure leads tohigher production rate during early years of production. However, for the lateryears of reservoir life, the production profile is almost identical for differentinitial pressures. Coal desorption time constant affects the methane productionby its own scale. In this study, the range of desorption time did not exceedlonger than three days and therefore the difference in production rate wasobserved only in the first few days of production.

Subjects/Keywords: coalbed methane

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APA (6^th Edition):

Karimi, K. (2005). Coal bed methane reservoir simulation studies. (Masters Thesis). University of New South Wales. Retrieved from http://handle.unsw.edu.au/1959.4/22449 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:765/SOURCE02?view=true

Chicago Manual of Style (16^th Edition):

Karimi, Kaveh. “Coal bed methane reservoir simulation studies.” 2005. Masters Thesis, University of New South Wales. Accessed April 21, 2021. http://handle.unsw.edu.au/1959.4/22449 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:765/SOURCE02?view=true.

MLA Handbook (7^th Edition):

Karimi, Kaveh. “Coal bed methane reservoir simulation studies.” 2005. Web. 21 Apr 2021.

Vancouver:

Karimi K. Coal bed methane reservoir simulation studies. [Internet] [Masters thesis]. University of New South Wales; 2005. [cited 2021 Apr 21]. Available from: http://handle.unsw.edu.au/1959.4/22449 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:765/SOURCE02?view=true.

Council of Science Editors:

Karimi K. Coal bed methane reservoir simulation studies. [Masters Thesis]. University of New South Wales; 2005. Available from: http://handle.unsw.edu.au/1959.4/22449 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:765/SOURCE02?view=true

Montana State University

6. Barnhart, Elliott Paul. In situ and enhanced coal-bed methane production from the Powder River Basin.

Degree: PhD, College of Letters & Science, 2014, Montana State University

URL: https://scholarworks.montana.edu/xmlui/handle/1/9354

► The majority of the coal in the Powder River Basin (PRB) is located in formations too deep to be economically mined but microorganisms within some… (more)

Subjects/Keywords: Coalbed methane; Methanobacteriaceae; Microorganisms; Evolution

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APA (6^th Edition):

Barnhart, E. P. (2014). In situ and enhanced coal-bed methane production from the Powder River Basin. (Doctoral Dissertation). Montana State University. Retrieved from https://scholarworks.montana.edu/xmlui/handle/1/9354

Chicago Manual of Style (16^th Edition):

Barnhart, Elliott Paul. “In situ and enhanced coal-bed methane production from the Powder River Basin.” 2014. Doctoral Dissertation, Montana State University. Accessed April 21, 2021. https://scholarworks.montana.edu/xmlui/handle/1/9354.

MLA Handbook (7^th Edition):

Barnhart, Elliott Paul. “In situ and enhanced coal-bed methane production from the Powder River Basin.” 2014. Web. 21 Apr 2021.

Vancouver:

Barnhart EP. In situ and enhanced coal-bed methane production from the Powder River Basin. [Internet] [Doctoral dissertation]. Montana State University; 2014. [cited 2021 Apr 21]. Available from: https://scholarworks.montana.edu/xmlui/handle/1/9354.

Council of Science Editors:

Barnhart EP. In situ and enhanced coal-bed methane production from the Powder River Basin. [Doctoral Dissertation]. Montana State University; 2014. Available from: https://scholarworks.montana.edu/xmlui/handle/1/9354

Montana State University

7. Hodgskiss, Logan Henry. Evaluation of a green alga isolate for growth and lipid accumulation in coal bed methane water from the Powder River Basin.

Degree: MS, College of Engineering, 2015, Montana State University

URL: https://scholarworks.montana.edu/xmlui/handle/1/10138

► Coal bed methane (CBM) production ponds are being constructed more frequently in areas such as the Powder River Basin in Montana and Wyoming where methane… (more)

▼ Coal bed methane (CBM) production ponds are being constructed more frequently in areas such as the Powder River Basin in Montana and Wyoming where methane production has been active in the past decade. These ponds are currently not being utilized and are holding billions of gallons of water. The extracted water in these ponds is presently being discharged to local stream drainages or infiltrating into the surrounding soil. The environmental impacts of this increase in water can have negative effects on the surrounding areas. The purpose of this thesis is to explore the possibility of using CBM production ponds in the Powder River Basin, in Montana and Wyoming, for the growth of microalgae and the production of biodiesel from their accumulated lipids. Microalgae have been known to grow in other bodies of undesirable water and research has been ongoing on how to effectively use microalgae as a resource by stimulating lipid accumulation through the use of various environmental stressors. Coal bed methane ponds already provide a source of non-potable water for microalgae cultivation. Exploring the possibility of making these ponds a growth medium for microalgae is the first step in determining whether they can be turned into a productive energy resource. A native green alga, CBMW, has been isolated from a CBM production pond in northeastern Wyoming. CBMW has been cultured and grown under laboratory conditions in sterile CBM water and Bold's Basal Medium (BBM). Chlorophyll levels, biomass growth, pH, lipid accumulation, and water chemistry were tracked while CBMW was grown in sterile CBM water to understand how the alga responds to varying environmental conditions. When grown under the right environmental conditions isolate CBMW increased biomass and accumulated lipids. These results suggest that attempting to grow CBMW on a larger scale in CBM production water could be an effective method to produce biodiesel while utilizing a potentially problematic water source. Advisors/Committee Members: Chairperson, Graduate Committee: Alfred B. Cunningham (advisor), Matthew W. Fields was a co-author of the article, 'Growth of a native algal species in coal bed methane water for biofuel and biomass accumulation' submitted to the journal 'Environmental Science and Technology' which is contained within this thesis. (other).

Subjects/Keywords: Coalbed methane; Biomass energy; Algae

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APA (6^th Edition):

Hodgskiss, L. H. (2015). Evaluation of a green alga isolate for growth and lipid accumulation in coal bed methane water from the Powder River Basin. (Masters Thesis). Montana State University. Retrieved from https://scholarworks.montana.edu/xmlui/handle/1/10138

Chicago Manual of Style (16^th Edition):

Hodgskiss, Logan Henry. “Evaluation of a green alga isolate for growth and lipid accumulation in coal bed methane water from the Powder River Basin.” 2015. Masters Thesis, Montana State University. Accessed April 21, 2021. https://scholarworks.montana.edu/xmlui/handle/1/10138.

MLA Handbook (7^th Edition):

Hodgskiss, Logan Henry. “Evaluation of a green alga isolate for growth and lipid accumulation in coal bed methane water from the Powder River Basin.” 2015. Web. 21 Apr 2021.

Vancouver:

Hodgskiss LH. Evaluation of a green alga isolate for growth and lipid accumulation in coal bed methane water from the Powder River Basin. [Internet] [Masters thesis]. Montana State University; 2015. [cited 2021 Apr 21]. Available from: https://scholarworks.montana.edu/xmlui/handle/1/10138.

Council of Science Editors:

Hodgskiss LH. Evaluation of a green alga isolate for growth and lipid accumulation in coal bed methane water from the Powder River Basin. [Masters Thesis]. Montana State University; 2015. Available from: https://scholarworks.montana.edu/xmlui/handle/1/10138

Montana State University

8. Barnhart, Elliott Paul. Analysis of methane producing communities within underground coal beds.

Degree: MS, College of Letters & Science, 2011, Montana State University

URL: https://scholarworks.montana.edu/xmlui/handle/1/874

► The Powder River Basin in southeastern Montana and northeast Wyoming is the largest source of coal mined in the United States but most of the… (more)

▼ The Powder River Basin in southeastern Montana and northeast Wyoming is the largest source of coal mined in the United States but most of the coal contained in the basin is buried too deeply to be economically accessible. These remote coal beds are dynamic zones where biogeochemical processes work to sustain a microbial ecosystem. Previous work has shown that a direct byproduct of these microbial processes is biogenic methane that can be harvested and utilized as an energy source. Methane is the principle component of natural gas and this can be used as an energy source for electricity generation, heat and transportation fuel producing only carbon dioxide and water when burned in the presence of oxygen. The only known organisms on the planet able to produce methane are classified as Archaea, microorganisms termed methanogens. However, little is known about the responsible methanogens, the conditions conducive to coal-associated methane production, nor the microbial community interactions that promote methane production. Advances in subsurface sampling and molecular techniques have provided a route to capture active microbial consortia from coal beds, but methods need to be refined in order to deal with the unique attributes of coal. Microorganisms involved in coal bed methane (CBM) formation were investigated by applying molecular methods in combination with cultivation techniques with and without nutrient supplementation to maximize methane production in batch, bench-scale incubations. Our research suggests that Clostridium species are involved with the breakdown of coal and Acetobacterium species are able to utilize substrates produced by the coal degradation. Coal and yeast extract each appear to contribute important nutrients that stimulate coal degrading communities. A better understanding of this microbial system and the biotic and abiotic parameters that control activity may permit microbially enhanced CBM production in situ to become an industrially sustainable process through the application of suitable methane stimulation strategies. Advisors/Committee Members: Chairperson, Graduate Committee: Matthew Fields (advisor).

Subjects/Keywords: Coalbed methane

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APA (6^th Edition):

Barnhart, E. P. (2011). Analysis of methane producing communities within underground coal beds. (Masters Thesis). Montana State University. Retrieved from https://scholarworks.montana.edu/xmlui/handle/1/874

Chicago Manual of Style (16^th Edition):

Barnhart, Elliott Paul. “Analysis of methane producing communities within underground coal beds.” 2011. Masters Thesis, Montana State University. Accessed April 21, 2021. https://scholarworks.montana.edu/xmlui/handle/1/874.

MLA Handbook (7^th Edition):

Barnhart, Elliott Paul. “Analysis of methane producing communities within underground coal beds.” 2011. Web. 21 Apr 2021.

Vancouver:

Barnhart EP. Analysis of methane producing communities within underground coal beds. [Internet] [Masters thesis]. Montana State University; 2011. [cited 2021 Apr 21]. Available from: https://scholarworks.montana.edu/xmlui/handle/1/874.

Council of Science Editors:

Barnhart EP. Analysis of methane producing communities within underground coal beds. [Masters Thesis]. Montana State University; 2011. Available from: https://scholarworks.montana.edu/xmlui/handle/1/874

Montana State University

9. Davis, Katherine Jean. Organic amendments for enhancing microbial coalbed methane production.

Degree: PhD, College of Engineering, 2017, Montana State University

URL: https://scholarworks.montana.edu/xmlui/handle/1/13718

► Coalbed methane (CBM) is natural gas found in subsurface coal beds and supplies approximately 4-6% of the annual U.S. natural gas requirements. Many unmineable coal… (more)

Subjects/Keywords: Coalbed methane; Microalgae; Microbial ecology

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APA (6^th Edition):

Davis, K. J. (2017). Organic amendments for enhancing microbial coalbed methane production. (Doctoral Dissertation). Montana State University. Retrieved from https://scholarworks.montana.edu/xmlui/handle/1/13718

Chicago Manual of Style (16^th Edition):

Davis, Katherine Jean. “Organic amendments for enhancing microbial coalbed methane production.” 2017. Doctoral Dissertation, Montana State University. Accessed April 21, 2021. https://scholarworks.montana.edu/xmlui/handle/1/13718.

MLA Handbook (7^th Edition):

Davis, Katherine Jean. “Organic amendments for enhancing microbial coalbed methane production.” 2017. Web. 21 Apr 2021.

Vancouver:

Davis KJ. Organic amendments for enhancing microbial coalbed methane production. [Internet] [Doctoral dissertation]. Montana State University; 2017. [cited 2021 Apr 21]. Available from: https://scholarworks.montana.edu/xmlui/handle/1/13718.

Council of Science Editors:

Davis KJ. Organic amendments for enhancing microbial coalbed methane production. [Doctoral Dissertation]. Montana State University; 2017. Available from: https://scholarworks.montana.edu/xmlui/handle/1/13718

Texas Tech University

10. Mahendra, Sumil K. Pressure transient testing in coalbed methane reservoirs.

Degree: Petroleum Engineering, 1997, Texas Tech University

URL: http://hdl.handle.net/2346/18881

► Pressure transient testing in coalbed methane reservoirs differs significantly from well testing in conventional gas reservoirs. Coal's storage and production mechanisms are the primary cause… (more)

▼ Pressure transient testing in coalbed methane reservoirs differs significantly from well testing in conventional gas reservoirs. Coal's storage and production mechanisms are the primary cause for the disparity in the analysis for the two types of reservoirs. A modification of conventional analysis methods is required, at most times, to adequately evaluate a coal reservoir. This study characterizes a dewatered coal gas reservoir at a specific test site through evaluation of pressure responses from the coal wells in the area. Three different analysis techniques, namely, single-well test analysis, multi-well test analysis and reservoir simulation, were employed to estimate the reservoir properties for the formation at the site. Additionally, the intent of this study was to identify the well testing model representative of the pressure response from a coal reservoir. The real gas pseudopressure method was employed for single- and multiwell test analysis using PIE, a well testing software. Some multi-well test analysis was also performed using Papadopulos-Ramey method, which is specifically designed for anisotropic formations. The reservoir simulation portion of the study, for evaluation of multi-well test analysis results, was performed on ECLIPSE-200, a coalbed methane simulator. Single- and multi-well test analysis of the pressure transient tests run on the coal wells at the site suggested a homogeneous and radial reservoir with boundary effects. This conclusion was reached despite the fact that coal is a dual porosity and dual permeability reservoir. Single- and multi-well test analysis also suggested scale dependent permeability and partially sealing no-flow boundaries at the formation site. Additionally, an average geometric mean permeability was determined for the site from multi-well test analysis. Reservoir simulation gave an estimate for the directional orientation of the face and butt cleat systems, and a measure of the anisotropic permeability ratio between the face and butt cleats for the tested site. Future work needs to be done to determine the exact location of the noflow boundaries and the orientation of the face and butt cleat systems.

Subjects/Keywords: Methane; Coalbed methane

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APA (6^th Edition):

Mahendra, S. K. (1997). Pressure transient testing in coalbed methane reservoirs. (Thesis). Texas Tech University. Retrieved from http://hdl.handle.net/2346/18881

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Mahendra, Sumil K. “Pressure transient testing in coalbed methane reservoirs.” 1997. Thesis, Texas Tech University. Accessed April 21, 2021. http://hdl.handle.net/2346/18881.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Mahendra, Sumil K. “Pressure transient testing in coalbed methane reservoirs.” 1997. Web. 21 Apr 2021.

Vancouver:

Mahendra SK. Pressure transient testing in coalbed methane reservoirs. [Internet] [Thesis]. Texas Tech University; 1997. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/2346/18881.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Mahendra SK. Pressure transient testing in coalbed methane reservoirs. [Thesis]. Texas Tech University; 1997. Available from: http://hdl.handle.net/2346/18881

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Southern Illinois University

11. Pandey, Rohit. Changes in properties of coal as a result of continued bioconversion.

Degree: MS, Mining Engineering, 2015, Southern Illinois University

URL: https://opensiuc.lib.siu.edu/theses/1745

► Microbial actions on coal have long been identified as a source of methane in coalbeds. Andrew Scott (1995) was the first to propose imitating… (more)

▼ Microbial actions on coal have long been identified as a source of methane in coalbeds. Andrew Scott (1995) was the first to propose imitating the natural process of biogenic gasification, possibly leading to recharging coalbed methane (CBM) reservoirs, or setting up natural gas reservoirs in non-producing coalbeds. This study was aimed at identifying the changes in coal properties that affect gas deliverability in coal-gas reservoirs, when treated with microbial consortia to generate/enhance gas production. The experimental work tested the sorption and diffusion properties for the coal treated and, more importantly, the variation in the relevant parameters with continued bio-conversion since these are the first two phenomena in CBM production. During the first phase, single component sorption-diffusion experiments were carried out using pure methane and CO2 on virgin/baseline coals, retrieved from the Illinois basin. Coals were then treated with nutrient amended microbial consortia for different periods. Gas production was monitored at the end of thirty and sixty days of treatment, after which, sorption-diffusion experiments were repeated on treated coals, thus establishing a trend over the sixty-day period. The sorption data was characterized using Langmuir pressure and volume constants, obtained by fitting it over the Langmuir isotherm. The diffusion coefficient, D, was estimated by establishing the variation trend as a function of pore pressure. The pressure parameter was considered critical since, with continued production of methane, the produced gas diffuses into the coal matrix, where it gets adsorbed with increasing pressure. During production, the pressure decreases and the process is reversed, gas diffusing out of the coal matrix and arriving at the cleat system. The results indicated an increase in the sorption capacity of coal as a result of bioconversion. This was attributed to increased pore surface areas as a result of microbial actions. However, significant hysteresis was observed during desorption of methane and was attributed to preferential desorption from sorption sites in the pathways leading to pore cavities. This is corroborated by the increased rates of diffusion, especially for methane, which exhibited rates higher than that for CO2. This contradicted the results for untreated/baseline coal, which were in agreement with previous studies. Effort was made to explain this anomaly by the non-monotonic dependence of effective diffusion coefficient on the size of the diffusing particles, where in coalbed environments, CO2 has smaller kinetic diameter than methane. Advisors/Committee Members: Harpalani, Satya.

Subjects/Keywords: Bioconversion; Coalbed Methane; Diffusion; Reservoir Characterization; Sorption

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APA (6^th Edition):

Pandey, R. (2015). Changes in properties of coal as a result of continued bioconversion. (Masters Thesis). Southern Illinois University. Retrieved from https://opensiuc.lib.siu.edu/theses/1745

Chicago Manual of Style (16^th Edition):

Pandey, Rohit. “Changes in properties of coal as a result of continued bioconversion.” 2015. Masters Thesis, Southern Illinois University. Accessed April 21, 2021. https://opensiuc.lib.siu.edu/theses/1745.

MLA Handbook (7^th Edition):

Pandey, Rohit. “Changes in properties of coal as a result of continued bioconversion.” 2015. Web. 21 Apr 2021.

Vancouver:

Pandey R. Changes in properties of coal as a result of continued bioconversion. [Internet] [Masters thesis]. Southern Illinois University; 2015. [cited 2021 Apr 21]. Available from: https://opensiuc.lib.siu.edu/theses/1745.

Council of Science Editors:

Pandey R. Changes in properties of coal as a result of continued bioconversion. [Masters Thesis]. Southern Illinois University; 2015. Available from: https://opensiuc.lib.siu.edu/theses/1745

Southern Illinois University

12. Schrader, Sawyer David. MODIFICATION OF A CURRENT COALBED METHANE PERMEABILITY MODEL FOR HORIZONTAL STRAIN ONLY.

Degree: MS, Mining Engineering, 2018, Southern Illinois University

URL: https://opensiuc.lib.siu.edu/theses/2392

► Cleat permeability of coal is the most critical parameter affecting the amount of production from a coalbed methane (CBM) reservoir. As a result, there… (more)

Subjects/Keywords: Coalbed methane; modeling; permeability; strain; unconventional energy

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APA (6^th Edition):

Schrader, S. D. (2018). MODIFICATION OF A CURRENT COALBED METHANE PERMEABILITY MODEL FOR HORIZONTAL STRAIN ONLY. (Masters Thesis). Southern Illinois University. Retrieved from https://opensiuc.lib.siu.edu/theses/2392

Chicago Manual of Style (16^th Edition):

Schrader, Sawyer David. “MODIFICATION OF A CURRENT COALBED METHANE PERMEABILITY MODEL FOR HORIZONTAL STRAIN ONLY.” 2018. Masters Thesis, Southern Illinois University. Accessed April 21, 2021. https://opensiuc.lib.siu.edu/theses/2392.

MLA Handbook (7^th Edition):

Schrader, Sawyer David. “MODIFICATION OF A CURRENT COALBED METHANE PERMEABILITY MODEL FOR HORIZONTAL STRAIN ONLY.” 2018. Web. 21 Apr 2021.

Vancouver:

Schrader SD. MODIFICATION OF A CURRENT COALBED METHANE PERMEABILITY MODEL FOR HORIZONTAL STRAIN ONLY. [Internet] [Masters thesis]. Southern Illinois University; 2018. [cited 2021 Apr 21]. Available from: https://opensiuc.lib.siu.edu/theses/2392.

Council of Science Editors:

Schrader SD. MODIFICATION OF A CURRENT COALBED METHANE PERMEABILITY MODEL FOR HORIZONTAL STRAIN ONLY. [Masters Thesis]. Southern Illinois University; 2018. Available from: https://opensiuc.lib.siu.edu/theses/2392

13. Tummons, Michael A. Testing environmental controls on methane generation during microbial degradation of coal and oil from the Cherokee basin, Kansas.

Degree: MS, Department of Geology, 2017, Kansas State University

URL: http://hdl.handle.net/2097/35565

► Biodegradation of crude oil to methane has long been known to exist in shallow petroleum reservoirs. It is only in the past decade, however, in… (more)

▼ Biodegradation of crude oil to methane has long been known to exist in shallow petroleum reservoirs. It is only in the past decade, however, in which the concept of in-reservoir petroleum biodegradation has changed from a model emphasizing aerobic crude-oil degradation (with oxygen delivered down from meteoric waters) to a more recent model in which crude-oil degradation is driven by anaerobic processes (methanogenic microorganisms). In this study, we examine controls on microbial conversion of crude oil and coal into methane in middle-Pennsylvanian strata in the Cherokee Basin, Kansas, USA and how access to oil or coal influence microbial communities. Specifically, we considered the following hypotheses: 1) microorganisms in the basin are capable of generating methane by degrading crude oil or coal and 2) potential controls on the rate of methane formation include microbial diversity, formation water chemistry, nutrient abundance, and carbon dioxide abundance. To test these hypotheses, we used three sets of laboratory experiments constructed of materials from the Cherokee basin, Kansas. One set tested environmental controls on methane generation from oil, another from coal, and a third was a control experiment that utilized methanogenic substrates rather than oil or coal. In the experiments with oil and coal, environmental factors tested ammonium/phosphate availability, feedlot wastewater injection, and carbon dioxide abundance. Our experiments also tested the influence of salinity, by including materials from a well producing water with relatively low salinity and a well producing water with relatively high salinity. The cultures were allowed to incubate from approximately 75 to 170 days, during which headspace of oil and coal bioreactors were sampled periodically and analyzed for methane concentrations. Post incubation analyses included microbial DNA sequencing. We determined that a higher concertation of methanogens existed in the lower salinity well, which has higher potential for practical stimulatory injection. Of methane produced, the only significant (Mann Whitney) treatment had access to oil in lower salinity formation water. Access to coal resulted in no significant results. Microbial diversity, in the form of methanogenic archaea abundance, formation water chemistry (salinity), and wastewater nutrient often correlated with increased, yet insignificant, rates of methane production, while carbon dioxide abundance showed no benefit. Of methanogenic substrates consumed, we determined that most Cherokee basin methanogens preferred methanol over hydrogen and acetate. Advisors/Committee Members: Matthew Kirk.

Subjects/Keywords: Natural Gas; Stimulation; Methane; Archaea; Coalbed; Microbiology

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APA (6^th Edition):

Tummons, M. A. (2017). Testing environmental controls on methane generation during microbial degradation of coal and oil from the Cherokee basin, Kansas. (Masters Thesis). Kansas State University. Retrieved from http://hdl.handle.net/2097/35565

Chicago Manual of Style (16^th Edition):

Tummons, Michael A. “Testing environmental controls on methane generation during microbial degradation of coal and oil from the Cherokee basin, Kansas.” 2017. Masters Thesis, Kansas State University. Accessed April 21, 2021. http://hdl.handle.net/2097/35565.

MLA Handbook (7^th Edition):

Tummons, Michael A. “Testing environmental controls on methane generation during microbial degradation of coal and oil from the Cherokee basin, Kansas.” 2017. Web. 21 Apr 2021.

Vancouver:

Tummons MA. Testing environmental controls on methane generation during microbial degradation of coal and oil from the Cherokee basin, Kansas. [Internet] [Masters thesis]. Kansas State University; 2017. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/2097/35565.

Council of Science Editors:

Tummons MA. Testing environmental controls on methane generation during microbial degradation of coal and oil from the Cherokee basin, Kansas. [Masters Thesis]. Kansas State University; 2017. Available from: http://hdl.handle.net/2097/35565

Louisiana State University

14. Hart, Eric M. Implications of geothermal history on microbial gas generation and coalbed methane production in the Ninilchik Field, Cook Inlet basin, Alaska.

Degree: MS, Earth Sciences, 2012, Louisiana State University

URL: etd-11022012-085228 ; https://digitalcommons.lsu.edu/gradschool_theses/2012

► Coalbed methane (CBM) production operations atop the Ninilchik anticline of Cook Inlet, Alaska pose intriguing questions regarding the nature of biogenic gas generation in a… (more)

▼ Coalbed methane (CBM) production operations atop the Ninilchik anticline of Cook Inlet, Alaska pose intriguing questions regarding the nature of biogenic gas generation in a thermally complex forearc basin setting. This thermal complexity stems, in part, from its up to 30,000 ft thick Tertiary section, comprised of braided stream alluvium and expansive, interbedded coal deposits. Rapid accumulation of cold, glacial strata is documented as being capable of regionally suppressing the elevated heat flux values expected within a forearc basin. In addition, beds with high organic content, such as the coal layers, act as natural insulators from basinal heat flux and possibly cause a further increase to the thermal gradient (i.e. subsurface temperatures may be encountered at comparatively deeper depths relative to a basin with a more thermally conductive lithology). According to Head et al. (2003), 80 °C is the generally accepted maximum temperature that methanogenic bacteria can withstand before being pasteurized inside CBM reservoirs; therefore, the basin’s geothermal history should play a pivotal role in determining which formations have sourced the highest amounts of methane and on what timescale this generation occurred. To investigate these questions, Ninilchik field’s thermal and geohistories were calculated using the PetroMod® basin modeling software package to measure the changes in each layers’ temperature with respect to time and depth. From these results, a sensitivity analysis of the controlling factors for biogenic gas generation (methanogenesis) was conducted to test the hypothesis that rapid Tertiary sedimentation has outpaced the basinal heat flux and is in fact the controlling variable for Ninilchik’s natural gas potential. Results show that regionally, within the deepest parts of the basin that exhibit the highest sedimentation rates, this hypothesis is accurate. Locally, however, it is found that relative anticlinal uplift decreases both subsidence and sedimentation rates, and holds the coal-bearing layers within the optimal temperature regime for extended periods of time. While it is previously understood that the anticlines create vast closures for hydrocarbon accumulation, it is concluded that, above all, relative anticlinal uplift gives rise to the most ideal reservoir conditions and instigates maximum methanogenesis within the Cook Inlet basin.

Subjects/Keywords: methanogenesis rate; thermophilic; mesophilic; coalbed methane enhancement

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APA (6^th Edition):

Hart, E. M. (2012). Implications of geothermal history on microbial gas generation and coalbed methane production in the Ninilchik Field, Cook Inlet basin, Alaska. (Masters Thesis). Louisiana State University. Retrieved from etd-11022012-085228 ; https://digitalcommons.lsu.edu/gradschool_theses/2012

Chicago Manual of Style (16^th Edition):

Hart, Eric M. “Implications of geothermal history on microbial gas generation and coalbed methane production in the Ninilchik Field, Cook Inlet basin, Alaska.” 2012. Masters Thesis, Louisiana State University. Accessed April 21, 2021. etd-11022012-085228 ; https://digitalcommons.lsu.edu/gradschool_theses/2012.

MLA Handbook (7^th Edition):

Hart, Eric M. “Implications of geothermal history on microbial gas generation and coalbed methane production in the Ninilchik Field, Cook Inlet basin, Alaska.” 2012. Web. 21 Apr 2021.

Vancouver:

Hart EM. Implications of geothermal history on microbial gas generation and coalbed methane production in the Ninilchik Field, Cook Inlet basin, Alaska. [Internet] [Masters thesis]. Louisiana State University; 2012. [cited 2021 Apr 21]. Available from: etd-11022012-085228 ; https://digitalcommons.lsu.edu/gradschool_theses/2012.

Council of Science Editors:

Hart EM. Implications of geothermal history on microbial gas generation and coalbed methane production in the Ninilchik Field, Cook Inlet basin, Alaska. [Masters Thesis]. Louisiana State University; 2012. Available from: etd-11022012-085228 ; https://digitalcommons.lsu.edu/gradschool_theses/2012

Virginia Tech

15. Louk, Andrew Kyle. Monitoring CO2 Plume Migration for a Carbon Storage-Enhanced Coalbed Methane Recovery Test in Central Appalachia.

Degree: PhD, Mining Engineering, 2019, Virginia Tech

URL: http://hdl.handle.net/10919/87434

► During the past decade, carbon capture, utilization, and storage (CCUS) has gained considerable recognition as a viable option to mitigate carbon dioxide (CO2) emissions. This… (more)

▼ During the past decade, carbon capture, utilization, and storage (CCUS) has gained considerable recognition as a viable option to mitigate carbon dioxide (CO2) emissions. This process involves capturing CO2 at emission sources such as power plants, refineries, and processing plants, and safely and permanently storing it in underground geologic formations. Many CO2 injection tests have been successfully conducted to assess the storage potential of CO2 in saline formations, oil and natural gas reservoirs, organic-rich shales, and unmineable coal reservoirs. Coal seams are an attractive reservoir for CO2 storage due to coal’s large capacity to store gas within its microporous structure, as well as its ability to preferentially adsorb CO2 over naturally occurring methane resulting in enhanced coalbed methane (ECBM) recovery. A small-scale CO2 injection test was conducted in Southwest Virginia to assess the storage and ECBM recovery potential of CO2 in a coalbed methane reservoir. The goal of this test was to inject up to 20,000 tons of CO2 into a stacked coal reservoir of approximately 15-20 coal seams. Phase I of the injection test was conducted from July 2, 2015 to April 15, 2016 when a total of 10,601 tons of CO2 were injected. Phase II of the injection was conducted from December 14, 2016 to January 30, 2017 when an additional 2,662 tons of CO2 were injected, for a total of 13,263 total tons of CO2 injected. A customized monitoring, verification, and accounting (MVA) plan was created to monitor CO2 injection activities, including surface, near-surface, and subsurface technologies. As part of this MVA plan, chemical tracers were used as a tool to help track CO2 plume migration within the reservoir and determine interwell connectivity. The work presented in this dissertation will discuss the development and implementation of chemical tracers as a monitoring tool, detail wellbore-scale tests performed to characterize CO2 breakthrough and interwell connectivity, and present results from both phases of the CO2 injection test. Advisors/Committee Members: Ripepi, Nino S. (committeechair), Karmis, Michael E. (committee member), Gilliland, Ellen (committee member), Luxbacher, Kramer Davis (committee member).

Subjects/Keywords: CO2 sequestration; coal; enhanced coalbed methane; tracers

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APA (6^th Edition):

Louk, A. K. (2019). Monitoring CO2 Plume Migration for a Carbon Storage-Enhanced Coalbed Methane Recovery Test in Central Appalachia. (Doctoral Dissertation). Virginia Tech. Retrieved from http://hdl.handle.net/10919/87434

Chicago Manual of Style (16^th Edition):

Louk, Andrew Kyle. “Monitoring CO2 Plume Migration for a Carbon Storage-Enhanced Coalbed Methane Recovery Test in Central Appalachia.” 2019. Doctoral Dissertation, Virginia Tech. Accessed April 21, 2021. http://hdl.handle.net/10919/87434.

MLA Handbook (7^th Edition):

Louk, Andrew Kyle. “Monitoring CO2 Plume Migration for a Carbon Storage-Enhanced Coalbed Methane Recovery Test in Central Appalachia.” 2019. Web. 21 Apr 2021.

Vancouver:

Louk AK. Monitoring CO2 Plume Migration for a Carbon Storage-Enhanced Coalbed Methane Recovery Test in Central Appalachia. [Internet] [Doctoral dissertation]. Virginia Tech; 2019. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/10919/87434.

Council of Science Editors:

Louk AK. Monitoring CO2 Plume Migration for a Carbon Storage-Enhanced Coalbed Methane Recovery Test in Central Appalachia. [Doctoral Dissertation]. Virginia Tech; 2019. Available from: http://hdl.handle.net/10919/87434

Virginia Tech

16. Keim, Steven Anthony. Optimization of Coalbed Methane Completion Strategies, Selection Criteria and Production Prediction: A Case Study in China's Qinshui Basin.

Degree: PhD, Mining and Minerals Engineering, 2011, Virginia Tech

URL: http://hdl.handle.net/10919/28842

► Advanced three-dimensional reservoir modeling was used to determine the optimum strategy for coalbed methane production in China's Qinshui Basin. Multiple completion strategies were analyzed for… (more)

▼ Advanced three-dimensional reservoir modeling was used to determine the optimum strategy for coalbed methane production in China's Qinshui Basin. Multiple completion strategies were analyzed for pre-mining methane drainage on the bases of economic, environmental, and mining-safety-based factors. Effective degasification in the Qinshui Basin is crucial to enhance the health and safety of the underground mining workforce and to decrease carbon dioxide equivalent greenhouse gas emissions. Active, large-scale degasification wells in the region include hydraulically stimulated vertical fracture wells and multilaterally drilled horizontal patterns, with the latter much less common. Reservoir modeling concludes that despite their limited implementation, horizontal coalbed methane drainage wells offer the benefits of faster reservoir depressurization, high gas production rates, and faster recovery times than traditional vertical fracture wells. Coupled with reservoir modeling results, discounted cash flow analyses show that high drilling density multilateral horizontal patterns are the most financially feasible degasification strategy in the Qinshui Basin, albeit a higher initial capital investment compared to traditional vertical fracture wells and lower drilling density horizontal patterns. Additionally, horizontal wellbore designs can be altered to account for varying permeability, enhancing the productivity of methane from reservoirs exhibiting permeability values less than 1 millidarcy. Furthermore, modeling suggests that proper orientation of select horizontal wellbore patterns is crucial to optimize recoverable reserves. Finally, a function was derived to represent the production rates of horizontal coalbed methane wells as a function of time. Analysis of the functionâ s validity to actual production data and simulated production data suggest that it is most applicable in gassy coal seams up to 10 feet in thickness. The production rate curve was transformed to an analytical model, representing a function of well geometry and coal permeability as applied to other geological conditions of the Qinshui Basin. Scientific contributions associated with this research include: An in depth study of degasification associated with the Qinshui Basin's low permeability coals; The methodology for assessing environmental, safety and economic benefits of coal degasification; The relationship between lateral spacing and permeability to maintain substantial gas production rates; An improved production model to describe the entire producing period of coalbed methane wells. Advisors/Committee Members: Luttrell, Gerald H. (committee member), Westman, Erik Christian (committee member), Faria, Claudio (committee member), Karmis, Michael E. (committeecochair), Luxbacher, Kramer Davis (committeecochair).

Subjects/Keywords: Qinshui Basin; reservoir modeling; coalbed methane

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APA (6^th Edition):

Keim, S. A. (2011). Optimization of Coalbed Methane Completion Strategies, Selection Criteria and Production Prediction: A Case Study in China's Qinshui Basin. (Doctoral Dissertation). Virginia Tech. Retrieved from http://hdl.handle.net/10919/28842

Chicago Manual of Style (16^th Edition):

Keim, Steven Anthony. “Optimization of Coalbed Methane Completion Strategies, Selection Criteria and Production Prediction: A Case Study in China's Qinshui Basin.” 2011. Doctoral Dissertation, Virginia Tech. Accessed April 21, 2021. http://hdl.handle.net/10919/28842.

MLA Handbook (7^th Edition):

Keim, Steven Anthony. “Optimization of Coalbed Methane Completion Strategies, Selection Criteria and Production Prediction: A Case Study in China's Qinshui Basin.” 2011. Web. 21 Apr 2021.

Vancouver:

Keim SA. Optimization of Coalbed Methane Completion Strategies, Selection Criteria and Production Prediction: A Case Study in China's Qinshui Basin. [Internet] [Doctoral dissertation]. Virginia Tech; 2011. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/10919/28842.

Council of Science Editors:

Keim SA. Optimization of Coalbed Methane Completion Strategies, Selection Criteria and Production Prediction: A Case Study in China's Qinshui Basin. [Doctoral Dissertation]. Virginia Tech; 2011. Available from: http://hdl.handle.net/10919/28842

University of New South Wales

17. Wang, Xingjin. Influence of coal quality factors on seam permeability associated with coalbed methane production.

Degree: Biological, 2007, University of New South Wales

URL: http://handle.unsw.edu.au/1959.4/43896 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:1214/SOURCE02?view=true

► Cleats are natural fractures in coal that serve as permeability avenues for darcy flow of gas and water to the well bore during production. Theoretically,… (more)

▼ Cleats are natural fractures in coal that serve as permeability avenues for darcy flow of gas and water to the well bore during production. Theoretically, the development of cleat and coal-seam permeability is related to the rank, type and grade of the coal concerned. The permeability of a coal seam, moreover, may change during gas production, due to either matrix shrinkage, cleat closure or both. Matrix shrinkage and cleat closure are also affected by numerous geological factors, including coal rank, desorption character and geological setting.A method integrating geochemical and petrographic analysis, reservoir engineering diagnosis, geophysical data and production characteristics has been developed, and used to determine the initial permeability of coal seam on a metre by metre scale. This overcomes the constraint of conventional well test by refining the test intervals.The effect of coal rank, grade and type on the initial permeability of coal seams was also investigated, with the special reference to the coals of the Galilee Basin. The permeability was estimated using analytical equations based on the permeability data obtained from well tests and from cleat descriptions within the seam section. This aspect of the study showed that the coal type, rank and grade strongly influence the initial permeability of individual coal seams. Increase in ash content has negative effect on cleat development and permeability. On contrast, increasing coal rank and proportion of bright coal lead to reduction in cleat spacing and increase in permeability.Twenty three core samples collected from the Qinshui Basin in China were evaluated in the laboratory to investigate the effects of coal grade, rank and type on the change in permeability during pressure depletion. The experimental factors included the coal's geochemical properties, the permeability against changing pressure, and strain with pore pressure depletion. This part of the study fund that permeability changes with pore pressure depletion in relation to coal rank, grade and type. The strain values determined by the experiments with pressure depletion were used to identify the mechanical principles associated with changes in permeability during pressure depletion in relation to the rank, grade and type of the coal concerned.A reservoir simulation study was used to investigate the effects of desorption pressure, geological setting and coal rank on the variation in permeability under in-situ conditions during coalbed methane production, based on a study in the Hedong area, Ordos Basin, China. The simulations allowed history matching of gas and water production from 12 wells with the actual well conditions specified as the model pressure. Good agreement was achieved between the model yields and the actual production data, suggesting that the changing permeability interpreted from the simulation is a realistic representation of the in-situ reservoir properties.The reservoir simulation study found that the decreases in permeability with production exceeded the increase in…

Subjects/Keywords: Coal; Coalbed methane

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APA (6^th Edition):

Wang, X. (2007). Influence of coal quality factors on seam permeability associated with coalbed methane production. (Doctoral Dissertation). University of New South Wales. Retrieved from http://handle.unsw.edu.au/1959.4/43896 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:1214/SOURCE02?view=true

Chicago Manual of Style (16^th Edition):

Wang, Xingjin. “Influence of coal quality factors on seam permeability associated with coalbed methane production.” 2007. Doctoral Dissertation, University of New South Wales. Accessed April 21, 2021. http://handle.unsw.edu.au/1959.4/43896 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:1214/SOURCE02?view=true.

MLA Handbook (7^th Edition):

Wang, Xingjin. “Influence of coal quality factors on seam permeability associated with coalbed methane production.” 2007. Web. 21 Apr 2021.

Vancouver:

Wang X. Influence of coal quality factors on seam permeability associated with coalbed methane production. [Internet] [Doctoral dissertation]. University of New South Wales; 2007. [cited 2021 Apr 21]. Available from: http://handle.unsw.edu.au/1959.4/43896 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:1214/SOURCE02?view=true.

Council of Science Editors:

Wang X. Influence of coal quality factors on seam permeability associated with coalbed methane production. [Doctoral Dissertation]. University of New South Wales; 2007. Available from: http://handle.unsw.edu.au/1959.4/43896 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:1214/SOURCE02?view=true

Colorado School of Mines

18. Tedesco, Steven A. Reservoir characterization and geology of the coals and carbonaceous shales of the Cherokee group in the Cherokee Basin, Kansas, Missouri and Oklahoma, U.S.A.

Degree: PhD, Geology and Geological Engineering, 2014, Colorado School of Mines

URL: http://hdl.handle.net/11124/260

► The Cherokee Basin is an inter-cratonic depression that is part of the Pennsylvanian-age Western Interior Basin. The coals and carbonaceous shales of the Cherokee and… (more)

▼ The Cherokee Basin is an inter-cratonic depression that is part of the Pennsylvanian-age Western Interior Basin. The coals and carbonaceous shales of the Cherokee and Marmaton groups of Desmoinesian age have produced significant quantities of gas for nearly 100 years from depths of less than 2,000 feet. This study determined that the location of the gas in the Cherokee Basin is related to a pre-Pennsylvanian Paleozoic thin, underling the Chautauqua Arch that allowed migrating low temperature hydrothermal fluids (LTHF) to thermally mature Desmoinesian-age coals and carbonaceous shales. This event occurred in the Late Permian and is associated with the Ouachita-Marathon Orogeny to the south. Two of the study areas presented in this study, Jefferson-Sycamore and Thayer, are located over the paleo-thin. In many parts of the basin, there are localized areas of production related to localize LTHF, structural and stratigraphic features. These are illustrated in the Chanute, Bourbon and Mound Valley study areas presented here. The seams in the basin are generally less than two feet thick, may be laminated with alternating bands of coal and shale, are High Volatile A Bituminous rank, high in sulfur, and contain low to moderate amounts of vitrinite as compared to equivalent coals in adjacent basins. The Tebo B, Tebo, V, Excello and Little Osage carbonaceous shales in ascending order, are deep water marine or lacustrine deposits, rich in organic matter and are capable of generating gas. The primary gas productive coals in ascending order across the basin are the Riverton, the Rowe, the Weir-Pittsburg and the Mulky coals. The Aw, Neutral, Drywood, Scammon, Mineral, Croweberg, Bevier and Mulberry coals are marginal or non-productive. The productive coals have sulfur contents over 5%, high fixed carbon or vitrinite and lower ash contents than the non-productive coals. The Excello Shale has over 2.5% sulfur, and high percentage of quartz and carbonates which results in excellent porosity and permeability. The majority of hydraulic fracture stimulations used slick water, but cross-linked gel and nitrogen have proven to be as effective but were more expensive. The study found that a single stimulation of a single zone is more productive than multiple stimulations with multiple zones. Multiple stimulations generally are detrimental and result in fracture communication between several zones, thus losing their effectiveness. The decline curves of these unconventional reservoirs in the Cherokee Basin resemble conventional production decline curves rather than the typical dewatering curve for coalbed methane wells. Throughout this study the integration of geology, production, reservoir characteristics and completion methods was used to understand why certain areas have significant gas in unconventional reservoirs. The overall conclusion of this study is that the gas being produced from the Desmoinesian unconventional reservoirs is a basin-centered gas play. Advisors/Committee Members: Curtis, John B. (advisor), Hendricks, Michael L. (committee member), Miskimins, Jennifer L. (committee member), Plink-Björklund, Piret (committee member), Benson, Robert D. (committee member).

Subjects/Keywords: Oklahoma; Cherokee Basin; coal; coalbed methane; Kansas; shale gas; Shale gas – Kansas; Shale gas – Missouri; Shale gas – Oklahoma; Coalbed methane – Kansas; Coalbed methane – Missouri; Coalbed methane – Oklahoma; Boring; Geology, Stratigraphic

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APA (6^th Edition):

Tedesco, S. A. (2014). Reservoir characterization and geology of the coals and carbonaceous shales of the Cherokee group in the Cherokee Basin, Kansas, Missouri and Oklahoma, U.S.A. (Doctoral Dissertation). Colorado School of Mines. Retrieved from http://hdl.handle.net/11124/260

Chicago Manual of Style (16^th Edition):

Tedesco, Steven A. “Reservoir characterization and geology of the coals and carbonaceous shales of the Cherokee group in the Cherokee Basin, Kansas, Missouri and Oklahoma, U.S.A.” 2014. Doctoral Dissertation, Colorado School of Mines. Accessed April 21, 2021. http://hdl.handle.net/11124/260.

MLA Handbook (7^th Edition):

Tedesco, Steven A. “Reservoir characterization and geology of the coals and carbonaceous shales of the Cherokee group in the Cherokee Basin, Kansas, Missouri and Oklahoma, U.S.A.” 2014. Web. 21 Apr 2021.

Vancouver:

Tedesco SA. Reservoir characterization and geology of the coals and carbonaceous shales of the Cherokee group in the Cherokee Basin, Kansas, Missouri and Oklahoma, U.S.A. [Internet] [Doctoral dissertation]. Colorado School of Mines; 2014. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/11124/260.

Council of Science Editors:

Tedesco SA. Reservoir characterization and geology of the coals and carbonaceous shales of the Cherokee group in the Cherokee Basin, Kansas, Missouri and Oklahoma, U.S.A. [Doctoral Dissertation]. Colorado School of Mines; 2014. Available from: http://hdl.handle.net/11124/260

Montana State University

19. Buchanan, Margaret MacNeill. Soil water flow and irrigated soil water balance in response to Powder River Basin coalbed methane product water.

Degree: MS, College of Agriculture, 2005, Montana State University

URL: https://scholarworks.montana.edu/xmlui/handle/1/1003

► A repacked soil columns experiment and a series of computer soil water balance simulations were conducted to examine potential impacts of coalbed methane (CBM) water… (more)

▼ A repacked soil columns experiment and a series of computer soil water balance simulations were conducted to examine potential impacts of coalbed methane (CBM) water from Montanaαs Powder River Basin (PRB) on soil water flow and water balance in PRB soils. CBM water is often high in sodium, which may separate soil clay particles, particularly after soil exposure to low-salinity rainfall or snowmelt, and when soils contain expansible smectite clay minerals. Aggregates in soils exposed to sodic water may swell and slake, and clays and other fine particles may disperse, clogging soil pores and slowing or preventing soil water flow. In the soil columns experiment, A and B horizon materials from sandy loam, silt loam, and clay loam soils were pre-treated with water having salinity and sodicity typical of PRB CBM water or of Powder River (PR) water currently used for irrigation in the basin. Tension infiltrometer measurements were used to determine infiltration flux, first using pre-treatment water, and subsequently deionized (DI) water, simulating rainwater. Measurements were compared by pre-treatment water, horizon, and soil type. Under pre-treatment water testing, the sandy loam and clay loam soils pre-treated with CBM water exhibited smaller infiltration flux values than when pre-treated with PR water. Only the sandy loam soil showed a greater decrease in infiltration flux with DI water on soils pre-treated with CBM relative to PR water pre-treated soils. There was no difference in infiltration flux decrease with DI water between A and B horizon soils, or between smectite and non-smectite soils. The soil water balance numerical simulations modeled potential effects of sodic irrigation waters on sandy loam, silt loam, clay loam and silty clay PRB soils under sprinkler or flood irrigation, during one growing season. Baseline soil water retention functions were constructed for the five soils, and adjusted via trends identified in the literature to create five additional functions for each soil, simulating exposure to five increasingly sodic irrigation waters. Simulation results showed greater impact of sodic irrigation under flood than sprinkler irrigation. The fine sandy loam and silty clay loam soils exhibited the fewest changes in water balance partitioning, while the silt loam and silty clay soils showed the greatest changes, especially in increased runoff and reduced transpiration. Advisors/Committee Members: Chairperson, Graduate Committee: Jon M. Wraith. (advisor).

Subjects/Keywords: Coalbed methane; Irrigation

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APA (6^th Edition):

Buchanan, M. M. (2005). Soil water flow and irrigated soil water balance in response to Powder River Basin coalbed methane product water. (Masters Thesis). Montana State University. Retrieved from https://scholarworks.montana.edu/xmlui/handle/1/1003

Chicago Manual of Style (16^th Edition):

Buchanan, Margaret MacNeill. “Soil water flow and irrigated soil water balance in response to Powder River Basin coalbed methane product water.” 2005. Masters Thesis, Montana State University. Accessed April 21, 2021. https://scholarworks.montana.edu/xmlui/handle/1/1003.

MLA Handbook (7^th Edition):

Buchanan, Margaret MacNeill. “Soil water flow and irrigated soil water balance in response to Powder River Basin coalbed methane product water.” 2005. Web. 21 Apr 2021.

Vancouver:

Buchanan MM. Soil water flow and irrigated soil water balance in response to Powder River Basin coalbed methane product water. [Internet] [Masters thesis]. Montana State University; 2005. [cited 2021 Apr 21]. Available from: https://scholarworks.montana.edu/xmlui/handle/1/1003.

Council of Science Editors:

Buchanan MM. Soil water flow and irrigated soil water balance in response to Powder River Basin coalbed methane product water. [Masters Thesis]. Montana State University; 2005. Available from: https://scholarworks.montana.edu/xmlui/handle/1/1003

Texas A&M University

20. Saugier, Luke Duncan. Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas.

Degree: MS, Petroleum Engineering, 2004, Texas A&M University

URL: http://hdl.handle.net/1969.1/278

► Greenhouse gases such as carbon dioxide (CO2) may be to blame for a gradual rise in the average global temperature. The state of Texas emits… (more)

▼ Greenhouse gases such as carbon dioxide (CO2) may be to blame for a gradual rise in the average global temperature. The state of Texas emits more CO2 than any other state in the U.S., and a large fraction of emissions are from point sources such as power plants. CO2 emissions can be offset by sequestration of produced CO2 in natural reservoirs such as coal seams, which may initially contain methane. Production of coalbed methane can be enhanced through CO2 injection, providing an opportunity to offset the rather high cost of sequestration. Texas has large coal resources. Although they have been studied there is not enough information available on these coals to reliably predict coalbed methane production and CO2 sequestration potential. The goal of the work was to determine if sequestration of CO2 in low rank coals is an economically feasible option for CO2 emissions reduction. Additionally, reasonable CO2 injection and methane production rates were to be estimated, and the importance of different reservoir parameters investigated. A data set was compiled for use in simulating the injection of CO2 for enhanced coalbed methane production from Texas coals. Simulation showed that Texas coals could potentially produce commercial volumes of methane if production is enhanced by CO2 injection. The efficiency of the CO2 in sweeping the methane from the reservoir is very high, resulting in high recovery factors and CO2 storage. The simulation work also showed that certain reservoir parameters, such as Langmuir volumes for CO2 and methane, coal seam permeability, and Langmuir pressure, need to be determined more accurately. An economic model of Texas coalbed methane operations was built. Production and injection activities were consistent with simulation results. The economic model showed that CO2 sequestration for enhanced coalbed methane recovery is not commercially feasible at this time because of the extremely high cost of separating, capturing, and compressing the CO2. However, should government mandated carbon sequestration credits or a CO2 emissions tax on the order of 10/ton become a reality, CO2 sequestration projects could become economic at gas prices of 4/Mscf. Advisors/Committee Members: McVay, Duane (advisor), Ayers, Walter (advisor), Wolken, Lawrence (committee member).

Subjects/Keywords: sequestration; coalbed methane; enhanced coalbed methane

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Saugier, L. D. (2004). Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/278

Chicago Manual of Style (16^th Edition):

Saugier, Luke Duncan. “Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas.” 2004. Masters Thesis, Texas A&M University. Accessed April 21, 2021. http://hdl.handle.net/1969.1/278.

MLA Handbook (7^th Edition):

Saugier, Luke Duncan. “Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas.” 2004. Web. 21 Apr 2021.

Vancouver:

Saugier LD. Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas. [Internet] [Masters thesis]. Texas A&M University; 2004. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/1969.1/278.

Council of Science Editors:

Saugier LD. Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas. [Masters Thesis]. Texas A&M University; 2004. Available from: http://hdl.handle.net/1969.1/278

Penn State University

21. Aslan, Erhan. Development and Testing of an Advanced Coalbed Methane Numerical Reservoir Simulator.

Degree: 2013, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/18784

► A three dimensional, dual-porosity, dual-permeability, two-phase and compositional reservoir simulator with local grid refinement approach is presented. A local grid refinement (LGR) protocol is used… (more)

▼ A three dimensional, dual-porosity, dual-permeability, two-phase and compositional reservoir simulator with local grid refinement approach is presented. A local grid refinement (LGR) protocol is used for replacing the Peaceman’s wellbore model to simulate complex wellbore geometries while Newton-Raphson procedure is used to find the improvements between each time step. The proposed LGR technique is different than the traditional reservoir simulation methodologies as it uses a high resolution grid system to identify and calculate the performances of complex wellbore structures for which traditional wellbore models are not suitable. The proposed model generates results that show that the new protocol is capable of accurately calculating the flowrate responses of simple well structures in comparison to available commercial simulators. After that the performances of complex wellbore structures, such as multi-lateral, slanted and undulating wells are compared within different reservoir configurations. Case studies show that the benefits of lateral wells diminish with increasing vertical anisotropy. Moreover, the local grid refinement technique is a significant undertaking for the computational performance. To deal with this issue, an iterative linear equation solver (GMRES) and advance matrix preconditioners (ParaSails and FASP) are incorporated to the CBM simulator. Furthermore, to increase the computational efficacy of the numerical simulator, two additional subroutines are implemented to have better initial guess at the Newton-Raphson iterations and at the same time to decrease the oscillations experienced during the Newton-Raphson iterations. These modifications yield significant decreases in the simulation time, where in some cases the simulation time was cut from a week to couple minutes1. 1 Computational platform: Intel Xeon E31125 @3.10 GHZ The proposed model generates results that show that the new protocol is capable of accurately calculating the flowrate responses of simple well structures in comparison to available commercial simulators. After that the performances of complex wellbore structures, such as multi-lateral, slanted and undulating wells are compared within different reservoir configurations. Case studies show that the benefits of lateral wells diminish with increasing vertical anisotropy. Moreover, the local grid refinement technique is a significant undertaking for the computational performance. To deal with this issue, an iterative linear equation solver (GMRES) and advance matrix preconditioners (ParaSails and FASP) are incorporated to the CBM simulator. Furthermore, to increase the computational efficacy of the numerical simulator, two additional subroutines are implemented to have better initial guess at the Newton-Raphson iterations and at the same time to decrease the oscillations experienced during the Newton-Raphson iterations. These modifications yield significant decreases in the simulation time, where in some cases the simulation time was cut from a week to couple minutes*. *… Advisors/Committee Members: Turgay Ertekin, Dissertation Advisor/Co-Advisor, Zuleima T Karpyn, Dissertation Advisor/Co-Advisor, Turgay Ertekin, Committee Chair/Co-Chair, Luis F Ayala H, Committee Member, Savas Yavuzkurt, Committee Member.

Subjects/Keywords: Coalbed methane; local grid refinement; coalbed methane simulator; shrinkage and swelling; parallel processing

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Aslan, E. (2013). Development and Testing of an Advanced Coalbed Methane Numerical Reservoir Simulator. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/18784

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Aslan, Erhan. “Development and Testing of an Advanced Coalbed Methane Numerical Reservoir Simulator.” 2013. Thesis, Penn State University. Accessed April 21, 2021. https://submit-etda.libraries.psu.edu/catalog/18784.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Aslan, Erhan. “Development and Testing of an Advanced Coalbed Methane Numerical Reservoir Simulator.” 2013. Web. 21 Apr 2021.

Vancouver:

Aslan E. Development and Testing of an Advanced Coalbed Methane Numerical Reservoir Simulator. [Internet] [Thesis]. Penn State University; 2013. [cited 2021 Apr 21]. Available from: https://submit-etda.libraries.psu.edu/catalog/18784.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Aslan E. Development and Testing of an Advanced Coalbed Methane Numerical Reservoir Simulator. [Thesis]. Penn State University; 2013. Available from: https://submit-etda.libraries.psu.edu/catalog/18784

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Colorado School of Mines

22. Gallagher, Lisa K. Evaluation of factors that influence microbial communities and methane production in coal microcosms.

Degree: PhD, Civil and Environmental Engineering, 2014, Colorado School of Mines

URL: http://hdl.handle.net/11124/10621

► Vast reserves of coal represent a largely untapped resource that can be used to produce methane gas, a cleaner energy alternative compared to burning oil… (more)

▼ Vast reserves of coal represent a largely untapped resource that can be used to produce methane gas, a cleaner energy alternative compared to burning oil or coal. The methane produced in subsurface coal seams, referred to as coalbed methane, represents an increasingly important source of domestic energy in the United States comprising approximately 10% of natural gas production. Biogenic coalbed methane is formed via the activity of microorganisms and contributes about 40% to the total amount of CBM produced in the world. Enhancement of biogenic coalbed methane has become an area of active research due to its potential impact on energy reserves as well as the positive environmental implications associated with its use. Enrichment cultures from coal were incubated and evaluated by DNA sequencing, qPCR analysis and gas chromatography to determine whether the presence of specific organisms was correlated to methane production and whether microbial community structure differed between productive and unproductive coal microcosms. Additionally, microcosm experiments were designed to assess how prior exposure of coal to oxygen might influence methane production and microbial community structure and dynamics. Microcosms with oxidized coal consistently produced between 50 and 100 micromoles less methane per gram of coal than the un-oxidized coal microcosms. Additionally, un-inoculated microcosms produced levels of methane comparable to their inoculated counterparts, demonstrating the importance of native, coal-associated microbial assemblages in biogenic methane production. Pelobacter was strongly correlated to methane production, suggesting its relevance for methane production. Productive microcosms in this study also had methanogenic populations that were dominated by Methanosarcina, a group of metabolically versatile methanogens. Copy number thresholds for methanogens (mcrA gene; 10[superscript 7] copies/mL), sulfate reducing bacteria (dsrA; 10[superscript 6] copies/mL) and acetogens (fhs; 10[superscript 5] copies/mL) were identified, below which methane production was limited. The results of this research add to the existing body of knowledge and provide findings that may help with increasing natural gas yields by stimulating existing seam activity or by reviving depleted wells. Further work is needed to better understand the intricacies of this process and ways to ensure coalbed methane remains a feasible energy resource. Advisors/Committee Members: Munakata Marr, Junko (advisor), Nummedal, Dag (committee member), Figueroa, Linda A. (committee member), Spear, John R. (committee member), Harris, Steve (committee member), Eydal, Hallgerd (committee member).

Subjects/Keywords: methanogens; biogenic methane; coal; coalbed methane; methanogenesis; sulfate-reducing bacteria; Coalbed methane; Microorganisms; Sulfate-reducing bacteria; Methane

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Gallagher, L. K. (2014). Evaluation of factors that influence microbial communities and methane production in coal microcosms. (Doctoral Dissertation). Colorado School of Mines. Retrieved from http://hdl.handle.net/11124/10621

Chicago Manual of Style (16^th Edition):

Gallagher, Lisa K. “Evaluation of factors that influence microbial communities and methane production in coal microcosms.” 2014. Doctoral Dissertation, Colorado School of Mines. Accessed April 21, 2021. http://hdl.handle.net/11124/10621.

MLA Handbook (7^th Edition):

Gallagher, Lisa K. “Evaluation of factors that influence microbial communities and methane production in coal microcosms.” 2014. Web. 21 Apr 2021.

Vancouver:

Gallagher LK. Evaluation of factors that influence microbial communities and methane production in coal microcosms. [Internet] [Doctoral dissertation]. Colorado School of Mines; 2014. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/11124/10621.

Council of Science Editors:

Gallagher LK. Evaluation of factors that influence microbial communities and methane production in coal microcosms. [Doctoral Dissertation]. Colorado School of Mines; 2014. Available from: http://hdl.handle.net/11124/10621

Colorado School of Mines

23. Glossner, Andrew W. Terminal microbial metabolisms in the deep subsurface under conditions relevant to CO2 sequestration and enhancing methanogenesis from coal.

Degree: PhD, Chemistry and Geochemistry, 2013, Colorado School of Mines

URL: http://hdl.handle.net/11124/79888

► Microbial life in the deep subsurface may extend several kilometers below the surface, and by some estimates surpasses the mass of all life on the… (more)

▼ Microbial life in the deep subsurface may extend several kilometers below the surface, and by some estimates surpasses the mass of all life on the surface of the Earth. Microbes living in the subsurface play important roles in the global carbon cycle, through the breakdown of organic matter and methane formation. The goal in this thesis is to describe the microbial dynamics of two deep subsurface environments, and relate how porewater geochemistry and human-induced changes to those environments affect microbial carbon cycling and community structure. The environments of interest in this thesis are 1) deeply buried coal seams, and 2) sandstone reservoirs. The goals in this thesis include the characterization of microbial community structure and metabolic function in methanogenic coal microcosm experiments in response to imposed geochemical gradients, and the characterization of a microbial community in response to supercritical CO2 injection. Acetate was found to be a key intermediate in methanogenic coal microcosms. Experiments with variable concentrations of sulfate showed the same methanogenic potential as molybdate inhibited experiments, showing that sulfate concentration is not a determining factor in methanogenesis from coal. Experiments amended with acetate showed a decreasing proportion of acetate consumed by methanogens as acetate concentrations increased, suggesting that in situ acetate concentrations determine the relative importance of methanogenesis and sulfate reduction in coal seams. The growth of sulfate reducers and methanogens was monitored using phospholipid fatty acids (PLFA) and quantitative polymerase chain reaction (qPCR) for the functional genes for methanogens (mcrA) and sulfate reducers (dsrA). Bioindicators for SRM, including 10Me16:0, and cy17:0 correlated positively with acetate amendment, which also corresponded with an increase in dsrA and mcrA copy numbers in experiments without molybdate, showing that sulfate reducers and methanogens could metabolize acetate simultaneously in coal bed aquifers with low acetate concentrations. Experiments with variable pCO2 and urea amendment showed that methanogenesis from coal was relatively insensitive to pCO2 at pressures up to 2.5 atm, but urea concentrations above 2.5 g/L caused a cessation of methanogenic activity, most likely due to a pH effect. Methanogenic potential in coal microcosms was also shown to be a function of the metabolic activity of fermenters making acetate prior to the start of each experiment. The consortium of organisms used for experiments with coal was also utilized for experiments with supercritical CO2 (scCO2) at 40 degrees C and 10 MPa. Pre-incubation of sandstone cores caused a 30-60% reduction in permeability of Berea sandstone cores, which was not recovered following scCO2 injection. The injection of a microbial enrichment into sterile sandstone cores also reduced the measured permeability up to 83%. scCO2 did not have a significant impact on the bacterial or archaeal microbial community, as measured by PLFA,… Advisors/Committee Members: Mandernack, Kevin W. (advisor), Simmons, E. Craig (committee member), Munakata Marr, Junko (committee member), Curtis, John B. (committee member), Voorhees, Kent J. (committee member), Nummedal, Dag (committee member), Mills, Christopher (committee member).

Subjects/Keywords: coal; sequestration; microbe; methane; carbon; Microorganisms; Microbial metabolism; Geological carbon sequestration; Coalbed methane

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Glossner, A. W. (2013). Terminal microbial metabolisms in the deep subsurface under conditions relevant to CO2 sequestration and enhancing methanogenesis from coal. (Doctoral Dissertation). Colorado School of Mines. Retrieved from http://hdl.handle.net/11124/79888

Chicago Manual of Style (16^th Edition):

Glossner, Andrew W. “Terminal microbial metabolisms in the deep subsurface under conditions relevant to CO2 sequestration and enhancing methanogenesis from coal.” 2013. Doctoral Dissertation, Colorado School of Mines. Accessed April 21, 2021. http://hdl.handle.net/11124/79888.

MLA Handbook (7^th Edition):

Glossner, Andrew W. “Terminal microbial metabolisms in the deep subsurface under conditions relevant to CO2 sequestration and enhancing methanogenesis from coal.” 2013. Web. 21 Apr 2021.

Vancouver:

Glossner AW. Terminal microbial metabolisms in the deep subsurface under conditions relevant to CO2 sequestration and enhancing methanogenesis from coal. [Internet] [Doctoral dissertation]. Colorado School of Mines; 2013. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/11124/79888.

Council of Science Editors:

Glossner AW. Terminal microbial metabolisms in the deep subsurface under conditions relevant to CO2 sequestration and enhancing methanogenesis from coal. [Doctoral Dissertation]. Colorado School of Mines; 2013. Available from: http://hdl.handle.net/11124/79888

Texas A&M University

24. Sinurat, Pahala Dominicus. The Optimization of Well Spacing in a Coalbed Methane Reservoir.

Degree: MS, Petroleum Engineering, 2012, Texas A&M University

URL: http://hdl.handle.net/1969.1/ETD-TAMU-2010-12-8628

► Numerical reservoir simulation has been used to describe mechanism of methane gas desorption process, diffusion process, and fluid flow in a coalbed methane reservoir. The… (more)

Subjects/Keywords: well spacing; reservoir simulation; sensitivity study; coalbed methane reservoir

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APA (6^th Edition):

Sinurat, P. D. (2012). The Optimization of Well Spacing in a Coalbed Methane Reservoir. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/ETD-TAMU-2010-12-8628

Chicago Manual of Style (16^th Edition):

Sinurat, Pahala Dominicus. “The Optimization of Well Spacing in a Coalbed Methane Reservoir.” 2012. Masters Thesis, Texas A&M University. Accessed April 21, 2021. http://hdl.handle.net/1969.1/ETD-TAMU-2010-12-8628.

MLA Handbook (7^th Edition):

Sinurat, Pahala Dominicus. “The Optimization of Well Spacing in a Coalbed Methane Reservoir.” 2012. Web. 21 Apr 2021.

Vancouver:

Sinurat PD. The Optimization of Well Spacing in a Coalbed Methane Reservoir. [Internet] [Masters thesis]. Texas A&M University; 2012. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2010-12-8628.

Council of Science Editors:

Sinurat PD. The Optimization of Well Spacing in a Coalbed Methane Reservoir. [Masters Thesis]. Texas A&M University; 2012. Available from: http://hdl.handle.net/1969.1/ETD-TAMU-2010-12-8628

Penn State University

25. Rajput, Vaibhav Hiralal. A Production Performance Prediction and Field Development Design Tool for Coalbed Methane Reservoirs.

Degree: 2012, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/14734

► ABSTRACT Ever growing energy demand has forced oil and gas exploration and production (E&P) companies to search and economically produce unconventional energy sources such as… (more)

Subjects/Keywords: Coalbed Methane; Reservoir Simulation; Artificial Neural Networks; Field Development Optimization

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APA (6^th Edition):

Rajput, V. H. (2012). A Production Performance Prediction and Field Development Design Tool for Coalbed Methane Reservoirs. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/14734

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Rajput, Vaibhav Hiralal. “A Production Performance Prediction and Field Development Design Tool for Coalbed Methane Reservoirs.” 2012. Thesis, Penn State University. Accessed April 21, 2021. https://submit-etda.libraries.psu.edu/catalog/14734.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Rajput, Vaibhav Hiralal. “A Production Performance Prediction and Field Development Design Tool for Coalbed Methane Reservoirs.” 2012. Web. 21 Apr 2021.

Vancouver:

Rajput VH. A Production Performance Prediction and Field Development Design Tool for Coalbed Methane Reservoirs. [Internet] [Thesis]. Penn State University; 2012. [cited 2021 Apr 21]. Available from: https://submit-etda.libraries.psu.edu/catalog/14734.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Rajput VH. A Production Performance Prediction and Field Development Design Tool for Coalbed Methane Reservoirs. [Thesis]. Penn State University; 2012. Available from: https://submit-etda.libraries.psu.edu/catalog/14734

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Penn State University

26. Jan, Yao-cheng. Dual-permeability dual-porosity simulator with permeability evolution for production analysis of coalbed methane reservoir.

Degree: 2015, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/27492

► The production behavior of CBM is complex and difficult to predict and analyze because it is governed by the complex physics including desorption mechanism, multi-mechanistic… (more)

Subjects/Keywords: coalbed methane; dual porosity; reservoir simulation; permeability evolution

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APA (6^th Edition):

Jan, Y. (2015). Dual-permeability dual-porosity simulator with permeability evolution for production analysis of coalbed methane reservoir. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/27492

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Jan, Yao-cheng. “Dual-permeability dual-porosity simulator with permeability evolution for production analysis of coalbed methane reservoir.” 2015. Thesis, Penn State University. Accessed April 21, 2021. https://submit-etda.libraries.psu.edu/catalog/27492.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Jan, Yao-cheng. “Dual-permeability dual-porosity simulator with permeability evolution for production analysis of coalbed methane reservoir.” 2015. Web. 21 Apr 2021.

Vancouver:

Jan Y. Dual-permeability dual-porosity simulator with permeability evolution for production analysis of coalbed methane reservoir. [Internet] [Thesis]. Penn State University; 2015. [cited 2021 Apr 21]. Available from: https://submit-etda.libraries.psu.edu/catalog/27492.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Jan Y. Dual-permeability dual-porosity simulator with permeability evolution for production analysis of coalbed methane reservoir. [Thesis]. Penn State University; 2015. Available from: https://submit-etda.libraries.psu.edu/catalog/27492

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of Johannesburg

27. Sandersen, Andrea. A review of the coalbed methane potential of South Africa's coal deposits and a case study from the north-eastern Karoo basin.

Degree: 2012, University of Johannesburg

URL: http://hdl.handle.net/10210/4510

►

M.Sc.

The potential target areas for coalbed methane in South Africa are reviewed and a case study based on borehole data from the north-eastern Karoo… (more)

▼

M.Sc.

The potential target areas for coalbed methane in South Africa are reviewed and a case study based on borehole data from the north-eastern Karoo basin was undertaken. The Early Permian coal seams of the Karoo Supergroup occur in several discrete sedimentary basins in South Africa, of which the Karoo basin is the largest. Using screening criteria based on geological, petrographical and analytical data some of the coal deposits can be excluded as potential coalbed methane producers. These include the Molteno Coalfield, large parts of the Karoo basin coal deposits and some of the Northern Province's coal deposits which are structurally disturbed. The traditional mining areas in the Free State, Witbank and Highveld coalfields are excluded from the coalbed methane study because the target seams occur at less than 200 metres below surface, too shallow for gas retention. Some of the coal seams in the Waterberg Coalfield occur at depths of several hundred metres below surface and these are unlikely to be mined by conventional means. These deep coals may be ideal coalbed methane producers. This regional overview was based on available, published data and two important parameters, permeability of coal and coalbed hydrology are unknown but important factors that will need to be taken into account in any future evaluations. The case study focused on an area close to Amersfoort that has a predicted potential for coalbed methane production. The study utilized 465 borehole descriptions from which isopach maps and geological cross-sections were constructed. Limited samples of borehole core provided lithological information from which a facies analyses was undertaken so as to establish the hydrodynamic origin of each facies types. The main lithofacies associated with the coal seams are mudstones, carbonaceous shales and fine- to coarse-grained sandstone. These data were combined with analyses from limited permeability data, petrographical data and proximate analyses for the Gus and Alfred seams. In addition to the sedimentary rocks, the role of dolerite intrusions was found to be significant as these occur as thick sills and dykes that occur below, within and above the coal seams. These may compartmentalize the seams into secondary targets within the study area. Thick sills overlying the coal zone also increase static loading and may be advantageous with respect to reducing the minimum depthbelow- surface requirements. Potential coalbed methane target areas are identified, although the entire study area is not suitable due to structural displacement of the coal seams, thinning of coal in places and devolatization caused by the dolerites.

Subjects/Keywords: Coalbed methane; Coal mines and mining; Economic geology

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Sandersen, A. (2012). A review of the coalbed methane potential of South Africa's coal deposits and a case study from the north-eastern Karoo basin. (Thesis). University of Johannesburg. Retrieved from http://hdl.handle.net/10210/4510

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Sandersen, Andrea. “A review of the coalbed methane potential of South Africa's coal deposits and a case study from the north-eastern Karoo basin.” 2012. Thesis, University of Johannesburg. Accessed April 21, 2021. http://hdl.handle.net/10210/4510.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Sandersen, Andrea. “A review of the coalbed methane potential of South Africa's coal deposits and a case study from the north-eastern Karoo basin.” 2012. Web. 21 Apr 2021.

Vancouver:

Sandersen A. A review of the coalbed methane potential of South Africa's coal deposits and a case study from the north-eastern Karoo basin. [Internet] [Thesis]. University of Johannesburg; 2012. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/10210/4510.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Sandersen A. A review of the coalbed methane potential of South Africa's coal deposits and a case study from the north-eastern Karoo basin. [Thesis]. University of Johannesburg; 2012. Available from: http://hdl.handle.net/10210/4510

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of the Western Cape

28. Mabitje, Mamphedi Sylvia. Determination of total organic carbon content using Passey’s ΔLogR method in coals of the Central Kalahari Karoo Basin, Botswana.

Degree: 2016, University of the Western Cape

URL: http://hdl.handle.net/11394/4974

► The Kalahari Karoo Basin is one of several basins in southern Africa filled with Late Carboniferous to Jurassic sediments that are primary targets for Permian… (more)

Subjects/Keywords: Kalahari Karoo Basin; Passey’s ΔLogR method; Coalbed methane; Coal; Botswana

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APA (6^th Edition):

Mabitje, M. S. (2016). Determination of total organic carbon content using Passey’s ΔLogR method in coals of the Central Kalahari Karoo Basin, Botswana. (Thesis). University of the Western Cape. Retrieved from http://hdl.handle.net/11394/4974

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Mabitje, Mamphedi Sylvia. “Determination of total organic carbon content using Passey’s ΔLogR method in coals of the Central Kalahari Karoo Basin, Botswana. ” 2016. Thesis, University of the Western Cape. Accessed April 21, 2021. http://hdl.handle.net/11394/4974.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Mabitje, Mamphedi Sylvia. “Determination of total organic carbon content using Passey’s ΔLogR method in coals of the Central Kalahari Karoo Basin, Botswana. ” 2016. Web. 21 Apr 2021.

Vancouver:

Mabitje MS. Determination of total organic carbon content using Passey’s ΔLogR method in coals of the Central Kalahari Karoo Basin, Botswana. [Internet] [Thesis]. University of the Western Cape; 2016. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/11394/4974.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Mabitje MS. Determination of total organic carbon content using Passey’s ΔLogR method in coals of the Central Kalahari Karoo Basin, Botswana. [Thesis]. University of the Western Cape; 2016. Available from: http://hdl.handle.net/11394/4974

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Virginia Tech

29. Vasilikou, Foteini. Modeling CO2 Sequestration and Enhanced Gas Recovery in Complex Unconventional Reservoirs.

Degree: PhD, Mining Engineering, 2014, Virginia Tech

URL: http://hdl.handle.net/10919/64320

► Geologic sequestration of CO2 into unmineable coal seams is proposed as a way to mitigate the greenhouse gas effect and potentially contribute to economic prosperity… (more)

▼ Geologic sequestration of CO2 into unmineable coal seams is proposed as a way to mitigate the greenhouse gas effect and potentially contribute to economic prosperity through enhanced methane recovery. In 2009, the Virginia Center for Coal and Energy Research (VCCER) injected 907 tonnes of CO2 into one vertical coalbed methane well for one month in Russell County, Virginia (VA). The main objective of the test was to assess storage potential of coal seams and to investigate the potential of enhanced gas recovery. In 2014, a larger scale test is planned where 20,000 tonnes of CO2 will be injected into three vertical coalbed methane wells over a period of a year in Buchanan County, VA. During primary coalbed methane production and enhanced production through CO2 injection, a series of complex physical and mechanical phenomena occur. The ability to represent the behavior of a coalbed reservoir as accurately as possible via computer simulations yields insight into the processes taking place and is an indispensable tool for the decision process of future operations. More specifically, the economic viability of projects can be assessed by predicting production: well performance can be maximized, drilling patterns can be optimized and, most importantly, associated risks with operations can be accounted for and possibly avoided. However, developing representative computer models and successfully simulating reservoir production and injection regimes is challenging. A large number of input parameters are required, many of which are uncertain even if they are determined experimentally or via in-situ measurements. Such parameters include, but are not limited to, seam geometry, formation properties, production constraints, etc. Modeling of production and injection in multi-seam formations for hydraulically fractured wells is a recent development in coalbed methane/enhanced coalbed methane (CBM/ECBM) reservoir modeling, where models become even more complex and demanding. In such cases model simulation times become important. The development of accurate simulation models that correctly account for the behavior of coalbeds in primary and enhanced production is a process that requires attention to detail, data validation, and model verification. A number of simplifying assumptions are necessary to run these models, where the user should be able to balance accuracy with computational time. In this thesis, pre- and post-injection simulations for the site in Russell County, VA, and preliminary reservoir simulations for the Buchanan County, VA, site are performed. The concepts of multi-well, multi-seam, explicitly modeled hydraulic fractures and skin factors are incorporated with field results to provide accurate modeling predictions. Advisors/Committee Members: Ripepi, Nino S. (committeechair), Karmis, Michael E. (committeechair), Luxbacher, Kramer Davis (committee member), Luttrell, Gerald H. (committee member), Agioutantis, Zacharias (committee member).

Subjects/Keywords: coalbed methane; carbon dioxide; reservoir modeling; unconventional reservoirs

Record Details Similar Records Cite « Share

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Vasilikou, F. (2014). Modeling CO2 Sequestration and Enhanced Gas Recovery in Complex Unconventional Reservoirs. (Doctoral Dissertation). Virginia Tech. Retrieved from http://hdl.handle.net/10919/64320

Chicago Manual of Style (16^th Edition):

Vasilikou, Foteini. “Modeling CO2 Sequestration and Enhanced Gas Recovery in Complex Unconventional Reservoirs.” 2014. Doctoral Dissertation, Virginia Tech. Accessed April 21, 2021. http://hdl.handle.net/10919/64320.

MLA Handbook (7^th Edition):

Vasilikou, Foteini. “Modeling CO2 Sequestration and Enhanced Gas Recovery in Complex Unconventional Reservoirs.” 2014. Web. 21 Apr 2021.

Vancouver:

Vasilikou F. Modeling CO2 Sequestration and Enhanced Gas Recovery in Complex Unconventional Reservoirs. [Internet] [Doctoral dissertation]. Virginia Tech; 2014. [cited 2021 Apr 21]. Available from: http://hdl.handle.net/10919/64320.

Council of Science Editors:

Vasilikou F. Modeling CO2 Sequestration and Enhanced Gas Recovery in Complex Unconventional Reservoirs. [Doctoral Dissertation]. Virginia Tech; 2014. Available from: http://hdl.handle.net/10919/64320

Montana State University

30. Mitchem, Melissa Deanne. Response of grass species to soil salt content and coversoil depth on lands developed for coalbed methane.

Degree: MS, College of Agriculture, 2005, Montana State University

URL: https://scholarworks.montana.edu/xmlui/handle/1/1884

► In areas where land is disturbed to extract energy resources such as coalbed methane, improper soil management may result in soils impaired by elevated salinity.… (more)

▼ In areas where land is disturbed to extract energy resources such as coalbed methane, improper soil management may result in soils impaired by elevated salinity. The objectives of this study were to evaluate the emergence and growth of three native grass species (Pseudorogeneria spicata, Hesperostipa comata, and Pascopyrum smithii) as a function of i) soil salt content and matric potential, and ii) coversoil depth overlying a saline substrate. The first study consisted of nine treatments, combining three soil salinity levels (0.80, 5.0 and 11.0 dS/m) and three matric potential ranges (-0.1 to -1.0, -1.0 to -7.0, and less than -7.0 bars). Seedling emergence, plant height, aboveground biomass, and belowground biomass were significantly decreased by increasing soil salinity and decreasing soil moisture. A correlation analysis showed matric potential to be more significantly correlated to seedling emergence and growth than soil salinity. This resulted in large reductions in growth when soil moisture was decreased within a salinity treatment. Emergence for plants grown in elevated salinity increased as much as 26.7 % when moisture was high. At low soil moisture, elevated salinity resulted in emergence losses as high as 88.3 %. Losses in aboveground biomass ranged from 23.0 to 97.9 % at moderate salinity and 27.3 to 98.5% at high salinity. Results indicate that the impacts of elevated soil salinity are highly influenced by soil moisture. Irrigation will be an important factor in revegetation of saline soils. Also, investigators studying plant growth on saline soils must closely consider the impact of soil moisture on study results. For the second study, a substrate consisting of a mixture of soil and geologic stratum was salinized to an EC of 11.0 dS/m. Non-saline coversoil was applied on top of the saline substrate at depths of 0, 5, 10, 15, 30 and 45 centimeters. Aboveground and belowground biomasses were significantly greater with increased coversoil depth, with depths of 15, 30 and 45 cm producing similar results. Results suggest that coversoil is necessary to improve plant growth on a saline substrate, but applications of less than 45 cm may be adequate. Advisors/Committee Members: Chairperson, Graduate Committee: Douglas J. Dollhopf. (advisor).

Subjects/Keywords: Coalbed methane; Soils; Salts; Revegetation

Record Details Similar Records Cite « Share

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Mitchem, M. D. (2005). Response of grass species to soil salt content and coversoil depth on lands developed for coalbed methane. (Masters Thesis). Montana State University. Retrieved from https://scholarworks.montana.edu/xmlui/handle/1/1884

Chicago Manual of Style (16^th Edition):

Mitchem, Melissa Deanne. “Response of grass species to soil salt content and coversoil depth on lands developed for coalbed methane.” 2005. Masters Thesis, Montana State University. Accessed April 21, 2021. https://scholarworks.montana.edu/xmlui/handle/1/1884.

MLA Handbook (7^th Edition):

Mitchem, Melissa Deanne. “Response of grass species to soil salt content and coversoil depth on lands developed for coalbed methane.” 2005. Web. 21 Apr 2021.

Vancouver:

Mitchem MD. Response of grass species to soil salt content and coversoil depth on lands developed for coalbed methane. [Internet] [Masters thesis]. Montana State University; 2005. [cited 2021 Apr 21]. Available from: https://scholarworks.montana.edu/xmlui/handle/1/1884.

Council of Science Editors:

Mitchem MD. Response of grass species to soil salt content and coversoil depth on lands developed for coalbed methane. [Masters Thesis]. Montana State University; 2005. Available from: https://scholarworks.montana.edu/xmlui/handle/1/1884

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