CO2 sequestration into the Wyodak coal seam of Powder River Basin—Preliminary reservoir characterization and simulation

To quantify and rank gas wettability of coal as a key parameter affecting the extent of CO 2 sequestration in coal and CH 4 recovery from coal, we developed a contact angle measuring system based on a captive gas bubble technique. We used this system to study the gas wetting properties of an Australian coal from the Sydney Basin. Gas bubbles were generated and captivated beneath a coal sample within a distilled water-filled (pH 5.7) pressurised cell. Because of the use of distilled water, and the continuous dissolution and shrinkage of the gas bubble in water during measurement, the contact angles measured correspond to a 'transient receding' contact angle. To take into account the mixed-gas nature (CO 2 , CH 4 , and to a lesser extent N 2 ) of coal seam gas in the basin, we evaluated the relative wettability of coal by CH 4 , CO 2 and N 2 gases in the presence of water. Measurements were taken at various pressures of up to 15 MPa for CH 4 and N 2 , and up to 6 MPa for CO 2 at a constant temperature of 22°C. Overall, our results show that CO 2 wets coal more extensively than CH 4 , which in turn wets coal slightly more than N 2 . Moreover, the contact angle reduces as the pressure increases, and becomes < 90°at various pressures depending on the gas type. In other words, all three gases wet coal better than water under sufficiently high pressure.

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“…; Kronimus et al . ; Saghafi ; Dutta & Zoback ). Coal seams are compact gas reservoirs and can also be considered aquifers.…”

Section: Introductionmentioning

confidence: 99%

Study of coal gas wettability for CO₂ storage and CH₄ recovery

2014

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“…Coal permeability is mainly related to the system of cleats within the coal structure. During the process of injecting CO 2 into the coal seam under supercritical conditions, it may be expected that pore and fracture permeability will increase, especially in the case of large depth storage [21]. Coal permeability may be significantly affected by the changes of relative permeability, which is highly dependent on the degree of rock saturation, on the effective stress exerted on the coal seam as well as on the pore pressure, which causes the coal matrix shrinking and swelling.…”

Section: Resultsmentioning

confidence: 99%

“…ECBM projects using CO 2 and N 2 have been carried on since the 1990s in San Juan Basin (USA). Such experimental ECBM works showed that the injection of these gases is technically and economically feasible because it resulted in an increase in methane extraction by about 17-18% in the case of CO 2 injection and about 10-20% in the case of N 2 injection [19][20][21].…”

Section: Introductionmentioning

confidence: 99%

Research on the Processes of Injecting CO2 into Coal Seams with CH4 Recovery Using Horizontal Wells

et al. 2020

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The paper presents a research study on modeling and computer simulation of injecting CO2 into the coal seams of the Upper Silesian Coal Basin, Poland connected with enhanced coal bed methane (ECBM) recovery. In the initial stage of the research activities, a structural parameter model was developed specifically with reference to the coal-bearing formations of the Upper Carboniferous for which basic parameters of coal quality and the distribution of methane content were estimated. In addition, a lithological model of the overall reservoir structure was developed and the reservoir parameters of the storage site were analyzed. In the next stage of the research, the static model was supplemented with detailed reservoir parameters as well as the thermodynamic properties of fluids and complex gases. The paper discusses a series of simulations of an enhanced coalbed methane recovery process with a simultaneous injection of carbon dioxide. The analyses were performed using the ECLIPSE software designed for simulating coal seam processes. The results of the simulations demonstrated that the total volume of CO2 injected to a designated seam in a coal mine during the period of one year equaled 1,954,213 sm3. The total amount of water obtained from the production wells during the whole period of the simulations (6.5 years) was 9867 sm3. At the same time, 15,558,906 sm3 of gas was recovered, out of which 14,445,424 sm3 was methane. The remaining 7% of the extracted gas was carbon dioxide as a result of reverse production of the previously injected CO2. However, taking into consideration the phenomena of coal matrix shrinking and swelling, the total amount of injected CO2 decreased to approximately 625,000 sm3.

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“…Some of the modeling work to date involves scCO 2 injection in homogeneous and relatively simple heterogeneous configurations (e.g., Birkholzer et al, 2009;Kim et al, 2012;Mathias et al, 2013). With increasing computational power, researchers have started to simulate flow and transport in heterogeneous reservoirs at the plume and basin scales (Benisch and Bauer, 2013;Dutta and Zoback, 2012;Pham et al, 2013;Person et al, 2013;Yamamoto et al, 2009;Senel et al, 2013;Sung et al, 2014;Zhou and Birkholzer, 2010;Doughty, 2010). The recent modeling applications comprise evaluations of injection into aquifers in Norway (Pham et al, 2013), Taiwan (Sung et al, 2014), Germany (Benish and Bauer, 2013), and Japan (Yamamoto et al, 2009) as well as at several U.S. sites.…”

Section: Introductionmentioning

confidence: 99%

“…The recent modeling applications comprise evaluations of injection into aquifers in Norway (Pham et al, 2013), Taiwan (Sung et al, 2014), Germany (Benish and Bauer, 2013), and Japan (Yamamoto et al, 2009) as well as at several U.S. sites. Sites selected for simulation of scCO 2 injection include the Powder River Basin in Wyoming (Dutta and Zoback, 2012), the Kimberlina aquifer in California (Doughty, 2010), the Frio brine pilot site in Texas (Doughty et al, 2008) and several sites in the Illinois Basin (Bandilla et al, 2012;Person et al, 2010;Senel et al, 2014;Zhou et al, 2010). The sandstone of interest in most of the Illinois Basin studies is the Mt.…”

Section: Introductionmentioning

confidence: 99%

Simulation of carbon dioxide injection at the FutureGen2.0 site: Class VI permit model and local sensitivity analysis

White

Zhang

Oostrom

2016

International Journal of Greenhouse Gas Control

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Numerical simulation was conducted to evaluate supercritical CO 2 (scCO 2) storage in the Mt. Simon sandstone at the FutureGen 2.0 site in Morgan County, Illinois. The simulations illustrate the recent modeling effort conducted to successfully obtain a Class VI permit under the Underground Injection Control Program of the U.S. Environmental Protection Agency. The scCO2 was injected into a highly stratified reservoir, distributed among four lateral wells. Results show that each of the multiple reservoir layers with low permeability traps a fraction of the scCO 2 beneath it so that the injected scCO 2 does not reach the top of the reservoir by the end of the simulation period. Hence, all of the injected scCO 2 is considered to be safely trapped by the stratified structure within the reservoir. A local sensitivity analysis (LSA) was conducted for injectivity and plume size at the end of the 20 year injection period. The LSA indicates that the imposed initial conditions and the hydraulic properties of the injection layer contribute the most to the sensitivity. Overall, the simulation outputs are very sensitive to only a small fraction of the inputs. However, the parameters that are important for controlling CO 2 injectivity are not the same as those controlling the plume area. The three most sensitive inputs for injectivity are the horizontal permeability and the residual aqueous saturation of the injection layer, and the initial fracture-pressure gradient. For the plume area, the most sensitive inputs are the horizontal permeability of the injection layer and the residual aqueous saturation of the two adjacent layers above the injection layer. The advantages of requiring just a single set of simulation results, scalability to the proper parameter errors, and straightforward calculation of the composite sensitivities make the proposed analysis attractive for guiding site characterization, injection well design, estimating Area of Review uncertainty and, and monitoring network design.

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CO2 sequestration into the Wyodak coal seam of Powder River Basin—Preliminary reservoir characterization and simulation

Cited by 16 publications

References 33 publications

Study of coal gas wettability for CO₂ storage and CH₄ recovery

Study of coal gas wettability for CO₂ storage and CH₄ recovery

Research on the Processes of Injecting CO2 into Coal Seams with CH4 Recovery Using Horizontal Wells

Simulation of carbon dioxide injection at the FutureGen2.0 site: Class VI permit model and local sensitivity analysis

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CO2 sequestration into the Wyodak coal seam of Powder River Basin—Preliminary reservoir characterization and simulation

Cited by 16 publications

References 33 publications

Study of coal gas wettability for CO2 storage and CH4 recovery

Study of coal gas wettability for CO2 storage and CH4 recovery

Research on the Processes of Injecting CO2 into Coal Seams with CH4 Recovery Using Horizontal Wells

Simulation of carbon dioxide injection at the FutureGen2.0 site: Class VI permit model and local sensitivity analysis

Contact Info

Product

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Study of coal gas wettability for CO₂ storage and CH₄ recovery

Study of coal gas wettability for CO₂ storage and CH₄ recovery