Central Appalachian Basin Unconventional (Coal/Organic Shale) Reservoir Small Scale CO2 Injection Test

2018 ◽  
Author(s):  
Michael Karmis ◽  
Nino Ripepi ◽  
Ellen Gilliland ◽  
Andrew Louk ◽  
Xu Tang ◽  
...  
Keyword(s):  
Appalachian Basin ◽  
Small Scale ◽  
Injection Test ◽  
Shale Reservoir ◽  
Organic Shale

scholarly journals Bayesian approach for three-dimensional aquifer characterization at the Hanford 300 Area

2010 ◽  
Vol 14 (10) ◽  
pp. 1989-2001 ◽  
Author(s):  
H. Murakami ◽  
X. Chen ◽  
M. S. Hahn ◽  
Y. Liu ◽  
M. L. Rockhold ◽  
...  
Keyword(s):  
Test Data ◽  
Bayesian Approach ◽  
Posterior Distribution ◽  
Large Scale ◽  
Three Dimensional ◽  
Measurement Data ◽  
Data Uncertainty ◽  
Small Scale ◽  
Injection Test ◽  
Conductivity Profile

Abstract. This study presents a stochastic, three-dimensional characterization of a heterogeneous hydraulic conductivity field within the Hanford 300 Area, Washington, USA, by assimilating large-scale, constant-rate injection test data with small-scale, three-dimensional electromagnetic borehole flowmeter (EBF) measurement data. We first inverted the injection test data to estimate the transmissivity field, using zeroth-order temporal moments of pressure buildup curves. We applied a newly developed Bayesian geostatistical inversion framework, the method of anchored distributions (MAD), to obtain a joint posterior distribution of geostatistical parameters and local log-transmissivities at multiple locations. The unique aspects of MAD that make it suitable for this purpose are its ability to integrate multi-scale, multi-type data within a Bayesian framework and to compute a nonparametric posterior distribution. After we combined the distribution of transmissivities with depth-discrete relative-conductivity profile from the EBF data, we inferred the three-dimensional geostatistical parameters of the log-conductivity field, using the Bayesian model-based geostatistics. Such consistent use of the Bayesian approach throughout the procedure enabled us to systematically incorporate data uncertainty into the final posterior distribution. The method was tested in a synthetic study and validated using the actual data that was not part of the estimation. Results showed broader and skewed posterior distributions of geostatistical parameters except for the mean, which suggests the importance of inferring the entire distribution to quantify the parameter uncertainty.

Application of 3D seismic attribute analysis to structure interpretation and hydrocarbon exploration southwest Pennsylvania, Central Appalachian Basin: A case study

2016 ◽  
Vol 4 (3) ◽  
pp. T291-T302 ◽  
Author(s):  
Thomas Donahoe ◽  
Dengliang Gao
Keyword(s):  
Shear Zones ◽  
Appalachian Basin ◽  
Structural Features ◽  
Hydrocarbon Exploration ◽  
Small Scale ◽  
3D Seismic ◽  
Seismic Attribute ◽  
Data Set ◽  
Fracturing Process ◽  
Southwest Pennsylvania

In the Central Appalachian Basin, southwest Pennsylvania, recently collected high-quality 3D seismic data provide critical information vital to the delineation of basin structures and depositional facies. It is therefore important for the development and verification of ideas associated with structural architecture and growth history of the basin. Traditional wiggle trace imagery has a low dominant frequency and signal-to-noise ratio. The conventional seismic attributes extracted from this data set, such as amplitude, frequency, and phase, are not effective at defining structural details and relations between faults and folds. To overcome these limitations, we have applied waveform regression, jointly with variance, and ant tracking to increase the resolution of structural features, leading to enhanced observations and interpretations. Forethrust to backthrust patterns and small-scale, intrainterval shear zones or detachment faults were observed within the Devonian intervals in which the Marcellus Shale has been developed. From the trend of discontinuities, the primary stress orientation during the Devonian was defined at approximately 105°–120° azimuth, which may affect drilling orientations in the hydraulic fracturing process of the Marcellus gas shale reservoir. Initial observations of gas production data hint at a correlation between structural quiescence and increased productivity in this study area. This effort demonstrates the importance of innovative 3D seismic-attribute techniques and analysis to understanding the relationship of subsurface structural features that are fundamental to the success of future exploration for and production of oil and gas.

scholarly journals Bayesian approach for three-dimensional aquifer characterization at the hanford 300 area

2010 ◽  
Vol 7 (2) ◽  
pp. 2017-2052 ◽  
Author(s):  
H. Murakami ◽  
X. Chen ◽  
M. S. Hahn ◽  
Y. Liu ◽  
M. L. Rockhold ◽  
...  
Keyword(s):  
Test Data ◽  
Bayesian Approach ◽  
Posterior Distribution ◽  
Large Scale ◽  
Three Dimensional ◽  
Measurement Data ◽  
Data Uncertainty ◽  
Small Scale ◽  
Injection Test ◽  
Conductivity Profile

Abstract. This study presents a stochastic, three-dimensional characterization of a heterogeneous hydraulic conductivity field within DOE's Hanford 300 Area site, Washington, by assimilating large-scale, constant-rate injection test data with small-scale, three-dimensional electromagnetic borehole flowmeter (EBF) measurement data. We first inverted the injection test data to estimate the transmissivity field, using zeroth-order temporal moments of pressure buildup curves. We applied a newly developed Bayesian geostatistical inversion framework, the method of anchored distributions (MAD), to obtain a joint posterior distribution of geostatistical parameters and local log-transmissivities at multiple locations. The unique aspects of MAD that make it suitable for this purpose are its ability to integrate multi-scale, multi-type data within a Bayesian framework and to compute a nonparametric posterior distribution. After we combined the distribution of transmissivities with depth-discrete relative-conductivity profile from the EBF data, we inferred the three-dimensional geostatistical parameters of the log-conductivity field, using the Bayesian model-based geostatistics. Such consistent use of the Bayesian approach throughout the procedure enabled us to systematically incorporate data uncertainty into the final posterior distribution. The method was tested in a synthetic study and validated using the actual data that was not part of the estimation. Results showed broader and skewed posterior distributions of geostatistical parameters except for the mean, which suggests the importance of inferring the entire distribution to quantify the parameter uncertainty.

Depositional impact on the elastic characteristics of the organic shale reservoir and its seismic application: A case study of the Longmaxi-Wufeng Shale in the Fuling gas field, Sichuan Basin

Geophysics ◽  
2020 ◽  
Vol 85 (2) ◽  
pp. B23-B33 ◽  
Author(s):  
Luanxiao Zhao ◽  
Yang Wang ◽  
Xiwu Liu ◽  
Jinqiang Zhang ◽  
Yuwei Liu ◽  
...  
Keyword(s):  
Sichuan Basin ◽  
Depositional Environment ◽  
Model Building ◽  
Seismic Inversion ◽  
Depositional Facies ◽  
Gas Field ◽  
Rock Structure ◽  
Shale Reservoir ◽  
Organic Shale ◽  
Elastic Characteristics

Seismic characterization of the depositional evolution history of the organic shale reservoir is essential for reservoir quality evaluation and geologic model building in unconventional plays. However, a direct link between the depositional environment and seismic elastic responses in organic-rich shales remains unclear. By combining the depositional history and rock-physics analysis, we have determined how the depositional environment affects the elastic characteristics of the Longmaxi-Wufeng Shale in the Fuling gas field, Sichuan Basin, Southwestern China. Sedimentological control on the elastic properties mainly lies in two aspects: First, the distinct elastic features of the overlying turbidity mudstone and the underlying deepwater shelf Longmaxi Formation are primarily caused by the rock structure difference due to water energy; second, within the deepwater shelf siliceous shale formation, the elastic property variations are primarily controlled by the progradation tract system and water depths. We evaluate the effect of two types of quartz (biogenic quartz and detrital quartz) in conjunction with organic matter on the elasticity of organic shale. Furthermore, we determine that the two most commonly used seismic inversion attributes, P-impedances and the [Formula: see text] ratio, can be used to indicate the depositional facies evolution. This also gives insights into using geophysical attributes to directly characterize depositional facies for unconventional shale reservoirs.

Reservoir Simulation of CO2 Sequestration in Shale Reservoir

2021 ◽  
Author(s):  
Qin He ◽  
Teresa Reid ◽  
Guofang Zheng
Keyword(s):  
Reservoir Simulation ◽  
Coalbed Methane ◽  
Co2 Sequestration ◽  
Carbon Capture ◽  
Gas Production ◽  
Small Scale ◽  
Gas Recovery ◽  
Service Companies ◽  
Shale Reservoir ◽  
Shale Reservoirs

Abstract Increased production in natural gas from shale reservoirs has sparked concern that greenhouse gas emissions have also been on the rise. As a result, large- and small-scale operators and service companies are enthusiastically supporting a push toward "net carbon zero emissions". Carbon capture utilization and storage (CCUS) is playing an impactful role in companies’ goals to reach net zero. CO2 sequestration is the process of capturing and storing CO2 emissions from industrial and energy-related sources. Most CO2 sequestration are recommended to locate in saline aquifer, coalbed zone and depleted reservoirs, while CO2 sequestration in shale reservoir could become another good option to minimize the environmental footprint and enhance the gas production. Similar as CO2 sequestration into coalbed methane reservoir, the fluid flow mechanism in shale also includes desorption, diffusion and Darcy's law. In this paper, the effects of CO2 sequestration on shale reservoirs will be discussed from a technical and economical viewpoint. A reservoir simulation was used to evaluate the quantity of CO2 that can be stored in shale, the effects of CO2 mitigation when injected into shale, and any significant opportunities for CO2 enhanced shale gas recovery. Lastly, an economic analysis was performed to evaluate the economic efficiency of such projects in shales.

An Effective Reservoir Parameter for Seismic Characterization of Organic Shale Reservoir

2017 ◽  
Vol 39 (3) ◽  
pp. 509-541 ◽  
Author(s):  
Luanxiao Zhao ◽  
Xuan Qin ◽  
Jinqiang Zhang ◽  
Xiwu Liu ◽  
De-hua Han ◽  
...  
Keyword(s):  
Seismic Characterization ◽  
Shale Reservoir ◽  
Reservoir Parameter ◽  
Organic Shale

Methodology and application of shale-reservoir natural fracture modeling based on microseismic monitoring data

2020 ◽  
Vol 8 (4) ◽  
pp. SP167-SP174
Author(s):  
Ziwei Liu ◽  
Jiapeng Wu ◽  
Wenzhong Han ◽  
Yonggui Zhang ◽  
Zhenyong Li ◽  
...  
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Microseismic Monitoring ◽  
Natural Fracture ◽  
Fracture Model ◽  
Monitoring Data ◽  
Small Scale ◽  
Shale Oil ◽  
Fracture Modeling ◽  
Shale Reservoir

Fracturing is a key factor for shale oil and gas enrichment and high production. An accurate fracture model can effectively guide shale oil and gas exploration and development. The establishment of a natural fracture model must address the challenges of difficult data acquisition and poor representativeness of data points. To solve these problems, we have developed a method of shale-reservoir natural fracture modeling based on microseismic monitoring data. This method includes three steps. First, we establish an initial natural fracture model based on scale classification, vertical stratification, and genetic classification. Second, the shape and density of the hydraulic fractures are interpreted by microseismic monitoring data to calibrate the initial model of the shale reservoir natural fractures. Third, we verify the rationality of the model by assessment of the fracture porosity and permeability values. The results show that it is possible to calibrate the natural fracture density model using the fracture shape and density as determined by microseismic monitoring. And we predict that an ideal hydraulic fracture network can be formed when the body density of the natural fracturing is greater than 0.3 m2/m3. The crude production of wells is negatively correlated with the development of large-scale structural fractures and positively correlated with small-scale structural fractures. The well trajectory should run through small-scale fracture development sections as much as possible, avoiding large-scale, high-angle fracture areas. This method provides a new approach to model natural fractures in shale reservoirs that has wide applicability and can be used for modeling shale oil and gas reservoirs.

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