An Integrated Geology-reservoir Description And Modeling of the Naturally Fractured Spraberry Trend Area Reservoirs

Cather, Martha; Guo, Boyun; Schechter, David S.; Banik, Ashish

doi:10.2118/98-32

Cited by 2 publications

(2 citation statements)

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“…The deterministic model can be decomposed into component models of fractures used varying scale and orientation and mode [19,20]. Another approach statistically analyzes the fracture parameters (e.g., azimuth and dip angle) and then randomly simulates a fracture distribution and builds a discrete fracture network (DFN) model [21,22]. Researchers are more enthusiastic about studying the distribution and prediction of HFs and conducting an extended simulation of the trend of fractures in shale gas reservoirs after hydraulic fracturing using finite element and boundary element methods [23][24][25][26].…”

Section: Introductionmentioning

confidence: 99%

A Workflow for Integrated Geological Modeling for Shale Gas Reservoirs: A Case Study of the Fuling Shale Gas Reservoir in the Sichuan Basin, China

2021

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Shale gas reservoir evaluation and production optimization both require geological models. However, currently, shale gas modeling remains relatively conventional and does not reflect the unique characteristics of shale gas reservoirs. Based on a case study of the Fuling shale gas reservoir in China, an integrated geological modeling workflow for shale gas reservoirs is proposed to facilitate its popularization and application and well improved quality and comparability. This workflow involves four types of models: a structure-stratigraphic model, reservoir (matrix) parameter model, natural fracture (NF) model, and hydraulic fracture (HF) model. The modeling strategies used for the four types of models vary due to the uniqueness of shale gas reservoirs. A horizontal-well lithofacies sublayer calibration-based method is employed to build the structure-stratigraphic model. The key to building the reservoir parameter model lies in the joint characterization of shale gas “sweet spots.” The NF models are built at various scales using various methods. Based on the NF models, the HF models are built by extended simulation and microseismic inversion. In the entire workflow, various types of models are built in a certain sequence and mutually constrain one another. In addition, the workflow contains and effectively integrates multisource data. Moreover, the workflow involves multiple model integration processes, which is the key to model quality. The selection and optimization of modeling methods, the innovation and development of modeling algorithms, and the evaluation techniques for model uncertainty are areas where breakthroughs may be possible in the geological modeling of shale gas reservoirs. The workflow allows the complex process of geological modeling of shale gas reservoirs to be more systematic. It is of great significance for a dynamic analysis of reservoir development, from individual wells to the entire gas field, and for optimizing both development schemes and production systems.

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Section: Introductionmentioning

confidence: 99%

A Workflow for Integrated Geological Modeling for Shale Gas Reservoirs: A Case Study of the Fuling Shale Gas Reservoir in the Sichuan Basin, China

2021

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“…Generally speaking, aqueous phase imbibition and retention are the two main causes of APT damages in oil and gas reservoirs. − Spontaneous imbibition is a capillary phenomenon for porous media, and imbibition rate is mainly controlled by capillary force . When a porous medium saturated with a certain fluid contacts with another fluid with stronger wettability, the fluid with stronger wettability will displace the original fluid from the porous medium on account of capillary force. − Moreover, such capillary imbibition is the main mechanism of oil recovery in fractured water-wet reservoirs during water flooding. − Generally, the capillary force exists as the imbibition force, while it is the resistance during the aqueous phase flowback. The greater the capillary force, the stronger the spontaneous imbibition ability of the aqueous phase, which would retain much more aqueous phase.…”

Section: Introductionmentioning

confidence: 99%

Impact of Aqueous Phase Trapping on Mass Transfer in Shales with Multiscale Channels

et al. 2020

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Large amounts of fracturing fluid retained in a shale reservoir could not only restrict gas production through aqueous phase trapping (APT) but also cause potential contamination of groundwater. In this work, experiments modeling in situ aqueous imbibition and flowback were conducted to quantitatively investigate the APT behavior in shales, including matrix, natural fracture, and artificial fracture. Results show that the forward imbibition process is slower than the reverse imbibition process. The aqueous phase tends to be imbibed through parallel bedding. Permeability reduction rates of matrix, natural fracture, and artificial fracture cores after imbibition could reach 100, 85, and 70%, respectively. Meanwhile, it is demonstrated that the aqueous flowback efficiency depends upon flowback timing, pressure difference, initial permeability, and bedding direction. The flowback efficiencies of matrix, natural fracture, and artificial fracture cores could be less than 7%, less than 30%, and less than 15%, respectively. Additionally, the permeability recovery rates of those could be less than 19%, less than 39%, and less than 67%, respectively. Finally, shale APT mechanisms are analyzed from both geological and engineering aspects. The quantitative investigation of shale APT is conducive to economically and environmentally developing shale gas reservoirs.

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An Integrated Geology-reservoir Description And Modeling of the Naturally Fractured Spraberry Trend Area Reservoirs

Cited by 2 publications

References 0 publications

A Workflow for Integrated Geological Modeling for Shale Gas Reservoirs: A Case Study of the Fuling Shale Gas Reservoir in the Sichuan Basin, China

A Workflow for Integrated Geological Modeling for Shale Gas Reservoirs: A Case Study of the Fuling Shale Gas Reservoir in the Sichuan Basin, China

Impact of Aqueous Phase Trapping on Mass Transfer in Shales with Multiscale Channels

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