A Stochastic Permeability Model for Shale Formations Based on EDFM

Xu, Shiqian; Feng, Qingsong; Wang, Sen; Zhang, Ming; Cui, Ronghao; Gao, Fangfang; Xu, Yajuan

doi:10.15530/urtec-2017-2691224

Cited by 4 publications

(1 citation statement)

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“…Although the EDFM was used widely to characterize the natural fracture in conventional oil/gas reservoirs, it has not been hitherto applied in gas-hydrate reservoirs to predict the gas well performance (Yan et al, 2016;Yan et al, 2018;Xu et al, 2017;Xu et al, 2018;Xu et al, 2021;Xu et al, 2022). For the scenarios of gas-hydrate reservoirs, multiphase flow, heat transfer, and hydrate dissociation all raise stringent barriers for one to build the EDFM model to evaluate the gas well productivity of the gashydrate reservoirs.…”

Section: Introductionmentioning

confidence: 99%

A new study of multi-phase mass and heat transfer in natural gas hydrate reservoir with an embedded discrete fracture model

Cui

Teng²,

Luo³

et al. 2023

Front. Earth Sci.

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Studies of the hydrate cores have shown that natural fractures can be frequently observed in hydrate reservoirs, resulting in a fracture-filled hydrate. Therefore, it is highly necessary for industries to predict the gas well productivity of fracture-filled hydrate reservoirs. In this work, an embedded discrete fracture model is applied to characterize the natural fractures of fracture-filled gas-hydrate reservoirs. The non-linear mass and energy conservation equations which are discretized with the finite-difference method are solved by the fully implicit approach, and the proposed model is justified by a commercial simulator. On the basis of the proposed model, we investigate the influences of natural fractures, fracture conductivity, and hydrate dissociation rate on the gas well productivity and the distributions of pressure, temperature, and hydrate saturation. The simulation results show that hydraulic and natural fractures exert significant impacts on the gas well productivity of the fracture-filled hydrate reservoirs, and the cumulative gas production is increased by 45.6% due to the existence of the connected natural fractures. The connected natural fractures can impose a more important influence on the gas well productivity than the unconnected natural fractures. The cumulative gas production is increased by 6.48% as Nnf is increased from 2 to 50, whereas the increase is 43.38% as Nf_con is increased from 0 to 4. In addition, A higher hydraulic fracture conductivity can be more favorable than a higher natural fracture conductivity for improving the gas well productivity, and a higher hydrate dissociation rate can lead to a lower temperature along fractures due to a more noticeable reduction of solid hydrate. This study provides a theoretical basis for developing fracture-filled hydrate reservoirs efficiently in the future.

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Section: Introductionmentioning

confidence: 99%

A new study of multi-phase mass and heat transfer in natural gas hydrate reservoir with an embedded discrete fracture model

Cui

Teng²,

Luo³

et al. 2023

Front. Earth Sci.

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Fracture Network Mapping Using Integrated Micro-Seismic Events Inverse with Rate-Transient Analysis

Wang¹,

Zhang²,

Su³

et al. 2019

International Petroleum Technology Conference

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Fracture Network Mapping Using Integrated Micro-Seismic Events Inverse with Rate-Transient Analysis

Wang

Zhang

et al. 2019

Day 3 Thu, March 28, 2019

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In the development of shale oil and gas reservoir, hydraulic fracture treatments may induce complex network configuration, which is very challenging to characterize. The existing fracture properties interpretation methods mostly rely on simplifying assumptions and are typically empirical in nature. The aim of this work is therefore to introduce an integrated framework involving fractal theory, inverse analysis of micro-seismic events (MSE), and rate-transient analysis to map the heterogeneity and distribution of fracture properties. In this work, a general framework is proposed to characterize both the geometry configuration and the owing properties of the complex fracture network (CFN). The CFN characterization framework is naturally divided into two stages: characterize the fracture geometry network by microseismic data and characterize the fracture dynamic properties by production data. In the fracture configuration characterization stage, a stochastic fractal fracture model based on an L-system fractal geometry is applied to describe the CFN geometry. Moreover, the genetic algorithm (GA) as a mixed integer programming (MIP) algorithm are applied to find the most probable fracture configuration based on the microseismic data. As to the owing properties characterization stage, we introduced embedded discrete fracture model (EDFM) for the computational concern and a Bayesian framework is used to quantify these fracture dynamical properties e.g., conductivity, porosity and pressure dependent multiplier by assimilating the production data. In addition, rate-transient analysis is also applied to calibrate the total fracture length and estimate effective stimulated-reservoir volume (ESRV). In order to validate this framework, a synthetic numerical case is developed. The result indicates that our integrated framework is able to characterize both CFN configuration and properties by assimilating microseismic and production data sequentially. The proposed workflow shows that the characterized CFN model would yield reasonable probability predictions in unconventional production rate.

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A Stochastic Permeability Model for Shale Formations Based on EDFM

Cited by 4 publications

References 0 publications

A new study of multi-phase mass and heat transfer in natural gas hydrate reservoir with an embedded discrete fracture model

A new study of multi-phase mass and heat transfer in natural gas hydrate reservoir with an embedded discrete fracture model

Fracture Network Mapping Using Integrated Micro-Seismic Events Inverse with Rate-Transient Analysis

Fracture Network Mapping Using Integrated Micro-Seismic Events Inverse with Rate-Transient Analysis

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