Transient pressure analysis of pressure-dependent naturally fractured reservoirs

Samaniego, V Fernando; Villalobos, Lorenzo

doi:10.1016/s0920-4105(03)00039-1

Cited by 13 publications

(7 citation statements)

References 14 publications

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“…Chen et al [29] established the mathematical model for tight gas reservoirs considering threshold pressure gradient, gas slipping, and stress sensitivity, and Xue et al [30] conducted research on tight sandstone gas reservoirs with water produced and showed that strong stress sensitivity appeared as a result and increased with the water production. Zhao et al [31], Jabbari et al [32], Samaniego and Villalobos [33], and Zhang et al [34] carried out research on the stress-sensitivity of fracture reservoirs, and Wang and Wang [35] proposed the mathematical model considering the effect of slipping and stress sensitivity in fractured gas reservoirs. Huang et al [36] presented the transient flow model for horizontal wells in stress-sensitivity composite reservoirs, and Li et al [37] presented the dual-porosity media model for horizontal wells in fractured tight gas reservoirs with stress sensitivity.…”

Section: Introductionmentioning

confidence: 99%

Well-Testing Model for Dual-Porosity Reservoir considering Stress-Sensitivity and Elastic Outer Boundary Condition

Kim,

Han,

Song

et al. 2023

Geofluids

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Stress sensitivity and the elastic outer boundary (EOB) condition have a great effect on the analysis of the characteristics of the fluid flow in a reservoir. When researchers analyzed the characteristics of the fluid flow, they have considered the stress sensitivity and the EOB condition separately but have not considered them simultaneously. Therefore, errors are inevitable during the analysis of well testing. The main object of this work is to present a well-testing model for stress-sensitivity dual-porosity reservoir (DPR) with EOB to improve the accuracy of the analysis of well-testing data. To this end, in this paper, we established a well-testing model for the DPR, considering the stress sensitivity and the EOB simultaneously, and presented its semianalytical solution. On the basis of the consideration of the EOB condition and stress sensitivity of permeability (SSP), a seepage model for the DPR with the EOB is built using the continuity equation, motion equation, state equation, and interporosity flow equation between matrix and fracture, which considers the stress sensitivity, wellbore storage, and skin. To solve this model, a nonlinear partial differential equation is changed into a linear form of a partial differential equation by introducing an effective well radius and applying Pedrosa’s transformation and perturbation transformation. Applying the Laplace transformation, an analytical solution in the Laplace space is obtained, and curves of pressure and pressure derivative (PPD) are drawn by numerically inverting them. The model is verified by comparing it with the EOB without consideration of SSP and using case data. The sensitivity of parameters on the curves of PPD is analyzed. This work may be significant for evaluating more accurately the parameters of wells and reservoirs using well testing.

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Section: Introductionmentioning

confidence: 99%

Well-Testing Model for Dual-Porosity Reservoir considering Stress-Sensitivity and Elastic Outer Boundary Condition

Kim,

Han,

Song

et al. 2023

Geofluids

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“…The behaviour of flow-reducing properties of rocks and overall controlling mechanism is well known through several methods including analytical, numerical (coupled flow models) or combined effects of reservoir properties including stress, pressure and fluid flow (Samaniego and Villalobos, 2003;Lei et al, 2007). Nevertheless, understanding the evolution of stress-dependent permeability in geothermal reservoir is of great interest because of the nature of the tight matrix and the fractures, which are more susceptible to stress changes (Zhang et al 2018).…”

Section: Introductionmentioning

confidence: 99%

Analysis of the influence of joint direction on production optimization in enhanced geothermal systems

Eyinla

2021

J Petrol Explor Prod Technol

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Heat extraction from geothermal reservoir by circulating cold water into a hot rock requires an amount of fluid pressure, which is capable of inducing fault opening. Although stress change promotes the potential of fault failure and reactivation, the rate at which fluid pressurization within the fault zone generates variations in pore pressure as fault geometry changes during geothermal energy production have not been thoroughly addressed to include the effects of joint orientation. This study examines how different fault/joint models result in different tendency of injection-induced shear failure, and how this could influence the production rate. Here, a numerical simulation method is adopted to investigate the thermo-hydro-mechanical (THM) response of the various fault/joint models during production in a geothermal reservoir. The results indicate that pore pressure evolution has a direct relationship with the evolution of production rate for the three joint models examined, and the stress sensitivity of the individual fault/joint model also produced an effect on the production rate. Changing the position of the injection well revealed that the magnitude of shear failure on the fault plane could be controlled by the hydraulic diffusivity of fluid pressure, and the production rate is also influenced by the magnitude of stress change at the injection and production wells. Overall, the location of the injection well along with the fault damage zone significantly influenced the resulting production rate, but a more dominating factor is the joint orientation with respect to the maximum principal stress direction. Thus, the rate of thermal drawdown is affected by pore pressure elevation and stress change while the fault permeability and the production rate are enhanced when the joint’s frictional resistance is low.

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“…For the first aspect, Reis (1998) and Samaniego and Villalobos (2003) presented a new model to simulate the transient and decline of reservoir pressure under the influence of fracturing. Zhang et al (2008) used fractal dimension theory to analysis the transmission of pressure.…”

Section: Introductionmentioning

confidence: 99%

Modeling and prediction for gas production during coalbed methane drainage based on two indirect reservoir parameters

Zou

Huang

et al. 2018

Energy Exploration & Exploitation

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Two indirect parameters influencing coalbed methane (CBM) drainage performances are proposed in this paper, which are effective desorption radius and difference between reservoir pressure and critical desorption pressure (DRPCDP). Variations of the two parameters during CBM drainage are investigated, which shows that they have a linear relationship. By using formula derivations, a theoretical model for gas production prediction is built. It suggests that the cumulative gas production is a product of square of effective desorption radius with DRPCDP, and there is also a cubic polynomial relationship between cumulative gas production and linear average DRPCDP. Furthermore, well PM01 located at southern Qinshui basin of China is selected as a case, and a commercial software is adopted to predict the gas production. Compared with the simulated and modeled cumulative gas productions, the simulated data match well with the modeled data, which indicates that the model has a good accuracy.

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Transient pressure analysis of pressure-dependent naturally fractured reservoirs

Cited by 13 publications

References 14 publications

Well-Testing Model for Dual-Porosity Reservoir considering Stress-Sensitivity and Elastic Outer Boundary Condition

Well-Testing Model for Dual-Porosity Reservoir considering Stress-Sensitivity and Elastic Outer Boundary Condition

Analysis of the influence of joint direction on production optimization in enhanced geothermal systems

Modeling and prediction for gas production during coalbed methane drainage based on two indirect reservoir parameters

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