The optimum pressure drawdown for production from a shale gas reservoir: A numerical study with a coupled geomechanics and reservoir model

Sun, Zhuang; Liu, Hui‐Hai; Han, Yanhui; Basri, Mustafa; Mesdour, Rabah

doi:10.1016/j.jngse.2021.103848

Cited by 9 publications

(2 citation statements)

References 44 publications

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“…Tight sandstone gas reservoir has poor properties, small porosity, low permeability, strong heterogeneity and complex seepage mechanism, showing strong stress sensitivity during development (Wei et al, 2008;Sun et al, 2018). Reasonable system of well is an important factor affecting economic limit production and ultimate recovery of gas field (Mousavi et al, 2020;Sun et al, 2021). Different from oil reservoir, gas wells are generally depleted (Xu et al, 2019a).…”

Section: Introductionmentioning

confidence: 99%

Study on reasonable production allocation method of tight sandstone gas reservoir—A case of XX block in ordos basin

Lv¹,

Cui²,

Lei³

et al. 2023

Front. Energy Res.

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Reasonable production allocation of tight sandstone gas reservoirs is an important basis for efficient development of wells. Combining multiple mathematical models, the modified flowing material balance equation was established considering the variation of viscosity and compressibility, and a reasonable production allocation process was developed. The results show that: ① The flow material balance method ignores the change of compressibility, viscosity and deviation coefficient in the calculation. Compared with the results calculated by the material balance method, the results of the flow material balance method are smaller. ② A modified flowing material balance method is established, verified by the production of 670 wells in the study area during stable period. Compared with the open flow rate method, the error of dynamic reserve allocation method is smaller, with an error of 0.07%. ③ When dynamic reserves are used to allocate production, the initial decline rate of wells is reduced by 74.65% on average, the production on stable period increases by 21.28%, and the time increases by 1.79%. This study provides support for dynamic reserve calculation and reasonable production allocation of gas wells in the study area, and has important guiding significance for the formulation of reasonable development plan and economic and efficient development of tight sandstone gas reservoirs.

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Section: Introductionmentioning

confidence: 99%

Study on reasonable production allocation method of tight sandstone gas reservoir—A case of XX block in ordos basin

Lv¹,

Cui²,

Lei³

et al. 2023

Front. Energy Res.

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show abstract

“…8 The rapid decline in the production capacity of single wells can be attributed to the strong stress sensitivity of reservoirs. The increased effective stress on the formation and fractures will, thereby, make reservoir conductive medium systems compacted 9 and shale gas flow channels deformed, 10 resulting in flow capacity reduction.…”

Section: Introductionmentioning

confidence: 99%

Pressure Drawdown Management Strategies for Multifractured Horizontal Wells in Shale Gas Reservoirs: A Review

Liu

et al. 2022

ACS Omega

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The flow capacity of shale gas reservoirs is easily impaired during the depletion process due to strong stress sensitivity. Thereby, an adequate production system, namely, the managed pressure drop method, has been widely introduced to the industrial practice application by decelerating the wellbore pressure drop rate and ultimately improving the long-term production process. This work presents a review of the pressure drawdown management mechanisms for shale gas formations. However, clarifying the water–shale interaction physical chemistry process and developing a mathematical model that accurately describes the water–shale interaction mechanism remain a challenge. Moreover, different classifications of the managed production simulation research approaches are discussed in detail. Each approach has its own merits and demerits. Among them, numerical simulations are commonly seen in cognizance of characterizing the managed pressure drawdown production period but are found to be relatively time-consuming and also computationally expensive. An optimized theoretical model is therefore essential because it can lead to a precise estimation of the ultimate long-term production and capture instantaneously the actual shale gas reservoir depletion phenomenon with various production systems compared to other available methods. The key influence of managed pressured production for single wells in shale reservoirs is elaborated as well. As observed from the current review, an accurate description of the pressure drop management mechanism is crucial for the theoretical model of the pressure control production process for shale gas wells. The influence of water–rock interaction on the managed pressure drawdown mechanism cannot be ignored. There have thus been works to improve and enhance it for use in theoretical models for shale formations. On the other hand, the advancement of theoretical models presents an opportunity for better representation of the managed pressure drop production process.

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An investigation of the effect of drawdown pressure on sand production in an Iranian oilfield using a hybrid numerical modeling approach

Nemati,

Ahangari,

Goshtasbi

et al. 2024

J Petrol Explor Prod Technol

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Reservoir pressure reduction due to continuous production from oil and gas wells affects the sand production rate. An increase in drawdown pressure and/or a decrease in reservoir pressure increases the sand production rate. Since the problem of sand production is one of the main issues in the Asmari sandstone formation located in one of the oilfields in the southwest of Iran, therefore, in this research, the variations in the sand production rate due to the changes in the reservoir and drawdown pressures were investigated. So, for the first time, a hybrid numerical model of finite difference method (FDM)—discrete element method (DEM)—finite element method (FEM)—computational fluid dynamics (CFD) was developed. This numerical model investigated the increase in the sand production rate due to variations in reservoir pressure with a constant bottom-hole flowing pressure. Then, by performing an extensive sensitivity analysis on different values of reservoir pressure and drawdown pressure, the changes in the sanding rate, the critical drawdown pressure, and the safe drawdown line were determined. The results showed that, if the production flow rate of the well is constant, increasing the drawdown pressure can change the sand production rate only to a certain extent, and more than that, will be produced at a constant rate. Also, adjusting the drawdown pressure within a safe range does not necessarily keep the sand production rate constant at a permissible value for a long time, while by keeping the bottom hole flowing pressure constant within an acceptable range, the sand production rate can be controlled for a longer period.

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The optimum pressure drawdown for production from a shale gas reservoir: A numerical study with a coupled geomechanics and reservoir model

Cited by 9 publications

References 44 publications

Study on reasonable production allocation method of tight sandstone gas reservoir—A case of XX block in ordos basin

Study on reasonable production allocation method of tight sandstone gas reservoir—A case of XX block in ordos basin

Pressure Drawdown Management Strategies for Multifractured Horizontal Wells in Shale Gas Reservoirs: A Review

An investigation of the effect of drawdown pressure on sand production in an Iranian oilfield using a hybrid numerical modeling approach

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