Field Application of a Novel Multi-resolution Multi-well Unconventional Reservoir Simulation: History Matching and Parameter Identification

Fu, Jia; Chen, Hongquan; Yao, Changqing; Sakaida, Shohei; Kerr, Erich; Johnson, Andrew S.; Datta‐Gupta, Akhil; Zhu, Ding; Hill, A.D.

doi:10.15530/urtec-2023-3857125

Cited by 3 publications

(1 citation statement)

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“…Gulong shale oil is the most typical in situ terrestrial shale oil and the reservoir is characterised by tight lithology and high clay mineral content compared to domestic and foreign shales dominated by marine or saline lake basin deposits; The storage space is a nano-matrix pore with a pore throat diameter of 10 nm-50 nm; Porosity ranges from 2.1% to 12.0% and permeability is less than 0.01 mD (Wang et al, 2021;He et al, 2023). Due to the characteristics of tight lithology, low porosity and low permeability, effective development is a major challenge and studies have shown that unconventional reservoirs can be effectively developed by gas injection to improve recovery (Fu et al, 2023).…”

Section: Introductionmentioning

confidence: 99%

Optimal design of gas injection development method for enhanced recovery in terrestrial shale oil reservoir

Cui,

Chen,

Wang

et al. 2024

Front. Energy Res.

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This study investigates the shale oil drainage characteristics from the Gulong Sag, The objective is to clarify the development method for effective recovery enhancement of terrestrial shale oil. The investigation employs elastic depletion, CO2 displacement, and CO2 huff and puff coupled with nuclear magnetic resonance (NMR) measurements and numerical simulation methods. The study found that the elastic depletion, CO2 displacement, and CO2 huff and puff utilization efficiencies were 17.4%, 18.87%, and 21%, respectively. The study evaluated the oil drainage efficiency of different pore sizes in elastic depletion and CO2 huff and puff modes. The results demonstrated a clear trend in the order of micropore, mesoporous and macropore, with micropores exhibiting the highest oil drainage efficiency due to gas channeling during CO2 displacement. The use of CO2 huff and puff has been shown to improve oil drainage efficiency by 6.02%∼9.2% for different pore sizes. The numerical simulation optimization results suggest an injection volume of 3,000 t per round per well, an injection rate of 100 t/d, and a soaking time of 20 d for optimal CO2 huff and puff injection. This will increase oil production by 65,000 m³, resulting in an overall improvement of 24%. The study results provide a strong theoretical foundation for improving the recovery rates of terrestrial shale oil and gas through injection.

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Section: Introductionmentioning

confidence: 99%

Optimal design of gas injection development method for enhanced recovery in terrestrial shale oil reservoir

Cui,

Chen,

Wang

et al. 2024

Front. Energy Res.

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A novel deep learning method based on 2-D CNNs and GRUs for permeability prediction of tight sandstone

Tian,

Wang,

et al. 2024

Geoenergy Science and Engineering

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Applications of Asymptotic Solutions of the Diffusivity Equation to Infinite Acting Pressure Transient Analysis

Wang,

Li,

King

2024

SPE Journal

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Summary Understanding how pressure propagates in a reservoir is fundamental to the interpretation of pressure and rate transient measurements at a well. Unconventional reservoirs provide unique technical challenges as the simple geometries and flow regimes [wellbore storage (WBS) and radial, linear, spherical, and boundary-dominated flow] applied in well test analysis are now replaced by nonideal flow patterns due to complex multistage fracture completions, nonplanar fractures, and the interaction of flow with the reservoir heterogeneity. In this paper, we introduce an asymptotic solution technique for the diffusivity equation applied to pressure transient analysis (PTA), in which the 3D depletion geometry is mapped to an equivalent 1D streamtube. This allows the potentially complex pressure depletion geometry within the reservoir to be treated as the primary unknown in an interpretation, compared with the usual method of interpretation in which the depletion geometry is assumed and parameters of the formation and well are the unknown properties. The construction is based upon the solution to the Eikonal equation, derived from the diffusivity equation in heterogeneous reservoirs. We develop a Green’s function that provides analytic solutions to the pressure transient equations for which the geometry of the flow pattern is abstracted from the transient solution. The analytic formulation provides an explicit solution for many well test pressure transient characteristics such as the well test semi-log pressure derivative (WTD), the depth of investigation (DOI), and the stabilized zone (SZ) (or dynamic drainage area), with new definitions for the limit of detectability (LOD), the transient drainage volume, and the pseudosteady-state (PSS) limit. Generalizations of the Green’s function approach to bounded reservoirs are possible (Wang et al. 2017) but are beyond the scope of the current study. We validate our approach against well-known PTA solutions solved using the Laplace transform, including pressure transients with WBS and skin. Our study concludes with a discussion of applications to unconventional reservoir performance analysis for which reference solutions do not otherwise exist.

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Field Application of a Novel Multi-resolution Multi-well Unconventional Reservoir Simulation: History Matching and Parameter Identification

Cited by 3 publications

References 0 publications

Optimal design of gas injection development method for enhanced recovery in terrestrial shale oil reservoir

Optimal design of gas injection development method for enhanced recovery in terrestrial shale oil reservoir

A novel deep learning method based on 2-D CNNs and GRUs for permeability prediction of tight sandstone

Applications of Asymptotic Solutions of the Diffusivity Equation to Infinite Acting Pressure Transient Analysis

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