Xia Yan¹, Wei Wang¹, Kai Shen^2,*, Yanqing Feng¹, Junyi Sun¹, Xiaogang Li¹, Wentao Zhu¹, Binbin Shi¹, Guanglong Sheng^2,3

Energy Engineering, Vol.123, No.1, 2026, DOI:10.32604/ee.2025.070360 - 27 December 2025

Abstract In the development of coalbed methane (CBM) reservoirs using multistage fractured horizontal wells, there often exist areas that are either repeatedly stimulated or completely unstimulated between fracturing stages, leading to suboptimal reservoir performance. Currently, there is no well-established method for accurately evaluating the effectiveness of such stimulation. This study introduces, for the first time, the concept of the Fracture Network Bridging Coefficient (FNBC) as a novel metric to assess stimulation performance. By quantitatively coupling the proportions of unstimulated and overstimulated volumes, the FNBC effectively characterizes the connectivity and efficiency of the fracture network. A background… More >

Nan Qin¹, Shaofeng Ning^2,*, Zihan Zhao^1,2, Yu Luo¹, Bo Chen¹, Xiaoxu Liu¹, Yongming He²

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.12, pp. 2997-3009, 2025, DOI:10.32604/fdmp.2025.074456 - 31 December 2025

Abstract Balancing CO₂ emission reduction with enhanced gas recovery in carbonate reservoirs remains a key challenge in subsurface energy engineering. This study focuses on the Maokou Formation gas reservoir in the Wolonghe Gas Field, Sichuan Basin, and employs a mechanistic model integrated with numerical simulations that couple CO₂–water–rock geochemical interactions to systematically explore the principal engineering and chemical factors governing Carbon Capture, Utilization, and Storage–Enhanced Gas Recovery (CCUS–EGR). The analysis reveals that both the injection–production ratio and gas injection rate exhibit optimal ranges. Maximum gas output under single-parameter variation occurs at an injection–production ratio of 0.7 and… More >

Tianen Liu^1,2, Kun Dai^1,2, Shiju Ren^1,2, Chuanxiang Zhang^1,2, Xiaoling Tang^3,*, Jinghong Hu^3,*, Yidong Cai³, Jun Lu³

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.12, pp. 2981-2995, 2025, DOI:10.32604/fdmp.2025.073859 - 31 December 2025

Abstract Many mature onshore oilfields have entered a high-water-cut stage, with reservoir recovery approaching economic limits. Converting these depleted or nearly depleted reservoirs into underground gas storage (UGS) facilities offers an efficient way to leverage their substantial storage potential. During cyclic gas injection and withdrawal, however, the reservoir experiences complex three-phase flow and repeated stress fluctuations, which can induce rock fatigue, inelastic deformation, and ultimately sand production. This study uses controlled physical experiments to simulate sand production in reservoir rocks subjected to alternating gas injection and production under three-phase conditions. After preparing oil-water-saturated cores through waterflooding,… More > Graphic Abstract

Sheng Lei^1,2,3, Guanglong Sheng^1,2,3,*, Hui Zhao^1,2,3

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.12, pp. 3011-3031, 2025, DOI:10.32604/fdmp.2025.073802 - 31 December 2025

Abstract This study investigates the unsteady flow characteristics of shale oil reservoirs during the depletion development process, with a particular focus on production behavior following fracturing and shut-in stages. Shale reservoirs exhibit distinctive production patterns that differ from traditional oil reservoirs, as their inflow performance does not conform to the classic steady-state relationship. Instead, production is governed by unsteady-state flow behavior, and the combined effects of the wellbore and choke cause the inflow performance curve to evolve dynamically over time. To address these challenges, this study introduces the concept of a “Dynamic IPR curve” and develops… More >

Yulong Zhao¹, Yang Luo^1,*, Yuming Luo², Yulai Pang², Ruihan Zhang¹, Zihan Zhao³

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.12, pp. 3073-3090, 2025, DOI:10.32604/fdmp.2025.070685 - 31 December 2025

Abstract The development of underground gas storage (UGS) systems is vital for maintaining stability between energy supply and demand. This study explores the dynamic response mechanisms of carbonate reservoirs subjected to intense injection–production cycling during UGS operations. By integrating three-dimensional digital core technology with a coupled poro-mechanical model, we simulate the pore-scale behavior of a representative Huangcaoxia UGS carbonate core. The results demonstrate that fluid–solid coupling effects markedly amplify permeability reduction, far exceeding the influence of porosity variations alone. More significantly, gas production leads to a pronounced decline in permeability driven by rising effective stress, arising More >

Bo Wang¹, Fuyang Wu², Zifeng Chen², Libin Dai¹, Yifan Dong¹, Xiaotao Gao³, Zongfa Li^2,*

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.11, pp. 2701-2719, 2025, DOI:10.32604/fdmp.2025.067298 - 01 December 2025

Abstract Tight gas reservoirs are often characterized by pronounced heterogeneity and poor continuity, resulting in wide variability in production enhancement and net present value (NPV) for different geological parameter combinations (see e.g., the Ordos Basin). The conditions governing geological adaptability remain insufficiently defined. To address these challenges, this study integrates large-volume hydraulic fracturing, numerical production simulation, and economic evaluation to elucidate the mechanisms by which large-scale fracturing enhances fracture parameters in tight gas formations. The analysis reveals that, for identical proppant and fluid volumes, increasing the fracturing injection rate leads to longer and taller fractures. Over… More >

Hai Li¹, Ziqiang Xia^2,3,*, Majia Zheng⁴, Weiyang Xie^2,3, Jianlin Li¹, Ruiqi Gao^2,3, Gaoxiang Wang^2,3, Jiangrong Feng^2,3

Energy Engineering, Vol.122, No.12, pp. 5039-5054, 2025, DOI:10.32604/ee.2025.069036 - 27 November 2025

Abstract To explore and evaluate the longitudinal utilization degree of marine shale gas horizontal wells in southern Sichuan Basin (hereinafter referred to as “southern Sichuan”), focusing on the shale of Wufeng formation-Longyi1 sub-member in the deep Z block. By using the data from core experiments, well logging, and fracture height detection, a systematic analysis from the perspectives of reservoir distribution, longitudinal utilization height of hydraulic fractures, and longitudinal utilization degree of horizontal wells was conducted. The research results show that: (1) The overall reservoir conditions of the Wufeng formation-Longyi1 sub-member in the study area are relatively… More > Graphic Abstract

Mengna Cheng¹, Hao Guo², Feng Cao², Jie Gong¹, Fengshuang Du^1,*

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.10, pp. 2629-2650, 2025, DOI:10.32604/fdmp.2025.070344 - 30 October 2025

Abstract Produced water reinjection is a common strategy in offshore oilfield operations, yet the presence of solid particles in produced water can lead to localized formation pressure buildup, increasing the risk of rock fracturing and leakage. In this study, we present an integrated experimental and numerical investigation to quantify the effects of particle migration on formation pressure and the spatial diffusion of injected water. Dynamic plugging experiments were performed to systematically examine the influence of injection rate and injection volume on core permeability. Results demonstrate that higher injection rates substantially reduce permeability, and the derived relationship More >

Yu Li^1,2,3,*, Jie Bian³, Liang Zhang^2,3, Xuesong Feng³, Jiachen Hu³, Ji Yu³, Chao Zhou³, Tian Lan³

FDMP-Fluid Dynamics & Materials Processing, Vol.21, No.10, pp. 2539-2556, 2025, DOI:10.32604/fdmp.2025.067685 - 30 October 2025

Abstract As oil and gas development increasingly targets unconventional reservoirs, the limitations of conventional hydraulic fracturing, namely high water consumption and significant reservoir damage, have become more pronounced. This has driven growing interest in the development of clean fracturing fluids that minimize both water usage and formation impairment. In this study, a low-liquid-content viscoelastic surfactant (VES) foam fracturing fluid system was formulated and evaluated through laboratory experiments. The optimized formulation comprises 0.2% foaming agent CTAB (cetyltrimethylammonium bromide) and 2% foam stabilizer EAPB (erucamidopropyl betaine). Laboratory tests demonstrated that the VES foam system achieved a composite foam… More >

Surajudeen Sikiru^1,2,*, Jemilat Yetunde Yusuf ³, Hassan Soleimani⁴, Niraj Kumar⁵, Zia ur Rehman⁶, Bonnia N N^1,*

Energy Engineering, Vol.122, No.10, pp. 3917-3960, 2025, DOI:10.32604/ee.2025.067815 - 30 September 2025

Abstract Enhanced oil recovery (EOR) refers to the many methodologies used to augment the volume of crude oil extracted from an oil reservoir. These approaches are used subsequent to the exhaustion of basic and secondary recovery methods. There are three primary categories of Enhanced Oil Recovery (EOR): thermal, gas injection, and chemical. Enhanced oil recovery methods may be costly and intricate; yet, they facilitate the extraction of supplementary oil that would otherwise remain in the reservoir. Enhanced Oil Recovery (EOR) may prolong the lifespan of an oil field and augment the total output from a specific… More >