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Processes
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Emerging Research and Intelligent Technologies for Reservoir Stimulation and Enhanced...
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Emerging Research and Intelligent Technologies for Reservoir Stimulation and Enhanced Oil and Gas Recovery

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Petroleum and Low-Carbon Energy Process Engineering".

Deadline for manuscript submissions: 31 January 2027 | Viewed by 816

Editors

Dr. Yunjin Wang

E-Mail Website
Guest Editor
State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing), Beijing 102249, China
Interests: hydraulic fracturing; machine learning; matrix acidizing; acid fracturing; artificial intelligence; simulation
Dr. Qing Wang

E-Mail Website
Guest Editor
School of Petroleum Engineering, Yangtze University, Wuhan 430100, China
Interests: acid fracturing; geological engineering integration; fracturing fluid
Dr. Yu Peng

E-Mail Website
Guest Editor
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China
Interests: rock mechanics; heat and mass transfer; fracture mechanics; rheology; interdisciplinary application of mathematics; numerical simulations related to oil and natural gas development
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

With the increasing global demand for efficient, sustainable and intelligent oil and gas development, reservoir stimulation and enhanced oil and gas recovery technologies are attracting growing attention from both academia and industry. In recent years, the integration of intelligent optimization, numerical simulation, advanced functional fluids and multiscale mechanism analysis has provided new opportunities for improving stimulation efficiency, reducing operational risks and promoting more sustainable oil and gas recovery processes.

This Special Issue on “Emerging Research and Intelligent Technologies for Reservoir Stimulation and Enhanced Oil and Gas Recovery” aims to cover recent advances in the development, evaluation, simulation, optimization and field application of reservoir stimulation and enhanced recovery technologies. Topics include, but are not limited to, methods and/or applications in the following areas:

  • Reservoir stimulation technologies for conventional, unconventional and complex reservoirs
  • Intelligent design, optimization, diagnosis and control of reservoir stimulation and enhanced recovery processes
  • Development, screening, evaluation and optimization of functional fluids for reservoir stimulation and enhanced oil and gas recovery
  • Fluid–rock, fluid–fluid and fluid–solid interactions in complex reservoir environments
  • Artificial intelligence, machine learning, digital twins and intelligent algorithms for stimulation design, production optimization and field decision-making
  • Experimental characterization, laboratory evaluation, field diagnosis and performance assessment of stimulation and enhanced recovery technologies

Integrated experimental, numerical, intelligent and field approaches for improving oil and gas recovery

Dr. Yunjin Wang
Dr. Qing Wang
Dr. Yu Peng
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 250 words) can be sent to the Editorial Office for assessment.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-anonymized peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Processes is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2400 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • reservoir stimulation
  • enhanced oil and gas recovery
  • advanced materials
  • artificial intelligence
  • numerical simulation
  • multiscale mechanisms
  • construction technology

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Published Papers (2 papers)

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Research

22 pages, 5578 KB  
Article
Study on CO2 Foam Acid Phase Evolution and Diverting Acidizing Performance in Heterogeneous Carbonate Reservoirs
by Xiuhui Li, Yunjin Wang, Jiacheng Yin, Weibo Ni, Jia Liu, Mengyu Li, Qi Wu and Jiawei Li
Processes 2026, 14(16), 2562; https://doi.org/10.3390/pr14162562 - 11 Aug 2026
Viewed by 237
Abstract
A coupled numerical model was developed to investigate the phase evolution and diverting acidizing performance of CO2-foamed acid in heterogeneous carbonate reservoirs. The model integrates CO2 phase evolution, gas–liquid two-phase Darcy flow, acid–rock reactions, heat transfer, pore-structure evolution, and foam [...] Read more.
A coupled numerical model was developed to investigate the phase evolution and diverting acidizing performance of CO2-foamed acid in heterogeneous carbonate reservoirs. The model integrates CO2 phase evolution, gas–liquid two-phase Darcy flow, acid–rock reactions, heat transfer, pore-structure evolution, and foam mobility control. By dynamically updating CO2 thermophysical properties in response to local temperature and pressure variations, the model captures the coupled effects of phase behavior on foam quality, apparent viscosity, flow resistance, and acid redistribution between high- and low-permeability layers. The effects of reservoir temperature, foam quality, and permeability contrast on wormhole propagation, foam distribution, and stimulation depth in the low-permeability layer were systematically evaluated. Under the simulated conditions, low-permeability-layer stimulation initially increased with reservoir temperature, reached its maximum near 393 K, and declined at 413 K. This non-monotonic behavior reflects the balance among CO2 phase behavior, foam stability, and acid–rock reaction rate: moderate temperatures promote the formation of a favorable foam region and effective diversion, whereas excessive temperatures weaken foam stability and accelerate acid consumption near the wellbore. Foam quality also exhibited a non-monotonic influence on diversion performance. Foam qualities of 60–80% provided strong mobility control and effective acid redistribution, while a foam quality of 90% restricted liquid-acid transport because of excessive near-wellbore foam accumulation. In contrast, the pure-acid system preferentially entered the high-permeability layer and broke through at approximately 0.3 PV. Increasing permeability contrast weakened foam retention and intensified preferential channeling; at a permeability contrast of 8, the wormhole length in the low-permeability layer was less than 50% of that obtained at a contrast of 4. These results demonstrate that phase-dependent foam resistance can redirect acid from preferential high-permeability channels toward low-permeability regions. This study defines an effective operating window for CO2-foamed-acid diversion and provides a theoretical basis for designing diverting acidizing treatments in heterogeneous, high-temperature carbonate reservoirs. Full article
(This article belongs to the Special Issue Emerging Research and Intelligent Technologies for Reservoir Stimulation and Enhanced Oil and Gas Recovery)
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25 pages, 8025 KB  
Article
Pore-Scale Dynamics of Water Imbibition and Residual-Gas Formation in Tight Gas Reservoir
by Fei Peng, Yafei Zhang, Qingyuan Zhu, Juan Zhai and Keliu Wu
Processes 2026, 14(15), 2493; https://doi.org/10.3390/pr14152493 - 4 Aug 2026
Viewed by 405
Abstract
Forced imbibition of a wetting liquid into a gas-filled tight rock is often expected to advance as a compact front because the liquid-to-gas viscosity ratio is favorable. This expectation can fail when narrow throats, pore-body/throat mismatch, capillary-valve pinning, and wall-associated wetting pathways reorganize [...] Read more.
Forced imbibition of a wetting liquid into a gas-filled tight rock is often expected to advance as a compact front because the liquid-to-gas viscosity ratio is favorable. This expectation can fail when narrow throats, pore-body/throat mismatch, capillary-valve pinning, and wall-associated wetting pathways reorganize the defending gas before it is displaced as a connected phase. We use a three-dimensional regularized color-gradient lattice Boltzmann model to examine these processes in a single, initially gas-saturated reconstructed tight-sandstone pore space. The simulations sample three capillary numbers, two or three Ohnesorge numbers depending on the capillary number, and two water-phase contact angles while keeping the water-to-gas viscosity ratio fixed at 26.11. The contact angle is measured through the aqueous phase, with θ = 20° representing strongly water-wet conditions and θ = 60° representing weakly water-wet conditions. For θ = 60°, terminal displacement efficiency changes little between the low and intermediate sampled capillary numbers and increases from approximately 0.660 to 0.736 at the highest sampled value. For θ = 20°, strong water-wetness is beneficial only after the bulk meniscus gains enough driving force to compete with precursor corner or wall flow; at a low capillary number, the same wetting affinity is associated with snap-off and premature gas isolation. The sampled Oh dependence is weaker than the Ca dependence and is consistent with conditional modulation of capillary-inertial damping and local interface relaxation; it is not interpreted as a new static entry criterion. Size-resolved and morphology-resolved statistics show contrasting terminal signatures: θ = 20° is associated with more large-pore gas and snap-off-consistent fragmentation, whereas θ = 60° is associated with more persistent small-pore gas and bypassing-consistent retention. Event-resolved phase-field sequences at one low-Ca condition directly show wall-first precursor advance, abrupt pore-body filling, gas-neck closure, persistent component splitting, and bypass-induced local entrapment. These events establish occurrence, not their frequency or dominance across parameter space. Because the study uses one pore-space realization and a sparse, non-factorial parameter matrix, the reported comparisons are restricted to the sampled conditions and do not define a continuous Ca–Oh–θ response surface or quantify structure-to-structure uncertainty. Full article
(This article belongs to the Special Issue Emerging Research and Intelligent Technologies for Reservoir Stimulation and Enhanced Oil and Gas Recovery)
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