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Processes
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Utilization and Storage of Carbon Dioxide in Petroleum Engineering
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Utilization and Storage of Carbon Dioxide in Petroleum Engineering

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Energy Systems".

Deadline for manuscript submissions: 20 May 2024 | Viewed by 6842

Special Issue Editor

Dr. Liang Zhang

E-Mail Website
Guest Editor
College of Petroleum Engineering, China University of Petroleum (Huadong), Qingdao 266580, China
Interests: gas Injection for EOR; unconventional resource development; CO2 geological storage and utilization; flow assurance of oil and gas wells
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

CO2 Capture, Utilization, and Storage (CCUS) is an emerging CO2 disposal technology with large-scale application potential, which is expected to achieve near-zero CO2 emissions from fossil energy use. The CO2 generated during industrial production can be captured and injected into specific geological structures, such as saline aquifer, oil and gas reservoirs, and unminable coalbed, for permanent storage. Since the early 1990s, countries around the world have successively carried out CO2 geological storage demonstration projects for various geological structures. The implementation of these projects has turned CO2 geological storage technology from theory into reality. It has accumulated valuable on-site experience for the further development and promotion of this technology and has gradually been recognized by governments and the public. In recent years, there have been new developments and applications in CCUS technology, such as combining the use of CO2 with geothermal development and injecting CO2 into basalt for rapid mineral trapping. At the same time, realizing the rapid and effective storage of CO2, effectively monitoring and preventing CO2 leakage, and ensuring the permanent safety of CO2 storage is still the priority in current CO2 storage technology research.

This Special Issue on “Utilization and Storage of Carbon Dioxide in Petroleum Engineering” seeks high-quality work focusing on the latest novel advances of CCUS in petroleum engineering. Topics include, but are not limited to:

  • Enhanced production mechanisms of CO2 injection in hydrocarbon and geothermal reservoirs;
  • CO2 trapping mechanisms in different geological structures;
  • Progress of CO2 geological storage and utilization demonstration project;
  • CO2 leakage risk, monitoring scheme, and preventive measures.

Dr. Liang Zhang
Guest Editor

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 papers will be 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 100 words) can be sent to the Editorial Office for announcement on this website.

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-blind 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 monthly 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 2000 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

  • CO2
  • enhanced oil recovery
  • trapping mechanism
  • geochemical reaction
  • leakage risk
  • geothermal energy
  • coalbed methane
  • natural gas hydrates
  • tight oil and gas

Published Papers (4 papers)

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Research

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14 pages, 4294 KiB  
Article
A Thermal-Fluid-Solid Coupling Computation Model of Initiation Pressure Using Supercritical Carbon Dioxide Fracturing
by Yi Chen, Zhihong Kang, Yuzhu Kang, Xiaocheng Chen, Xiaohong Chen, Qingteng Fan, Yukun Du and Jinguang Wang
Processes 2023, 11(2), 437; https://doi.org/10.3390/pr11020437 - 01 Feb 2023
Viewed by 1077
Abstract
With the characteristics of low fracturing pressure, little damage to the reservoirs, and assuming the role of carbon storage, supercritical carbon dioxide (SC-CO2) fracturing is suitable for the development of unconventional oil and gas resources. Based on the tensile failure mechanism [...] Read more.
With the characteristics of low fracturing pressure, little damage to the reservoirs, and assuming the role of carbon storage, supercritical carbon dioxide (SC-CO2) fracturing is suitable for the development of unconventional oil and gas resources. Based on the tensile failure mechanism of rocks, this paper establishes a thermal-fluid-solid coupling initiation pressure model for SC-CO2 fracturing. Using this model, the changes in formation temperature and pore pressure near a wellbore caused by invasion of CO2 into the formation are analyzed, as well as the impact of these changes on the tangential stress of reservoir rocks. The field data of SC-CO2 fracturing in a sandstone gas well are used to validate the reliability of the model. The results show that SC-CO2 fracturing can significantly reduce the initiation pressure, which decreases with the increase in fracturing fluid injection rate. The minimum value of tangential stress is located at the well wall, and the direction of tangential stress caused by formation temperature and pore pressure is opposite, with the former greater than the latter. The increase in Poisson’s ratio, the increase in elastic modulus and the decrease in bottom hole temperature can reduce the initial fracturing pressure of the reservoir. The computation model established in this paper provides an effective method for understanding the reservoir fracturing mechanism under the condition of SC-CO2 invasion. Full article
(This article belongs to the Special Issue Utilization and Storage of Carbon Dioxide in Petroleum Engineering)
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19 pages, 2806 KiB  
Article
FTIR as a Powerful Tool for Measurements of Diffusion in Supercritical Carbon Dioxide Using Taylor Dispersion Method
by Cecilia I. A. V. Santos, Marisa C. F. Barros, Maria P. R. T. Faro, Valentina Shevtsova and Ana C. F. Ribeiro
Processes 2022, 10(8), 1528; https://doi.org/10.3390/pr10081528 - 03 Aug 2022
Cited by 2 | Viewed by 1954
Abstract
A new experimental high-pressure setup for measuring diffusion coefficients in supercritical fluids, based on Taylor dispersion method, and using an FTIR detector to operate up to 25.0 MPa was designed and optimized. Tracer diffusivities, D12, of toluene and benzene in supercritical [...] Read more.
A new experimental high-pressure setup for measuring diffusion coefficients in supercritical fluids, based on Taylor dispersion method, and using an FTIR detector to operate up to 25.0 MPa was designed and optimized. Tracer diffusivities, D12, of toluene and benzene in supercritical carbon dioxide were measured in the temperature range of 306.15–320.15 K, and pressure range of 7.5–17 MPa to evaluate the setup and experimental protocol. The effects of flow velocity, volume of the cell, absorbance at different wavenumbers on the diffusion coefficient as well as all parameters respecting the Taylor dispersion method have been analyzed. The obtained diffusion coefficients are in excellent agreement with the available literature data. The dependence of D12 on temperature, pressure, and solvent density were examined. Some correlation models based on the hydrodynamic theory were used to estimate the diffusion coefficients in supercritical carbon dioxide, which is the best agreement obtained for an improved version of the Wilke–Chang model. Full article
(This article belongs to the Special Issue Utilization and Storage of Carbon Dioxide in Petroleum Engineering)
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13 pages, 3338 KiB  
Article
Study on the Plugging Limit and Combination of CO2 Displacement Flow Control System Based on Nuclear Magnetic Resonance (NMR)
by Chang-Hua Yang, Pan-Pan Lu, Ya-Ming Cao, Min Xu, Zhen-Ye Yu and Peng-Fei Cheng
Processes 2022, 10(7), 1342; https://doi.org/10.3390/pr10071342 - 10 Jul 2022
Viewed by 1121
Abstract
CO2 displacement is an important technology to reduce emissions and improve crude oil recovery, as well as prevent CO2 escape. Effective storage is key to the successful implementation of this technology, especially for medium and high permeability reservoirs. The current flow [...] Read more.
CO2 displacement is an important technology to reduce emissions and improve crude oil recovery, as well as prevent CO2 escape. Effective storage is key to the successful implementation of this technology, especially for medium and high permeability reservoirs. The current flow control systems that are applied to seal gas escape are mainly gas/water alternation, CO2 foam, and CO2 foam gel, but there is no clear understanding of the plugging limits of various flow control systems and the mechanism of their combined use of residual oil. Therefore, in this paper, a series of core replacement experiments are conducted for different flow control systems and their combinations. The quantitative characterization of the core pore size distribution before and after the replacement is carried out using the NMR technique to try and determine the plugging limits of different plugging systems, and to investigate the residual oil utilization patterns of self-designed flow control system combinations and common flow control system combinations under two reservoir conditions with and without large pores. The results show that the plugging limits of water/gas alternation, CO2 foam, and CO2 foam gel systems are 0.86–21.35 μm, 0.07–28.23 μm, and 7–100 μm, respectively, as inferred from the T2 (lateral relaxation time) distribution and pore size distribution. When different combinations of flow control systems are used for repelling, for reservoirs without large pore channels, the combination of flow control systems using higher strength CO2 foam first can effectively improve the degree of crude oil mobilization in small pore throats, compared to using gas/water alternation directly. For reservoirs containing large pore channels, using high-strength CO2 foam gel first to seal the large pore channels increases the degree of utilization of the large pore channels; using water/gas alternation first causes damage to the middle pore channels; High-strength CO2 foam gel seals the large pore channels when the plugging strength is not enough; and using water/gas alternation can effectively improve the degree of utilization of small and medium pore channels. The results of this paper can provide theoretical guidance for the multi-stage flow control of CO2 displacement in the field. Full article
(This article belongs to the Special Issue Utilization and Storage of Carbon Dioxide in Petroleum Engineering)
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Review

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22 pages, 7018 KiB  
Review
Development of CO2-Sensitive Viscoelastic Fracturing Fluid for Low Permeability Reservoirs: A Review
by Allah Bakhsh, Liang Zhang, Huchao Wei, Azizullah Shaikh, Nasir Khan, Zeeshan Khan and Ren Shaoran
Processes 2022, 10(5), 885; https://doi.org/10.3390/pr10050885 - 29 Apr 2022
Cited by 6 | Viewed by 1750
Abstract
There are economic and technical challenges to overcome when increasing resource recovery from low permeability reservoirs. For such reservoirs, the hydraulic fracturing plan with the development of clean and less expensive fracturing fluid plays a vital aspect in meeting the energy supply chain. [...] Read more.
There are economic and technical challenges to overcome when increasing resource recovery from low permeability reservoirs. For such reservoirs, the hydraulic fracturing plan with the development of clean and less expensive fracturing fluid plays a vital aspect in meeting the energy supply chain. Numerous recent published studies have indicated that research on worm-like micelles (WLMs) based on viscoelastic surfactant (VES) fluid has progressed substantially. This study looks at the development of CO2-sensitive viscoelastic fracturing fluid (CO2-SVFF), its applications, benefits, limitations, and drawbacks of conventional fracturing fluids. The switchable viscoelasticity of CO2-SVFF system signifies how reusing of this fluid is attained. Compared to conventional surfactants, the CO2-SVFF system can be switched to high viscosity (to fracture formation and transporting proppants) and low viscosity (easy removal after causing fracture). The effect of pH, conductivity, temperature, and rheological behaviors of CO2-SVFFs are also highlighted. Further, the aid of Gemini surfactants and nanoparticles (NPs) with low concentrations in CO2-SVFF can improve viscoelasticity and extended stability to withstand high shear rates and temperatures during the fracturing process. These studies provide insight into future knowledge that might lead to a more environmentally friendly and successful CO2-SVFFs in low-permeability reservoirs. Despite the increased application of CO2-SVFFs, there are still several challenges (i.e., formation with high-temperature range, pressure, and salinity). Full article
(This article belongs to the Special Issue Utilization and Storage of Carbon Dioxide in Petroleum Engineering)
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