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Energies
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CO2 EOR and Sequestration: Conventional and Unconventional Reservoirs
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CO2 EOR and Sequestration: Conventional and Unconventional Reservoirs

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H: Geo-Energy".

Deadline for manuscript submissions: closed (20 November 2020) | Viewed by 10090

Special Issue Editors

Dr. Japan Trivedi

E-Mail Website
Guest Editor
Department of Civil and Environmental Engineering, School of Mining and Petroleum, University of Alberta, Edmonton, AB T6G 2R3, Canada
Interests: polymer (ASP) characterization; chemical EOR, functional polymer; rheology; polymer-enhanced foam
Special Issues, Collections and Topics in MDPI journals
Dr. Ali Telmadarreie

E-Mail Website
Guest Editor
CERC Research Associate, Office of the Vice-President (Research), University of Calgary, Calgary, AB, Canada
Interests: foam assisted EOR; complex fluids; steam/CO2 foam; CO2 sequestration; nanoparticle
Dr. Madhar S. Azad

E-Mail Website
Guest Editor
Post Doctoral Researcher (EOR), School of Mining and Petroleum Engineering, University of Alberta, Edmonton, AB, Canada
Interests: reservoir engineering; chemical EOR; tight oil; heavy oil; polymer rheology

Special Issue Information

Dear Colleagues,

CO2-EOR not only increases oil recovery but also contributes to CO2 sequestration in geological formations. While the field demonstrations projects of CO2 sequestration in oil and gas reservoirs and saline aquifers are on rise; the fundamental understanding of CO2 interactions with reservoir oil and brine, experimentation of multiphase flow in porous media and numerical simulations provide pore- and core- scale insight. The use of chemical additives with CO2 has also been studied and applied for CO2-EOR field projects. CO2 EOR can play an important role in Carbon Capture Utilization and Storage (CCUS) to minimize the carbon footprint of the current oil recovery process while improving the efficiency of oil extraction. Considering wide applications of CO2 EOR/IOR in Conventional/Unconventional Reservoirs, this special issue invites scientific output in the following topics:

  • CO2 Flooding: Miscible, immiscible and WAG
  • Huff-n-puff and Cyclic Gas Injection 
  • CO2-foams: Lab Design, Pilot and Field tests
  • Field demonstration
  • CO2 sequestration

Dr. Japan Trivedi
Dr. Ali Telmadarreie
Dr. Madhar S. Azad
Guest Editors

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Keywords

  • CO2 Flooding: Miscible, immbiscible and WAG
  • Huff-n-puff and Cyclic Gas Injection
  • CO2-foams: Lab Design, Pilot and Field tests
  • Field demonstration

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Published Papers (3 papers)

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Research

15 pages, 4321 KiB  
Article
CO2 Foam and CO2 Polymer Enhanced Foam for Heavy Oil Recovery and CO2 Storage
by Ali Telmadarreie and Japan J Trivedi
Energies 2020, 13(21), 5735; https://doi.org/10.3390/en13215735 - 2 Nov 2020
Cited by 30 | Viewed by 3917
Abstract
Enhanced oil recovery (EOR) from heavy oil reservoirs is challenging. High oil viscosity, high mobility ratio, inadequate sweep, and reservoir heterogeneity adds more challenges and severe difficulties during any EOR method. Foam injection showed potential as an EOR method for challenging and heterogeneous [...] Read more.
Enhanced oil recovery (EOR) from heavy oil reservoirs is challenging. High oil viscosity, high mobility ratio, inadequate sweep, and reservoir heterogeneity adds more challenges and severe difficulties during any EOR method. Foam injection showed potential as an EOR method for challenging and heterogeneous reservoirs containing light oil. However, the foams and especially polymer enhanced foams (PEF) for heavy oil recovery have been less studied. This study aims to evaluate the performance of CO2 foam and CO2 PEF for heavy oil recovery and CO2 storage by analyzing flow through porous media pressure profile, oil recovery, and CO2 gas production. Foam bulk stability tests showed higher stability of PEF compared to that of surfactant-based foam both in the absence and presence of heavy crude oil. The addition of polymer to surfactant-based foam significantly improved its dynamic stability during foam flow experiments. CO2 PEF propagated faster with higher apparent viscosity and resulted in more oil recovery compared to that of CO2 foam injection. The visual observation of glass column demonstrated stable frontal displacement and higher sweep efficiency of PEF compared to that of conventional foam. In the fractured rock sample, additional heavy oil recovery was obtained by liquid diversion into the matrix area rather than gas diversion. Aside from oil production, the higher stability of PEF resulted in more gas storage compared to conventional foam. This study shows that CO2 PEF could significantly improve heavy oil recovery and CO2 storage. Full article
(This article belongs to the Special Issue CO2 EOR and Sequestration: Conventional and Unconventional Reservoirs)
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22 pages, 3727 KiB  
Article
Gas Pressure Cycling (GPC) and Solvent-Assisted Gas Pressure Cycling (SA-GPC) Enhanced Oil Recovery Processes in a Thin Heavy Oil Reservoir
by Olusegun Ojumoola, Hongze Ma and Yongan Gu
Energies 2020, 13(19), 5047; https://doi.org/10.3390/en13195047 - 25 Sep 2020
Cited by 1 | Viewed by 2920
Abstract
In this paper, gas pressure cycling (GPC) and solvent-assisted gas pressure cycling (SA-GPC) were developed as two new and effective enhanced oil recovery (EOR) processes. Eight coreflood tests were conducted by using a 2-D rectangular sandpacked physical model with a one or two-well [...] Read more.
In this paper, gas pressure cycling (GPC) and solvent-assisted gas pressure cycling (SA-GPC) were developed as two new and effective enhanced oil recovery (EOR) processes. Eight coreflood tests were conducted by using a 2-D rectangular sandpacked physical model with a one or two-well configuration. More specifically, two cyclic solvent injection (CSI), three GPC, and three SA-GPC tests were conducted after the primary production, whose pressure was declined in steps from Pi = 3.0 MPa to Pf = 0.2 MPa. It was found that the CSI tests had poor performances because of the known CSI technical shortcomings and an additional technical issue of solvent trapping found in this study. Quick heavy oil viscosity regainment resulted in the solvent-trapping zone. In contrast, C3H8-GPC test at a pressure depletion step size of ∆PEOR = 0.5 MPa and C3H8-SA-CO2-GPC test at ∆PEOR = 1.0 MPa had the highest total heavy oil recovery factors (RFs) of 41.9% and 36.6% of the original oil-in-place (OOIP) among the two respective series of GPC and SA-GPC tests. The better performances of these two tests than C3H8- or CO2-CSI test were attributed to the effective displacement of the foamy oil toward the producer in the two-well configuration. Thus the back-and-forth movements of the foamy oil in CSI test in the one-well configuration were eliminated in these GPC and SA-GPC tests. Furthermore, C3H8-GPC test outperformed C3H8-SA-CO2-GPC test in terms of the heavy oil RF and cumulative gas-oil ratio (cGOR) because of the formation of stronger foamy-oil flow and the absence of CO2, which reduced the solubility of C3H8 in the heavy oil in the latter test. In summary, different solvent-based EOR processes were ranked based on the heavy oil RFs as follows: C3H8-GPC > C3H8-SA-CO2-GPC > CO2-GPC > C3H8-CSI > CO2-CSI. Full article
(This article belongs to the Special Issue CO2 EOR and Sequestration: Conventional and Unconventional Reservoirs)
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15 pages, 5354 KiB  
Article
Development of Greener D-Metal Inorganic Crosslinkers for Polymeric Gels Used in Water Control in Oil and Gas Applications
by Hassan I. Nimir, Ahmed Hamza and Ibnelwaleed A. Hussein
Energies 2020, 13(16), 4262; https://doi.org/10.3390/en13164262 - 18 Aug 2020
Cited by 5 | Viewed by 2392
Abstract
Crosslinkable polymers, such as polyacrylamide (PAM), are widely applied for water control in oil and gas reservoirs. Organic and inorganic crosslinkers are used to formulate a gel with PAM. Although chromium has a high level of toxicity, it has been implemented as an [...] Read more.
Crosslinkable polymers, such as polyacrylamide (PAM), are widely applied for water control in oil and gas reservoirs. Organic and inorganic crosslinkers are used to formulate a gel with PAM. Although chromium has a high level of toxicity, it has been implemented as an effective crosslinker combined with carboxylates because of the controllability of crosslinking time at low temperatures. The objective of this work was to develop greener d-metal inorganic crosslinkers based on cobalt, copper, and nickel to replace chromium for application at reservoir conditions. The obtained results showed that the gelation chemistry of the developed systems depends on the metal charge density. The gelation of PAM with d-metals depends on pH and temperature for low- and high-charge density, respectively. Cobalt (II) acetate (CoAc) was effective at high temperatures (130–150 °C) and forms (4% CoAc + 9%PAM) stable, and strong gels at a pH > 7 with a storage modulus exceeding 4300 Pa. However, Nickel Acetate and Cupper Acetate formed stable weak gels at low temperatures (50–70 °C) and a pH > 6 and gel decomposition was observed upon increasing the temperature. The developed formulations were compatible with low-salinity water (1000 ppm NaCl). Full article
(This article belongs to the Special Issue CO2 EOR and Sequestration: Conventional and Unconventional Reservoirs)
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