Analysis of CO2 storage mechanisms at a CO2‐EOR site, Cranfield, Mississippi

Hosseini, Seyyed A.; Alfi, Masoud; Nicot, Jean‐Philippe; Nunez-Lopez, Vanessa

doi:10.1002/ghg.1754

Cited by 14 publications

(5 citation statements)

References 20 publications

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“…Understanding of multiphase flow in natural porous media is of essential importance in many applications including geological storage of CO 2 , enhanced oil recovery (EOR), groundwater remediation, and nuclear waste storage (Baehr & Corapcioglu, 1987; Bakhshian, Hosseini, & Shokri, 2019; Hosseini et al., 2018; Xu et al., 2008). One of the main complications in understanding these multiphase systems stems from the fact that geological formations are heterogeneous at all scales.…”

Section: Introductionmentioning

confidence: 99%

New Insights Into Complex Interactions Between Heterogeneity and Wettability Influencing Two‐Phase Flow in Porous Media

Bakhshian

Rabbani

Hosseini

et al. 2020

Geophysical Research Letters

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Coupled effects of wettability and pore geometry on pore‐scale dynamics of immiscible two‐phase fluid displacement were investigated using a multiphase lattice Boltzmann model in homogeneous and heterogeneous porous media under a wide range of contact angle θ (25° ≤θ≤ 175°). The observed invasion patterns indicate that the complex interactions between wettability and pore morphology play crucial roles in controlling the displacement patterns. The detailed pore‐scale analysis enabled us to delineate how wettability influences the recovery efficiency of the defending fluid in homogeneous and heterogeneous porous media. As the wetting condition changes from strong drainage to imbibition, we observed a transition from burst to corner flow leading to a compact displacement and hence a higher recovery efficiency in the heterogeneous sample. The present study sheds new insights on how the interaction between wettability and heterogeneity influences fluid displacement in porous media.

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Section: Introductionmentioning

confidence: 99%

New Insights Into Complex Interactions Between Heterogeneity and Wettability Influencing Two‐Phase Flow in Porous Media

Bakhshian

Rabbani

Hosseini

et al. 2020

Geophysical Research Letters

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“…Pressure-volume-temperature (PVT) data were tuned and the solubility of CO2 into the aqueous phase (oil and brine) was included using Henry's Law. A detailed description of the numerical reservoir simulation can be found in Hosseini et al [21]. We then used a commercial package (CMG-GEM) to run the numerical simulations, and matched historic production from 1944 to 1964, as well as a shut-in period from 1964 to 2008 and the first four years of the current EOR tertiary stage.…”

Section: Subsurface Modeling For Eor Operational Performancementioning

confidence: 99%

Section: Subsurface Modeling For Eor Operational Performancementioning

confidence: 99%

Environmental and Operational Performance of CO2-EOR as a CCUS Technology: A Cranfield Example with Dynamic LCA Considerations

2019

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This study evaluates the potential of carbon dioxide-enhanced oil recovery (CO2-EOR) to reduce greenhouse gas emissions without compromising oil production goals. A novel, dynamic carbon lifecycle analysis (d-LCA) was developed and used to understand the evolution of the environmental impact (CO2 emissions) and mitigation (geologic CO2 storage) associated with an expanded carbon capture, utilization and storage (CCUS) system, from start to closure of operations. EOR operational performance was assessed through CO2 utilization rates, which relate usage of CO2 to oil production. Because field operational strategies have a significant impact on reservoir engineering parameters that affect both CO2 storage and oil production (e.g., sweep efficiency, flood conformance, fluid saturation distribution), we conducted a scenario analysis that assessed the operational and environmental performance of four common and novel CO2-EOR field development strategies. Each scenario was evaluated with and without stacked saline carbon storage, an EOR/storage combination strategy where excess CO2 from the recycling facility is injected into an underlying saline aquifer for long-term carbon storage. The dynamic interplay between operational and environmental performance formed the basis of our CCUS technology analysis. The results showed that all CO2-EOR evaluated scenarios start operating with a negative carbon footprint and, years into the project, transitioned into operating with a positive carbon footprint. The transition points were significantly different in each scenario. Water-alternating-gas (WAG) was identified as the CO2 injection strategy with the highest potential to co-optimize EOR and carbon storage goals. The results provide an understanding of the evolution of the system’s net carbon balance in all four field development strategies studied. The environmental performance can be significantly improved with stacked storage, where a negative carbon footprint can be maintained throughout the life of the operation in most of the injection scenarios modelled. This information will be useful to CO2-EOR operators seeking value in storing more CO2 through a carbon credit program (e.g., the 45Q carbon credit program in the USA). Most importantly, this study serves as confirmation that CO2-EOR can be operationally designed to both enhance oil production and reduce greenhouse gas emissions into the atmosphere.

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“…Gas injection EOR processes have continuously attracted more concerns as an EOR method among others since its discovery. The reason is chiefly because of its remarkable performance in oil recovery and because of its added feature of storing greenhouse gases [1,2]. Gas injection can be classified based on their miscibility status or based on the nature of injection fluid.…”

Section: Introductionmentioning

confidence: 99%

Simulation Studies on Determination of Displacement and Areal Sweep Efficiencies for Hot CO2 Flooding in Niger Delta Heavy Oilfield

Abili¹,

Izuwa²,

Onyejekwe³

et al. 2021

OGCE

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Recovery efficiency is very important in enhanced oil recovery (EOR) processes as it helps in the planning, design and selection of EOR methods that will be technically and economically feasible. In this study, Simulation on hot CO 2 flooding is conducted using data from Niger Delta heavy oil reservoir. The compositional simulation process was carried out in ECLIPSE 300 compositional oil simulator. The recovery efficiency and injection calculations were modeled and simulated in Matlab. Numerical equations enabled the determination of the residual oil saturation and the consequent calculation of the injection and recovery before and after solvent breakthroughs. CO 2 of 0.095cp viscosity was injected at pressure of 3500 psia and 200°F to heat up the reservoir at payzone and reduce the viscosity of the reservoir oil at in-situ reservoir condition. The reservoir oil initially at 14.23cp at initial reservoir temperature and pressure was heated and reduced to a viscosity of 2cP making the oil mobile and amenable to flow. Results show recovery of the process before and after breakthroughs. CO 2 breakthrough was realized after 221 days of the flooding process. Of the 2461.2 ft distance from the injection wells to the producer well, CO 2 reached only a distance of 100 ft at breakthrough. Out of the 2.77 PV total volume of CO 2 injected in the flooding process, 0.1222 PV of CO 2 was injected as at breakthrough. The recovery efficiency result show that the displacement efficiency at CO 2 breakthrough and at the end of the flooding process are 15.17% and 78.63% respectively while the areal sweep efficiency at CO 2 breakthrough and at the end of the flooding process are 44.02% and 93.32% respectively. The low displacement and areal sweep efficiency at breakthrough were due to early breakthrough of CO 2 which did not allow sufficient period of time for the CO 2 to contact considerable portions of the reservoir given its viscous nature. Furthermore, at CO 2 breakthrough time, the injected hot CO 2 had no sufficient time to soak the reservoir and reduce the viscosity of the oil; as such only a small fraction of the in-situ oil became mobile. An overall recovery efficiency of 73.33% realized in the flooding process signifies favourable flooding design hence is recommended for the development and recovery of Niger Delta heavy oilfield.

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Analysis of CO₂ storage mechanisms at a CO₂‐EOR site, Cranfield, Mississippi

Cited by 14 publications

References 20 publications

New Insights Into Complex Interactions Between Heterogeneity and Wettability Influencing Two‐Phase Flow in Porous Media

New Insights Into Complex Interactions Between Heterogeneity and Wettability Influencing Two‐Phase Flow in Porous Media

Environmental and Operational Performance of CO2-EOR as a CCUS Technology: A Cranfield Example with Dynamic LCA Considerations

Simulation Studies on Determination of Displacement and Areal Sweep Efficiencies for Hot CO<sub>2</sub> Flooding in Niger Delta Heavy Oilfield

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Analysis of CO2 storage mechanisms at a CO2‐EOR site, Cranfield, Mississippi

Cited by 14 publications

References 20 publications

New Insights Into Complex Interactions Between Heterogeneity and Wettability Influencing Two‐Phase Flow in Porous Media

New Insights Into Complex Interactions Between Heterogeneity and Wettability Influencing Two‐Phase Flow in Porous Media

Environmental and Operational Performance of CO2-EOR as a CCUS Technology: A Cranfield Example with Dynamic LCA Considerations

Simulation Studies on Determination of Displacement and Areal Sweep Efficiencies for Hot CO&lt;sub&gt;2&lt;/sub&gt; Flooding in Niger Delta Heavy Oilfield

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Analysis of CO₂ storage mechanisms at a CO₂‐EOR site, Cranfield, Mississippi

Simulation Studies on Determination of Displacement and Areal Sweep Efficiencies for Hot CO<sub>2</sub> Flooding in Niger Delta Heavy Oilfield