Impact of field development strategies on CO2 trapping mechanisms in a CO2–EOR field: A case study in the permian basin (SACROC unit)

Hosseininoosheri, Pooneh; Hosseini, Seied Ali; Nunez-Lopez, Vanessa; Lake, Larry W.

doi:10.1016/j.ijggc.2018.03.002

Cited by 49 publications

(21 citation statements)

References 30 publications

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“…The mechanisms that trapped oil within the reservoir also act to trap CO 2 . The fact that oil was trapped over geologic time provides confidence that CO 2 will be safely trapped/stored for that long in four different forms: (1) structurally beneath an impermeable barrier, (2) residually as an immobile phase FIGURE 2 | CO 2 trapping mechanisms (Hosseininoosheri et al, 2018).…”

Section: Associated Storage Of Co 2 Through Eormentioning

confidence: 99%

Potential of CO2-EOR for Near-Term Decarbonization

Nunez-Lopez

Moskal

2019

Front. Clim.

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This paper provides an overview of carbon dioxide enhanced oil recovery (CO 2-EOR) and its ability to reduce greenhouse gas (GHG) emissions (even to the point of negative emissions), the role it needs to play in the challenge of decarbonization, and the need to scale up implementation and deployment in order to meet climate goals. Limitations in current legal and regulatory frameworks for CO 2 injection are explored for both economic and environmental purposes, as well as the economic implications of combining CO 2-EOR with geologic carbon storage. Results from a recent study, which demonstrate that all CO 2-EOR operations produce negative emissions oil during the first several years of production, are analyzed in the context of the urgency of climate change mitigation. Acknowledging that fossil fuels currently provide the energy foundation upon which global societies function, and that a sudden shift in the composition of that foundation can potentially destabilize the global economy and key elements of modern society, we bring CO 2-EOR to the fore as it can supply reduced carbon oil to support the current energy foundation as it steadily transitions toward decarbonization. In order to meet this urgent transition, greater fiscal, and regulatory incentives are needed to begin scaling CO 2-EOR with storage around the globe. A viable and large-scale CO 2-EOR/storage industry depends upon significant capital investments for CO 2 capture and transportation infrastructure. Policy consistency and predictability, combined with targeted subsidies, will help to achieve this goal.

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Section: Associated Storage Of Co 2 Through Eormentioning

confidence: 99%

Potential of CO2-EOR for Near-Term Decarbonization

Nunez-Lopez

Moskal

2019

Front. Clim.

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“…On the other hand, a Darcy‐based simulation is the most commonly used approach in reservoir simulation studies 26–28 . It is also used to model CO 2 flow in porous media for CO 2 ‐enhanced oil recovery (EOR) 29–33 and plume migration in aquifers 34–36 . Currently, there are several open‐source and commercial Darcy‐based codes.…”

Section: Introductionmentioning

confidence: 99%

Modeling CO₂ plume migration using an invasion‐percolation approach that includes dissolution

et al. 2020

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Geological carbon dioxide (CO 2 ) sequestration has been proposed as a viable technique to decrease effective emissions of CO 2 into the atmosphere. However, the security of this sequestration is tied to our understanding of the long-term migration of CO 2 in subsurface. The dissolution of CO 2 in the reservoir brine is one of the main long-term trapping mechanisms. However, the assumptions used in large-scale reservoir simulations usually lead to an overestimation of the dissolution volume. We propose a modified approach based on the macroscopic invasion-percolation (MIP) theory that allows the dissolution of CO 2 into brine. We used a high-resolution geological model to compare the Darcy-, modified MIP-, and classic MIP-based simulation results. We observed a significant shrinkage in the nonaqueous plume volume when dissolution is considered during the MIP simulation. In the case of Darcy-based simulation, the plume was completely trapped inside the reservoir with limited migration even after a thousand-year simulation. On the other hand, the majority of the plume migrated out of the simulated reservoir in the case of MIP. Our approach provides more realistic estimation of the dissolution volume and nonaqueous plume extent while leveraging the computational efficiency enjoyed by MIP. C Several modeling approaches are available to forecast the fate of CO 2 in the underground. [8][9][10][11][12] One of these approaches is modified invasion percolation (MIP), which assumes negligible effect for viscous forces on fluid displacement. Therefore, the balance between the buoyancy and capillary forces is the key factor in the MIP method to predict the plume migration. 13,14 On the other hand, Darcy-based approaches solve a set of

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“…Screening methods (such as analytical and numerical analysis) 34,39,56,57 have been used to evaluate the efficiency of each step. In this case, numerical and analytical methods provide tools to evaluate the effect of specific parameters on EOR and CO 2 ‐storage performance including the effect of miscibility on CO 2 ‐EOR performance, 41,50,58–61 different injection strategies, 35 wettability and hysteresis, 49,52,62 fracture–matrix interaction, 25 and CO 2 ‐EOR and storage efficiency 34,36,63–71 …”

Section: Introductionmentioning

confidence: 99%

The effect of natural fractures on CO₂storage performance and oil recovery from CO₂and WAG injection in an Appalachian basin reservoir

2020

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Natural fractures affect both the oil recovery from the enhanced oil recovery (EOR) process and the associated CO 2 storage during and after EOR. The main objective of this study is to evaluate two performance parameters: (1) oil recovery during CO 2 and water alternating gas (WAG) injection, and (2) CO 2 storage, during and after EOR, in a fractured oil reservoir of the Appalachian basin. While previous studies have shown the potential of CO 2-EOR to enhance oil recovery in the Appalachian basin, this work investigates WAG performance in comparison to continuous CO 2-EOR. A compositional numerical modeling approach was used to quantify the incremental oil recovery stemming from incorporating natural fractures. History matching of primary production and CO 2 huff-and-puff pilot test for a well producing from a depleted oil field in Ohio was used to assign the fracture network parameters in the dual continuum model. The scenarios modeled include continuous CO 2 and WAG injection under two injection pore volumes. Each scenario is followed by a CO 2 storage phase. These simulations help evaluate the performance of different scenarios in terms of oil recovery and CO 2 storage. Simulation results show how oil recovery and CO 2 storage vary significantly as a function of operational parameters. The results also show the amount of CO 2 stored during WAG injection is significantly lower than that stored during the storage phase at the end of oil recovery. In addition, the operational parameters during WAG affect the amount of CO 2 stored at the end of following storage phase.

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Impact of field development strategies on CO2 trapping mechanisms in a CO2–EOR field: A case study in the permian basin (SACROC unit)

Cited by 49 publications

References 30 publications

Potential of CO2-EOR for Near-Term Decarbonization

Potential of CO2-EOR for Near-Term Decarbonization

Modeling CO₂ plume migration using an invasion‐percolation approach that includes dissolution

The effect of natural fractures on CO₂storage performance and oil recovery from CO₂and WAG injection in an Appalachian basin reservoir

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Impact of field development strategies on CO2 trapping mechanisms in a CO2–EOR field: A case study in the permian basin (SACROC unit)

Cited by 49 publications

References 30 publications

Potential of CO2-EOR for Near-Term Decarbonization

Potential of CO2-EOR for Near-Term Decarbonization

Modeling CO2 plume migration using an invasion‐percolation approach that includes dissolution

The effect of natural fractures on CO2storage performance and oil recovery from CO2and WAG injection in an Appalachian basin reservoir

Contact Info

Product

Resources

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Modeling CO₂ plume migration using an invasion‐percolation approach that includes dissolution

The effect of natural fractures on CO₂storage performance and oil recovery from CO₂and WAG injection in an Appalachian basin reservoir