Characterization and Determination of CO2-Reservoir Oil Miscibility

Saini, Dayanand

doi:10.1007/978-3-319-95546-9_2

Cited by 3 publications

(1 citation statement)

References 78 publications

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“…The Gibbs free energy and solubility parameters were applied to quantify the miscibility and/or determine the MMP. 40,41 The Gibbs free energy, a thermodynamic potential used to calculate the maximum reversible work that a thermodynamic system may perform, was used to differentiate the miscible and immiscible states. 42 More specifically, a Gibbs free energy less than zero and its second derivative with respect to the composition larger than zero should be concurrently reached to form a miscible blend.…”

Section: Introductionmentioning

confidence: 99%

HLD-Based Formulation Prediction for Degassed Oil with Equivalent Minimum Miscibility Pressure

Wang,

Zhao,

Guo

et al. 2024

Energy Fuels

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Shale cores, with their ultralow permeability, often require pressurization for saturation with target fluids, as flowthrough saturation is inefficient. This saturation method, when applied by using live oil, leads to fluid loss during core transfer and system vacuuming in subsequent experimental steps. As a result, most shale-related experiments utilize degassed oils, typically dead oil or kerosene. However, researchers account for only density or viscosity similarities in degassed oil preparation, missing key aspects of the gas injection mechanism. This study focuses on the representativeness of degassed oil and develops a procedure to prepare degassed surrogate oil that accurately replicates the live oil's minimum miscibility pressure (MMP). We propose a predictive oil formulation procedure based on thermodynamic similarities between oil/gas miscible systems and oil/water middle-phase microemulsion systems under the hydrophilic−lipophilic deviation (HLD) theory. This procedure, validated with real reservoir oil samples, uses liquid light hydrocarbons to reduce the equivalent alkane carbon number (EACN) of dead oil for surrogate oil preparation. EACN for dead, live, and surrogate oils was determined through slim tube and microemulsion phase behavior experiments. Light hydrocarbon addition quantities were estimated by linear EACN mixing. The surrogate oil's MMP, tested against CO 2 in slim tube experiments and verified through salinity scanning phase behavior experiments, was 27.83 MPa, closely matching the live oil's MMP of 28.15 MPa. These results validate the predictivity of our procedure, eliminating trial and error in adjusting light hydrocarbon volumes. The surrogate oil's lack of dissolved gases addresses fluid loss issues during rock core transfers, solving saturation and transfer challenges in tight rock core experiments.

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Section: Introductionmentioning

confidence: 99%

HLD-Based Formulation Prediction for Degassed Oil with Equivalent Minimum Miscibility Pressure

Wang,

Zhao,

Guo

et al. 2024

Energy Fuels

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Optimising the transition from CO2 EOR-EGR towards CCS for a mature oil and gas reservoir

Rakotondrazaka,

Johnson,

et al. 2023

APPEA J.

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This study evaluates carbon dioxide enhanced oil recovery (CO2 EOR) for enhanced oil recovery (EOR), enhanced gas recovery (EGR) and carbon capture and storage (CCS) purposes in the mature Mereenie Oil and Gas Field (‘Mereenie’). Mereenie consists of a rim oil and gas cap reservoir with low aquifer activity. We evaluate the microscopic and macroscopic displacement efficiencies of CO2 EOR techniques after determining the minimum miscibility pressure of the CO2 and reservoir oil system. Investigations on EOR, EGR and CCS are then conducted on a sector model containing the main pay zones. The CO2 flood, water alternating gas (CO2 WAG) and Huff ‘n’ Puff methods are evaluated within three strategies: unstructured well placement, five-spot pattern configuration and gravity-assisted flood. The sector model shows performance of an immiscible process in oil and gas recovery and CO2 storage potential. The CO2 flood is efficient in oil recovery but less efficient in CO2 utilisation, making it a good option for a half oil recovery–half CO2 storage objective. The CO2 Huff ‘n’ Puff is more efficient for oil recovery at early stages of operation, and also very efficient for gas recovery. The CO2 Huff ‘n’ Puff technique is not a good option for the CO2 storage objective. The CO2 WAG could be a good technique for oil recovery and CO2 storage with proper CO2 slug size and WAG ratio. The five-spot pattern configuration enhances sweep efficiency. The gravity-assisted flood strategy can be appropriate for the rim oil reservoir with gas cap in Mereenie.

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Enhancing Viscous Oil Recovery in the Microbubble Filtration Mode Using Supercritical Fluid Systems

Radaev

Sabirzyanov

2022

J Appl Mech Tech Phy

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Characterization and Determination of CO2-Reservoir Oil Miscibility

Cited by 3 publications

References 78 publications

HLD-Based Formulation Prediction for Degassed Oil with Equivalent Minimum Miscibility Pressure

HLD-Based Formulation Prediction for Degassed Oil with Equivalent Minimum Miscibility Pressure

Optimising the transition from CO2 EOR-EGR towards CCS for a mature oil and gas reservoir

Enhancing Viscous Oil Recovery in the Microbubble Filtration Mode Using Supercritical Fluid Systems

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