Experimental Study of Multiphase Flow in Porous Media during CO2 Geo-Sequestration Processes

Saeedi, Ali

doi:10.1007/978-3-642-25041-5

Cited by 19 publications

(13 citation statements)

References 135 publications

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“…The apparatus is designed for pressures up to 15,000 psi (1,000 bar) and temperatures up to 200 o C in one standalone integrated system. More information about the apparatus, data logging and monitoring/controlling system is provided in Saeedi [15]. The core-holder, fluid accumulators and flow-lines carrying the fluids are located in a convection oven with three fans to keep the temperature constant during the experiments (with an accuracy of +/-0.2 o C).…”

Section: Experimental Measurements and Procedures 21 Experimental Apmentioning

confidence: 99%

CO₂-brine injectivity tests in high co₂ content carbonate field, sarawak basin, offshore east Malaysia

et al. 2019

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We conducted relatively long duration core-flooding tests on three representative core samples under reservoir conditions to quantify the potential impact of flow rates on fines production/permeability change. Supercritical CO2 was injected cyclically with incremental increases in flow rate (2─14 ml/min) with live brine until a total of 7 cycles were completed. To avoid unwanted fluid-rock reaction when live brine was injected into the sample, and to mimic the in-situ geochemical conditions of the reservoir, a packed column was installed on the inflow accumulator line to pre-equilibrate the fluid before entering the core sample. The change in the gas porosity and permeability of the tested plug samples due to different mechanisms (dissolution and/or precipitation) that may occur during scCO2/live brine injection was investigated. Nuclear magnetic resonance (NMR) T2 determination, X-ray CT scans and chemical analyses of the produced brine were also conducted. Results of pre- and post-test analyses (poroperm, NMR, X-ray CT) showed no clear evidence of formation damage even after long testing cycles and only minor or no dissolution (after large injected pore volumes (PVs) ~ 200). The critical flow rates (if there is one) were higher than the maximum rates applied. Chemical analyses of the core effluent showed that the rock samples for which a pre-column was installed do not experience carbonate dissolution.

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Section: Experimental Measurements and Procedures 21 Experimental Apmentioning

confidence: 99%

CO₂-brine injectivity tests in high co₂ content carbonate field, sarawak basin, offshore east Malaysia

et al. 2019

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“…Complete H 2 O replacement (S w = 0) could not be achieved in any of the given domains, which is partly due to trapping and bubble-forming effects. A more detailed description about such effects is given in Saeedi (2012).…”

Section: Dynamic Evolution Of Co 2 -Water Interfacementioning

confidence: 99%

Development of a numerical workflow based on <i>μ</i>-CT imaging for the determination of capillary pressure–saturation-specific interfacial area relationship in 2-phase flow pore-scale porous-media systems: a case study on Heletz sandstone

Peche¹,

Halisch²,

Tatomir³

et al. 2016

Solid Earth

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Abstract. In this case study, we present the implementation of a finite element method (FEM)-based numerical porescale model that is able to track and quantify the propagating fluid-fluid interfacial area on highly complex microcomputed tomography (µ-CT)-obtained geometries. Special focus is drawn to the relationship between reservoir-specific capillary pressure (p c ), wetting phase saturation (S w ) and interfacial area (a wn ). The basis of this approach is highresolution µ-CT images representing the geometrical characteristics of a georeservoir sample. The successfully validated 2-phase flow model is based on the Navier-Stokes equations, including the surface tension force, in order to consider capillary effects for the computation of flow and the phase-field method for the emulation of a sharp fluid-fluid interface.In combination with specialized software packages, a complex high-resolution modelling domain can be obtained. A numerical workflow based on representative elementary volume (REV)-scale pore-size distributions is introduced. This workflow aims at the successive modification of model and model set-up for simulating, such as a type of 2-phase problem on asymmetric µ-CT-based model domains. The geometrical complexity is gradually increased, starting from idealized pore geometries until complex µ-CT-based pore network domains, whereas all domains represent geostatistics of the REV-scale core sample pore-size distribution. Finally, the model can be applied to a complex µ-CT-based model domain and the p c -S w -a wn relationship can be computed.

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“…Shape factor (d) can be defined for Kazemi model, as a function of matrix block size (a) that can be simplified to d = 4/a 2 (Saeedi 2012). Fracture compressibility (C f ) in dual-porosity systems might be 1-100-folds higher than matrix compressibility.…”

Section: Characterizing Srv Using Dual-porosity Simulation Modelmentioning

confidence: 99%

Well test, rate transient analysis and reservoir simulation for characterizing multi-fractured unconventional oil and gas reservoirs

Bahrami

Pena

Lusted

2015

J Petrol Explor Prod Technol

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Unconventional reservoirs such as shale gas and shale oil have become an increasingly important source of energy in the USA with potential reservoirs identified worldwide. Due to the insufficient permeability of the shale reservoirs, they require efficient stimulation using multistage hydraulic fractures to produce gas in commercial quantities. A critical challenge in the reservoirs is performance evaluation of the fracturing and characterization of the stimulated reservoir volume (SRV) for permeability and hydraulic fracture size. Conventional well test analysis in multi-stage fractured shale reservoirs may not provide reliable results due to the extensive wellbore storage effect, fracture complexities, and heterogeneity of the low-permeability reservoir. To overcome such issues, advanced well test analysis techniques integrated with rate transient analysis can be used to reduce uncertainties associated with estimation of the reservoir and hydraulic fractures' dynamic parameters. This paper proposes a practical methodology and workflow for characterizing the SRV parameters in multi-fractured wells in unconventional oil and gas reservoirs using well test and rate transient data analysis based on diffusivity equation solution for linear and elliptical flow regimes integrated with numerical reservoir simulation. A reservoir simulation model is built and run for a typical fractured shale reservoir to verify the reliability of the proposed simplified approach. Furthermore, multi-fractured unconventional reservoir field examples of well test analysis, reservoir simulation and history matching are presented to show how the stimulated reservoir volume can be characterized to perform a more reliable production forecast in shale oil and shale gas reservoirs.

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Experimental Study of Multiphase Flow in Porous Media during CO2 Geo-Sequestration Processes

Abstract: This thesis contains no material which has been accepted for the award of any other degree or diploma in any university. To the best of my knowledge and belief this thesis contains no material previously published by any other person except where due acknowledgment has been made.

Cited by 19 publications

References 135 publications

CO₂-brine injectivity tests in high co₂ content carbonate field, sarawak basin, offshore east Malaysia

CO₂-brine injectivity tests in high co₂ content carbonate field, sarawak basin, offshore east Malaysia

Development of a numerical workflow based on <i>μ</i>-CT imaging for the determination of capillary pressure–saturation-specific interfacial area relationship in 2-phase flow pore-scale porous-media systems: a case study on Heletz sandstone

Well test, rate transient analysis and reservoir simulation for characterizing multi-fractured unconventional oil and gas reservoirs

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Experimental Study of Multiphase Flow in Porous Media during CO2 Geo-Sequestration Processes

Abstract: This thesis contains no material which has been accepted for the award of any other degree or diploma in any university. To the best of my knowledge and belief this thesis contains no material previously published by any other person except where due acknowledgment has been made.

Cited by 19 publications

References 135 publications

CO2-brine injectivity tests in high co2 content carbonate field, sarawak basin, offshore east Malaysia

CO2-brine injectivity tests in high co2 content carbonate field, sarawak basin, offshore east Malaysia

Development of a numerical workflow based on &lt;i&gt;μ&lt;/i&gt;-CT imaging for the determination of capillary pressure–saturation-specific interfacial area relationship in 2-phase flow pore-scale porous-media systems: a case study on Heletz sandstone

Well test, rate transient analysis and reservoir simulation for characterizing multi-fractured unconventional oil and gas reservoirs

Contact Info

Product

Resources

About

CO₂-brine injectivity tests in high co₂ content carbonate field, sarawak basin, offshore east Malaysia

CO₂-brine injectivity tests in high co₂ content carbonate field, sarawak basin, offshore east Malaysia

Development of a numerical workflow based on <i>μ</i>-CT imaging for the determination of capillary pressure–saturation-specific interfacial area relationship in 2-phase flow pore-scale porous-media systems: a case study on Heletz sandstone