Assessment of two-phase flow on the chemical alteration and sealing of leakage pathways in cemented wellbores

Iyer, Jaisree; Walsh, Stuart; Ye, Hao; Carroll, Susan A.

doi:10.1016/j.ijggc.2017.12.001

Cited by 22 publications

(26 citation statements)

References 29 publications

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“…The Burdine [37] parameters for the computed fracture saturation-pressure values that were determined from the Wang and Narasimhan [47] model using Eq 16 are h b = 1.831 cm and λ = 1.0. These values were obtained by fitting discrete pressure-saturation values generated using Eq 16 (with terms defined by Eqs 12–14) with the Brooks-Corey [32] model, Eq 17. Note that only the λ parameter appears in the Burdine [37] relative permeability functions, Eqs 18 and 19.…”

Section: Resultsmentioning

confidence: 99%

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Relative permeability for water and gas through fractures in cement

Rod

Colby

et al. 2019

PLoS ONE

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Relative permeability is an important attribute influencing subsurface multiphase flow. Characterization of relative permeability is necessary to support activities such as carbon sequestration, geothermal energy production, and oil and gas exploration. Previous research efforts have largely neglected the relative permeability of wellbore cement used to seal well bores where risks of leak are significant. Therefore this study was performed to evaluate fracturing on permeability and relative permeability of wellbore cement. Studies of relative permeability of water and air were conducted using ordinary Portland cement paste cylinders having fracture networks that exhibited a range of permeability values. The measured relative permeability was compared with three models, 1) Corey-curve, often used for modeling relative permeability in porous media, 2) X-curve, commonly used to represent relative permeability of fractures, and 3) Burdine model based on fitting the Brooks-Corey function to fracture saturation-pressure data inferred from x-ray computed tomography (XCT) derived aperture distribution results. Experimentally-determined aqueous relative permeability was best described by the Burdine model. Though water phase tended to follow the Corey-curve for the simple fracture system while air relative permeability was best described by the X-curve.

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Section: Resultsmentioning

confidence: 99%

“…Effluent air flow was measured using a precision air flow meter (M series meter, Alicat Scientific, Tucson AZ). Air and 0.1M NaNO 3 solution were selected for performing the tests to minimize reactions with the cement paste, which could change the fracture aperture through precipitation or dissolution reactions [32].…”

Section: Methodsmentioning

confidence: 99%

Relative permeability for water and gas through fractures in cement

Rod

Colby

et al. 2019

PLoS ONE

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“…GEOS accommodates detailed descriptions of 3D features such as stress and modulus variability, along with a discrete, mechanically-coupled representation of numerous preexisting natural fractures. More recent development has extended GEOS to include coupled chemical processes [29], and the prediction of hydrocarbon production in fractured, unconventional reservoirs [30][31][32], although in this work we focus upon leveraging its ability to capture coupled flow and mechanics during stimulation.…”

Section: Geomechanical Simulator Geosmentioning

confidence: 99%

A New Modeling Framework for Multi-Scale Simulation of Hydraulic Fracturing and Production from Unconventional Reservoirs

et al. 2021

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This paper describes a new modeling framework for microscopic to reservoir-scale simulations of hydraulic fracturing and production. The approach builds upon a fusion of two existing high-performance simulators for reservoir-scale behavior: the GEOS code for hydromechanical evolution during stimulation and the TOUGH+ code for multi-phase flow during production. The reservoir-scale simulations are informed by experimental and modeling studies at the laboratory scale to incorporate important micro-scale mechanical processes and chemical reactions occurring within the fractures, the shale matrix, and at the fracture-fluid interfaces. These processes include, among others, changes in stimulated fracture permeability as a result of proppant behavior rearrangement or embedment, or mineral scale precipitation within pores and microfractures, at µm to cm scales. In our new modeling framework, such micro-scale testing and modeling provides upscaled hydromechanical parameters for the reservoir scale models. We are currently testing the new modeling framework using field data and core samples from the Hydraulic Fracturing Field Test (HFTS), a recent field-based joint research experiment with intense monitoring of hydraulic fracturing and shale production in the Wolfcamp Formation in the Permian Basin (USA). Below, we present our approach coupling the reservoir simulators GEOS and TOUGH+ informed by upscaled parameters from micro-scale experiments and modeling. We provide a brief overview of the HFTS and the available field data, and then discuss the ongoing application of our new workflow to the HFTS data set.

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“…Note that in these simulations, no attempt is made to compute the relative permeability to scCO 2 (super-critical carbon dioxide) in two-phase flow in the fracture system, neither is an attempt made to model miscibility effects between scCO 2 and resident brine [21]. Therefore, no accompanying geochemical interactions between the flowing CO 2 and brine mixture with the different lithologies are taken care of [22].…”

Section: Evaluation Of Permeability Increase Along the Faultmentioning

confidence: 99%

Simulation of Stress Hysteresis Effect on Permeability Increase Risk Along A Fault

Rongved

Cerasi

2019

Energies

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CO2 sequestration projects will in the coming years include both aquifer and depleted oil and gas field sites, with different stress paths and history. Stress changes and stress concentration effects on faults will have to be readily assessed, potentially endangering shallower permeable formations. Usually, a fault is modeled as a singularity with shear strength or friction properties, and simulations are run to determine whether the fault is reactivated through shear failure. In this paper, we model a simple rectilinear fault as a finite surface with lowered mechanical properties compared to elsewhere in the domain, which represents a fractured zone alongside the fault core. SINTEF’s Modified Discrete Element code is used coupled to the flow simulator TOUGH2, to model the fracture initiation and propagation, monitoring the permeability increase along the fault. A simplified scenario is simulated, with a sandstone storage reservoir bounded by a fault, penetrating a shale caprock to a shallower sandstone layer. The storage site either undergoes depletion before CO2 injection or has its pore pressure increased to simulate the case of aquifer storage. Results show that during depletion, shear stresses may develop such that fractures propagate alongside the fault to the upper aquifer. However, for the mirror fault orientation with regards to verticality, no such fractures develop. These results are reversed for the aquifer storage case.

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Assessment of two-phase flow on the chemical alteration and sealing of leakage pathways in cemented wellbores

Cited by 22 publications

References 29 publications

Relative permeability for water and gas through fractures in cement

Relative permeability for water and gas through fractures in cement

A New Modeling Framework for Multi-Scale Simulation of Hydraulic Fracturing and Production from Unconventional Reservoirs

Simulation of Stress Hysteresis Effect on Permeability Increase Risk Along A Fault

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