Alteration of Bakken reservoir rock during CO2-based fracturing—An autoclave reaction experiment

Lu, Jiemin; Nicot, Jean‐Philippe; Mickler, P. J.; Ribeiro, Lionel H.; Darvari, Roxana

doi:10.1016/j.juogr.2016.03.002

Cited by 40 publications

(26 citation statements)

References 39 publications

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“…However, the changes of elements between subcritical CO 2 and supercritical CO 2 saturated samples are not obvious under the brine circumstance. These results are in consistency with the results from Qin et al, 19 Wang et al 27 and Lu et al 34 However, the percentages of minerals alteration are not in the same, which may be related to the heterogeneous of the rock materials, such as different mineral compositions. In general, the intensity of the reaction between uids and rocks may be related to the internal and external factors such as types of samples, reaction temperature, carbon dioxide pressure and phase states etc.…”

Section: Laboratory Instrumentssupporting

confidence: 91%

“…41 However, reaction between different saturation uids and minerals of shale is dependent on pH value, 42 CO 2 pressure, 20 salinity of the saturation condition, 18 reservoir temperature, 12 saturation time 43 and the circumstance with or without water. 34 In general, crystal water exists in shales and cannot be evaporated easily, these crystal water can combine with CO 2 and form an acidic environment, then leads to the dissolution of minerals, which resulting in reduction of elements in shale aer CO 2 saturation. Besides this, the difference in minerals reduction between subcritical CO 2 and supercritical CO 2 saturated samples is due to the unique extraction effect of supercritical CO 2 , which can extract organic matters in shale, then further causing elemental changes in shale.…”

Section: Discussionmentioning

confidence: 99%

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Mechanical behaviour of Longmaxi black shale saturated with different fluids: an experimental study

et al. 2017

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The fluid-shale interaction during carbon dioxide (CO 2 ) enhanced shale gas recovery processes may have significant influences on the mechanical behaviour of shale, and it is also of great importance for the longterm safety of CO 2 geological sequestration in shale formations. In this work, shale samples from the Longmaxi formation in the Sichuan basin were used to investigate the mechanical properties and the acoustic emission (AE) behaviour of shale upon saturation with different fluids (water, brine, and CO 2 -brine mixture with different CO 2 phase states) at 45 C. X-ray fluorescence (XRF) analysis results show that major element alterations occur after shale is treated with supercritical CO 2 -brine and subcritical CO 2 -brine, the element content of Ca, K and Al in supercritical CO 2 -brine saturated shale was decreased by 16.7%, 5.8% and 6.3%, respectively. Field emission scanning electron microscopy (FESEM) analysis results indicate that significant surface structural changes occur in shale after saturated with CO 2 and brine. Furthermore, the uniaxial compressive strength (UCS) and elastic modulus (E) of shale with different fluid saturation were decreased. Supercritical CO 2 cause a greater reduction of UCS and E compared to subcritical CO 2 due to its higher adsorption capability and larger CO 2 adsorption induced swelling. The maximum reduction in UCS and E of shale was observed in the case of CO 2 -brine saturated samples, and the influence of the CO 2 phase on the mechanical behaviour of shale under brine conditions is not negligible. The fracture propagation pattern changes in shale after fluid saturation are also explained by the AE analysis.

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Section: Laboratory Instrumentssupporting

confidence: 91%

Section: Discussionmentioning

confidence: 99%

Mechanical behaviour of Longmaxi black shale saturated with different fluids: an experimental study

et al. 2017

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“…Other areas that have recently caught interest due to their importance in understanding the fluid behavior in shale or increasing the productivity are (i) spontaneous imbibition in shales [218,[223][224][225], (ii) thermodynamic phase behavior of fluids inside shales as a function of pressure drawdown during production [226][227][228][229][230][231], (iii) alternate fracturing fluids [232][233][234][235][236][237] for better reservoir stimulation and to avoid water usage, and (iv) enhancing oil recovery by injection of fluids [238][239][240].…”

Section: Literature Reviewmentioning

confidence: 99%

Critical Review of Fluid Flow Physics at Micro‐ to Nano‐scale Porous Media Applications in the Energy Sector

Singh

Myong

2018

Advances in Materials Science and Engineering

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While there is a consensus in the literature that embracing nanodevices and nanomaterials helps in improving the efficiency and performance, the reason for the better performance is mostly subscribed to the nanosized material/structure of the system without sufficiently acknowledging the role of fluid flow mechanisms in these systems. This is evident from the literature review of fluid flow modeling in various energy-related applications, which reveals that the fundamental understanding of fluid transport at micro- and nanoscale is not adequately adapted in models. Incomplete or insufficient physics for the fluid flow can lead to untapped potential of these applications that can be used to increase their performance. This paper reviews the current state of research for the physics of gas and liquid flow at micro- and nanoscale and identified critical gaps to improve fluid flow modeling in four different applications related to the energy sector. The review for gas flow focuses on fundamentals of gas flow at rarefied conditions, the velocity slip, and temperature jump conditions. The review for liquid flow provides fundamental flow regimes of liquid flow, and liquid slip models as a function of key modeling parameters. The four porous media applications from energy sector considered in this review are (i) electrokinetic energy conversion devices, (ii) membrane-based water desalination through reverse osmosis, (iii) shale reservoirs, and (iv) hydrogen storage, respectively. Review of fluid flow modeling literature from these applications reveals that further improvements can be made by (i) modeling slip length as a function of key parameters, (ii) coupling the dependency of wettability and slip, (iii) using a reservoir-on-chip approach that can enable capturing the subcontinuum effects contributing to fluid flow in shale reservoirs, and (iv) including Knudsen diffusion and slip in the governing equations of hydrogen gas storage.

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“…As indicated by relevant studies on CO 2 flooding for enhanced oil recovery (EOR), the injected CO 2 is involved in strong chemical reactions with the formation brine, and the generated precipitates block the rock pore throats and reduce the porosity and the permeability of the reservoir. This leads to significant changes in the physical properties of the formation rocks (Fischer et al, 2010;Zhao et al, 2010;Liu et al, 2012;Yu et al, 2012;Alam et al, 2014;Lu et al, 2016) and thereby lowers the oil recovery rate.…”

Section: Introductionmentioning

confidence: 99%

Mathematical Characterization of Inorganic Salt Precipitation From the Reaction of CO2 With Formation Brine and Its Application

Zhou

Zhang

et al. 2020

Front. Energy Res.

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In the process of CO 2 enhanced oil recovery (CO 2-EOR), CO 2 interacts with formation brine containing high concentrations of scale-forming ions to produce inorganic salt precipitation, which blocks the rock pore throats, changes the characteristics of the reservoir, and thereby reduces the oil recovery rate. In this study, a series of experiments on the static reaction of CO 2-formation brine was conducted. The amounts of precipitation formed from the interaction of CO 2-formation brine under various conditions were tested. Using the PHREEQC software, the mathematical characterization formulas between the precipitation amount and various environmental factors (e.g., temperature, pressure difference, scale-forming ion concentration, and pH) were established. On this basis, a numerical simulation model of CO 2 flooding in a typical area of oil field C was established. The distribution of inorganic salt precipitation during continuous gas flooding was predicted, and the effect of inorganic salt precipitation on oil field recovery was analyzed.

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Alteration of Bakken reservoir rock during CO2-based fracturing—An autoclave reaction experiment

Cited by 40 publications

References 39 publications

Mechanical behaviour of Longmaxi black shale saturated with different fluids: an experimental study

Mechanical behaviour of Longmaxi black shale saturated with different fluids: an experimental study

Critical Review of Fluid Flow Physics at Micro‐ to Nano‐scale Porous Media Applications in the Energy Sector

Mathematical Characterization of Inorganic Salt Precipitation From the Reaction of CO2 With Formation Brine and Its Application

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