Numerical investigation of wellbore temperature and pressure fields in CO2 fracturing

Lyu, Xinrun; Zhang, Shicheng; Ma, Xinfang; Wang, Fei; Mou, Jianye

doi:10.1016/j.applthermaleng.2017.12.095

Cited by 20 publications

(5 citation statements)

References 29 publications

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“…In the 1D + 1D transient fully coupled model, the continuity, momentum, and energy equations are coupled together through the interaction among pressure, temperature, and CO 2 physical properties to form a transient nonlinear system, which requires an iteration solving method. The Span-Wagner EoS [44], Fenghour model [45] and Vesovic model [46] are used here as the physical properties models, which are proven to be highly accurate [10,11]. Two iteration loops are set up during the solution process: the pressurespeed and temperature iterations.…”

Section: Solving Methodsmentioning

confidence: 99%

“…CO 2 fracturing can simultaneously avoid the above disadvantages and achieve the effects of carbon sequestration (CCS) [4,5] and gas recovery enhancement (EGR) [6][7][8][9], which is a potential alternative technology to the slick-water fracturing. Unlike the water-based fracturing fluid, the physical properties of CO 2 vary significantly with temperature and pressure [10,11], which can affect the sand-carrying capacity and the performance of the stimulation. Additionally, it is impractical to modify the CO 2 temperature during the fracturing process based on the temperature monitor data because of the expense and time consumed.…”

Section: Introductionmentioning

confidence: 99%

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Numerical Investigation on Wellbore Temperature Prediction during the CO2 Fracturing in Horizontal Wells

Lyu

Zhang

et al. 2021

Sustainability

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A novel model is established to predict the temperature field in the horizontal wellbore during CO2 fracturing. The pressure work and viscous dissipation are considered, and the transient energy, mass and momentum equations as well as the CO2 physical properties are solved fully coupled. The model passes the convergence test and is verified through a comparison using the COMSOL software. Then, a sensitivity analysis is performed to study the effects of the treating parameters. Results illustrate that the relationship between the injection rate and the stable bottom-hole temperature (hereinafter referred to as BHT) is non-monotonic, which is different from the hydraulic fracturing. The existence of the horizontal section will increase the BHT at 2 m3/min condition but reduce the BHT at 10 m3/min condition. The problem of high wellbore friction can be alleviated through tube size enhancement, and the ultimate injection rate allowed increased from 2.7 m3/min to 29.6 m3/min when the tube diameter increased from 50.3 mm to 100.3 mm. Additionally, the open-hole completion method of the horizontal section can increase the BHT to 2.7 °C but reduce the near formation temperature to 24.5 °C compared with the casing completion method.

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Section: Solving Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Numerical Investigation on Wellbore Temperature Prediction during the CO2 Fracturing in Horizontal Wells

Lyu

Zhang

et al. 2021

Sustainability

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“…The Span-Wagner state equation was used in their models to calculate CO 2 physical properties. Yi et al [21], Guo and Zeng [22], Gong et al [23], Wang et al [24], Lyu et al [25,26], Li et al [27], and Yang et al [28] proposed transient models to simulate CO 2 temperature and discussed the sensitivity of some key factors.…”

Section: Introductionmentioning

confidence: 99%

Modeling Transient Flow in CO2 Injection Wells by Considering the Phase Change

Wan¹,

Wang

Hou

et al. 2021

Processes

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A transient model to simulate the temperature and pressure in CO2 injection wells is proposed and solved using the finite difference method. The model couples the variability of CO2 properties and conservation laws. The maximum error between the simulated and measured results is 5.04%. The case study shows that the phase state is primarily controlled by the wellbore temperature. Increasing the injection temperature or decreasing the injection rate contributes to obtaining the supercritical state. The variability of density can be ignored when the injection rate is low, but for a high injection rate, ignoring this may cause considerable errors in pressure profiles.

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“…The main finding was that the Joule–Thomson effect could be ignored in engineering applications. Lyu et al 18 . developed a CO 2 fracturing wellbore temperature and pressure model coupled with flow and heat transfer, which predicted a strong effect of viscous dissipation in annulus on wellbore temperature and pressure at large displacement injection and a negligible effect of natural convection heat transfer.…”

Section: Introductionmentioning

confidence: 99%

“…Noteworthy is that the above models were based on tubing injection. However, the tubing and annulus co‐injection method is often used in the process of SC‐CO 2 fracturing to reduce wellbore friction 4–5,18 . The main difference of mathematical model between tubing injection and co‐injection is the heat transfer mode in the annulus.…”

Section: Introductionmentioning

confidence: 99%

Transient temperature‐pressure field model of supercritical CO₂ fracturing wellbore with tubing and annulus co‐injection

Luo

Zhao

et al. 2021

Greenhouse Gases

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The physical parameters of supercritical carbon dioxide (SC‐CO2) fracturing fluid are sensitive to temperature and pressure. Accurate prediction of wellbore temperature and pressure during injection is critical for the fracturing efficiency. In this paper, a transient pressure‐field model of SC‐CO2 fracturing wellbore with tubing and annulus co‐injection was established, which was adjusted to consider the Joule–Thomson effect, axial heat conduction, expansion/compression heat, and friction heat. The model predicted the variation patterns of wellbore temperature and pressure, comparing them with those under tubing injection conditions. Effects of tubing‐annulus injection ratios and endothermic mode on bottom‐hole temperature (BHT) and wellhead pressure (WHP) were analyzed in detail. Compared with pure tubing injection, co‐injection provided higher BHT and lower WHP. At constant BHP, WHP dropped with time in the processes of tubing injection or co‐injection, while the former provided a larger WHP drop. With an increase in tubing injection ratio, the difference between tubing and annulus BHT values slightly grew. When the tubing and annulus injection displacements were allocated according to their cross‐sectional area ratio, their WHP was minimal. If CO2 was assumed to absorb all the friction heat, overestimation of BHT and WHP would be observed, which was more pronounced at larger injection displacements. This study's findings are considered instrumental in the design optimization and field application of SC‐CO2 fracturing in unconventional reservoirs. © 2021 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Numerical investigation of wellbore temperature and pressure fields in CO2 fracturing

Cited by 20 publications

References 29 publications

Numerical Investigation on Wellbore Temperature Prediction during the CO2 Fracturing in Horizontal Wells

Numerical Investigation on Wellbore Temperature Prediction during the CO2 Fracturing in Horizontal Wells

Modeling Transient Flow in CO2 Injection Wells by Considering the Phase Change

Transient temperature‐pressure field model of supercritical CO₂ fracturing wellbore with tubing and annulus co‐injection

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Numerical investigation of wellbore temperature and pressure fields in CO2 fracturing

Cited by 20 publications

References 29 publications

Numerical Investigation on Wellbore Temperature Prediction during the CO2 Fracturing in Horizontal Wells

Numerical Investigation on Wellbore Temperature Prediction during the CO2 Fracturing in Horizontal Wells

Modeling Transient Flow in CO2 Injection Wells by Considering the Phase Change

Transient temperature‐pressure field model of supercritical CO2 fracturing wellbore with tubing and annulus co‐injection

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Transient temperature‐pressure field model of supercritical CO₂ fracturing wellbore with tubing and annulus co‐injection