Pressure and rate transient modeling of multi fractured horizontal wells in shale gas condensate reservoirs

Dahim, Sadegh; Taghavinejad, Amin; Razghandi, Milad; Rigi, Hamed Rahimi; Moeini, Kianoosh; Jamshidi, Saeid; Sharifi, Mohammad

doi:10.1016/j.petrol.2019.106566

Cited by 25 publications

(13 citation statements)

References 40 publications

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“…Thus, it shows that stressdependent permeability model causes almost 9%, 10%, and 16% decrease in average cumulative CO2 injection to the reservoir, respectively, in cases of reservoir permeabilities 0.1-, 1-, and 10-time base reservoir permeability. Reduction percentage of with/without stress dependence, % 9 10 16…”

Section: Resultsmentioning

confidence: 99%

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CO2 Capture and Storage Performance Simulation in Depleted Shale Gas Reservoirs as Sustainable Carbon Resources

Shirbazo¹,

Taghavinejad²,

Bagheri³

2021

JCM

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Underground carbon capture and sequestration (CCS) is a useful technique for separating this kind of greenhouse gas from atmosphere and store it under the surface of the earth. As a matter of fact, CO2 can be transferred to underground petroleum reservoirs which are initially contained oil and gas, or aquifers which are initially saturated with water. This kind of CCS takes place using an injection well which is drilled from surface to the target underground bedrocks. A shale gas reservoir (SGR) is a type of petroleum gas reservoir in which natural gas is stored in ultra-tight pores of the shale rock. In this study, a flow modeling analysis in SGR with a multi-stage fractured horizontal well (MSFHW) is conducted using numerical simulation. In this shale layer, a horizontal well is drilled and several transverse hydraulic fractures, for increasing the flow efficiency between the well and porous medium, are created. The studied SGR – a depleted reservoir acting as a macroscopic sustainable material for the CCS – is initially saturated with methane gas, and carbon dioxide is required to be injected for the storage. The most outstanding results of this study is about sensitivity analyses for SGR permeability with different conditions of gas adsorption and stress-dependent permeability which are from important features of SGRs. The results show a minor reduction in cumulative gas injection due to the effect of stress-dependent permeability in all measures for reservoir permeabilities. Furthermore, gas sorption shows a considerable positive correlation with CO2 storage response in high-permeability SGR and a minor increasing effect on SGRs with lower permeability values.

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Section: Resultsmentioning

confidence: 99%

“…Schematic view of naturally fractured SGR rock comprising matrix and fractures containing free and adsorbed gas (visualized from[9])…”

mentioning

confidence: 99%

CO2 Capture and Storage Performance Simulation in Depleted Shale Gas Reservoirs as Sustainable Carbon Resources

Shirbazo¹,

Taghavinejad²,

Bagheri³

2021

JCM

Self Cite

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“…Recent activities in shale gas exploration have shown that shale gas will be the most significant portion of the future global energy supply as traditional reserves begin to decline 1 – 4 . Improved reservoir conditions, advancement in horizontal drilling, and hydraulic fracking technology make shale gas extraction commercially feasible and successful 5 , 6 . However, in contrast to traditional reservoirs, shale gas reservoirs appear to be more costly to develop and require specific technology for gas to be cost-effectively extracted due to the extremely low matrix permeability and porosity of shale 7 , 8 .…”

Section: Introductionmentioning

confidence: 99%

Prediction of gas production rate from shale gas reservoirs using a micro–macro analysis

Lin

Zhang

et al. 2023

Sci Rep

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Shale gas has become one of the important contributors to the global energy supply. The declining pattern of the gas production rate with time from an unconventional gas reservoir is due to the depletion of shale gas stored in the nanovoids of the shale formation. However, there are only limited ways to predict the variation of the gas production rate with time from an unconventional gas reservoir. This is due to the multiple transport mechanisms of gas in nano-scale pores and changes in shale gas permeability with pressures in nano-scale pores, which is impacted by the pore structure of the shale. In this study, the permeability-pressure (K-p) relationship for different shales (Eagle Ford, Haynesville, Longmaxi and Opalinus) were determined using an equivalent anisotropic pore network model (PNM). This PNM has REV-scale shale gas flow in randomly generated nanovoids and their connection in the shale matrix, and the multiphase flow of shale gas including viscous flow, slip flow and Knudsen diffusion. These predicted K-p correlations were then used in a finite element model (FEM) to predict the variation of the gas production rate with time (flux-time curves) at the macroscale. The simulation results show that the flux-time curves can be simplified to two linear segments in logarithmic coordinates, which are influenced by the fracture length and initial gas pressure. The predicted results using the PNM-FEM were validated by comparing them with the reported field test data. The method described in this study can be used to upscale the gas transport process from micro- to macroscale, which can provide a predictive tool for the gas production in shales.

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“…Currently, shale gas production mostly adopts horizontal wells (Wenbin et al, 2009;Nobakht et al, 2013;Yuan et al, 2016), with large-scale hydraulic fracturing (Guo et al, 2018), staged fracturing (Williams-Kovacs and Clarkson, 2016) and repeated fracturing (Rahman and Rahman, 2010) as the major completion strategies through which the main purpose is to connect the natural fractures using secondary fracturing techniques (Rammay and Awotunde, 2016) in order to obtain a larger discharge area and increase the productivity of the shale gas wells (Kulga et al, 2017;Dahim et al, 2020). However, during the fracturing process, the cement sheath will be subjected to multiple changes in temperature and higher static loads, cyclic loads, and shock loads, and its integrity will be compromised (Kuanhai et al, 2020;Wang et al, 2021;Xi et al, 2021;Zhang et al, 2022).…”

Section: Introductionmentioning

confidence: 99%

Study on mineral composition design and mechanical properties improvement mechanism of high ferrite oil well cement

Fan¹,

Huang

Yang³

et al. 2022

Front. Mater.

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In shale gas production, secondary fracturing technology is often used to improve shale gas production capacity. However, the toughness of cement stone used in Class G oil wells is poor, and the cement sheath is easily damaged by impact load during fracturing, resulting in cement sheath sealing failure. To solve this problem, this paper proposes to improve the strength and toughness of cement paste by optimizing the mineral composition of Class G oil well cement. The cement clinker is burned in the laboratory, and the microstructure differences of clinker under different mineral composition ratios are observed by reflection microscope. The mechanical properties of cement paste before and after optimization are analyzed, and the best mineral composition ratio is obtained. The petrographic structure, hydration products and microstructure of high ferrite oil well cement were analyzed by petrography, X-ray diffraction analysis (XRD), thermal analysis (TG/DTG) and scanning electron microscopy (SEM), analyzed and explored its enhancement mechanism. The results show that the best mineral composition mass ratios of C3S, C2S, C3A and C4AF in high ferrite oil well cement are 58.34%, 16.39%, 1.51% and 17.94% respectively. Compared with grade G oil well cement, the compressive strength and flexural strength of curing 28 days are increased by 14.11% and 19.51%, respectively. The stress-strain results show that high ferrite oil well cement has better toughness. The petrographic results show that the lithofacies structure of high ferrite oil well cement is evenly distributed and the particle size is moderate; XRD, TG/DTG and microanalysis show that there are more hydration products in high ferrite oil well cement, the hydration products are closely combined, the hydration degree is more thorough, and the structure of cement paste is more compact. High ferrite oil well cement has the advantages of high strength and good toughness, which has potential advantages for shale gas cementing.

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Pressure and rate transient modeling of multi fractured horizontal wells in shale gas condensate reservoirs

Cited by 25 publications

References 40 publications

CO2 Capture and Storage Performance Simulation in Depleted Shale Gas Reservoirs as Sustainable Carbon Resources

CO2 Capture and Storage Performance Simulation in Depleted Shale Gas Reservoirs as Sustainable Carbon Resources

Prediction of gas production rate from shale gas reservoirs using a micro–macro analysis

Study on mineral composition design and mechanical properties improvement mechanism of high ferrite oil well cement

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