Experimental determination of dynamic pore-throat structure characteristics in a tight gas sandstone formation with consideration of effective stress

Liu, Guangfeng; Yin, Handong; Lan, Yifei; Fei, Shi-xiang; Yang, Daoyong

doi:10.1016/j.marpetgeo.2019.104170

Cited by 28 publications

(17 citation statements)

References 46 publications

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“…The comparison between calculated results and experimental results are seen in Figures 2 and 3 and Tables 3 and 4. Figure 2 shows the comparison between initial permeability calculated by the proposed model and that found in experiments in the works of Liu et al [48] and Zhong et al [49]. From Figure 2, we can see that the initial permeability is consistent with that found in experiments in the works of Liu et al [48] and Zhong et al [49].…”

Section: Fractal Permeability Model Verificationsupporting

confidence: 78%

“…In this section, we present verifications of the fractal permeability model by comparing it with published experimental results and models. Liu et al [48] and Zhong et al [49] conducted permeability stress sensitivity evaluation experiments of tight reservoirs by means of core flooding, thin-section analysis, and the nuclear magnetic resonance/high-pressure mercury intrusion. The core's parameters in the works of Liu et al [48] and Zhong et al [49] are given in Table 1.…”

Section: Fractal Permeability Model Verificationmentioning

confidence: 99%

“…Liu et al [48] and Zhong et al [49] conducted permeability stress sensitivity evaluation experiments of tight reservoirs by means of core flooding, thin-section analysis, and the nuclear magnetic resonance/high-pressure mercury intrusion. The core's parameters in the works of Liu et al [48] and Zhong et al [49] are given in Table 1. By combining the data in Table 1 and Equations ( 3) and ( 8)-( 10), we could obtain the pore fractal dimension and the tortuosity fractal dimension seen in Table 2.…”

Section: Fractal Permeability Model Verificationmentioning

confidence: 99%

See 2 more Smart Citations

A Fractal Permeability Model of Tight Oil Reservoirs Considering the Effects of Multiple Factors

Cui

Yang

et al. 2022

Fractal Fract

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The prediction of permeability and the evaluation of tight oil reservoirs are very important to extract tight oil resources. Tight oil reservoirs contain enormous micro/nanopores, in which the fluid flow exhibits micro/nanoscale flow and has a slip length. Furthermore, the porous size distribution (PSD), stress sensitivity, irreducible water, and pore wall effect must also be taken into consideration when conducting the prediction and evaluation of tight oil permeability. Currently, few studies on the permeability model of tight oil reservoirs have simultaneously taken the above factors into consideration, resulting in low reliability of the published models. To fill this gap, a fractal permeability model of tight oil reservoirs based on fractal geometry theory, the Hagen–Poiseuille equation (H–P equation), and Darcy’s formula is proposed. Many factors, including the slip length, PSD, stress sensitivity, irreducible water, and pore wall effect, were coupled into the proposed model, which was verified through comparison with published experiments and models, and a sensitivity analysis is presented. From the work, it can be concluded that a decrease in the porous fractal dimension indicates an increase in the number of small pores, thus decreasing the permeability. Similarly, a large tortuous fractal dimension represents a complex flow channel, which results in a decrease in permeability. A decrease in irreducible water or an increase in slip length results in an increase in flow space, which increases permeability. The permeability decreases with an increase in effective stress; moreover, when the mechanical properties of rock (elastic modulus and Poisson’s ratio) increase, the decreasing rate of permeability with effective stress is reduced.

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Section: Fractal Permeability Model Verificationsupporting

confidence: 78%

Section: Fractal Permeability Model Verificationmentioning

confidence: 99%

Section: Fractal Permeability Model Verificationmentioning

confidence: 99%

See 1 more Smart Citation

A Fractal Permeability Model of Tight Oil Reservoirs Considering the Effects of Multiple Factors

Cui

Yang

et al. 2022

Fractal Fract

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“…20 And Cao and Lei 21 thought the curve changed in stages. Liu et al 22,23 studied the effect of particle composition, grain size, clay minerals, and pore and throat types on stress sensitivity with electron microscopy and X-ray diffraction techniques.…”

Section: Introductionmentioning

confidence: 99%

Experimental study on stress sensitivity of high‐temperature and high‐pressure sandstone gas reservoirs in Yingqiong Basin

Yi-long

et al. 2020

Energy Science & Engineering

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“…As an important and unconventional clean fossil fuel, tight oil is expected to play an increasingly important role in meeting the energy demand (Song et al, 2015;Yang et al, 2015a;Song and Yang, 2017;Wang M. et al, 2018;Amjed et al, 2019;Jiang et al, 2020a). Owing to the advancement of drilling horizontal wells with multistage hydraulic fractures (HFs), tight oil reservoirs have been exploited commercially though the flow behavior is quite different from those of the conventional reservoirs due to the extremely low permeability (Miller et al, 2008;Meyer and Bazan, 2011;Liu et al, 2018b;Liu et al, 2020a;Liu et al, 2020b. To reduce operational costs and mitigate the negative environmental impact, multi-well pad schemes have proven to be more effective for exploiting tight oil/gas reservoirs with and without natural fractures (NFs) (Manchanda and Sharma, 2013;Meng et al, 2017;Xiao et al, 2018;Jiang et al, 2020b;Jiang et al, 2020c); however, multi-well pressure interference under multiwell pad schemes severely distorts the flow patterns.…”

Section: Introductionmentioning

confidence: 99%

Effect of Stress-Sensitive Fracture Conductivity on Transient Pressure Behavior for a Multi-Well Pad With Multistage Fractures in a Naturally Fractured Tight Reservoir

Meng

Tan

et al. 2020

Front. Energy Res.

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This paper presents a semianalytical solution for evaluating transient pressure behavior of a multi-well pad with multistage fractures in a naturally fractured tight reservoir by considering the stress-sensitive effect imposed by both natural and hydraulic fractures. More specifically, the model pertaining to matrix/natural fractures is considered as a dual-porosity continuum, while its analytical flow model can be obtained by use of a slab-source function in the Laplace domain. The hydraulic fracture model is solved by discretizing each fracture into small segments to describe the flow behavior, while stress sensitivity in both the natural fracture (NF) subsystem and hydraulic fracture (HF) subsystem has been taken into account. To validate the newly developed semianalytical model, its solution has been obtained and compared with those of a commercial numerical simulator. By generating the type curves, there may exhibit eight flow regimes: pure wellbore storage, skin effect transition flow, linear flow regime within HFs, early radial flow, biradial flow, transition flow, pseudo-steady diffusion, and the late-time pseudo-radial flow. Furthermore, late-time flow regimes are found to be significantly distorted by the multi-well pressure interference. The smaller the well-rate ratio is, the more distorted the pressure and pressure derivative curves will be. In addition, well spacing and fracture length are found to dominate the flow behavior when multi-well pressure interference occurs. As the well spacing is decreased, the fracture length is increased, and thus occurrence of multi-well pressure interference is initiated earlier. Permeability moduli of NFs and HFs impose no impact on the multi-well pressure interference; however, it can distort flow regimes, leading to a severe distortion of pressure and pressure derivative curves. Similarly, the effect of HF permeability modulus on the flow in a hydraulic fracture, the minimum fracture conductivity is another key factor affecting the “hump” on the pressure curve. As the crossflow coefficient is increased, flow exchange between matrix and NFs is increased. With an increase in the storage ratio, flow exchange lasts longer and the second “dip” on the pressure curve becomes deeper.

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Experimental determination of dynamic pore-throat structure characteristics in a tight gas sandstone formation with consideration of effective stress

Cited by 28 publications

References 46 publications

A Fractal Permeability Model of Tight Oil Reservoirs Considering the Effects of Multiple Factors

A Fractal Permeability Model of Tight Oil Reservoirs Considering the Effects of Multiple Factors

Experimental study on stress sensitivity of high‐temperature and high‐pressure sandstone gas reservoirs in Yingqiong Basin

Effect of Stress-Sensitive Fracture Conductivity on Transient Pressure Behavior for a Multi-Well Pad With Multistage Fractures in a Naturally Fractured Tight Reservoir

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