Permeability stress-sensitivity in 4D flow-geomechanical coupling of Shouyang CBM reservoir, Qinshui Basin, China

Zhu, Hehua; Tang, Xuanhe; Liu, Qingyou; Liu, Shujie; Zhang, Binhai; Jiang, Shu; McLennan, John

doi:10.1016/j.fuel.2018.05.078

Cited by 38 publications

(17 citation statements)

References 31 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…For example, when the number of NF lines increases sharply, the calculation time for solving the process of complex fracture extension under the condition of coupled fluid and stress is prone to nonconvergence and exponential increase in the calculation time. 27,28 Therefore, most of the current studies on complex fracture network can only be applied to mechanical research, and it is difficult to apply to engineering. In addition, when fluid flows in HF and NF, the fluid filtration is generally treated as the filtration loss is zero or the filtration loss is calculated through the filtration coefficient.…”

Section: And Olson and Wumentioning

confidence: 99%

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Wang

Zhao

et al. 2020

Energy Science & Engineering

View full text Add to dashboard Cite

The study on induced stress of hydraulic fracturing is an important part of hydraulic fracturing design, temporary plugging and steering fracturing design, and completion design in oil and gas development. Based on fracture continuum method (FCM), cohesive unit method, and finite volume method (FVM), the propagation behavior of multiple hydraulic fractures (HFs) in fractured‐porous media reservoir is simulated from the perspective of fluid and geological stress coupling. The influence of natural fractures (NFs) on stress distribution and stress inversion sensitive factors are studied. NFs in the model are equivalent to physical models controlled by tension and shear bonds. The proposed model can deal with any number of NFs, which greatly improves the computational efficiency of the model. Then PKN analytic solution and Abaqus software results were used to verify the correctness of our model. The results show that the NF will make the reservoir stress show strong heterogeneity after fracturing, and the prominent feature is the regional stress mutation. The sudden change of stress shows the sudden increase or decrease in stress; with the increase in the initial stress difference, the stress inversion becomes more difficult. When the stress difference exceeds 3 MPa, the stress inversion area is almost 0. The stress interference increases with the decrease in cluster spacing. The stress inversion region between HFs decreases, while the external stress inversion region increases; Biot coefficient has great influence on stress and stress inversion. With the decrease in Biot coefficient, stress inversion region will decrease obviously. When the Biot coefficient is 0.4, there is no stress inversion area in the whole reservoir. Poisson's ratio has little influence on stress inversion. When Poisson's ratio changes between 0.1 and 0.3, the change range of stress is within 1 MPa, and the stress inversion area is almost unchanged. Our results can be helpful for understanding the stress distribution after hydraulic fracturing in fractured‐porous media.

show abstract

Section: And Olson and Wumentioning

confidence: 99%

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Wang

Zhao

et al. 2020

Energy Science & Engineering

View full text Add to dashboard Cite

show abstract

“…Based on the fractal theory, prediction models for the permeability and porosity of porous media were proposed. [29][30][31][32][33][34][35] A new stress-sensitive permeability analysis model was proposed by Zhu et al 36 And Zhu et al 37 thought the permeability performance under reservoir condition was divided into two stages through a semi-analytical model. The relationship between stress and permeability was studied through numerical simulation by Zhang et al 38 and Zhao et al 39,40 In addition, some scholars [41][42][43] have studied the changing of permeability in the production process.…”

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

View full text Add to dashboard Cite

show abstract

“…Cai et al [21] improved the foaming volume of foamed drilling fluid up to 50% by using chemically treated nano-SiO 2 dispersions. By studying the foam's properties, Su et al [22] found that the appropriate temperature was 40-100 • C and that the foaming performance of hard foam could maintain within 120 • C. Fractures and minerals affect the permeability of CBM reservoirs [23][24][25][26][27][28]. Cui et al [29] combined FESEM with X-ray mu-CT together with EDS to quantify the mineral and fracture characteristics.…”

Section: Introductionmentioning

confidence: 99%

Development and Performance Evaluation of Solid-Free Drilling Fluid for CBM Reservoir Drilling in Central Hunan

et al. 2020

View full text Add to dashboard Cite

Solid-free drilling fluid is a matter of cardinal significance in the course of Coal bed Methane (CBM) reservoir drilling. This study evaluated the performance of solid-free CBM drilling fluid in central Hunan. Three types of surfactants, namely TX-10 (nonionic), HSB1618 (zwitterionic) and penetrant T (anionic), were added in basic fluid at various concentrations of 0.05, 0.10 and 0.15% (m/m). This study comprised of drilling fluid rheology, sample mineral analysis, sample nuclear magnetic resonance (NMR) scanning, sample wettability, and sample surface micro characteristics tests. The results show that TX-10 and HSB1618 enhance the rheological properties of drilling fluid, such as yield point and gel strength. Penetrant T has opposite effect on it. It was found that the minimum American Petroleum Institute (API) filtration is only 0.3 mL. This study adopted a new method using laser particle size analyzer to evaluate suspension performance. Based on the surface micro characteristics of the sample and the NMR scanning tests, it is found that the residual amount of basic fluid + HSB1618 in the sample is the smallest. The wettability modification curve indicates that three surfactants decrease the sample’s hydrophobicity. With the increase of surfactant concentration, all above parameters change regularly. The basic fluid + 0.10% HSB1618 has the strongest hydrophobicity for sample at pH = 10. This study obtained a set of solid-free drilling fluid system, which provides better suspension capacity and large contact angle and reduces residue of drilling fluid in CBM reservoir. Ultimately, it can accelerate the desorption of coal gas and reduce damage to the reservoir.

show abstract

Permeability stress-sensitivity in 4D flow-geomechanical coupling of Shouyang CBM reservoir, Qinshui Basin, China

Cited by 38 publications

References 31 publications

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

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

Development and Performance Evaluation of Solid-Free Drilling Fluid for CBM Reservoir Drilling in Central Hunan

Contact Info

Product

Resources

About