Theoretical Analysis of the Mechanism of Fracture Network Propagation with Stimulated Reservoir Volume (SRV) Fracturing in Tight Oil Reservoirs

Su, Yuliang; Ren, Lan; Meng, Fankun; Xu, Chen

doi:10.1371/journal.pone.0125319

Cited by 12 publications

(2 citation statements)

References 28 publications

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“…The development of these reservoirs relies on a combination of multi-stage completions and hydraulic stimulation along horizontal wells that are typically one to two miles long. Stimulation processes generate dominant propped induced fractures with permeability several orders of magnitude higher than the rock matrix, which enables and accelerates hydrocarbon production [2].…”

Section: Introductionmentioning

confidence: 99%

The Effect of Hydraulic Fracture Geometry on Well Productivity in Shale Oil Plays with High Pore Pressure

et al. 2021

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We propose three idealized hydraulic fracture geometries (“fracture scenarios”) likely to occur in shale oil reservoirs characterized by high pore pressure and low differential in situ stresses. We integrate these geometries into a commercial reservoir simulator (CMG-IMEX) and examine their effect on reservoir fluids production. Our first, reference fracture scenario includes only vertical, planar hydraulic fractures. The second scenario has stimulated vertical natural fractures oriented perpendicularly to the vertical hydraulic fractures. The third fracture scenario has stimulated horizontal bedding planes intersecting the vertical hydraulic fractures. This last scenario may occur in mudrock plays characterized by high pore pressure and transitional strike-slip to reverse faulting stress regimes. We demonstrate that the vertical and planar fractures are an oversimplification of the hydraulic fracture geometry in anisotropic shale plays. They fail to represent the stimulated volume geometric complexity in the reservoir simulations and may confuse hydrocarbon production forecast. We also show that stimulating mechanically weak bedding planes harms hydrocarbon production, while stimulated natural fractures may enhance initial production. Our findings reveal that stimulated horizontal bedding planes might decrease the cumulative hydrocarbon production by as much as 20%, and the initial hydrocarbon production by about 50% compared with the reference scenario. We present unique reservoir simulations that enable practical assessment of the impact of varied hydraulic fracture configurations on hydrocarbon production and highlight the importance of constraining present-day in situ stress state and pore pressure conditions to obtain a realistic hydrocarbon production forecast.

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Section: Introductionmentioning

confidence: 99%

The Effect of Hydraulic Fracture Geometry on Well Productivity in Shale Oil Plays with High Pore Pressure

et al. 2021

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“…It makes full use of the formation bedding and natural fractures to produce a number of transverse and longitudinal artificial fractures which communicate with the natural fracture system away from the wellbore. It is intended to further expand the discharge area, rather than to control the expansion of natural fractures 6,7 . The volume fracturing technology will most likely communicate further natural fractures and form a larger seepage scope 8,9 .…”

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confidence: 99%

Impact Analysis of Multiple Parameters on Fracture formation during Volume Fracturing in Coalbed Methane Reservoirs

Jiang

Zhang

2017

Current Science

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Uniaxial and triaxial compression, Brazilian splitting and three-point bending tests have been carried out to determine the mechanical parameters of the coal reservoir in Jiaozuo coal mining district, Henan Province, China. Based on the experimental results and combined with the target reservoir geological characteristics, a 3D geological mechanical model has been established to analyse the hydraulic fracture propagation during volume fracturing using MEYER software. Effects of the modulus of coal rock, difference between horizontal principal stresses, fracturing fluid viscosity and fracturing fluid injection rate on the fracturing network geometry are studied. Results show that fracturing network development intensity in the coalbed methane (CBM) reservoir is determined both by the geological conditions and the hydraulic fracturing parameters. The intensity of fracturing in the CBM reservoir is positively related with the elastic modulus of the coal rock, and is inversely proportional to the difference between the two horizontal principal stresses. Increasing fluid viscosity reduces the fracturing area. Low injection rate is beneficial to improving hydraulic treatment areas when it is larger than that required to guarantee that the crack extends. The results can provide a case reference for optimization design of volume fracturing and productivity prediction analysis of CBM reservoirs.Keywords: Coalbed methane reservoir, fracture network, numerical simulation, volume fracturing.IN volume fracturing, the resulting fracture network geometry is mainly determined by the in situ stress and rock physical and mechanical properties (elastic modulus, Poisson ratio, tensile strength and fracture toughness). In addition, the fracturing implementation parameters (such as construction scale, capacity, viscosity and filtration of fracturing fluid, etc.) affect fracture geometry to a certain extent 1,2 . Coalbed methane (CBM) reservoirs contain a large number of pores 3 , which make the fracture geometry more complicated. The analysis of fracture network geometry can guide an efficient exploitation of CBM and be of significance on the later evaluation of fracturing effectiveness 4,5 . Volume fracturing as a new kind of fracturing technology is totally different from conventional hydraulic fracturing. It makes full use of the formation bedding and natural fractures to produce a number of transverse and longitudinal artificial fractures which communicate with the natural fracture system away from the wellbore. It is intended to further expand the discharge area, rather than to control the expansion of natural fractures 6,7 . The volume fracturing technology will most likely communicate further natural fractures and form a larger seepage scope 8,9 . It will exert the advantages of the natural fracture network to increase production and enhance matrix supply capacity. It will also improve the stimulation effect and have importance in unconventional reservoir recovery.Coal rock mechanics parameters are the prerequisites of CBM res...

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Progress of the research on productivity prediction methods for stimulated reservoir volume (SRV)-fractured horizontal wells in unconventional hydrocarbon reservoirs

Ren

Zhan

et al. 2019

Arab J Geosci

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Theoretical Analysis of the Mechanism of Fracture Network Propagation with Stimulated Reservoir Volume (SRV) Fracturing in Tight Oil Reservoirs

Cited by 12 publications

References 28 publications

The Effect of Hydraulic Fracture Geometry on Well Productivity in Shale Oil Plays with High Pore Pressure

The Effect of Hydraulic Fracture Geometry on Well Productivity in Shale Oil Plays with High Pore Pressure

Impact Analysis of Multiple Parameters on Fracture formation during Volume Fracturing in Coalbed Methane Reservoirs

Progress of the research on productivity prediction methods for stimulated reservoir volume (SRV)-fractured horizontal wells in unconventional hydrocarbon reservoirs

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