Investigation on the influence of multiple fracture interference on hydraulic fracture propagation in tight reservoirs

Liao, Songze; Hu, Jinghong; Zhang, Yuan

doi:10.1016/j.petrol.2022.110160

Cited by 24 publications

(5 citation statements)

References 37 publications

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“…To characterize the flow of the fracturing fluid in the fracture, Poiseuille flow is used to represent the fluid flow in the fracture, which can be expressed as q = d 3 12 μ ∇ p where q is the tangential flow rate, m 3 /s, d is the opening width of the cohesive element, m, μ is the viscosity coefficient of the fracturing fluid, mPa·s, and p is the fluid pressure within the cohesive element, MPa.…”

Section: Mathematical Modelmentioning

confidence: 99%

Influence of Engineering Parameters on Fracture Vertical Propagation in Deep Shale Reservoir: A Numerical Study Based on FEM

Zhang,

Liao,

et al. 2024

ACS Omega

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The geometry of hydraulic fractures in deep shale facies is significantly affected by the longitudinal inhomogeneity of rock physical properties and stresses. Numerous studies have been conducted on the influence of the longitudinal inhomogeneity of rocks on fracture morphology. However, there is still a lack of research that simultaneously considers the reservoir dip, bedding plane interface, and longitudinal inhomogeneity of the reservoir. To fill this gap, a three-dimensional (3D) numerical model of multireservoir hydraulic fracturing, which takes into account the bedding plane interface, was developed using the finite element method (FEM). The Drucker−Prager elastic-plasticity criterion was incorporated to accurately represent the plasticity of deep shale. The research revealed the influence of the formation dip angle on fracture morphology. Additionally, the perforation layer position and pump rate were optimized based on the actual geological parameters in North Jiangsu shale reservoir. The study findings indicate that reservoir fractures with a formation dip are easily detected by the interface. However, it is not necessarily true that the larger the formation dip, the easier it is for fluids to enter the interface. Fracturing from high-strength and stress reservoirs to lower reservoirs promotes the propagation of fracture height and the connectivity of multiple reservoirs. On the other hand, fractures initiated from low-strength and stress reservoirs tend to be confined to adjacent reservoirs more easily. The pump rate significantly affects the vertical propagation of fractures. At high interface strength, fractures with pump rate below 2.4 m 3 /min can only propagate at the perforation layer. The limited fracture height in shale reservoirs is likely due to substantial energy consumption by the fracturing fluid at the bedding plane interface. These studies offer theoretical guidance for understanding the vertical propagation of fractures in a deep multilayer reservoir.

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Section: Mathematical Modelmentioning

confidence: 99%

Influence of Engineering Parameters on Fracture Vertical Propagation in Deep Shale Reservoir: A Numerical Study Based on FEM

Zhang,

Liao,

et al. 2024

ACS Omega

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“…(Guo et al, 2015;Jahandideh et al, 2016;Li et al, 2017;Dubey et al, 2019). In the reservoirs with high brittleness, a complex hydraulic fracture network will likely be formed after fracturing; and in the reservoirs with low brittleness, a single long hydraulic fracture will be formed (Ru et al, 2020;Liao et al, 2022). Therefore, it is reasonable to infer that under the action of multi-stages tectonic activity, there must be certain correlation between the degree of natural fracture development in the Shunbei reservoir and the brittle characteristics of the reservoir rocks.…”

Section: Quanti Cation Of Rock Brittlenessmentioning

confidence: 99%

Evaluation of natural fractures and geological sweet spot in the Shunbei ultra-deep carbonate fault-controlled reservoir, Tarim Basin

Zhang,

Ru,

et al. 2024

Carbonates Evaporites

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The Shunbei ultra-deep carbonate strike-slip fault-controlled reservoir in Tarim Basin is rich in reserves. The strike-slip faults and natural structural fractures are the main storage space and ow channels of hydrocarbon resources. Therefore, studying the natural fracture development characteristics in this kind of reservoir is of great signi cance. The lithology of the Middle and Lower Ordovician strata in the Shunbei area is limestone and dolomite, including packstone, wackestone, grainstone, boundstone, lime mudstone, silici ed limestone and silty-ne crystalline dolomite, medium-coarse crystalline dolomite. Based on the statistics of fracture density and brittleness index of core samples, it is found that in limestone, lime mudstone has the highest brittleness index, while boundstone has the lowest; in dolomite, the brittleness index of mediumcoarse crystalline dolomite is higher than that of silty-ne crystalline dolomite. The natural structural fracture density has an obvious positive correlation with the rock brittleness index. The brittleness index of dolomite is generally higher than that of limestone. When the brittleness index is the same, dolomite has superior porosity and permeability whereas limestone has a stronger capacity to fracture. Those kinds of highly brittle layers in carbonate reservoirs are more likely to be geological sweet spots in the Shunbei area.

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“…For the given volume of fracturing fluid, the fracture volume is determined by the fluid leak-off rate. To simply this problem, treatment volume per stage, Q in (m 3 ), is calculated by: (7) where α denotes the fluid injection coefficient, which is defined as the ratio of the actual fluid injection volume to the fracture volume. The coefficient α is determined by the fluid leak-off rate, which is highly influenced by treatment pressure [23].…”

Section: Cost Functionmentioning

confidence: 99%

“…Liu et al introduced a nonplanar fracture propagation model based on XFEM and optimized fracture spacing in sequentially and simultaneously fractured horizontal wells [6]. Liao et al first investigated fracture propagation, when a horizontal wellbore is not co-linear, with the minimum horizontal principal stress [7]. Zhang et al proposed a hybrid numerical approach combining the XFEM and phase-field model [8].…”

Section: Introductionmentioning

confidence: 99%

Automatic Optimization of Multi-Well Multi-Stage Fracturing Treatments Combining Geomechanical Simulation, Reservoir Simulation and Intelligent Algorithm

Wang

Fang²,

et al. 2023

Processes

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Shale reserves have become an ever-increasing component of the world’s energy map. The optimal design of multi-well multi-stage fracturing (MMF) treatments is essential to the economic development of such resources. However, optimizing MMF treatments is a complex process. It requires geomechanical simulation, reservoir simulation, and automatic optimization. In this work, an integrated workflow is proposed to optimize MMF treatments in an unconventional reservoir, and the net present value (NPV) of reserves was treated as the objective function. The forward model consists of two submodels: a hydraulic fracturing model and a reservoir simulation model. The stochastic simplex approximation gradient (StoSAG) is used with the steepest ascent algorithm to maximize the NPV function. The computational results show that optimizing the fracture design can achieve a 20% higher NPV than that obtained with the field reference case. The drainage area of the optimal design is larger than that of the initial design. The maximum gas production rate increases from 23.75 MMSCF/day to 34.43 MMSCF/day and the maximum oil production rate increases from 497 STB/day to 692 STB/day. Therefore, new optimization paths can accelerate fracture design and help increase well production. This paper innovatively proposes a coupled workflow that can reduce the waste of manpower and improve the optimization results.

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Investigation on the influence of multiple fracture interference on hydraulic fracture propagation in tight reservoirs

Cited by 24 publications

References 37 publications

Influence of Engineering Parameters on Fracture Vertical Propagation in Deep Shale Reservoir: A Numerical Study Based on FEM

Influence of Engineering Parameters on Fracture Vertical Propagation in Deep Shale Reservoir: A Numerical Study Based on FEM

Evaluation of natural fractures and geological sweet spot in the Shunbei ultra-deep carbonate fault-controlled reservoir, Tarim Basin

Automatic Optimization of Multi-Well Multi-Stage Fracturing Treatments Combining Geomechanical Simulation, Reservoir Simulation and Intelligent Algorithm

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