Dealing With the Challenges of Hydraulic Fracture Initiation in Deviated-Cased Perforated Boreholes

Fallahzadeh, Seyed Hassan; Shadizadeh, Reza; Pourafshary, Peyman

doi:10.2523/132797-ms

Cited by 13 publications

(10 citation statements)

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“…Several researchers have conducted studies in order to investigate the mechanism of a hydraulic fracture creation in cased perforated wellbores [7][8][9][10][11][12]. They have shown that the wellbore inclination and azimuth as well as perforations spacing, phasing and orientations with respect to the in-situ stress directions play important roles in the process of fracture initiation and near wellbore propagation.…”

Section: Introductionmentioning

confidence: 99%

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Near Wellbore Hydraulic Fracture Propagation from Perforations in Tight Rocks: The Roles of Fracturing Fluid Viscosity and Injection Rate

et al. 2017

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Abstract:Hydraulic fracture initiation and near wellbore propagation is governed by complex failure mechanisms, especially in cased perforated wellbores. Various parameters affect such mechanisms, including fracturing fluid viscosity and injection rate. In this study, three different fracturing fluids with viscosities ranging from 20 to 600 Pa.s were used to investigate the effects of varying fracturing fluid viscosities and fluid injection rates on the fracturing mechanisms. Hydraulic fracturing tests were conducted in cased perforated boreholes made in tight 150 mm synthetic cubic samples. A true tri-axial stress cell was used to simulate real far field stress conditions. In addition, dimensional analyses were performed to correspond the results of lab experiments to field-scale operations. The results indicated that by increasing the fracturing fluid viscosity and injection rate, the fracturing energy increased, and consequently, higher fracturing pressures were observed. However, when the fracturing energy was transferred to a borehole at a faster rate, the fracture initiation angle also increased. This resulted in more curved fracture planes. Accordingly, a new parameter, called fracturing power, was introduced to relate fracture geometry to fluid viscosity and injection rate. Furthermore, it was observed that the presence of casing in the wellbore impacted the stress distribution around the casing in such a way that the fracture propagation deviated from the wellbore vicinity.

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Section: Introductionmentioning

confidence: 99%

“…This has been later investigated further through an analytical study. Fallahzadeh, et al [11] found that when the perforation direction is oriented away from the direction of the tensile zone on the wellbore circumference, the fracture initiation pressure also increases.…”

Section: Introductionmentioning

confidence: 99%

Near Wellbore Hydraulic Fracture Propagation from Perforations in Tight Rocks: The Roles of Fracturing Fluid Viscosity and Injection Rate

et al. 2017

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“…The stagnation pressure combined with annular pressure can then result in fracture initiation from inside the jetted tunnel while the pressure inside the wellbore annulus is lower. 22 Sand or a proppant is mixed into the fracturing fluid to avoid closure of the stimulated fractures, and the mentioned technology can be applied to two kinds of sand-injecting methods. The method involving pumping of sand-laden fluid through the annulus (HPAP) 20,23 has greater and faster sand transporting capacity and is generally used in the treatment of vertical wells.…”

Section: Mathematical Modelsmentioning

confidence: 99%

Flow field characters near fracture entrance in supercritical carbon dioxide sand fracturing

et al. 2019

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To investigate the flow field near fracture entrance and promote the development of sand fracturing with carbon dioxide as the working fluid, numerical simulation of multiphase flow was conducted with a 3D geological model considering the compressibility of carbon dioxide. The flow field of carbon dioxide alone was firstly investigated to lay the foundation for the analysis of multiphase flow, and then comparative analysis was conducted on the flow field of both the injecting sand from the pipe and the annulus. The results show that jet fracture with carbon dioxide can achieve a 4.46 MPa pressure boost at the fracture tip compared to the annulus pressure, which theoretically validates the feasibility of the mentioned technology. Sand fracturing can achieve a higher pressure boost in the cavity, while it needs greater pump pressure at the surface. Injecting sand from the annulus could decrease the need for pump pressure by 6.62 MPa at the condition of injecting 25% carbon dioxide from the annulus simultaneously, while the pressure difference between the cavity tip and the annulus decreases as a result. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…It has become a research hotspot and difficulty of CBM hydraulic fracturing. Nowadays the study of breakdown pressure in sandstone is mainly based on the tensile failure criterion in elasticity, and the relative calculation model was based on the premise of homogeneous formation [1][2][3][4]. For the fractured reservoir, Yan Jin and Mian Chen [5,6] took the influence of reservoir fractures on breakdown pressure of open hole well into consideration and established the relative calculation model.…”

Section: Introductionmentioning

confidence: 99%

The Breakdown Pressure Calculating Model for Open Hole Completion CBM Well Hydraulic Fracturing

Ai²,

Liu³

et al. 2014

TOEFJ

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Abstract:The open hole completion CBM borehole wall intersects with the weak surface such as cleats and fractures. In the process of hydraulic fracturing, the fractures may origin from coal body or cleats, which makes the rupture mechanism and rupture models of the borehole wall being different from the conventional reservoirs. The previous model for calculating breakdown pressure of open hole completion borehole wall considering tension failure has poor applicability for calculating breakdown pressure. Considering the spatial relationship of the intersection of borehole wall and cleats, analyzing the stress state of borehole wall rock and cleats wall, and basing on elastic mechanics and fracture mechanics, the breakdown pressure calculation model for CBM open hole completion hydraulic fracturing was established. In the model, fractures initiate from coal rock body, tensile failure along with face cleats, shear failure along with face cleats, tensile failure along with butt cleats and shear failure along with butt cleats five kinds of damage modes were considered. According to example calculation, the breakdown pressure of HX-L1 well calculated using the model is 14.81 MPa. The actual pressure obtained by bottom hole pressure gage is 15.42 MPa, and the relative error is 3.96%. The calculated result agrees with the actual conditions. It can be concluded that the model can be used to calculate the breakdown pressure for open hole completion CBM well hydraulic fracture.

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Dealing With the Challenges of Hydraulic Fracture Initiation in Deviated-Cased Perforated Boreholes

Cited by 13 publications

References 0 publications

Near Wellbore Hydraulic Fracture Propagation from Perforations in Tight Rocks: The Roles of Fracturing Fluid Viscosity and Injection Rate

Near Wellbore Hydraulic Fracture Propagation from Perforations in Tight Rocks: The Roles of Fracturing Fluid Viscosity and Injection Rate

Flow field characters near fracture entrance in supercritical carbon dioxide sand fracturing

The Breakdown Pressure Calculating Model for Open Hole Completion CBM Well Hydraulic Fracturing

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