Abstract
Hydraulic fracture initiation poses a challenging issue on fracturing wells landed in deep and tight reservoirs, often necessitating a high breakdown pressure for fracture initiation. Oriented perforation represents a potential solution to alleviate this issue, not only reducing the breakdown pressure but also enhancing fracture geometry alignment. This paper introduces a novel approach to address this issue, featuring a computational framework for calculating breakdown pressure and optimal perforation direction, along with a new perforation cluster layout design. The developed breakdown pressure model is capable, and applicable to various fracturing scenarios, including deviated, cased hole, and clustered perforation fracturing. It accounts for the casing-cement interaction effect and perforation quality. The optimal perforation direction is defined as the one along which hydraulic fractures can be initiated with the lowest breakdown pressure at a measured depth. Using the minimum breakdown pressure and its associated phase angle, the optimal perforation direction is subsequently calculated in terms of perforation azimuth and dip. This information will be used to control the perforation device, ensuring it rotates and fires at the optimal direction in downhole. Numerical examples are given to verify the model performance and effectiveness first. Then a field well case study is provided to further demonstrate how to use the approach to provide pre-fracturing suggestions in practice. The case study validated the accuracy and reliability on solving breakdown issue. To further enhance fracture initiation, a new perforation cluster layout design is also presented. The two central perforations, positioned next to each other, utilize a relatively larger perforation diameter with a phase difference of \({180}^{^\circ }\). The two central perforations will be aligned at the optimal perforation direction in subsurface, which facilitates faster and easier fracture initiation. Moreover, the new perforation design reduces near wellbore fracture tortuosity and minimizes entry pressure loss. All these efforts working together offer a significant improvement on fracture initiation for stimulating wells in deep and tight reservoirs.
Highlights
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Successfully developed a novel computational framework for calculating the required breakdown pressure envelope applicable to cased hole, deviated and perforation hydraulic fracturing treatment.
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Developed comprehensive formulations to calculate the optimal perforation direction, along which fracture initiation can be achieved with the lowest breakdown pressure.
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A novel perforation cluster layout design is offered, which can further alleviate the breakdown issue for fracturing horizontal wells in deep and tight reservoirs.
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Abbreviations
- \({\sigma }_{{\text{SHmin}}}\) :
-
Minimum horizontal stress
- \({\sigma }_{{\text{V}}}\) :
-
Vertical stress
- \({\sigma }_{{\text{SHmax}}}\) :
-
Maximum horizontal stress
- \({x}_{{\text{G}}}^{n}{y}_{{\text{G}}}^{n}{z}_{{\text{G}}}^{n}\) :
-
Global coordinate system
- \({x}_{{\text{B}}}^{n}{y}_{{\text{B}}}^{n}{z}_{{\text{B}}}^{n}\) :
-
Borehole coordinate system
- \({x}_{{\text{P}}}^{m}{y}_{{\text{P}}}^{m}{z}_{{\text{P}}}^{m}\) :
-
Perforation coordinate system
- \(P_{w}\) :
-
Borehole bottom pressure
- \({\varvec{\sigma}}^{{\text{I}}}\) :
-
Induced stress around the perforation base due to in-situ stresses
- \({\varvec{\sigma}}^{{{\text{II}}}}\) :
-
Induced stress around the perforation base due to wellbore pressure
- \({\varvec{\sigma}}^{{{\text{III}}}}\) :
-
Induced stress around the perforation base due to the perforation pressure
- \(\theta_{{\sigma_{{\text{H}}} }}\) :
-
The azimuth of maximum horizontal stress
- \(\alpha_{{\text{D}}}\) :
-
Wellbore deviation at a measured depth
- \(\alpha_{{\text{A}}}\) :
-
Wellbore azimuth at a measured depth
- \({\alpha }_{{z}_{{\text{B}}}}^{n}\) :
-
Perforation phase angle
- \({{\varvec{R}}}_{\mathbf{G}\to \mathbf{B}}^{{\varvec{n}}}\) :
-
Transformation matrix from global coordinate system to the borehole coordinate system
- \({{\varvec{\sigma}}}^{\mathbf{G}}\) :
-
The in situ stresses tensor in the global coordinate system
- \({{\varvec{\sigma}}}^{{\text{P}}}\) :
-
The total effective stress around the perforation base
- \({{\varvec{\sigma}}}^{{\text{B}},I}\) :
-
The in-situ stresses tensor in the borehole coordinate system
- \({\varvec{\sigma}}^{{\text{P,I}}}\) :
-
The in-situ stress tensor in the perforation coordinate system
- \(\Delta {P}_{{\text{perf}}}\) :
-
Perforation pressure loss
- \(\rho\) :
-
Fluid density
- \(d\) :
-
Perforation diameter
- \(C_{{\text{d}}}\) :
-
Perforation coefficient of discharge
- \(Q\) :
-
The fluid flow rate
- \(N\) :
-
The number of perforations for a perforation cluster
- \(P_{{{\text{perf}}}}\) :
-
Perforation pressure
- \({\beta }_{{\text{perf}}}\) :
-
The fraction of wellbore pressure effectively acting on the perforation tunnel
- \({P}_{{\text{cr}}}\) :
-
The cement–formation interaction pressure
- \({\beta }_{{\text{cr}}}\) :
-
The fraction of wellbore pressure transferred to the cement–formation interface
- R os :
-
Casing outer radius
- R is :
-
Casing inside radius
- R oc :
-
Cement outer radius
- R ic :
-
Cement inside radius
- μ s :
-
Poisson’s ratio of casing
- μ c :
-
Poisson’s ratio of cement
- \({\sigma }_{R}^{{\text{B}},II}\) :
-
The induced radial stress at the perforation base due to the interface pressure \({P}_{{\text{cr}}}\)
- \({\sigma }_{\theta }^{{\text{B}},II}\) :
-
The induced circumferential stress at the perforation base due to the interface pressure \({P}_{{\text{cr}}}\)
- \({\text{Perf}}\_{\text{A}}{\text{ZI}}\) :
-
Perforation azimuth
- \({\text{Perf}}\_{\text{DIP}}\) :
-
Perforation dip
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This research received no specific grant from any funding agency in the public. The paper was written based on the authors’ project currently conducted within Saudi Aramco.
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Xia, K., Cui, Y. & Mahmood, T. A Novel Oriented Perforation Approach for Fracturing Deep and Tight Reservoirs. Rock Mech Rock Eng (2024). https://doi.org/10.1007/s00603-024-03846-1
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DOI: https://doi.org/10.1007/s00603-024-03846-1