Modelling the effect of injection system compressibility and viscous fluid flow on hydraulic fracture breakdown pressure

Bunger, Andrew P.; Lakirouhani, Ali; Detournay, Emmanuel

doi:10.1201/9780415601658-11

Cited by 24 publications

(23 citation statements)

References 3 publications

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“…Justification for this assumption is discussed in the supporting information. Although this numerical model is built on prior works related to the numerical simulations of single HF process (Bunger et al, ; Detournay & Carbonell, ; Lakirouhani et al, ), the main novelty in our model is that the propagation of the hydraulic fracture is now governed by the subcritical crack growth law, equation . Thus, stable HF growth is allowed at wellbore pressures that are insufficient to satisfy

K_{normalI} = K_{IC}

, the critical LEFM criterion.…”

Section: Mathematical Modelmentioning

confidence: 99%

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Time‐Dependent Hydraulic Fracture Initiation

Gordeliy

Prioul

et al. 2020

JGR Solid Earth

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Rocks are known to fail in a time‐dependent manner similar to many brittle and quasi‐brittle materials. However, observed time dependence of hydraulic fracture initiation has ubiquitously been attributed to fluid flow‐related mechanisms without consideration of the intrinsic time dependence of rock failure. Laboratory delayed hydraulic fracturing breakdown experiments on three rocks (granite, sandstone, and limestone) show sensitivity to rock properties associated with subcritical crack growth as well as fluid viscosity and ambient confining pressure applied to the specimens. A new hydraulic fracture initiation model accounting for subcritical crack growth and fluid flow in a poroelastic medium, as well as the additional energy dissipation required for fluid flow in the rough fracture tip, is then used to estimate the value of the subcritical index n based on characterization experiments. Given this characterization data, the model is shown to be capable of predicting time‐dependent hydraulic fracture initiation with variation of fluid viscosity and confining stress.

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K_{normalI} = K_{IC}

, the critical LEFM criterion.…”

Section: Mathematical Modelmentioning

confidence: 99%

“…Plane strain model of a longitudinal hydraulic fracture from a wellbore drilled in the direction of intermediate (or maximum) in situ stress (after Bunger et al, ; Lakirouhani et al, ).…”

Section: Mathematical Modelmentioning

confidence: 99%

Time‐Dependent Hydraulic Fracture Initiation

Gordeliy

Prioul

et al. 2020

JGR Solid Earth

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show abstract

“…However all these approaches are quite computationally intensive which may limit their applications in 3D cases. This is highly dynamical stage influenced by fluid viscosity, injection rate and line compressibility over which initiation of transverse fracture may still be followed by longitudinal one if that is more energetically favorable Abbas and Lecampion 2013;Bunger et al 2010). Also it should be noticed that in the present work we focused only on the estimation of fracture initiation pressures while leaving behind the further process of "pressure rollover" which take place between the moment when the rock breaks and until the fracture grown to the extent it is capable to take all the fluid injected into the borehole and the pressure starts to decrease.…”

Section: Test 3 Testmentioning

confidence: 99%

Model of Hydraulic Fracture Initiation from the Notched Open Hole

et al. 2015

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In stimulating tight carbonate formations, the propagation of multiple transverse fractures is highly desirable to contact as much matrix as possible. The application of this method to openhole well environments is challenged by the dominating impact of hoop stresses in the near-wellbore vicinity rather than far-field stress in the producing layer. As a result, even if the open hole is drilled in the direction of minimal horizontal far-field stress, there is a high probability that hydraulic fractures initiate longitudinally and then turn to the preferred fracture plane, creating undesired tortuosity.One of the approaches towards controlling both the position and direction of fracture initiation is to cut notches in the wellbore wall at specified positions. As pressure increases during fracturing, those notches can locally eliminate the influence of the wellbore hoop stress and develop high tensile stress concentrations initiating transverse hydraulic fractures at lower pressures.A theoretical model is proposed herein that aims to predict the position, orientation, and pressure at which a fracture initiates. In the model, the 3D stress state around wellbore and notch(es) is analyzed using the brittle fracture criteria. In the numerical implementation, the stresses are efficiently resolved using the boundary element method. The model is used to interpret published laboratory data on fracture initiation including those from hydraulic fracturing block tests. It is shown that the conventional maximum tensile stress (MTS) criterion fails to reproduce the observed trends in initiation pressure and fracture orientation. The nonlocal modification of the MTS criterion based on the stress averaging technique (SAMTS), reveals a good match with initiation pressures in simplified tests. When applied to hydraulic fracturing block test data, SAMTS captures the observed fracture orientations while overestimating the absolute pressure values. The discussion of possible reasons for that overestimate and the way forward concludes the paper.

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“…Incorporating them is probably a next step for the industry of fracturing to take. Among the attempts to couple elasticity and fluid flow, are several by Garagash and Detournay (1997), Detournay and Carbonell (1997), Bunger et al (2010), and Lecampion (2012) for the case of axial fractures and those by Lhomme (2005), Lhomme et al (2005), and Abbas and Lecampion (2013) for the case of transverse fractures.…”

Section: Existing Models Overviewmentioning

confidence: 99%

Impact of Wellbore Orientation on Fracture Initiation Pressure in Maximum Tensile Stress Criterion Model for Tight Gas Field in the Sultanate of Oman

Briner¹,

Florez²,

Nadezhdin

et al. 2015

Day 1 Mon, September 14, 2015

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The goal of the present work is to numerically simulate the effects of wellbore orientation on fracture initiation pressure (FIP). These simulations support the study of FIP sensitivity to arbitrary wellbore position and finding the orientations that correspond to the lowest FIP. A 3D numerical model of the fracture initiation from a perforated wellbore in linear elastic rock is used to model FIP. This model is based on the boundary element method (BEM) and maximum tensile stress (MTS) criterion. The data used were from different zones and blocks of a tight gas-bearing sandstone field in the Sultanate of Oman. The amount and quality of available data allowed comprehensive model development. The model is built for the four blocks of the main field, but can be applied to the other blocks and fields. Since the equations and correlations are not empirical and not field-specific, the model is applicable to a wide range of conditions. Some practical applications of the study include selection of the optimum perforated intervals intended for fracturing stimulation in deviated or almost horizontal wellbores where different parts of lateral sections are not exactly aligned with principal stresses. Drilling wells in a particular direction to the principal stresses for the specific reason to reduce the FIP has not been tested to date and is a subject to further discussion.• Stronger completions • Revised (reduced) safety margins for the pressure during fracturing • Use of heavy brine for formation breakdown • Different (so called hybrid) fracturing schedules

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Modelling the effect of injection system compressibility and viscous fluid flow on hydraulic fracture breakdown pressure

Cited by 24 publications

References 3 publications

Time‐Dependent Hydraulic Fracture Initiation

Time‐Dependent Hydraulic Fracture Initiation

Model of Hydraulic Fracture Initiation from the Notched Open Hole

Impact of Wellbore Orientation on Fracture Initiation Pressure in Maximum Tensile Stress Criterion Model for Tight Gas Field in the Sultanate of Oman

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