Interaction of Multiple Hydraulic Fractures in Horizontal Wells

Wong, Sau-Wai; Geǐlikman, M. B.

doi:10.2118/163982-ms

Cited by 42 publications

(23 citation statements)

References 21 publications

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“…In the anisotropic far-field case, there is a reduced curvature of fracture paths compared with the isotropic case. In summary, our model compares favorably with the nonplanar results generated by Wu et al (2012).…”

Section: Model Validationmentioning

confidence: 69%

“…For multiple-fracture propagation, fracture interaction plays an important role in fracture geometry. For nonplanar propagation validation, we refer for comparison to the nonplanar model of Weng et al (2011) and Wu et al (2012) horizontal wellbore with two initial fractures (Fig. 8a) and two horizontal wellbores with one fracture each (Fig.…”

Section: Model Validationmentioning

confidence: 99%

“…Roussel and Sharma (2011) used a 3D finite-difference numerical model to calculate stress distributions around uniform-pressure fractures, accounting for propagation by assuming fractures would follow principal-stress trajectories. Weng et al (2011) and Wu et al (2012) describe a model for simulating multiple hydraulic fractures in naturally fractured reservoirs combining standard pseudo-3D equations for fracture-width calculations coupled with the displacement discontinuity approach of Olson (2004) to account for stress-interaction effects between fractures. Meyer and Bazan (2011) presented a discretefracture-network model to simulate planar-fracture growth in the three principal planes, with the Olson (2004) analytical solution to describe the interaction between induced fractures.…”

Section: Introductionmentioning

confidence: 99%

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Simultaneous Multifracture Treatments: Fully Coupled Fluid Flow and Fracture Mechanics for Horizontal Wells

2014

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Successfully creating multiple hydraulic fractures in horizontal wells is critical for unconventional gas production economically. Optimizing the stimulation of these wells will require models that can account for the simultaneous propagation of multiple, potentially nonplanar, fractures.In this paper, a novel fracture-propagation model (FPM) is described that can simulate multiple-hydraulic-fracture propagation from a horizontal wellbore. The model couples fracture deformation with fluid flow in the fractures and the horizontal wellbore. The displacement discontinuity method (DDM) is used to represent the mechanics of the fractures and their opening, including interaction effects between closely spaced fractures. Fluid flow in the fractures is determined by the lubrication theory. Frictional pressure drop in the wellbore and perforation zones is taken into account by applying Kirchoff's first and second laws. The fluid-flow rates and pressure compatibility are maintained between the wellbore and the multiple fractures with Newton's numerical method. The model generates physically realistic multiple-fracture geometries and nonplanar-fracture trajectories that are consistent with physical-laboratory results and inferences drawn from microseismic diagnostic interpretations.One can use the simulation results of the FPM for sensitivity analysis of in-situ and fracture treatment parameters for shale-gas stimulation design. They provide a physics-based complex fracture network that one can import into reservoir-simulation models for production analysis. Furthermore, the results from the model can highlight conditions under which restricted width occurs that could lead to proppant screenout.

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Section: Model Validationmentioning

confidence: 69%

Section: Model Validationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Simultaneous Multifracture Treatments: Fully Coupled Fluid Flow and Fracture Mechanics for Horizontal Wells

2014

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“…Using this method, researchers have attempted to analyze the impact of simultaneous multiple fracture growth (Yamamoto et al 2004;Min and Ghassemi 2012;Wong et al 2013;Lecampion and Desroches 2015;Wu and Olson 2015). Several of these methods have been extended to allow for interaction with heterogeneities in the reservoir (Weng et al 2011;Sesetty and Ghassemi 2012;McClure and Horne 2013;Wu and Olson 2013;McClure et al 2015).…”

Section: Introductionmentioning

confidence: 99%

Strategies for Effective Stimulation of Multiple Perforation Clusters in Horizontal Wells

Manchanda

Bryant

Bhardwaj

et al. 2016

Day 1 Tue, February 09, 2016

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Increasing the efficiency of completions in horizontal wells is an important concern in the oil and gas industry. To decrease the number of fracturing stages per well it is common practice to use multiple clusters per stage. This is done with the hope that most of the clusters in the stage will be effectively stimulated. Diagnostic evidence, however, suggests that in many cases only 1 or 2 clusters out of 4 or 5 clusters in a stage are effectively stimulated.In this paper strategies to maximize the number of effectively stimulated perforation clusters are discussed. A fully 3-D poroelastic model that simulates the propagation of non-planar fractures in heterogeneous media is developed and used to model the propagation of multiple competing, fractures. A parametric study is first conducted to show how important fracture design variables such as limited entry perforations and cluster spacing; and formation parameters such as permeability, lateral and verical heterogeneity affect the growth of competing fractures. The effect of stress shadowing due to both mechanical and poroelastic effects is accounted for.3-D numerical simulations have been performed to show the impact of some operational and reservoir parameters on simultaneous competitive fracture propagation. It was found that an increase in stage spacing decreases the stress interference between propagating fractures and increases the number of propagating fractures in a stage. It was also found that an increase in reservoir permeability can decrease the stress interference between propagating fractures because of poro-elastic stress changes. A modest (about 25%) variability in reservoir mechanical properties along the wellbore is shown to be enough to alter the number of fractures created in a hydraulic fracturing stage and mask the effects of stress shadowing. Inter-stage fracture simulations show post-shutin fracture extension induced by stress interference from adjacent propagating fractures. The impact of poro-elasticity is highlighted for infill well fracture design and preferential fracture propagation towards depleted regions is clearly observed in multi-well pad fracture simulations.The results in this paper attempt to provide practitioners with a better understanding of multi-cluster fracturing dynamics. Based on these findings recommendations are made on how best to design fracture treatments that will not only lead to the successful placement of fluid and proppant in a single fracture, but in a set of fractures that are competing with each other for growth. The ability to successfully stimulate all perforation clusters is shown to be a function of key fracture design parameters.

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“…• Optimization of fracture spacing along a given lateral (Baig et al 2012;Geilikman et al 2013;Jo 2013). • The impact of long-term time between the completion of a delineation wellbore and an adjacent development well (Ajani and Kelkar 2012;Manchanda et al 2013;Okuma Mangha et al 2012).…”

Section: Introductionmentioning

confidence: 99%

Effects of Well Placement Timing and Conductivity Loss on Hydrocarbon Production in Multiple Hydraulically Fractured Horizontal Wells in a Liquids-Rich Shale Play

2016

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Horizontal wells in liquids-rich shale plays are now being drilled such that lateral and vertical distances between adjacent wells are significantly reduced. In multistacked reservoirs, fracture height and orientation from geomechanical effects coupled with natural fractures create additional complications; therefore, predicting well performance using numerical simulation becomes challenging. This paper describes numerical simulation results from a three-well pad in a stacked liquids-rich reservoir (containing gas condensates) to understand the interaction between wells and production behavior. This paper discusses the use of an unstructured grid-based numerical simulator that incorporates complicated geometries of both hydraulic and natural fractures. It can handle compositional simulation to better model gas condensates with special focus on timing of third well placement and the loss of conductivity effects on production from these wells. A base case was created with a stacked shale play containing three parallel wells but with staggered elevations. Variables used in this study include matrix permeability, condensate-to-gas ratio (CGR), fracture length, well staggering, time of well placement, conductivity degradation, and presence of natural fractures. Simulation runs were conducted for a five-year duration.More than 20 compositional simulation runs were conducted. For the base case, staggering resulted in a slight decrease in both cumulative oil and gas production compared to a case without staggering. Matrix permeability had the most dominant effect on both oil and gas production. Fracture and matrix conductivity losses were more detrimental to cumulative gas production than oil production. For the limited cases studied, placement of the third well one year after the first two wells began producing resulted in a spike in both oil and gas production from the pad. This produced cumulative oil and gas amount was close to that of three wells producing simultaneously, especially if fracture half-lengths for the third well were the same as the first two. However, cumulative oil and gas production reduced significantly if fracture half-lengths were smaller than the other two wells. When all wells experienced significant conductivity loss, gas production was affected more than oil production when the third well was placed one year after the first two wells began producing. In all cases, placing the third well between the other wells was helpful in increasing overall production from this pad. Natural fractures increased both oil and gas production in the cases studied.This paper addresses important issues associated with a liquids-rich unconventional play. It demonstrates successful use of unstructured grid-based reservoir simulation modeling to address well placement timing, well staggering, conductivity damage effects, natural fractures, hydraulic fractures not perpendicular to the wellbores, and several other important issues for which little is known so far. Results from this study type can be used to make impor...

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Interaction of Multiple Hydraulic Fractures in Horizontal Wells

Cited by 42 publications

References 21 publications

Simultaneous Multifracture Treatments: Fully Coupled Fluid Flow and Fracture Mechanics for Horizontal Wells

Simultaneous Multifracture Treatments: Fully Coupled Fluid Flow and Fracture Mechanics for Horizontal Wells

Strategies for Effective Stimulation of Multiple Perforation Clusters in Horizontal Wells

Effects of Well Placement Timing and Conductivity Loss on Hydrocarbon Production in Multiple Hydraulically Fractured Horizontal Wells in a Liquids-Rich Shale Play

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