An Integrated Petrophysics and Geomechanics Approach for Fracability Evaluation in Shale Reservoirs

Jin, Xiaochun; Shah, Subhash; Roegiers, J.-C.; Zhang, Bo

doi:10.2118/168589-pa

Cited by 168 publications

(66 citation statements)

References 18 publications

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“…This aspect of the problem will be explored further in the future. Impact of lateral heterogeneity Heterogeneity in formation properties along the horizontal well has been used to select locations for perforation in regions of good ЉfracabilityЉ (Mullen and Enderlin 2012;Fang and Amro 2014;Jahandideh and Jafarpour 2014;Jin et al 2014Jin et al , 2015Su et al 2014). Different researchers pose different ways to determine the fracability of the reservoir in the vicinity of horizontal well stages.…”

Section: Impact Of Matrix Permeabilitymentioning

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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Section: Impact Of Matrix Permeabilitymentioning

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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“…Therefore, well logging data estimation is more practical for the evaluation of brittleness in tight carbonate reservoirs. In this paper, the brittleness evaluation method is used and proposed by Rickman et al [20], which has been verified by Jin et al [13] and Sun et al [14]. Rickman et al [20] think that the concept of rock brittleness combines both Poisson's Ratio and Young's Modulus to reflect the rocks ability to fail under stress (Poisson's Ratio) and maintain a fracture (Young's Modulus) once the rock fractures.…”

Section: Rock Brittlenessmentioning

confidence: 90%

“…However, the absence of universally accepted definition and measurement of brittleness has led to various methods or models for its quantification [22,23]. Jin et al [13] has assembled a table of definitions of brittleness, as presented in Table A. From which it can be seen that brittleness is obtained mainly by rock mechanics tests and well logging data.…”

Section: Rock Brittlenessmentioning

confidence: 99%

“…Besides the dolomite, other carbonate minerals, such as calcite in limestone, are also more brittle than clay [26e28]. Therefore, a new expression of brittleness is proposed by Jin et al [13] in the following: Table 2, showing homogeneity in mineralogical compositions. The dominant minerals in the carbonate samples were dolomite and calcite.…”

Section: Rock Brittlenessmentioning

confidence: 99%

See 1 more Smart Citation

Feasibility study on application of volume acid fracturing technology to tight gas carbonate reservoir development

Dai

Liu³

et al. 2015

Petroleum

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Keywords:Tight oil and gas reservoir Tight carbonate rock Volume acid fracturing Fracture network Ordos basin SRV a b s t r a c t How to effectively develop tight-gas carbonate reservoir and achieve high recovery is always a problem for the oil and gas industry. To solve this problem, domestic petroleum engineers use the combination of the successful experiences of North American shale gas pools development by stimulated reservoir volume (SRV) fracturing with the research achievements of Chinese tight gas development by acid fracturing to propose volume acid fracturing technology for fractured tightgas carbonate reservoir, which has achieved a good stimulation effect in the pilot tests. To determine what reservoir conditions are suitable to carry out volume acid fracturing, this paper firstly introduces volume acid fracturing technology by giving the stimulation mechanism and technical ideas, and initially analyzes the feasibility by the comparison of reservoir characteristics of shale gas with tight-gas carbonate. Then, this paper analyzes the validity and limitation of the volume acid fracturing technology via the analyses of control conditions for volume acid fracturing in reservoir fracturing performance, natural fracture, horizontal principal stress difference, orientation of insitu stress and natural fracture, and gives the solution for the limitation. The study results show that the volume acid fracturing process can be used to greatly improve the flow environment of tight-gas carbonate reservoir and increase production; the incremental or stimulation response is closely related with reservoir fracturing performance, the degree of development of natural fracture, the small intersection angle between hydraulic fracture and natural fracture, the large horizontal principal stress difference is easy to form a narrow fracture zone, and it is disadvantageous to create fracture network, but the degradable fiber diversion technology may largely weaken the disadvantage. The practices indicate that the application of volume acid fracturing process to the tight-gas carbonate reservoir development is feasible in the Ordovician Majiagou Formation of lower Paleozoic, which is of great significance and practical value for domestic tight-gas carbonate reservoir development and studies in the future.

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“…There have also been studies on how to integrate a petrophysics and geomechanics fracability evaluation in shale plays by Jin et al (2014Jin et al ( , 2015 and Zhang et al (2015). There have also been studies on how to integrate a petrophysics and geomechanics fracability evaluation in shale plays by Jin et al (2014Jin et al ( , 2015 and Zhang et al (2015).…”

Section: Introductionmentioning

confidence: 99%

Selecting optimum log measurements for hydraulic fracturing

2016

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We have developed a statistical method for investigating the importance of different log measurements for picking the best zones for hydraulic fracturing. We have determined the method's applicability using data from unconventional reservoirs (Eagle Ford, Haynesville, Barnett, and a reservoir from the Middle East). The analysis began with single log measurements (e.g., gamma ray [GR], compressional and shear sonic [DTC and DTS], and spectral gamma ray [SGR], which could measure the radioactivity of uranium [U], potassium [K], and thorium [Th]). Other types of measurements, including density (RhoB), neutron porosity (NPHI), and resistivity, were added to obtain more complex logging suites. These log measurements were the inputs for this analysis. Each input combination was referred to as a "scenario." Parameters such as effective porosity (PhiE), brittleness, total organic carbon (TOC), production index (PI), and fracture index (FI) were referred to as the outputs for the analysis. We have investigated linear and nonlinear combinations of the inputs to predict the outputs. Various scenarios, beginning with the simplest cases and ending with the most complete combination, were tested. The selection of log combinations was either based on the importance of individual logs or on industry-standard combinations (such as triple and quad combos). For each scenario, we computed correlation coefficients and root-mean-square errors of predicting the output parameters. The prediction accuracies generally increased as a result of increasing the number of input logs. Our analysis clearly found the importance of using SGR (for PI and FI prediction) and resistivity (for TOC prediction) logs. Based on comparison of the reconstruction results, actual values, and correlation coefficients/errors, we ranked the log combinations for predicting/modeling a specific parameter. The most challenging properties to model included TOC, PhiE, PI, and FI; the easiest properties to predict were brittleness and Young's modulus.

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An Integrated Petrophysics and Geomechanics Approach for Fracability Evaluation in Shale Reservoirs

Cited by 168 publications

References 18 publications

Strategies for Effective Stimulation of Multiple Perforation Clusters in Horizontal Wells

Strategies for Effective Stimulation of Multiple Perforation Clusters in Horizontal Wells

Feasibility study on application of volume acid fracturing technology to tight gas carbonate reservoir development

Selecting optimum log measurements for hydraulic fracturing

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