What Broke? Microseismic analysis using seismic derived rock properties and structural attributes in the Eagle Ford play

Meek, Robert; Suliman, Bailo; Hull, Robert; Bello, Hector; Portis, Doug

doi:10.1190/urtec2013-147

Cited by 11 publications

(1 citation statement)

References 5 publications

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“…Snelling et al, 2013;Jabbari et al, 2015), evaluate diverters (Waters et al, 2009;Diakhate et al, 2015), and link the effectiveness of hydraulic fracture treatment to structural features of the reservoir (e.g. Rich and Ammerman, 2010;Meek et al, 2013).…”

Section: Introductionmentioning

confidence: 99%

Optimizing Unconventional Field Development through an Integrated Reservoir Characterization and Simulation Approach

Shojaei

Lipp

2016

Proceedings of the 4th Unconventional Resources Technology Conference

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The URTeC Technical Program Committee accepted this presentation on the basis of information contained in an abstract submitted by the author(s). The contents of this paper have not been reviewed by URTeC and URTeC does not warrant the accuracy, reliability, or timeliness of any information herein. All information is the responsibility of, and, is subject to corrections by the author(s). Any person or entity that relies on any information obtained from this paper does so at their own risk. The information herein does not necessarily reflect any position of URTeC. Any reproduction, distribution, or storage of any part of this paper without the written consent of URTeC is prohibited.

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Section: Introductionmentioning

confidence: 99%

Optimizing Unconventional Field Development through an Integrated Reservoir Characterization and Simulation Approach

Shojaei

Lipp

2016

Proceedings of the 4th Unconventional Resources Technology Conference

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Geomechanical modeling of hydraulic fractures interacting with natural fractures — Validation with microseismic and tracer data from the Marcellus and Eagle Ford

Aimène

Ouenes²

2015

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We have developed a new geomechanical workflow to study the mechanics of hydraulic fracturing in naturally fractured unconventional reservoirs. This workflow used the material point method (MPM) for computational mechanics and an equivalent fracture model derived from continuous fracture modeling to represent natural fractures (NFs). We first used the workflow to test the effect of different stress anisotropies on the propagation path of a single NF intersected by a hydraulic fracture. In these elementary studies, increasing the stress anisotropy was found to decrease the curving of a propagating NF, and this could be used to explain the observed trends in the microseismic data. The workflow was applied to Marcellus and Eagle Ford wells, where multiple geomechanical results were validated with microseismic data and tracer tests. Application of the workflow to a Marcellus well provides a strain field that correlates well with microseismicity, and a maximum energy release rate, or [Formula: see text] integral at each completion stage, which appeared to correlate to the production log and could be used to quantify the impact of skipping the completion stages. On the first of two Eagle Ford wells considered, the MPM workflow provided a horizontal differential stress map that showed significant variability imparted by NFs perturbing the regional stress field. Additionally, a map of the strain distribution after stimulating the well showed the same features as the interpreted microseismic data: three distinct regions of microseismic character, supported by tracer tests and explained by the MPM differential stress map. Finally, the workflow was able to estimate, in the second well with no microseismic data, its main performance characteristics as validated by tracer tests. The field-validated MPM geomechanical workflow is a powerful tool for completion optimization in the presence of NFs, which affect in multiple ways the final outcome of hydraulic fracturing.

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Inversion and interpretation of seismic-derived rock properties in the Duvernay play

et al. 2018

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We have developed an interpretive seismic workflow that incorporates multicomponent seismic inversion, guided by structural mapping, for characterizing low-permeability unconventional reservoirs. The workflow includes the determination of a calibrated time-depth relationship, generation of seismic-derived structural maps, poststack inversion, amplitude-variation-with-offset analysis, and PP-PS joint inversion. The subsequent interpretation procedure combines structural and inversion results with seismic-derived lithologic parameters, such as the Young’s modulus, Poisson’s ratio, and brittleness index. We applied this workflow to a 3D multicomponent seismic data set from the Duvernay play in the Kaybob area in Alberta, Canada. Subtle faults are discernible using isochron maps, horizontal time slices, and seismic stratal slices. Fault-detection software is also used to aid in the delineation of structural discontinuities. We found that seismic-derived attributes, coupled with structural mapping, can be used to map reservoir facies and thus to highlight zones that are most favorable for hydraulic-fracture stimulation. By imaging structural discontinuities and preexisting zones of weakness, seismic mapping also contributes to an improved framework for understanding the induced-seismicity risk.

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What Broke? Microseismic analysis using seismic derived rock properties and structural attributes in the Eagle Ford play

Cited by 11 publications

References 5 publications

Optimizing Unconventional Field Development through an Integrated Reservoir Characterization and Simulation Approach

Optimizing Unconventional Field Development through an Integrated Reservoir Characterization and Simulation Approach

Geomechanical modeling of hydraulic fractures interacting with natural fractures — Validation with microseismic and tracer data from the Marcellus and Eagle Ford

Inversion and interpretation of seismic-derived rock properties in the Duvernay play

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