Modelling microseismicity of a producing reservoir from coupled fluid‐flow and geomechanical simulation

Angus, D.A.; Kendall, J.‐M.; Fisher, Q.J.; Segura, J. M.; Skachkov, S.V.; Crook, A. J. L.; Dutko, M.

doi:10.1111/j.1365-2478.2010.00913.x

Cited by 40 publications

(26 citation statements)

References 34 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The subsurface model we use in this study is a graben-style reservoir consisting of three reservoir compartments separated by two normal faults (Angus et al 2010;Lynch et al 2013). Two production cases are examined, one having high fault fluid-flow transmissibility (HFT) and the other having low fault fluid-flow transmissibility (LFT).…”

Section: Two-fault Graben Reservoir Modelmentioning

confidence: 99%

“…This is because the low fluid-flow transmissibility of both faults inhibits fluid flow from the central and right compartments to the production well in the left compartment and hence pore pressure reduction is restricted to the left compartment. The slight observable changes that occur in the central and right compartments relate to stress arching due to stress redistribution in the overburden above the left compartment and fault movement (Angus et al 2010). …”

Section: Calculation Of Time-lapse Seismic Attributesmentioning

confidence: 99%

See 1 more Smart Citation

Analysis of time-lapse travel-time and amplitude changes to assess reservoir compartmentalization

Angus

Clark

et al. 2015

Geophysical Prospecting

Self Cite

View full text Add to dashboard Cite

Fluid depletion within a compacting reservoir can lead to significant stress and strain changes and potentially severe geomechanical issues, both inside and outside the reservoir. We extend previous research of time-lapse seismic interpretation by incorporating synthetic near-offset and full-offset common-midpoint reflection data using anisotropic ray tracing to investigate uncertainties in timelapse seismic observations. The time-lapse seismic simulations use dynamic elasticity models built from hydro-geomechanical simulation output and a stress-dependent rock physics model. The reservoir model is a conceptual two-fault graben reservoir, where we allow the fault fluid-flow transmissibility to vary from high to low to simulate non-compartmentalized and compartmentalized reservoirs respectively. The results indicate time-lapse seismic amplitude changes and traveltime shifts can be used to qualitatively identify reservoir compartmentalization. Due to the high repeatability and good quality of the time-lapse synthetic dataset, the estimated traveltime shifts and amplitude changes for near-offset data match the true model subsurface changes with minimal errors. A 1D velocity-strain relation was used to estimate the vertical velocity change for the reservoir bottom interface by applying zero-offset time-shifts from both the near-offset and full-offset measurements.For near-offset data, the estimated P-wave velocity changes were within 10% of the true value.However, for full-offset data, time-lapse attributes are quantitatively reliable using standard time-lapse seismic methods when an updated velocity model is used rather than the baseline model.

show abstract

Section: Two-fault Graben Reservoir Modelmentioning

confidence: 99%

Section: Calculation Of Time-lapse Seismic Attributesmentioning

confidence: 99%

Analysis of time-lapse travel-time and amplitude changes to assess reservoir compartmentalization

Angus

Clark

et al. 2015

Geophysical Prospecting

Self Cite

View full text Add to dashboard Cite

show abstract

“…Angus et al [90] developed a model, which can predict pseudo-scalar moments of seismic events for a reservoir in production with two faults. However, they did not consider fracture shear slip during fluid injection (hydraulic fracturing) and consequently could not predict event magnitudes.…”

Section: Modeling Microseismicitymentioning

confidence: 99%

A Review of Numerical Simulation Strategies for Hydraulic Fracturing, Natural Fracture Reactivation and Induced Microseismicity Prediction

Shahid¹,

Fokker²,

Rocca³

2016

TOPEJ

View full text Add to dashboard Cite

Hydraulic fracturing, natural fracture reactivation and resulting induced microseismicity are interconnected phenomena involved in shale gas exploitation. Due to their multi-physics and their complexity, deep understanding of these phenomena as well as their mutual interaction require the adoption of coupled mechanical and fluid flow approaches. Modeling these systems is a challenging procedure as the involved processes take place on different scales of space and also require adequate multidisciplinary knowledge. An extensive literature review is presented here to provide knowledge on the modeling approaches adopted for these coupled problems. The review is intended as a guide to select effective modeling approaches for problems of different complexity.

show abstract

“…This is especially important for modelling reservoir stress path and stress path asymmetry. Furthermore, poroelastoplasticity also enables the prediction of when and where failure occurs in the model, allowing us to model the likely microseismic response of a reservoir (Angus et al 2010.…”

Section: Introductionmentioning

confidence: 99%

Reservoir stress path and induced seismic anisotropy: results from linking coupled fluid-flow/geomechanical simulation with seismic modelling

et al. 2016

Self Cite

View full text Add to dashboard Cite

We present a workflow linking coupled fluid-flow and geomechanical simulation with seismic modelling to predict seismic anisotropy induced by non-hydrostatic stress changes. We generate seismic models from coupled simulations to examine the relationship between reservoir geometry, stress path and seismic anisotropy. The results indicate that geometry influences the evolution of stress, which leads to stress-induced seismic anisotropy. Although stress anisotropy is high for the small reservoir, the effect of stress arching and the ability of the side-burden to support the excess load limit the overall change in effective stress and hence seismic anisotropy. For the extensive reservoir, stress anisotropy and induced seismic anisotropy are high. The extensive and elongate reservoirs experience significant compaction, where the inefficiency of the developed stress arching in the side-burden cannot support the excess load. The elongate reservoir displays significant stress asymmetry, with seismic anisotropy developing predominantly along the long-edge of the reservoir. We show that the link between stress path parameters and seismic anisotropy is complex, where the anisotropic symmetry is controlled not only by model geometry but also the nonlinear rock physics model used. Nevertheless, a workflow has been developed to model seismic anisotropy induced by non-hydrostatic stress changes, allowing field observations of anisotropy to be linked with geomechanical models.

show abstract

Modelling microseismicity of a producing reservoir from coupled fluid‐flow and geomechanical simulation

Cited by 40 publications

References 34 publications

Analysis of time-lapse travel-time and amplitude changes to assess reservoir compartmentalization

Analysis of time-lapse travel-time and amplitude changes to assess reservoir compartmentalization

A Review of Numerical Simulation Strategies for Hydraulic Fracturing, Natural Fracture Reactivation and Induced Microseismicity Prediction

Reservoir stress path and induced seismic anisotropy: results from linking coupled fluid-flow/geomechanical simulation with seismic modelling

Contact Info

Product

Resources

About