Imaging Seismic Deformation Induced by Hydraulic Fracture Complexity

Maxwell, Shawn; Waltman, Charles; Warpinski, N.R.; Mayerhofer, Michael; Boroumand, Neda

doi:10.2118/102801-pa

Cited by 76 publications

(22 citation statements)

References 13 publications

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“…The SRV is defined as the portion of the reservoir that is influenced directly by the hydraulic fractures; hence, it is limited to the lateral extent of the hydraulic fractures. It has been reported in the literature that for extremely low permeabilities, the contribution from the reservoir beyond the SRV is negligible (Bello and Wattenbarger 2008;Carlson and Mercer 1989;Fisher et al 2004;Mayerhofer et al 2005Mayerhofer et al , 2006Maxwell et al 2009;Medeiros et al 2008;Ozkan et al 2011). As a result, it is reasonable to assume that the drainage beyond the SRV is insignificant."…”

Section: Basic Modelmentioning

confidence: 99%

Simplified Forecasting of Tight/Shale-Gas Production in Linear Flow

Nobakht

Mattar²,

Moghadam³

et al. 2012

Journal of Canadian Petroleum Technology

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This paper presents a simplified method of production forecasting for tight/shale-gas reservoirs exhibiting extended periods of linear flow, without the use of complex tools (e.g., analytical models or numerical models). The method, which is applicable to hydraulically fractured vertical wells and multifractured horizontal wells, is based on the theory of linear flow and combines the transient linear-flow period with hyperbolic decline during boundary-dominated flow.The dominant flow regime observed in most tight/shale-gas wells is linear flow, which may continue for several years. This linear flow will be followed by boundary-dominated flow at later times. Therefore, the method proposed in this study is applicable for forecasting production data for these wells because it considers these two important flow regimes. Although the derivation is presented for a hydraulically fractured vertical well, this method can be applied both to hydraulically fractured vertical wells and to horizontal wells with multiple fractures. The application of this method to multifractured horizontal wells in the Marcellus and Barnett shale gas is also presented.The method is validated by comparing its results with test cases, which are built using numerical simulation for hydraulically fractured vertical wells. For each case, only the first year of the synthetic production data is then used for the analysis. It is found that there is reasonable agreement between the forecast rates obtained using this method and the numerically simulated rates.

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Section: Basic Modelmentioning

confidence: 99%

Simplified Forecasting of Tight/Shale-Gas Production in Linear Flow

Nobakht

Mattar²,

Moghadam³

et al. 2012

Journal of Canadian Petroleum Technology

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“…A great number of events were recorded, with the activity concentrated in specific regions around the injection wells. For each event, a seismic moment (Maxwell et al 2009) (product of shear modulus, area of slip, and displacement) is a robust measurement of the strength of an earthquake. A moment-magnitude scale (Maxwell et al 2009) is used to describe the moment on a normal logarithmic magnitude scale, nominally analogous to the Richter magnitude scale.…”

Section: Microseismic Resultsmentioning

confidence: 99%

“…In order to compare the seismic and surface deformations, the total cumulative seismic moment [logarithm of seismic moment is proportional to moment magnitude (Maxwell et al 2009)] was computed. Fig.…”

Section: Discussionmentioning

confidence: 99%

Monitoring SAGD Steam Injection Using Microseismicity and Tiltmeters

Maxwell

Du²,

Shemeta³

et al. 2009

SPE Reservoir Evaluation &Amp; Engineering

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A combination of microseismic and surface-deformation monitoring with an array of tiltmeters was used to monitor the warm-up phase of a steam-assisted-gravity-drainage (SAGD) well pair. A sequence of microseismic events was recorded with signal characteristics that suggested deformation associated with thermal expansion of the wellbore, in addition to events apparently associated with induced fracturing in the reservoir. Integration of the microseismic data with volumetric strain, inverted from the measured surface deformation, indicates a discrete deforming region near the toe of the well. The volumetric strain also shows another region near the heel of the well, although the area is too far from the microseismic observation well for any associated microseismicity to be recorded. The central portion of the well pair did not have significant deformation, indicating poor steam conformance during this warm-up phase. A comparison of the temporal response of the microseismic deformation with the surface uplift suggests a lag between periods of accelerated seismic deformation followed by an associated period of accelerated uplift a few days later. This timing suggests the creation of a fracture network and related seismic deformation, which then fills with steam and starts to expand over a period of a few days. In a related paper (Du et al. 2007), stress changes associated with the volumetric strain are used to examine potential geomechanical failure zones that match the observed locations of microseisms. Together, the volumetric strain, computed stress changes, and failure zones could be used to calibrate a geomechanically linked reservoir simulator.

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“…3(a). It is reported in the literature that for extremely low permeabilities, the contribution from the reservoir beyond SRV is negligible (Fisher et al, 2004;Mayerhofer et al, 2005;Maxwell et al, 2009;Medeiros et al, 2008;Ozkan et al, 2011) and as a result, the outer reservoir can be ignored …”

Section: Contribution From Outer Reservoirmentioning

confidence: 99%