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Imaging Seismic Deformation Induced by Hydraulic Fracture Complexity

2006; Linguagem: Inglês

10.2523/102801-ms

Shawn Maxwell, C. K. Waltman, Norman R. Warpinski, Michael Mayerhofer, Neda Boroumand,

NMR spectroscopy and applications

Imaging Seismic Deformation Induced by Hydraulic Fracture Complexity Shawn C. Maxwell; Shawn C. Maxwell Pinnacle Technologies Inc. Search for other works by this author on: This Site Google Scholar Charles Waltman; Charles Waltman Search for other works by this author on: This Site Google Scholar Norman Raymond Warpinski; Norman Raymond Warpinski Pinnacle Search for other works by this author on: This Site Google Scholar Michael J. Mayerhofer; Michael J. Mayerhofer Pinnacle Technologies Inc. Search for other works by this author on: This Site Google Scholar Neda Boroumand Neda Boroumand Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, September 2006. Paper Number: SPE-102801-MS https://doi.org/10.2118/102801-MS Published: September 24 2006 Connected Content Related to: Imaging Hydraulic-Fracture-Induced Seismic Deformation Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Maxwell, Shawn C., Waltman, Charles, Warpinski, Norman Raymond, Mayerhofer, Michael J., and Neda Boroumand. "Imaging Seismic Deformation Induced by Hydraulic Fracture Complexity." Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, September 2006. doi: https://doi.org/10.2118/102801-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Annual Technical Conference and Exhibition Search Advanced Search AbstractMicroseismic mapping is extensively utilized in the Barnett Shale, to map hydraulic fracture complexity associated with interactions of the stimulation with pre-existing fractures. Previous studies have indicated a fair correlation between the well performance and extent of the seismically active volume. However, in addition to this measure of the extent of the stimulated fracture network, the characteristics of this fracture network is also expected to impact the well performance. In particular, the fracture spacing is believed to be important factor controlling the potential gas flow. In this paper, we utilize the density of the total seismic moment release (a robust measure of the microseism strength) as an indication of the seismic deformation that may correlate to the fracture density. The study uses a set of microseismic maps of hydraulic fracture stimulations, including cases where the stimulated reservoir volume measured by the extent of the seismically active region poorly correlated with the well performance. Incorporating the seismic moment density to assess the fracture density with the network extent, an improved correlation with the well performance was observed.IntroductionMicroseismic mapping of hydraulic fracture stimulations has become a common technique to map the fracture growth and geometry1–5. Microseismic images provide details of the fracture azimuth, height, length, and complexity resulting from interaction with pre-existing fratures. The resulting images can be used to calibrate numerical simulations of the fracture growth, allowing more confident modeling of other stimulations in the field, and a better identification of the stimulated region that may ultimately be drained by the well.Arguably, the Barnett Shale is the field that has had the most fracs mapped over the last several years. Microseismic mapping in the Barnett has repeatedly demonstrated extreme fracture complexity resulting from interaction between the injection and a pre-existing fracture network2–6. Even between neighbouring wells, the geometry of the stimulated fracture network shows a high degree of variability due to localized differences in the fracture network2. The Barnett has very low intrinsic matrix permeability, and the permeability enhancement associated with the fracture stimulation results in permeable fracture networks sufficient for economic gas recovery in the field. Previous studies have shown a correlation between the volume of the reservoir that is stimulated, as measured by the volume of the reservoir that emits microseisms during the stimulation, and the production ultimately realized from the well2,4,6. The correlation is attributed to larger fracture networks being stimulated in wells where a large microseismically active volume of the reservoir has been realized, resulting in more permeable fracture pathways connected to the well and hence a higher potential for gas flow to the well. Recently, many operators in the Barnett have attempted horizontal completions, which have allowed large volumes of the reservoir to be stimulated with large fracture networks. Many of these completions use perforated, cemented liners and the microseismic images allow for identification of improved perforation staging to maximize the stimulated reservoir volume (SRV)4.Many of the Barnett stimulations are water fracs, where high volumes of water are injected at high rate7. One possible mechanism for the success of waterfracs is that increased fluid pressure in natural fractures induced shear failure, resulting in fracture dilation associated with mismatched surfaces on opposite sides of the fracture. Within this conceptual framework, the microseismic events correspond to the actual fracture movement. The earlier investigations of the SRV measured the total volume of the microseismically active region. However, this measure of the stimulated volume does not take into account the properties of the fracture network, which has also been indicated to impact well performance6. Furthermore, the permeability enhancement of the fracture may be related to deformation associated with fracturing. Beyond the basic hypocentral locations of the microseisms used to calculate the SRV, additional seismic signal characteristics allow investigation of the source of the mechanical deformation resulting in the microseisms. In particular, the seismic moment8, a robust measure of the strength of an earthquake or microearthquake, can be used to quantify the seismic deformation9. Keywords: Reservoir Characterization, correlation, Upstream Oil & Gas, well performance, hydraulic fracturing, stimulation, hydraulic fracture complexity, SRV, deformation, microseism Subjects: Hydraulic Fracturing, Reservoir Characterization, Seismic processing and interpretation This content is only available via PDF. 2006. Society of Petroleum Engineers You can access this article if you purchase or spend a download.