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Integrating Fracture Diagnostics and Engineering Data in the Marcellus Shale

Michael Mayerhofer¹, Dion Billard¹, Neil Stegent¹, James Barth², and Kevin Ryan²
¹Pinnacle a Halliburton Service, [email protected]; [email protected]
²Seneca Resources, [email protected]

The paper presents an integrated engineering study from a group of Marcellus shale horizontal wells. The offset wells were completed in sequential fashion with pre-planned fracture and reservoir diagnostics to better understand completion and stimulation efficiency, effective fracture lengths and drainage patterns given a certain well spacing in the Marcellus shale. The insights were gained by integrating microseismic fracture mapping, diagnostic fracture injection tests (DFIT’s), downhole pressure gauges to monitor well communication, post-frac pressure transient analysis, chemical tracers and production data.

Microseismic fracture mapping was performed during the completion of two offset horizontal wells. Since the two wells were completed sequentially it was possible to deploy downhole pressure gauges in one well while the offset well was being completed. This allowed for the unique opportunity to monitor potential communication between the two wells and correlate with the overlap of microseismic activity. The pressure gauges were also used to monitor post-frac buildups in both wells.

The integration of various engineering data allowed for interesting conclusions with respect to effective fracture length, correlation of microseismic events with actual hydraulic fracture communication, and production interference. These insights provide important information for optimizing infill drilling, well placement and fracture completion strategies in the Marcellus Shale.


AAPG Search and Discovery Article #90154©2012 AAPG Eastern Section Meeting, Cleveland, Ohio, 22-26 September 2012