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Combining Microseismic Hydraulic Fracture Monitoring, Petrophysical Evaluation and New Analytical Techniques to Improve Reservoir Management

Joel Le Calvez1, Tom Creegan2, Robert Tehan2, Kevin Tanner1, Roy Yates1, Leo Eisner3, Rick Lewis1, and Les Bennett4
1Schlumberger, 1700 Research Parkway, College Station, Texas 77840
2Dominion Exploration and Production, Inc., 14000 Quail Springs Parkway, Suite 600, Oklahoma City, Oklahoma 73134
3Schlumberger, High Cross, Madingley Road, Cambridge CB30EL, United Kingdom
4Schlumberger, 6601 Broadway, Oklahoma City, Oklahoma 73116

Proper characterization of the created fracture geometry is essential to the effectiveness of any stimulation program. We present the results of a multistage microseismic hydraulic fracture monitoring campaigns performed during 2004 on a Dominion Exploration and Production, Inc.'s producing well in a mature, tight gas field in south Texas.

The objective of the initial microseismic monitoring surveys was to determine the overall geometry of the hydraulically-induced fractures in a six-stage completion interval as part of a completion optimization program. Newly developed techniques (e.g., full-waveform moment tensor inversion and multiplet analysis) help describe geological relationships between induced microseismic events.

All available geological and petrophysical data pertaining to both the monitor and treatment wells are integrated with a vertical seismic profile to develop a robust calibrated velocity model, which leads to the accurate processing of the microseismic data acquired during the hydraulic fracturing operation. Interpretation of the microseismic data illustrates unique geometries in each of the fracture stages. These include larger-than-anticipated fracture heights generated in some stages while others demonstrate good vertical containment, as well as a situation in which all stages are oriented along the same azimuth. While no stage achieved the designed length, several stages exhibit asymmetric wing propagation. We show how these techniques, in addition to traditional petrophysical evaluation, fracture models and prorated production-rate transient analyses, improve our understanding of natural and hydraulic fracture systems. These observations led to suggest changes in (a) drilling pattern and (b) completion methodology (e.g., fracturing fluids, injection rate, etc.).


AAPG Search and Discovery Article #90080©2005 GCAGS 55th Annual Convention, New Orleans, Louisiana