Record and interpret microseismic activity during hydraulic fracturing
Analyze hydraulic fracturing performance to improve stimulation effectiveness and well economics.
StimMAP hydraulic fracture mapping service provides fracture monitoring in real time—within 30 seconds of microseismic activity. Based on proprietary coalescence microseismic mapping (CMM) that enables processing more events per minute than would be possible with hand picking, it delivers close agreement for the fracture geometry on the same dataset. The CMM technique provides more events because multiple arrivals can be handled in a single time window.
Understanding fracture geometry is key to effective stimulation treatments and well economics. Microseismic fracture monitoring provides imaging of the geometry of a hydraulic fracture to accurately measure fracture geometry. Accurately measuring the fracture geometry offers precise data on hydraulic fracture systems to increase understanding of the fracturing process. This increased understanding in real time
Direct measurement of hydraulic fracture geometry.
This paper presents an operator’s approach to optimize future well performance by fully integrating all the data captured in the Vaca Muerta shale.
Hydraulic-fracture microseismicity sometimes exhibits fairly uniform radiation patterns, as revealed by systematic patterns of P- and S-wave first motions and amplitude ratios. These patterns suggest a predictable failure condition and allow composite source mechanism information to be obtained from sparse receiver coverage.
Microseismic evidence of fracture complexity has lead to the recent development of new modeling tools to simulate the growth of complex fracture networks. Typically these complex fracture models rely on calibration from microseismic location information, although microseismic source mechanics can also provide additional model verification.
StimMORE fiber-laden diversion fluid treatment saves 10 h and eliminates well interventions in Montney shale.