https://www.math.ubc.ca/~peirce/Computer%20simulation%20of%20HF_Adachi_Siebrits_Peirce_Desroaches_IJRM_MS_V44_p739_2007.pdf

Computer simulation of hydraulic fractures

What Is Stimulated Reservoir Volume

Thirty Years of Gas Shale Fracturing: What Have We Learned?

Modeling of Hydraulic-Fracture-Network Propagation in a Naturally Fractured Formation

/pdf/development-of-an-efficient-embedded-discrete-fracture-model-24f3tauvjl.pdf

Development of an Efficient Embedded Discrete Fracture Model for 3D Compositional Reservoir Simulation in Fractured Reservoirs

Microseismic Imaging of Hydraulic Fracture Complexity in the Barnett Shale

Summary This paper describes the application of ESG Canada's FRACMAP service using induced microseismicity to map the spatial and temporal growth of a series of hydraulic fractures in Carthage, Texas. A series of 10 fracs in 6 UPRC wells were monitored over a period of 21 days in January 2000. For each treatment well, an offsetting production well at a distance between 1000' and 1750' was used as an observation well. A 12-level, triaxial geophone array was deployed just above the reservoir in the observation well. ESG's Hyperion Microseismic System was used to detect induced microearthquakes, archive the seismograms, and automatically compute event locations and source parameters (magnitude, stress and energy release). The real-time microseismic results were then transmitted via a local network to a visualization computer at the frac site, where petroleum engineers could view interactive 4d maps of the frac geometry. During the microseismic monitoring of the treatments, an OYO DAS unit exported SEG-Y files of continuous signals segregated into 4 second blocks of data. The DAS sampled at 2 kHz, with a low-cut filter at 8 Hz and an extented anti-aliasing filter at 750 Hz. The SEG-Y data files were exported from the DAS over a local network to a PC running ESG's acquisition software. Event detection software was used to trigger a microseismic event when the amplitude on a pre-set number of geophones exceededs a specified amplitude within a specified time window. Following a positive event trigger, a 0.5 second seismogram for all the sensors with a suitable pre-trigger window, was archived over the local network to a second processing PC. The SEG-Y files were concatenated together so that events overlapping two files could be still be detected. The processing PC applied automated picking algorithms to determine the arrival time of the P- and S-waves of the seismograms for each triaxial level. Hodogram analysis of the spacially oriented triaxial geophone packages was also automatically applied. Figure 1 shows an example of the seismograms recorded on the different levels of the array, with different components of the triaxials plotted in a different colour. This seismogram exhibits excellent signal-to-noise and the automated arrival time picks clearly identify the onset of both the P- and S-waves. Event locations were automatically determined based on the arrival times and automated hodogram analysis of the azimuth of the event. Source parameters (moment magnitude, seismic moment, source radius, P- and S-wave seismic energy release and static stress drop) were also automatically determined. A data visualization package displayed the event locations, with highlighted displays of the latest activity during the previous few minutes. As new events were processed, the automatic data was quality controlled by verifying the arrival times and hodogram, before sending the data to a visualization computer at the frac site, where petroleum engineers could view interactive 4d maps of the frac geometry.

Real-Time Microseismic Mapping of Hydraulic Fractures In Carthage, Texas

Passive seismic imaging is used to map the development of hydraulic fractures in relatively non-fractured and naturally fractured reservoirs. The images obtained for multiple stimulations throughout the U.S. identified non-complex preferential fracture growth patterns with constrained permeability enhanced pathways, lithologically controlled symmetric and asymmetric hydraulic fractures, and complex fracture patterns associated with fluid-flow along pre-existing fault networks. In this paper, we examine these observations in the context of establishing effective field drainage through optimal well placement.

https://www.esgsolutions.com/sites/esgsolutions.com/files/resource/2002_seg-assessing_hydraulic_fracture_effectiveness.pdf

Assessing the Effectiveness of Hydraulic Fractures With Microseismicity

Microseismic Imaging of Hydraulic Fracture Complexity in a Naturally Fractured Reservoir

Summary Seismic events recorded during the hydrofrac of three zones of a deep gas well in the Cotton Valley formation are reported upon. Several thousand events were detected from three production fracs and a subset of these were located in the field. Induced fractures were observed to be longer than the predicted 750’-850’, with most of that length occuring early in the treatment. Asymmetric growth along the predicted fracture direction was documented, with one of the fracs appearing to have broken through a shale above the perforated interval.

R. Zinno

Papers

Microseismic Imaging of Hydraulic Fracture Complexity in the Barnett Shale

Real-Time Microseismic Mapping of Hydraulic Fractures In Carthage, Texas

Assessing the Effectiveness of Hydraulic Fractures With Microseismicity

Microseismic Imaging of Hydraulic Fracture Complexity in a Naturally Fractured Reservoir

Siesmic imaging of Cotton Valley hydraulic fractures