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Collaborating Authors
Results
Evaluation of Effective Drainage Height through Integration of Microseismic and Geochemical Depth Profiling of Produced Hydrocarbons
Maxwell, Shawn (Ovintiv) | Brito, Richard (Ovintiv) | Ritter, Geoff (Ovintiv) | Sinclair, John (Ovintiv) | Leavitt, Aaron (Ovintiv) | Liu, Faye (Revochem) | Bachleda, Jana (Revochem)
Abstract This study integrates microseismic hydraulic fracture mapping with geochemical production profiling to understand the interaction between mechanical stratigraphy, fracture geometry, and effective drainage for wells landed in different benches of the STACK play in Oklahoma. Microseismic monitoring was used to map the extents of the hydraulic fracture system contacted during stimulation, while high resolution geochemical analysis or ‘fingerprinting’ was used to assess how different formations in the reservoir were draining. Microseismicity showed that hydraulic fracture growth from an Upper Meramec well rapidly cover the entire Meramec interval with some growth downward into the Woodford. Conversely, microseismicity initiating from a Woodford well clustered in that layer and grew upward into the Lower Meramec with time. Geochemical profiling closely matched the microseismic depth distributions for the associated well landing zones. Similar to the microseismic hydraulic heights from both Upper and Lower Meramec wells consistently produced from the entire Meramec, with additional recovery from the Woodford. Woodford landed wells produced Woodford oil with some production also coming from the Lower Meramec, also consistent with the microseismic depths. These production profiling trends were found to be very consistent across multiple sets of wells drilled into the same target formations. Integrating mapping of hydraulic fracture growth with geochemical assessment of the effective drainage within the hydraulically contacted zones provides unique insights into the reservoir contact and drainage. Understanding the mechanical stratigraphic controls on hydraulic fracture height growth relative to the reservoir drainage is key to informed decisions on wine-rack configurations for optimal reservoir drainage.
- North America > United States > Texas (1.00)
- North America > United States > Oklahoma > Kingfisher County (0.35)
- North America > United States > Oklahoma > Canadian County (0.25)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.69)
- North America > United States > Texas > Permian Basin > Midland Basin (0.99)
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > Texas > Marietta Basin (0.99)
- (14 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
The 6 Injection Induced Seismicity Workshop, hosted by SEG and the Society of Petroleum Engineers, was held 7–9 June 2022 in Austin, Texas. The workshop series has provided the opportunity for important dialogue among induced-seismicity practitioners and subject-matter experts. The Austin workshop was no exception. The venue location underscored the importance of the increasing occurrence of induced seismicity in the Permian Basin.
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.48)
- Geology > Geological Subdiscipline (0.47)
- Energy > Oil & Gas > Upstream (1.00)
- Law (0.95)
- Government > Regional Government > North America Government > United States Government (0.48)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
Fault Reactivation and Induced Seismicity During Multistage Hydraulic Fracturing: Microseismic Analysis and Geomechanical Modeling
Zhang, Fengshou (Tongji University) | Yin, Zirui (Tongji University) | Chen, Zhaowei (CNPC Engineering Technology R&D Company Limited) | Maxwell, Shawn (MaxSeis LLC) | Zhang, Lianyang (University of Arizona) | Wu, Yinghui (Silixa Ltd.)
Summary This paper presents a case study of fault reactivation and induced seismicity during multistage hydraulic fracturing in Sichuan Basin, China. The field microseismicity data delineate a fault activated near the toe of the horizontal well. The spatio-temporal characteristics of the microseismicity indicate that the seismic activity on the fault during the first three stages is directly related to the fluid injection, while after Stage 3, the seismic activity is possibly due to the relaxation of the fault. The fault‐related events have larger magnitudes and different frequency‐magnitude characteristics compared to the fracturing‐related events. Three‐dimensional (3D) fully coupled distinct element geomechanical modeling for the first two hydraulic fracturing stages and a shut‐in stage between them is performed. The modeling result generates features of microseismicity similar to that of the field data. The energy budget analysis indicates that the aseismic deformation consumes a major part of the energy. The simulated fault shear displacement is also consistent with the casing deformation measured in the field. The model is also used to investigate the impact of possible operational changes on expected seismic responses. The results show that lower injection rate and lower fluid viscosity would be helpful in reducing casing deformation but not in mitigating seismicity. Decreasing the total fluid injection volume is an effective way to mitigate the seismicity, but it may hinder the stimulation of the reservoir formation and the production of the well.
- North America > United States > California (0.46)
- Asia > China > Sichuan Province (0.35)
- North America > United States > Texas (0.28)
- Research Report > New Finding (0.67)
- Research Report > Experimental Study (0.48)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.48)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
The 2017 edition of the Unconventional Resources Technology Conference (URTeC) took place 24–26 July in Austin, Texas. URTeC is an event focused on the latest science and technology applied to the exploration, appraisal, analysis, and development of unconventional resources. URTeC, cosponsored by SEG, the American Association of Petroleum Geologists, and the Society of Petroleum Engineers, provides a showcase for integrated geoscience and engineering technology for unconventional resources.
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (6 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (0.56)
ABSTRACT As regulators introduce operational protocols based on seismic magnitudes occurring during hydraulic fracturing, operation strategies are required to mitigate the seismic hazard. In certain cases, pressure increases associated with the hydraulic fracture injection, can induce slip of tectonically stressed faults leading to triggered seismicity. A coupled hydrogeomechanical model is used here to examine fault activation during multi-stage hydraulic fracturing and to examine operational scenarios. The model shows that the relative stage sequencing relative to the direction of fault slip can significantly impact the fault slip. Changing the viscosity of the fracturing fluid is also explored as an operational mitigation scenario, which is found to have a strong impact on fault slip and associated seismic magnitudes. Presentation Date: Tuesday, September 26, 2017 Start Time: 11:25 AM Location: 362D Presentation Type: ORAL
- Geology > Structural Geology > Fault (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (0.69)
Abstract Bed-parallel fracture slip (BPFS) is a mechanism increasingly promoted to explain shear-induced microseismicity during the growth of a tensile hydraulic fracture in shales. Strong evidence for this particular microseismic mechanism comes from a variety of microseismic projects. Much of this evidence is based on geophysical investigation of microseismic fault-plane solutions, with interpretations relying on conceptual models and geological analogs. Understanding microseismic mechanisms is critical to quantitatively link the microseismicity with the hydraulic fracture geometry, and ultimately to extract maximal value from the monitoring data. In this paper, we explore reservoir geomechanical conditions leading to BPFS using a coupled hydraulic-mechanical simulation. BPFS was found to be the primary source mechanism of microseismicity detected during Wolfcamp hydraulic fracture stimulations. A hydraulic-geomechanical simulation was used to investigate fracture network growth and the associated microseismic response characteristics. A minor amount of slip was found in a scenario when only bed-parallel, pre-existing fractures were included. However, the microseismic intensity is not sufficient for these events to be detected in the field and are restricted to a region where the hydraulic fracture crossed a change in fracture gradient. Inclusion of pre-existing vertical fractures along with the bed-parallel resulted in microseismically detectable BPFS. Sensitivity studies of changing various geomechanical attributes of the reservoir, indicate most factors that promote Coulomb slip conditions promote a BPFS microseismic mechanism. Introduction Microseismic monitoring is a common imaging technique to map hydraulic fracture growth in unconventional reservoirs. During hydraulic fracture growth, microseismicity is generated as the hydraulic fracture interacts with pre-existing fractures, causing slip and associated microseismic sources. Observing the location and timing of the microseismicity provides an ability to understand the hydraulic fracture growth and is often interpreted to describe the fracture characteristics and geometry. Interest in microseismic source mechanisms is increasing as the source mechanism provides additional information about the microseismic sources. Source mechanism studies range from fault-plane solutions that use "beach-ball diagrams" to represent the fracture orientation and sense of shear slip on the surface, to full moment tensor inversion that estimate the full range of potential source deformation including opening along with shearing (e.g., Maxwell, 2014). In certain cases, source mechanisms have identified slip on bed-parallel fractures (BPFS) as a predominant microseismic mechanism (e.g., Rutledge et al., 2013, Rutledge et al., 2015). Interpretations are often focused on conceptual models and geological analogs.
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Summary We present a case study of hydraulic fracturing treatments for two horizontal wells located in the Horn River Basin, B.C. The wells were completed using a technique that we refer to as Short Interval Re-injection (SIR). For each individual treatment stage, this technique makes use of an initial injection interval using conventional hydraulic fracturing pumping procedures, followed by a "soaking" period that may last from a few hours to about one day in duration, during which the well is temporary shut in. This is followed by a subsequent re-injection interval with a pumping schedule similar to the first interval. Several commercial names are in use to describe this type of approach, which has a desired goal of enhancing the overall effectiveness of the treatment. In this study, we observe a significant increase in the rate of microseismic activity that occurs after the initial soaking period. This type of response has been documented previously and, in some cases, has been empirically related to increased production for wells. We postulate that cohesion of pre-existing fractures is reduced by the initial injection and soaking period, facilitating reactivation of fractures during the second injection. A numerical model has been developed using the software 3DEC in which the cohesion parameter for a discrete fracture network (DFN) is set to zero after the first injection stage. Preliminary results produce a satisfactory match with respect to increased events. Future work will include adjustments to the DFN in order to increase the match with the spatial locations. Introduction The Horn River Basin (HRB) is an important resource play in northeastern British Columbia, Canada. While conventional oil and gas developments have been underway in the HRB for several decades, since 2005 operators have targeted the large shale resources that are in place.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Petroleum Play Type > Unconventional Play (0.88)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (10 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Management > Energy Economics > Unconventional resource economics (1.00)
Microseismic geomechanical interpretation of asymmetric hydraulic fractures
Maxwell, Shawn (IMaGE) | Chorney, Drew (IMaGE) | Smith, Mike (IMaGE) | Mack, Mark (IMaGE)
ABSTRACT A case study is presented of using a geomechanical simulation of hydraulic fracturing in the Montney shale to interpret microseismicity. The model replicates apparent fracture asymmetry between fracturing stages, and points to a single, primary fracture activating proximal pre-existing fractures. Proppant is estimated to be distributed is estimated to be distributed through the long primary fracture. The microseismically validated model can then be used to explore alternate engineering designs to optimize the propped reservoir contact. Presentation Date: Tuesday, October 18, 2016 Start Time: 11:35:00 AM Location: 144/145 Presentation Type: ORAL
- North America > Canada > British Columbia (0.35)
- North America > Canada > Alberta (0.35)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
ABSTRACT A laboratory experiment was performed to characterize a hydraulic fracture created in rock samples subjected to various stress states. Hydraulic fracture geometries were determined using a µCT scan and compared to recorded acoustic emissions (AE) with moment magnitudes smaller than -7. The experiment found that more planar fracture geometries were created at higher levels of differential stress, and that the associated number of AE was reduced. Geomechanical modeling of the hydraulic fracturing surfaces was able to reproduce similar fracture geometries, and the model estimated AE were consistent with the AE observations. Laboratory hydraulic fracturing provides a controlled setting to understand the influence of geomechanical factors controlling fracture networks, providing a unique opportunity to understand the context of passive seismic observations. Presentation Date: Wednesday, October 19, 2016 Start Time: 10:45:00 AM Location: 167 Presentation Type: ORAL
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Geomechanical modeling of microseismic depletion delineation
Mack, Mark (Itasca IMaGE) | Zhang, Frank (Itasca IMaGE) | Lee, BT (Itasca IMaGE) | Maxwell, Shawn (Itasca IMaGE) | Dohmen, Ted (Hess) | Cipolla, Craig (Hess)
ABSTRACT We verify the concept of Microseismic Depletion Delineation via geomechanical modeling which produces synthetic microseismic events similar to those observed in the field. Microseismic geomechanics is a powerful interpretation tool for microseismic imaging of hydraulic fracturing for various conditions of pressure depletion. In cases of induced fracture interactions with previously produced regions, significant changes in the geomechanical conditions can lead to complex fracturing and microseismic patterns. The microseismic patterns can be understood and interpreted using microseismic geomechanics. Presentation Date: Tuesday, October 18, 2016 Start Time: 8:00:00 AM Location: 143/149 Presentation Type: ORAL
- North America > Canada > Saskatchewan > Williston Basin > Bakken Shale Formation (0.99)
- North America > Canada > Manitoba > Williston Basin > Bakken Shale Formation (0.99)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)