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Results
Calibration of Continuous Wavelet Transform for Dynamic Hydraulic Fracture Propagation with Micro-Seismic Data: Field Investigation
Gabry, Mohamed Adel (Petroleum Engineering Department, University of Houston, Houston, Texas, USA) | Gharieb, Amr (Apache Egypt Corp., Cairo, Egypt) | Soliman, Mohamed Y. (Petroleum Engineering Department, University of Houston, Houston, Texas, USA) | Cipolla, Craig (HESS Corp., Houston, Texas, USA) | Farouq-Ali, S. M. (Petroleum Engineering Department, University of Houston, Houston, Texas, USA) | Eltaleb, Ibrahim (Petroleum Engineering Department, University of Houston, Houston, Texas, USA)
Abstract The aim of this study is to investigate the potential of the Continuous Wavelet Transform (CWT) as a mathematical tool for improving the understanding of hydraulic fracture propagation mechanisms and evaluating interactions between fractures and formation. The study examines one of the CWT techniques: the normalized scalogram technique for understanding fracture propagation. However, the implementation of these techniques requires calibration using observed measured variables, such as microseismic events. To overcome this obstacle, micro-seismic events, and pressure data recorded in wells are used to calibrate the normalized CWT scalogram. The objective of this study is to validate the effectiveness of these approaches as cost-effective techniques for understating the fracture propagation modes in scenarios where micro-seismic events are not available. The Continuous Wavelet Transform (CWT) is a powerful mathematical technique that can be used for analyzing hydraulic fracturing data. It involves convolving a short wavelet signal with the measured pressure data in a smooth and continuous manner, applying various dilation and translation operations to produce a scaled representation of the pressure data. This process acts as a local microscope, enhancing the high-frequency information in the pressure signal. The resulting CWT scalogram is normalized to represent fracturing pressure data, which can provide valuable insights into treatment propagation. However, a major challenge in implementing these techniques is the need for calibration using observed measured variables, such as microseismic events. To address this issue, microseismic data recorded in the Bakken was used to calibrate the normalized CWT scalogram. The objective of this study was to validate the effectiveness of this approach as a cost-effective alternative for dynamic fracture events detection in cases where microseismic events are not available. The validation of the normalized CWT scalogram was carried out by calibrating against microseismic events recorded in the Bakken. This confirmation was established by assessing the correlation between fracture events detected by microseismic events and those observed using the normalized CWT scalogram. This paper validates the application of normalized CWT scalograms for understanding fracture propagation modes. These techniques offer a cost-effective approach to optimizing hydraulic fracturing in unconventional reservoirs.
- North America > United States > North Dakota (0.94)
- North America > Canada (0.94)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Three Forks Group Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > Montana > 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)
A Real-Time Inversion Approach for Fluid-Flow Fractures in Unconventional Stimulated Reservoirs
Sheng, Guanglong (Hubei Key Laboratory of Drilling and Production Engineering for Oil and Gas, Yangtze University / School of Petroleum Engineering, Yangtze University) | Zhao, Hui (Hubei Key Laboratory of Drilling and Production Engineering for Oil and Gas, Yangtze University / School of Petroleum Engineering, Yangtze University (Corresponding author)) | Huang, Luoyi (Hubei Key Laboratory of Drilling and Production Engineering for Oil and Gas, Yangtze University / School of Petroleum Engineering, Yangtze University (Corresponding author)) | Huang, Hao (Hubei Key Laboratory of Drilling and Production Engineering for Oil and Gas, Yangtze University / School of Petroleum Engineering, Yangtze University) | Liu, Jinghua (Hubei Key Laboratory of Drilling and Production Engineering for Oil and Gas, Yangtze University / School of Petroleum Engineering, Yangtze University)
Summary Fluid-flow fractures, through which fluids can move under pressure, make a more significant contribution to increasing production than do microseismic and propagation fractures. An accurate description of the distribution of fluid-flow fractures is the basis for evaluating hydraulic fracturing and oil/gas recovery. In this study, a real-time inversion approach for fluid-flow fractures was proposed, and the complex fluid-flow fracture morphology was obtained in real time by updating the data of the fracturing construction curve. First, a dynamic permeability model was proposed to describe the filtration rate of the fracturing fluid during hydraulic fracturing. Combined with the point source function, the flowing bottomhole pressure (pwf) can be quickly calculated based on the fracture morphology and displacement of the fracturing fluid. The variance of pwf and bottomhole pressure (pwb) obtained by pump pressure were used as an objective function, and the length of fluid-flow fractures and fracture morphology were used as fitting parameters. The length of the fluid-flow fractures was updated with the simultaneous perturbation stochastic approximation (SPSA) to achieve a rough fitting of the bottomhole pressure. On this basis, a probability function was used to constrain the randomness of the fractures, and the fracture morphology with a fixed fracture length was continuously simulated and finely matched. Finally, a complex fluid-flow fracture morphology was obtained. The method was used to analyze the fluid-flow fracture morphology of multifractured horizontal wells in shale reservoirs, and the fitting rate of the fracturing construction curve was more than 95%. The results show that the total length of the fluid-flow fractures in one stage in naturally fractured reservoirs was approximately 629 m, and those in homogeneous reservoirs and high-stress difference reservoirs were 564 m and 532 m, respectively. The length of fluid-flow fractures with โgroovesโ in the fracturing construction curve was longer than the length of fluid-flow fractures with โbulges.โ The effectively stimulated reservoir area with fluid-flow fractures was only approximately 28โ51% of the stimulated reservoir area with microseismic fractures.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.49)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- North America > United States > Texas > Permian Basin > Midland Basin (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- (3 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- (5 more...)
Analysis of Re-Fracturing Effect of Horizontal Wells in Jimsar Shale Oil Field
Zhao, Kun (Xinjiang Oilfield Company, CNPC) | Lu, Linmao (Xinjiang Oilfield Company, CNPC) | He, Yongqing (Xinjiang Oilfield Company, CNPC) | Li, Zeyang (Xinjiang Oilfield Company, CNPC) | Ren, Guangcong (China University of Petroleum (Beijing)) | Ma, Xinfang (China University of Petroleum (Beijing)) | Duan, Guifu (Research Institute of Petroleum Exploration and Development, CNPC)
Abstract As the low permeability and porosity, some severe problems including rapid production decline and low recovery ratio usually occur in Jimsar Shale Oil Field. Re-fracturing of horizontal wells is a good treatment to improve oil production and recovery ratio by enlarging the contact area between the wellbore and reservoir. Therefore, the field tests of horizontal well re-fracturing were carried out in Jimsar shale oil reservoir. However, it varied in effect. In this paper, based on the engineering parameters of primary fracturing, a fuzzy evaluation model was established firstly to quantify the potentiality of candidate horizontal wells for re-fracturing. For the test wells, a production history match was completed using reservoir numerical simulation method and the oil saturation before re-fracturing was obtained. By comparing the location of high-saturation area and new perforation, rationality of re-fracturing stages selection is determined. Finally, comprehensively using fracturing pressure and microseismic data, the initiation and propagation areas re-fractured was obtained, which showed the location of new fractures. Above all, the reason for poor re-fracturing effect is analyzed. The results show that quantitative index of each test well ranks low among the candidate wells, which means the test wells have the low potentiality to be re-fractured. For the test wells, numerical simulation results show that new perforations of re-fracturing are not located in high-oil-saturation area. The fracturing pressure of re-fracturing stages is generally smaller than primary fracturing, and the microseismic event locates in highly depleted area, which means large quantities of fluid flow into primary fractures and few new fractures are created during re-fracturing.
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.85)
- Asia > China > Shanxi > Ordos Basin > Changqing Field (0.99)
- Asia > China > Shaanxi > Ordos Basin > Changqing Field (0.99)
- Asia > China > Ningxia > Ordos Basin > Changqing Field (0.99)
- (2 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Re-fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
- (2 more...)
Multi-Pronged Diagnostics with Modeling to Improve Development Decisions-An Operator Case Study
Kerr, Erich (SM Energy Company) | Haustveit, Kyle (Devon Energy) | Scofield, Reid (SM Energy Company) | Estrada, Erick (SM Energy Company) | Johnson, Andrew (SM Energy Company) | Galuska, Scott (SM Energy Company) | Haffener, Jackson (Devon Energy) | Landry, Miles (SM Energy Company)
Abstract The drive for capital efficiency in unconventionals has encouraged operators to understand subsurface interactions as effectively as possible. Combining multiple types of new and proven field technology systematically with advanced fracture modeling tools has led to continued improvements in field testing, understanding, and acreage development. Careful selection and application of these tools and technologies to understand subsurface characteristics and responses is a high priority when determining how to improve the net asset value. Diagnostic and modeling results will be integrated together to show how these learnings, when combined appropriately, equate to a sum greater than their parts. Several field case studies will be provided to illustrate the benefits of the multi-pronged diagnostics with modeling approach. Fiber optic strain monitoring and Sealed Wellbore Pressure Monitoring (SWPM) tests will be combined and performed across multiple wellbore distances with multiple fracture design tests. Results will then be analyzed to understand fracture growth characteristics by using a hydraulic fracture simulator capable of convective particle transport, multi-fracture stress and strain shadowing, and complex fluid rheology. Select results will then be coupled with concurrent diagnostics that include microseismic, formation imaging, and casing caliper data to show how hydraulic fracturing interactions occur dynamically in the subsurface. The geomechanics models will then be used to inform stage and cluster level details derived from field diagnostics that include stimulation and production performance behaviors, which incorporate combined non-Darcy and multi-phase flow impacts. Technologies will include erosion imaging diagnostics and permanent fiber optic warmback results. Finally, a cluster-level analysis with downhole fiber optics strain data will be analyzed in conjunction with SWPM to inform subsurface dynamics and show how fracture treatment design optimization may be achieved by combining field learnings with the modeling. These case studies are summarized to show how proper geomechanics modeling, application of field data, collection of the necessary diagnostics, and testing methods are used together to effectively improve completion designs, well spacing configurations, field diagnostics, and real-time stimulation and post-stimulation production analyses.
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.51)
- North America > United States > Wyoming > Wind River Basin (0.99)
- 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)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- (9 more...)
- Information Technology > Modeling & Simulation (1.00)
- Information Technology > Communications > Networks (0.90)
Impact of Completion Design on Various Infill Scenarios: A Data Driven Permian Case Study
Darneal, Chad (ConocoPhillips Company) | Friehauf, Kyle (ConocoPhillips Company) | McLin, Kristie (ConocoPhillips Company) | Rajappa, Bharath (ConocoPhillips Company) | Zhou, Hui (ConocoPhillips Company) | Hoang, Phuong (ConocoPhillips Company) | Hammond, Justin (ConocoPhillips Company) | Swan, Herbert (ConocoPhillips Company)
Abstract An ongoing challenge in unconventional reservoirs is the significant production degradation (loss of production) realized from child wells drilled adjacent to depleted parent wells. One strategy hypothesized to reduce the realized degradation is to modify the completion design in the child well. The main objective of this case study will be to test this hypothesis and quantify the impact completion design has on child well degradation; specifically, the case focuses on the stage architecture component of completion design defined as the combination of cluster spacing, number of clusters per stage, and stage length. This paper covers an integrated, multi-disciplined review of a unique development situation in the Permian where three different depletion scenarios surround a single well at various well spacings. This data rich review will characterize the SRV (Stimulated Rock Volume) and DRV (Drained Rock Volume) from each of four completion designs within the different depletion scenarios. Data sets include fiberoptic DAS/DTS (Distributed Acoustic/Temperature Sensing) and microseismic during stimulation, along with downhole pressure gauges, chemical tracers, downhole camera for perforation erosion, additional fiber-optic DAS/DTS production logs, and interference (well communication) tests. A single well with four different completion designs surrounded by three different depletion scenarios creates a rare opportunity to analyze the impact completion design has on child well degradation. Eight different forms of data acquisition technologies were used to increase understanding of completion variable impacts to SRV and DRV as well as validate several new cost-effective data acquisition technologies that were successfully trialed for this pilot. The SRV-related data shows fracture interference with offset depletion, but the amount of interference did not conclusively change among the various completion designs tested. Similarly, DRV-related data shows child well degradation when exposed to parent well depletion, but the amount of degradation did not conclusively change among the various completion designs tested. This suggests that factors other than stage architecture are the dominant drivers of well performance. Detailed analysis from the cross-functional team provides multiple perspectives on the results acquired as they pertain to the overall motivating objectives of the pilot.
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Selection and Design (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (6 more...)
- Information Technology > Communications > Networks (0.50)
- Information Technology > Artificial Intelligence (0.34)
Application of brittleness index to interpret microseismic event distribution in a hydraulically fractured shale formation
Li, Dewei (China University of Mining and Technology-Beijing) | Yang, Ruizhao (China University of Mining and Technology-Beijing) | Meng, Lingbin (China University of Mining and Technology-Beijing) | Li, Wang (China University of Mining and Technology-Beijing)
Abstract Many factors can impact the location data of microseismic events, including natural fractures, rock lithology, in situ stress, and hydraulic-fracturing parameters. The distribution of microseismic events generally tends toward highly brittle areas or areas with brittle minerals. Moreover, location data of microseismic events lack effective evaluation methods. Therefore, we have developed a method to use lithologic information and prestack seismic data to explain the distribution of well Tian Xing microseismic events. We have analyzed the brittleness of the target formation through the well logs and core. We inverted the Youngโs modulus and Poissonโs ratio based on simultaneous amplitude variation with offset inversion by the prestack seismic data. We then computed the 3D brittleness index (BI) property volume by Grieser and Rickmanโs method. In addition, the microseismic event distribution and BI map were then combined to show the internal relationship between the two results. We found that the well logs and core analysis demonstrated that the target formation has high brittleness. Generally, areas with more natural fractures have a higher probability of inducing hydraulic fractures. However, the analysis results show that the BI has an impact on the distribution of hydraulic fractures. Therefore, BI explains the reason for the distribution of almost all events in the northeast of the perforation. These observations also supported the concept that microseismic events preferentially grow toward more brittle areas.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Mississippi > East Gulf Coast Tertiary Basin > Tuscaloosa Marine Shale Formation (0.99)
- North America > United States > Louisiana > East Gulf Coast Tertiary Basin > Tuscaloosa Marine Shale Formation (0.99)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
In the Permian Wolfcamp shale formation in west Texas, density fields of microseismic events were mapped in four dimensions and variations were noted in the geometry of the hydraulic stimulation as well as in the development of pressure away from the perforations. In addition to aiding well-spacing decisions, these data were used to study individual-well geometries and compare variations in the microseismic response between adjacent wells. The data sets demonstrate that high-fidelity microseismic data can be acquired by use of downhole tractored and multiobservational well-imaging techniques to understand stimulations and the stress fields better as indicated by microseismic data. The data are called high-fidelity because, in general, they are excellent data that are consistent and conform to standard understandings of stimulations. Beyond the robustness in event counts, the data typically have a high signal/noise ratio with high-quality waveforms for picking and consistent hodograms across the tools within the array.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.92)
- Geology > Geological Subdiscipline (0.73)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.62)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Abstract This paper introduces a 3D hydraulic fracturing propagation model (3D-HFPM) for evaluating fracture extension, geometry, stress response, fracture spacing, and potential for refracturing. The model is illustrated with data of the Horn River shale of Canada. The model is developed using a combination of finite element method (FEM) and boundary element method (BEM) for evaluating fluid-flow, fracture deformation, and stress change in the reservoir. The model is calibrated using a limited amount of microseismic observations and recreate the fracture network when microseismic data are unavailable. An adapting meshing algorithm is incorporated to improve the capacity of the model to handle large and complex fracture networks such as the ones found in low permeability reservoirs. The continuity of fracture propagation and fluid leak-off during stimulation may be high enough to connect different production intervals and to create interference between stages, especially in wells with small path fracture spacing and multi-level completions. The comparison between the propagation model and microseismic data shows good agreement as the number of events increases as the fracture propagates into the reservoir. However, using only microseismic data to calculate the extension of the hydraulic fracture results in an overestimation of the fracture length. The model quantifies the altered stress zone, which is helpful to determine possible fracture reorientation and spacing. The evaluation of stress shadow and fracture reorientation reveals the advantages of refracturing using new over old perforations. The operation restores fracture conductivity and increases the fracture network as well as the drainage areas leading to an economic operation. The model improves the characterization of the Stimulated Reservoir Volume (SRV) in tight and shale reservoirs in those cases where microseismic data are scarce. Furthermore, the model is a viable tool for evaluating potential refracturing candidates.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.70)
- North America > United States > California > Sacramento Basin > 2 Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Horn River Basin > Otter Park Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Horn River Basin > Muskwa Field > Muskwa Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Horn River Basin > Horn River Shale Formation (0.99)
- 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)
Microseismic monitoring using a fiber-optic distributed acoustic sensor array
Verdon, James P. (University of Bristol) | Horne, Steve A. (Chevron Energy Technology Company, Lytt) | Clarke, Andrew (Silixa Ltd.) | Stork, Anna L. (University of Bristol, Silixa Ltd.) | Baird, Alan F. (University of Bristol) | Kendall, J.-Michael (University of Bristol)
ABSTRACT We have developed a case study demonstrating the use of an โLโ-shaped downhole fiber-optic array to monitor microseismicity. We use a relatively simple method to detect events from continuous waveform data, and develop a workflow for manual event location. Locations are defined with a cylindrical coordinate system, with the horizontal axis of the distributed acoustic sensing (DAS) cable being the axis of symmetry. Events are located using three manual โpicks,โ constraining (1)ย the zero-offset โbroadsideโ channel to the event, (2)ย the P-S-wave arrival time difference at the broadside channel, and (3)ย the angle of the event from the array. Because the 1C DAS array is unable to record P-wave energy on the broadside channel, the P-wave pick is made indirectly by ensuring that the modeled P- and S-wave moveout curves match the observed data. The angle requires that signal is observed on the vertical part of the array; in our case, this is possible because an engineered fiber, rather than standard telecommunications fiber, provided a significant reduction in the noise level. Because only three picks need to be made, our manual approach is significantly more efficient than equivalent manual processing of downhole geophone data, in which picks for P- and S-waves must be made for each receiver. We find that the located events define a tight cluster around the injection interval, indicating that this approach provides relatively precise and accurate event locations. A surface microseismic array was also used at this site, which detected significantly fewer events, the locations of which had significantly greater scatter than the DAS array locations. We conclude by examining some other aspects of the DAS microseismic data, including the presence of multiple events within very short time windows, and the presence of converted phases that appear to represent scattering of energy from the hydraulic fractures themselves.
- North America > United States (0.46)
- Europe > United Kingdom > England (0.28)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation (0.99)
- North America > United States > Montana > 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)
Hydraulic Fracturing Stimulation Monitoring with Distributed Fiber Optic Sensing and Microseismic in the Permian Wolfcamp Shale Play
Jayaram, Vikram (Pioneer Natural Resources) | Hull, Robert (Pioneer Natural Resources) | Wagner, Jed (Pioneer Natural Resources) | Zhang, Shuang (Pioneer Natural Resources)
Abstract Hydraulic fracturing stimulation designs are moving towards tighter spaced clusters, longer stage length, and more proppant volumes. However, effectively evaluating the hydraulic fracturing stimulation efficiency remains a challenge. Distributed fiber optic sensing, which includes Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS), can continuously monitor the hydraulic fracturing stimulation downhole and be compared with other monitoring technology such as microseismic. The DAS and DTS data, when integrated with the microseismic, highlight processes relevant to the completion design and allow for a better understanding and interpretation of each dataset. This paper outlines a workflow to improve processing and interpretation of DAS and DTS data. In addition, an estimate of the slurry distribution can be made. These methods will be demonstrated for a horizontal Wolfcamp well in the Permian Basin. Here we compare key aspects of the microseismic, DAS, and DTS results in several fracture stages to understand the downhole geomechanical processes. In order to interpret the DTS data a thermal model is developed (using DTS data) to simulate the temperature behavior after pumping has ceased. A slurry distribution is obtained by matching the simulated temperature with the measured temperature from DTS. In addition, the DAS data signal is studied in the frequency domain and the dominant frequencies are identified that are mostly related to fluid flow and to reduce the background noise. This time frequency analysis enhances the ability to monitor and optimize well treatments. After reducing the background noise, the acoustic intensity is correlated to the slurry distribution. The fluid distribution data from DAS and DTS are compared with the microseismic and near field strain to better understand the completion processes. We utilized fiber optic microseismic to better understand and compare it to conventional microseismic. Finally, we highlight the dynamics of strain and microseismic signature as fluid moves from an offset well completion into the prior stimulated fiber well to better understand the reservoir and far field effects of the completion.
- Geology > Geological Subdiscipline > Geomechanics (0.88)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.40)
- 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)
- (24 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- (2 more...)