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Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- (20 more...)
- North America > United States > Texas (1.00)
- Europe (0.93)
- Research Report > New Finding (0.93)
- Overview (0.88)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- (20 more...)
Abstract The importance of interpretation through DFITs in characterizing reservoirs is widely recognized, leading to their incorporation into major commercial PTA software packages. However, certain limitations inherent in classical methodologies, especially for low-permeability reservoirs, have been overcome through the adoption of type-curve interpretation methodologies (Craig, 2014), and whose advantages have been exposed by Gonzalez and Arhancet (2022). Given the complexity and lack of available tools for employing this methodology, a hybrid team with technical and programming expertise developed a Python application that facilitates the integration of this new methodology and makes it accessible to all technical staff within the company, increasing efficiency and saving costs. The use of type-curve methodology offers a significant advantage in the interpretation of initial pressures, transmissibility, and permeability in low-permeability reservoirs, which could not be obtained using classical techniques. Until now, this new workflow has been carried out using spreadsheets in a handmade and rudimentary manner, requiring considerable time from the user. Although the data is often available, spreadsheets methodology makes interpretation difficult for end users, and it is very time compsuming. To address this issue, an ad hoc Python application was developed, using popular libraries such as pandas and matplotlib. This application allows users to interact with multiple screens to load and preprocess data in an agile, intuitive, and standardized manner. The development of an application with a standardized and well-organized workflow significantly improves the quality and efficiency of interpretation, especially for users with less experience. Having such a tool reduces the need to understand the functioning of spreadsheets and decreases the possibility of errors. The use of this application allows for maintaining an updated database with more than 200 records in a consistent manner. In addition to the benefit related to data interpretation, in-house hybrid team development allowed for faster time to value and enabled the tool to be developed in an agile manner, adapting to business needs. This means lower costs compared to other development methods, such as hiring a programming company or adopting commercial software. Having a tool that is currently not available in commercial software allowed for the consolidation of this methodology, which was already being used in a more handmade way and enabled the valuation of a large number of DFITs that could not be interpreted with the classical methodology. Having updated databases improves the quality of subsequent analyses (correlations, mappings, etc.). The tool has both the classical and type curve methodologies in a single environment, allowing the user to perform a complete analysis without the need for other software. In future steps, an upgrade will be made to include interpretation of post-frac fall offs. And although the application was born for a specific need for unconventional formations, its use can be extrapolated to any formation type.
- North America > United States > Texas (0.47)
- South America > Argentina > Patagonia Region (0.41)
- South America > Argentina > Neuquรฉn Province > Neuquรฉn (0.41)
- North America > Canada > Alberta (0.28)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Vaca Muerta Field > Vaca Muerta Shale Formation (0.98)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (5 more...)
Understanding the mechanisms of wave-induced fluid flow in the pore space combined with attenuation and dispersion measurements may be used to estimate rock hydraulic properties. Including macroscopic, mesoscopic, and local/squirt flow, a systematic treatment of attenuation and dispersion mechanisms is presented.
- Europe (1.00)
- Asia (1.00)
- North America > United States > Texas (0.92)
- Summary/Review (1.00)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- (3 more...)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (1.00)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.67)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Borehole Geophysics (1.00)
- (4 more...)
- North America > United States > West Virginia > Appalachian Basin > Berea Sandstone Formation (0.97)
- North America > United States > Pennsylvania > Appalachian Basin > Berea Sandstone Formation (0.97)
- North America > United States > Ohio > Appalachian Basin > Berea Sandstone Formation (0.97)
- North America > United States > Kentucky > Appalachian Basin > Berea Sandstone Formation (0.97)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation > Scaling methods (1.00)
- (15 more...)
Fracture Performance Evaluation from High-Resolution Distributed Strain Sensing Measurement During Production: Insights for Completion Design Optimization
Ma, Wei (Texas A&M University) | Wu, Kan (Texas A&M University) | Ge, Jin (Colorado School of Mines) | Yu, Wei (Sim Tech LLC / The University of Texas at Austin)
Abstract Distributed Strain Sensing based on Rayleigh Frequency Shift (DSS-RFS), a novel fiber optic diagnostic technique, can measure the strain change along the fiber with high spatial resolution and measuring sensitivity. Data of strain changes during shut-in and reopening operations have been measured and analyzed in the Hydraulic Fracture Test site 2 (HFTS2) project (Jin et al., 2021). The shape and magnitude of the observed strain changes are quantifiably different between two completion designs in the same well. However, the driven mechanisms for the various observations remain unclear. The objective of this paper is to simulate the various strain responses observed in HFTS 2 and improve understanding of the DSS measurements, near-wellbore fracture characteristics, and fracture performance. Different patterns of strain changes along the fiber were investigated during the shut-in and re-open periods using our in-house coupled fluid-flow and geomechanics model simulator. The well was shut-in for 4 days after 8 months production, reopen again after the shut-in, and continued producing for 1 year (Jin et al. 2021). We investigated the effect of different fracture properties on strain responses (fracture aperture change, the positive strain width, peak value of positive strain change) during the shut-in period as well as the strain-change/pressure diagnostic curve. Different width and peak strain change patterns are observed at the perforation location. Clear path discrepancy is observed in the strain-change/pressure diagnostic curve between shut-in and reopen periods. The strains responses and discrepancy of the diagnostic curve are dependent on the near-wellbore fracture properties. The impacts of all fracture parameters on the signatures of DSS signals were ranked to provide guidelines for history matching of field observations. In addition, we history-matched the observed DSS responses in two different completion designs (6 clusters per stage vs. 10 clusters per stage) to quantitatively evaluate the completion efficiency and fracture performance. Positive strain signals at the perforation location and negative strain signals between the clusters were observed. Each cluster shows its own strain-change/pressure path during shut-in and reopening periods in Stages A and B. The pattern of strain change and the diagnostic curve are related to the completion efficiency and production performance. In general, the "fat" pattern of strain response and the larger opening of strain-change/pressure diagnostic curve show a better production performance. This study significantly improves our understanding of the driving mechanisms of the observed DSS signals, which provides critical insights for near-wellbore fracture characteristics, fracture performance, and completion design optimization in unconventional reservoirs.
- 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)
- (23 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (3 more...)
A Review of Hydraulic Fracturing and Latest Developments in Unconventional Reservoirs
Temizel, Cenk (Saudi Aramco) | Canbaz, Celal Hakan (Ege University) | Palabiyik, Yildiray (ITU) | Hosgor, Fatma Bahar (Petroleum Experts LLC) | Atayev, Hakmyrat (ITU) | Ozyurtkan, Mustafa Hakan (ITU) | Aydin, Hakki (METU) | Yurukcu, Mesut (UTPB) | Boppana, Narendra (UTPB)
Abstract Hydraulic fracturing is a widely accepted and applied stimulation method in the unconventional oil and gas industry. With the increasing attention to unconventional reservoirs, hydraulic fracturing technologies have developed and improved more in the last few years. This study explores all applications of hydraulic fracturing methods to a great extent. It can be used as a guideline study, covering all the procedures and collected data for conventional reservoirs by considering the limited parameters of unconventional reservoirs. This paper intends to be a reference article containing all the aspects of the hydraulic fracturing method. A comprehensive study has been created by having a wide scope of examinations from the applied mechanisms to the technological materials conveyed from the different industries to utilize this technique efficiently. Furthermore, this study analyses the method, worldwide applications, advantages and disadvantages, and comparisons in different unconventional reservoirs. Various case studies that examine the challenges and pros & cons of hydraulic fracturing are included. Hydraulic fracturing is a promising stimulation technique that has been widely applied worldwide. It is challenging due to the tight and nanoporous nature, low permeability, complex geological structure, and in-situ stress field in unconventional reservoirs. Consequently, economic conditions and various parameters should be analyzed individually in each case for efficient applications. Therefore, this study provides the primary parameters and elaborate analysis of the techniques applied for a successful stimulation under SPECIFIC circumstances and provides a full spectrum of information needed for unconventional field developments. All the results are evaluated and detailed for each field case by providing the principles of applying hydraulic fracturing technologies. Many literature reviews provide different examples of hydraulic fraction methods; however, no study covers and links up both the main parameters and learnings from real cases worldwide. This study will fill this gap and illuminate the application of the hydraulic fracturing method.
- North America > United States > Texas (1.00)
- North America > United States > North Dakota (1.00)
- Europe (1.00)
- (4 more...)
- Research Report > Experimental Study (0.67)
- Research Report > New Finding (0.45)
- Overview > Innovation (0.45)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.94)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.67)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- (20 more...)
Summary Rayleigh frequency-shift-based distributed strain sensing (RFS-based DSS) is a fiber-optic-based diagnostic technique, which can measure the strain change along the fiber. The spatial resolution of RFS-based DSS can be as low as 0.2โm, and the measuring sensitivity is less than 1 . Jin et al. (2021) presented a set of DSS data from the Hydraulic Fracture Test Site 2 project to demonstrate its potential to characterize near-wellbore fracture properties and to evaluate perforation efficiency during production and shut-in periods. Extensional strain changes are observed at locations around perforations during a shut-in period. At each perforation cluster, the observed responses of strain changes are significantly different. However, the driving mechanisms for the various observations are not clear, which hinders accurate interpretations of DSS data for near-wellbore fracture characterization. In this study, we applied a coupled flow and geomechanics model to simulate the observed DSS signals under various fractured reservoir conditions. The objective is to improve understanding of the DSS measurements and characterize near-wellbore fracture geometry. We used our in-house coupled flow and geomechanics simulator, which is developed by a combined finite-volume and finite-element method, to simulate strain responses within and near a fracture during shut-in and reopen periods. Local grid refinement was adopted around fractures and the wellbore, so that the simulated strain data can accurately represent the DSS measurements. The plane-strain condition is assumed. Numerical models with various fracture geometries and properties were constructed with representative parameters and in-situ conditions of the Permian Basin. The simulated well was shut-in for 4โdays after producing 240โdays, and reopened again for 1โday, following the actual field operation as shown in Jin et al. (2021). The characters of the strain changes along the fiber were analyzed and related to near-wellbore fracture properties. A novel diagnostic plot of relative strain change vs. wellbore pressure was presented to infer near-wellbore fracture characteristics. The impacts of permeability and size of the near-wellbore-stimulated region, fracture length, and near-perforation damage zone on strain responses were investigated through sensitivity analysis. The strain responses simulated by our model capture the observed signatures of field DSS measurements. During the shut-in period, clear positive strain changes are observed around the perforation locations, forming a โhumpโ signature. The shape of the โhumpโ region and peak value of each โhumpโ are dependent on the size and permeability of the near-wellbore fractured zone. Once the well is reopened, the strain changes decrease as the pressure drops. However, in one cycle of shut-in and reopen, the strain-pressure diagnostic plot shows path dependency. The discrepancy between the shut-in and reopen periods is highly influenced by the properties of near-wellbore fractured zones. The differences in the strain-pressure diagnostic plots can help to identify the conductive fractures. This study provides better understandings of the DSS measurements and their relations to the near-wellbore fracture properties, which is of practical importance for near-wellbore fracture characterization and completion/stimulation optimization.
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (4 more...)
Abstract In this paper, we present a novel fracture diagnostic method to determine the geometry of multiple propagating fractures. The method relies on the measurement of the zimuthally esolved llbore train ensor (ARWEST) as a function of time at multiple locations in an observation well. A pad-scale fracturing simulator is used to simulate dynamic fracture propagation in a treatment well. The geometry of the monitoring wellbore is represented with a very fine (millimeter scale) computation mesh to capture the impact of the propagating fractures on the monitoring wellbore. The axial and radial strain at different locations along the wellbore is computed as a function of time as the fractures approach the observation wellbore. These measurements together with the wellbore pressure response are interpreted to obtain the height, length and width of the fractures as well as the cluster efficiency of the stage. The emergence of peaks in the strain and pressure monitoring data clearly detects the arrival of each fracture. As the fracture approaches the monitoring well, the tensile strain measured within the wellbore in the axial direction increases, the compressive strain in the radial direction increases and the sealed wellbore pressure increases. As the fracture intersects the wellbore, the tensile strain in axial direction decreases and compressive strain in the radial direction decreases. The sealed wellbore pressure further increases. When the treatment is complete, both the magnitude of the monitored strain and pressure decrease. The major axis of the oval wellbore is oriented towards the tip of the propagating fracture. The wellbore ovality, therefore, provides a direct measure of the location of the fracture tip in 3-D. The results obtained from these azimuthal wellbore measurements can be interpreted with the aid of the simulations to provide a new low cost facture diagnostic method. This new 3-D fracture diagnostics method allows us to infer (a) the location of the fracture front, (b) estimate the geometry (length, height, width) and (c) determine the cluster efficiency by monitoring the strain tensor as a function of time along an observation well. The results presented here will allow operators to integrate the measured casing strain tensor and the sealed wellbore pressure data. Such a diagnostic method opens the possibility of real-time fracture diagnostics and optimization.
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.94)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (0.94)
- (2 more...)
Summary Rayleigh frequency-shift-based distributed strain sensing (RFS-based DSS) is a fiber-optic-based diagnostic technique, which can measure the strain change along the fiber. The spatial resolution of RFS-based DSS can be as low as 0.2โm, and the measuring sensitivity is less than 1 . Jin et al. (2021) presented a set of DSS data from the Hydraulic Fracture Test Site 2 project to demonstrate its potential to characterize near-wellbore fracture properties and to evaluate perforation efficiency during production and shut-in periods. Extensional strain changes are observed at locations around perforations during a shut-in period. At each perforation cluster, the observed responses of strain changes are significantly different. However, the driving mechanisms for the various observations are not clear, which hinders accurate interpretations of DSS data for near-wellbore fracture characterization. In this study, we applied a coupled flow and geomechanics model to simulate the observed DSS signals under various fractured reservoir conditions. The objective is to improve understanding of the DSS measurements and characterize near-wellbore fracture geometry. We used our in-house coupled flow and geomechanics simulator, which is developed by a combined finite-volume and finite-element method, to simulate strain responses within and near a fracture during shut-in and reopen periods. Local grid refinement was adopted around fractures and the wellbore, so that the simulated strain data can accurately represent the DSS measurements. The plane-strain condition is assumed. Numerical models with various fracture geometries and properties were constructed with representative parameters and in-situ conditions of the Permian Basin. The simulated well was shut-in for 4โdays after producing 240โdays, and reopened again for 1โday, following the actual field operation as shown in Jin et al. (2021). The characters of the strain changes along the fiber were analyzed and related to near-wellbore fracture properties. A novel diagnostic plot of relative strain change vs. wellbore pressure was presented to infer near-wellbore fracture characteristics. The impacts of permeability and size of the near-wellbore-stimulated region, fracture length, and near-perforation damage zone on strain responses were investigated through sensitivity analysis. The strain responses simulated by our model capture the observed signatures of field DSS measurements. During the shut-in period, clear positive strain changes are observed around the perforation locations, forming a โhumpโ signature. The shape of the โhumpโ region and peak value of each โhumpโ are dependent on the size and permeability of the near-wellbore fractured zone. Once the well is reopened, the strain changes decrease as the pressure drops. However, in one cycle of shut-in and reopen, the strain-pressure diagnostic plot shows path dependency. The discrepancy between the shut-in and reopen periods is highly influenced by the properties of near-wellbore fractured zones. The differences in the strain-pressure diagnostic plots can help to identify the conductive fractures. This study provides better understandings of the DSS measurements and their relations to the near-wellbore fracture properties, which is of practical importance for near-wellbore fracture characterization and completion/stimulation optimization.
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (4 more...)
Abstract Stress-dependence of reservoir matrix and fractures can strongly affect the performance of multifractured horizontal wells (MFHWs) completed in unconventional hydrocarbon reservoirs. In order to model fluid flow in unconventional reservoirs exhibiting this stress-dependence, most traditional reservoir flow simulators, and many simulators described in published work, use conventional reservoir fluid flow model formulations. These formulations typically neglect the influence of the rate of change of volumetric strain of the reservoir matrix and fractures, even though reservoir stress and pressure change significantly during the course of production. As a result, the effect of matrix and fracture deformation on production is neglected, which can lead to errors in predicting production performance in most stress-sensitive reservoirs. To address this problem, some studies have proposed the use of porosity and transmissibility multipliers to model stress-sensitive reservoirs. However, in order to apply this approach, multipliers must be estimated from laboratory experiments, or used as a history-match parameter, possibly resulting in large errors in well performance predictions. Alternatively, fully-coupled, fully numerical geomechanical simulation can be performed, but these methods are computationally costly, and models are difficult to setup. This paper presents a new fully-coupled, two-way analytical modeling approach that can be used to simulate fluid flow in stress-sensitive unconventional reservoirs produced through MFHWs. The model couples poroelastic geomechanics theory with fluid flow formulations. The two-way coupled fluid flow-geomechanical analytical model is applied simultaneously to both the matrix and fracture regions. In the proposed algorithm, a porosity-compressibility coupling parameter for the two physical models is setup to update the stress- and pressure-dependent fracture/matrix properties iteratively, which are later used as input data for the fracture-matrix reservoir fluid flow model at each iteration step. The analytical approach developed for the fully-coupled, two-way analytical model, using the enhanced fracture region conceptual model, is validated by comparing the results with numerical simulation. Predictions using the fully-coupled enhanced fracture region model are then compared with the same enhanced fracture region model but with the conventional pressure-dependent modeling approach implemented. A sensitivity study performed by comparing the new fully-coupled model predictions with and without geomechanics effects accounted for reveals that, without geomechanics effects, production performance in stress-sensitive reservoirs might be overestimated. The study also demonstrates that use of the conventional stress-dependent modeling approach may cause production performance to be underestimated. Therefore, the proposed fully-coupled, two-way analytical model can be useful for practical engineering purposes.
- North America > Canada > Alberta (0.46)
- North America > United States > Texas (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.48)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Greater Peace River High Basin > Upper Montney Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- (2 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Integration of geomechanics in models (1.00)
- (4 more...)