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Collaborating Authors
Results
A Novel Technique for Assessment of Fracture Geometry and Injection Domain From Falloff Tests After Fractured Injection of Slurry: Case Study
Loloi, Mehdi (Advantek International) | Abou-Sayed, Ahmed (Advantek International) | Abou-Sayed, Omar (Advantek International) | Bill, Michael (ASRC Energy Services)
Abstract This paper presents a novel technique for assessment of fracture and injection domain geometry from fall off tests. Using type curve analysis techniques established in part for long term water injection, algorithms were developed for assessment of geomechanical and fracture properties of injectors. These properties include the stress contrast between the injection and containment layers, the rate of fracture shrinkage (height and/or length) during fall off, the extent of the inner relative permeability domain and outer domain, and others. A software tool was developed to incorporate these algorithms. The tool was used to analyze fall-off test results obtained from a large-scale slurry injection operation used for disposal of drilling wastes in Alaska’s North Slope. The software tool’s predicted fracture height showed very good agreement to the height interpreted from temperature logs conducted by the operator in the well.
Abstract Re-Injection is one of the most important methods to dispose fluid associated with oil and natural gas production. Disposed fluids include produced water, hydraulic fracture flow back fluids, and drilling mud fluids. Several formation damage mechanisms are associated with the injection including damage due to filter cake formed at the formation face, bacteria activity, fluid incompatibility, free gas content, and clay activation.
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Escondido Formation (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)
- (2 more...)
- Well Drilling > Formation Damage (1.00)
- Well Drilling > Drilling Fluids and Materials (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- (4 more...)
Abstract Crushed salt is being considered as a backfilling material to place around nuclear waste within a salt repository environment. In-depth knowledge of salt thermal and mechanical properties as it reconsolidates is critical to thermal and mechanical modeling of the reconsolidation process. An experimental study was completed to quantitatively evaluate the thermal conductivity of consolidated crushed salt as a function of porosity. Temperature dependence of this thermal conductivity was also determined. Porosities ranged from 1% to 40%, and temperatures ranged from ambient up to 300°C. This range of conditions is expected to more than cover those that might be encountered in a radioactive waste disposal facility. Two different experimental devices were used to measure these values. The thermal conductivity of reconsolidated crushed salt decreases with increasing porosity or increasing temperature; conversely, salt thermal conductivity increases as the salt consolidates. Thermal conductivity of experimentally deformed bedded salt cores was shown to be related to fracture density, as a type of porosity. Crushed salt for this study came from the Waste Isolation Pilot Plant (WIPP). Salt was observed to dewater during heating, and the weight loss from dewatering was quantified. A simple mixture theory model is presented to represent the data developed in this study.
- Europe (1.00)
- North America > United States > New Mexico (0.29)
- Water & Waste Management > Solid Waste Management (1.00)
- Energy > Power Industry > Utilities > Nuclear (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.69)
- 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)
- (22 more...)
Abstract Four in-situ tests performed in salt caverns in France and Germany are described. The main objective of these tests was to increase our understanding of the long-term behavior of abandoned caverns. It is proven that, in the long term, when cavern brine has reached thermal equilibrium with the rock mass, pressure evolution is governed by cavern creep closure and brine micropermeation through the cavern walls. An equilibrium pressure is reached when the closure rate exactly equals the permeation rate. In the shallow caverns described in this paper, equilibrium pressure is significantly lower than geostatic pressure, ruling out any risk of fracture onset at the cavern roof. Interpretation of these tests allows salt permeability to be back-calculated.
- Europe (1.00)
- North America > United States > Texas (0.28)
Abstract This laboratory investigation involved evaluating the potential to enhance drilling Rate of Penetration (ROP) and drilling efficiency by applying axial vibrations on the bit using a pulse cavitation drilling tool in combination with varying levels of axial compliance. The pulse cavitation tool generates cavitation bubbles in the drilling fluid by flowing through a venturi. When the cavitation bubbles produced within the tool are collapsed, pressure pulses are generated which produce pressure pulsations and oscillatory forces on the bit. Drilling results were evaluated on the basis of ROP, Mechanical Specific Energy (MSE), bit loads and bit displacements. The tool was tested both with and without compliance to evaluate the effects of the compliant element. Experimental results show that the pulse cavitation tool starts to cavitate and produce vibrations when a critical flow rate is reached. When the drilling system was rigid (i.e. no compliance was used), the vibration produced did not have any significant effect on the ROP. However, when the drilling system was compliant the vibrations produced by the tool intensified the natural displacement vibration of the compliant element and the ROP was increased and MSE was decreased.
- North America > Canada (0.30)
- North America > United States (0.28)
- Research Report > New Finding (0.49)
- Research Report > Experimental Study (0.49)
Abstract In this paper, the use of microseismic data for calibration and modification of wellbore temperature models will be introduced. Moreover, fracturing fluid distribution obtained using the modified temperature numerical model is coupled with the microseismic field data for several Eagle Ford shale wells to improve hydraulic fracture stimulation characterization. By measuring the temperature change along the wellbore, distributed temperature sensing (DTS) data may provide relative fluid distribution. This information may be used to assess the simple geometry of the hydraulic fractures, the fracture initiation points along the wellbore, wellbore integrity issues, and the effectiveness of isolation tools. With recently published wellbore temperature models, quantitative information about which zones receive the stimulation fluid can be numerically solved. However, DTS measurements and fluid distributions calculated using DTS data are restricted to the wellbore and near wellbore environment. For far field diagnostics of hydraulic fracturing stimulation other measurements are needed, specifically microseismic. By combining these two measurements, a new workflow is created which incorporates both the far field and wellbore measurements to characterize hydraulic fractures, both real-time and after the stimulation job. This workflow is especially useful in reservoirs that are naturally fractured or in wellbores were stress shadowing effects are significant, such as multistage fracturing multiple wells that are in close proximity to each other. In these scenarios the path that the fluid travels may be complex, even in the near wellbore environment. Due to this complexity, fluid distributed calculations based on DTS data may provide misleading results. Using information gained from microseismic, the wellbore temperature models may be modified to increase the reliability of the numerically calculated fluid distributions. The purpose of this paper is to propose how microseismic data may be used to modify the wellbore temperature models, and how stimulation fluid placement determined from the modified models may then be coupled with the microseismic to improve hydraulic fracture stimulation characterization.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.34)
- 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 > Hawkville Field > 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 Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Flow of Dense Suspensions Through Fractures: Experimental And Computational Observation of Velocity-Field Heterogeneity
Medina, R. (University of California) | Elkhoury, J.E. (University of California) | Detwiler, R.L. (University of California) | Morris, J.P. (Schlumberger-Doll Research Center) | Prioul, R. (Schlumberger-Doll Research Center) | Desroches, J. (Services Pétroliers Schlumberger)
Abstract We conducted experiments in which a high concentration (50% v/v) of granular solids suspended in a non-Newtonian carrier fluid (0.75% guar gum in water) flowed through a parallel-plate fracture. Digital imaging and particle-imagevelocimetry analysis provided a detailed map of velocities within the fracture. Results demonstrate development of a strongly heterogeneous velocity field within the fracture. We observed the highest velocities along the no-flow boundaries of the fracture and the lowest velocities along the centerline of the fracture. Computational fluid dynamics (CFD) simulations using a recently developed model of the rheology of dense suspensions of mono-disperse solids in Newtonian carrier fluids closely reproduced experimental observations of pressure gradient versus flow rate. Results from additional simulations suggest that small (3%) variations in solid volume fraction within the fracture could lead to significant (factor of two) velocity variations within the fracture with negligible changes in observed pressure gradients. The variations in solid volume fraction persist over the length of the fracture, suggesting that such heterogeneities may play a significant role in the transport of dense suspensions. Our work suggests that a simple average conductivity parameter does not adequately represent the flow of high solid content suspensions in a fracture, as the flow develops strong three-dimensional structure even in a uniform rectangular channel.
- Research Report > Experimental Study (0.88)
- Research Report > New Finding (0.66)
- Well Completion > Hydraulic Fracturing (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (0.94)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (0.62)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (0.51)