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Recent advances in distributed acoustic sensing (DAS) technology allow active seismic monitoring of stimulated rock volume (SRV) development. This study showcases an interstage DAS vertical seismic profiling (VSP) survey acquired during a zipper-fracturing stimulation. Incident P-waves scattered by the SRV and converted to S-waves are observed in the data. The signals are associated not only with hydraulic fracturing stages of the instrumented well, but also with fracturing of an adjacent well in the zipper group. A workflow is developed to monitor and characterize the SRV, fracture closure time, and interactions between zipper wells. 3D full wavefield modeling confirms the data interpretation and provides additional insight. As a result, we have been able to estimate SRV properties, including SRV height, width, and the fracture closure time for all wells within the zipper group. Moreover, for adjacent wells, the length and azimuth of SRV can be constrained. Our work provides critical information for optimizing hydraulic fracturing operations.
Recent advances in distributed acoustic sensing (DAS) technology allow active seismic monitoring of stimulated rock volume (SRV) development. This study showcases an interstage DAS vertical seismic profiling (VSP) survey acquired during a zipper-fracturing stimulation. Incident P-waves scattered by the SRV and converted to S-waves are observed in the data. The signals are associated not only with hydraulic fracturing stages of the instrumented well, but also with fracturing of an adjacent well in the zipper group. A workflow is developed to monitor and characterize the SRV, fracture closure time, and interactions between zipper wells. 3D full wavefield modeling confirms the data interpretation and provides additional insight. As a result, we have been able to estimate SRV properties, including SRV height, width, and the fracture closure time for all wells within the zipper group. Moreover, for adjacent wells, the length and azimuth of SRV can be constrained. Our work provides critical information for optimizing hydraulic fracturing operations.
Horizontal wells have become the "industry standard" for unconventional and tight formation gas reservoirs. Because these reservoirs have poorer quality pay it takes a well planned completion and fracture stimulation(s) to make an economic well. Even in sweet spots in unconventional and tight gas reservoirs good completion and stimulation practices are required to achieve economic success. But what are the objectives of horizontal wells and how do we relate the completion and stimulation(s) to achieving these goals? How many completions/stimulations do we need for best well performance and/or economics? How do we maximize the value from horizontal wells? When should a horizontal well be drilled longitudinally or transverse? These are just a few questions to be addressed in this paper. This paper focuses on some of the key elements of well completions and stimulation practices as they apply to horizontal wells. Economic optimization studies were conducted for tight gas reservoirs highlighting the importance of lateral length, number of fractures, inter-fracture distance, fracture halflength, and fracture conductivity. In addition to the tight gas completion and stimulation considerations, network complexity will also be considered. These results will be used to develop a horizontal well decision tree for evaluating the various drilling, completion, and stimulation issues encountered in horizontal wells in tight and unconventional gas reservoirs. Field examples will be used to highlight these strategies. This work benefits the petroleum industry by: Developing well performance and economic objectives for horizontal wells and highlighting the incremental benefits of various completion and stimulation strategies, Establishing well performance and economic based criteria for drilling longitudinal or transverse horizontal wells, Integrating the reservoir objectives and geomechanical limitations into a horizontal well completion and stimulation strategy, Developing a horizontal well completion and stimulation decision tree for pre-horizontal well planning purposes.
This paper presents a tailored coated proppant that provides improved solutions for various hydraulic fracturing challenges. The coating aims to enhance proppant transport with slickwater fluids while improving the hydrocarbon mobility into the proppant pack and reducing respirable crystalline silica during the operations. The paper discusses results from over 30 field trials in multiple low permeability formations. The novel multifaceted coating was designed to modify the wettability of proppants’ surfaces to increase the surface's affinity for gases and reduce the generation of respirable airborne particles. By adding small volumes of gases into the proppant-laden slurry, gas bubbles get attached to the surface of the proppant leading to significant reduction in its apparent specific gravity. In order to prove the operational and economic advantages of the multifunctional proppant, a series of novel laboratory experiments were conducted under various operational conditions, followed by numerous field trials in several low permeability formations. The laboratory tests showed that the coated proppant can stay suspended in the presence of gases for extended period of time. The laboratory evaluation involved testing under pressures and temperatures up to 12,500 psi and 400°F with different fluid systems made from both fresh and high-salinity waters. Oil mobility tests showed that the oil flow rate was increased by 74% compared to uncoated sand. Several multistage fracturing treatments executed with significantly higher proppant concentrations up to 6.1 lbs/gal in typical slickwater treatments when used with 1.5 – 10 % foam quality. Onsite measurements have proven that the coating reduced the generation of respirable airborne particles down to 10 – 30 μg/m3 throughout the proppant lifecycle. Data obtained from numerous field trials showed that the novel proppant technology resulted in improved well productivity, increased oil cuts and reduced water production.
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