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This paper details the results from a comprehensive study to evaluate completion effectiveness and optimize field development in the Utica. Optimizing the number and location of perforation clusters, number of stages, and treatment size requires a clear understanding of how these parameters affect fracture geometry and well productivity. The goal of this work was to determine how the number of perforation clusters per stage and treatment size affect fracture geometry and well productivity, and to integrate these results into the overall field development optimization. A comprehensive evaluation of plug and perf (PNP) and controlled entry point (CEP) completions and treatment size was performed using a five-well pad in the Utica (wet gas area). The evaluation included PNP completions with 3-4 perforation clusters and CEP completions with 1-2 perforation clusters. Treatment size was varied by a factor of two to evaluate the effect of fluid volume on fracture length. Microseismic data were gathered on 81 PNP stages and 95 CEP stages. The microseismic data were used to calibrate hydraulic fracture models. Fracture geometries for the five-well pad plus a direct offset well (a six well total of 250+ stages) were discretely gridded in a reservoir simulation model. The reservoir simulation model was calibrated by history matching 14+ months of production data. Proppant Tracer data and DFIT measurements from previous Utica work were used to support the hydraulic fracture modeling and reservoir simulations. The microseismic data provided a clear understanding of the relationship between treatment size and fracture length for each completion scenario. The results indicate that fracture length may be dependent on completion type, with CEP completions showing less fracture length than PNP completions. Simple production comparisons and detailed reservoir simulation history matching showed that (1) well productivity is governed by the number of perforation clusters, with PNP wells outperforming CEP wells and (2) well-to-well communication is evident. This work did NOT identify any gross inefficiencies with PNP completions and suggests that CEP completions do NOT result in better productivity, at least in this Utica pad. The calibrated models were used to optimize perf cluster spacing, treatment size, and well spacing for PNP completions. The optimization results are summarized in the paper, but the focus of the paper is the evaluation of PNP and CEP completions, characterization of hydraulic fracture length-volume relationships, and calibration of hydraulic fracture and reservoir simulation models.
This paper details the results from a comprehensive study to evaluate completion effectiveness and optimize field development in the Utica. Optimizing the number and location of perforation clusters, number of stages, and treatment size requires a clear understanding of how these parameters affect fracture geometry and well productivity. The goal of this work was to determine how the number of perforation clusters per stage and treatment size affect fracture geometry and well productivity, and to integrate these results into the overall field development optimization. A comprehensive evaluation of plug and perf (PNP) and controlled entry point (CEP) completions and treatment size was performed using a five-well pad in the Utica (wet gas area). The evaluation included PNP completions with 3-4 perforation clusters and CEP completions with 1-2 perforation clusters. Treatment size was varied by a factor of two to evaluate the effect of fluid volume on fracture length. Microseismic data were gathered on 81 PNP stages and 95 CEP stages. The microseismic data were used to calibrate hydraulic fracture models. Fracture geometries for the five-well pad plus a direct offset well (a six well total of 250+ stages) were discretely gridded in a reservoir simulation model. The reservoir simulation model was calibrated by history matching 14+ months of production data. Proppant Tracer data and DFIT measurements from previous Utica work were used to support the hydraulic fracture modeling and reservoir simulations. The microseismic data provided a clear understanding of the relationship between treatment size and fracture length for each completion scenario. The results indicate that fracture length may be dependent on completion type, with CEP completions showing less fracture length than PNP completions. Simple production comparisons and detailed reservoir simulation history matching showed that (1) well productivity is governed by the number of perforation clusters, with PNP wells outperforming CEP wells and (2) well-to-well communication is evident. This work did NOT identify any gross inefficiencies with PNP completions and suggests that CEP completions do NOT result in better productivity, at least in this Utica pad. The calibrated models were used to optimize perf cluster spacing, treatment size, and well spacing for PNP completions. The optimization results are summarized in the paper, but the focus of the paper is the evaluation of PNP and CEP completions, characterization of hydraulic fracture length-volume relationships, and calibration of hydraulic fracture and reservoir simulation models.
Recent development of horizontal well completions and stimulation methods enhanced the development of conventional and unconventional resources. Multistage fracturing allowed oil and gas operators to stimulate long laterals in continuous and efficient operations that increase the reservoir contact, thus increasing the recovery of oil and gas. Oil and gas operators work to improve the efficiency of multistage fracturing treatments by developing and integrating enabler hardware, processes and chemical technologies to enhance the fracturing operations and reduce cost. This paper reviews and discusses the different types of horizontal wells with multistage fracturing completions and stimulation techniques including plug-and-perf, abrasive jetting, just-in-time perforation, sliding sleeve systems, coiled-tubing conveyed fracturing systems and annular isolation methods. The efficiency of the multistage fracturing treatments depends on multiple factors comprising the operational time and cost associated with different type of completions such as plugs and sleeves, different intervention operations such as wireline or coiled-tubing and different stage distribution and pumping designs. Combination of multiple multistage fracturing methods resulted in hybrid cost-effective treatments. In addition, multistage fracturing fluids diversions contribute significantly to the stimulation efficiency. Different types of diversion methods are discussed for each stimulation system. This paper provides a comprehensive summary of the operational practices, fracturing methods, and different multistage fracturing completions in horizontal wells while emphasizing on the recent advancements available in the market. The ability to develop an efficient and effective multistage fracturing operation is based on understanding the reservoir requirements, and identifying logistical and resource challenges at the geological location where the operation is taking place. The developed solutions would be an integration of currently available process, with proper completions, materials and development of innovative enabler technologies to accomplish optimum procedures. In recent years, several enabler technologies were developed to address the challenges within the existing multistage fracturing operations. The electronic monobore sliding sleeve was developed to address the limitation caused by small ball seat (baffle) in ball actuated sliding sleeve completions. Plug-and-perf operation was enhanced by applying the Just-In Time Perforation (JITP) method by developing a new perforation gun assembly that cuts operation time. Development of autonomous completion elements with the ability to navigate and self-destruct after accomplishing the job helped to reduce the number of trips into the well that greatly affected the operation efficiency. Completion elements and diverters built from dissolvable materials eliminated the drill-out and cleanout operations, which reflect positively on the efficiency of the fracturing process. Reviewing current advancements of multistage fracturing completions and treatments can pave the way for further operation optimization and cost reduction.
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