Methods for analyzing surface pressure data in real time are proposed and demonstrated to improve the completion design and cluster efficiency of child wells while protecting nearby parent wells. This study involves three parent wells and ten child wells, landed horizontally in the Wolfcamp A and B reservoirs in the Delaware Basin. An integrated real-time analysis of surface pressure measurements acquired from parent and offset child well completions enabled informed decisions regarding pump rate, fluid volume, frac stage sequence, and diverter schedule on subsequent stages. Results included the mitigation of frac-hits at the parent wells and improved fluid distribution of the child wells. Real-time monitoring indicated significant fluid communication during treatment between child and parent wells. The order of operations and completion design were changed during the job to reduce the risk of adverse effects on both well types from frac hits. By changing the treatment design, the magnitude and characteristics of pressures observed in the parent well showed significant reduction in the intensity of fluid communication. The design change also improved cluster efficiency of the nearby child wells, with no indication of damaging frac hits occurring. Pressure-based fracture mapping was used to supplement observations from the parent well. These pressure responses, recorded from an isolated stage on an offset well, were used to compute fracture geometries and growth rates of the stimulated fractures. The fracture height of the child wells decreased after adjusting the order of operations and completion designs during stimulation, which indicated fracture containment within the target zone. These results validated the improved cluster efficiency findings. The differences in geometries and growth curves were interpreted as improved fracture quality near the wellbore, with no damaging frac hits from the completion stages. Real-time pressure monitoring and analysis provides immediate, accurate feedback during stimulation. Data-driven decisions enables optimization of the frac design and pump schedule (slurry rate, slurry volume, proppant volume, proppant concentration, etc). Comprehensive understanding of the fracture growth behaviors assists in making more-informed decisions during the execution of a well stimulation program, mitigates parent well damage, and enhances child well production.

This paper demonstrates how to use pressure data from offset wells to assess fracture growth and evolution through each stage by quantifying the impacts of nearby parent well depletion, completion design, and formation. Production data is analyzed to understand the correlation between fracture geometries, well interactions, and well performance. The dataset in this project includes three child wells and one parent well, landed within two targets of the Wolfcamp B reservoir in the Midland Basin. The following workflow helped the operator understand the completion design effectiveness and its impact to production:Parent well pressure analysis during completionIsolated stage offset pressure analysis during completionOne-month initial production analysis followed by one month shut-inPressure interference test: sequentially bringing wells back onlineProduction data comparison before and after shut-in period An integrated analysis of surface pressure data acquired from parent and offset child wells during completions provides an understanding of how hydraulic dimensions of each fracture stage are affected by fluid volume, proppant amount, frac stage order of operations, and nearby parent well depletion. Production data from all wells was analyzed to determine the impact of depletion on child well performance and to investigate the effects of varying completion designs. A pressure interference test based on Chow Pressure Group was also performed to further examine the connectivity between wells, both inter- and intra-zone. Surface pressure data recorded from isolated stages in the offset child wells during completions was used to resolve geometries and growth rates of the stimulated fractures. Asymmetric fracture growth, which preferentially propagates toward the depleted rock volume around the parent well, was identified at the heel of the child well closest to the parent. Fracture geometries of various child well stage groups were analyzed to determine the effectiveness of different completion designs and the impact of in situ formation properties. Analysis of parent well surface pressure data indicates that changing the completion design effectively reduced the magnitude of Fracture Driven Interactions (FDIs) between child and parent wells. Child well production was negatively impacted in the wells where the fracture boundary overlapped with the parent well depleted volume in the same formation zone. This study combines pressure and production analyses to better understand inter- and intra-zone interference between wells. The demonstrated workflow offers a very cost-effective approach to studying well interference. Observing and understanding the factors that drive fracture growth behavior enables better decision-making during completion design planning, mitigation of parent-child communication, and enhancement of offset well production.