Innovative 3d Modeling and Well Optimization for Mauddud Formation Development in Greater Burgan Field

Traditional exploration strategies have primarily focused on conventional, well-understood geological features, i.e. simple anticlinal traps and thick reservoir formations, due to their favorable structural characteristics and economic viability. However, contemporary challenges to increase production necessitate a paradigm shift towards less conventional exploration domains, emphasizing on geologically complex and previously underutilized regions that were historically deemed economically unfeasible. Development attempts of Mauddud formation in the Greater Burgan Area has been regarded as strategically favorable. While appearing as a thin reservoir in Southeast Kuwait, one of the primary factors driving significant interest in Mauddud formation is its hydraulic connection with the underlying extensive main Burgan clastic reservoir, suggesting potential migration and mutual influence between the two formations. KOC Reservoir Study Team (RST) and Innovation & Technology (I&T) in partnership with SLB have been tasked with the challenge of identifying optimal locations for the new well placement, defining suitable candidates for the re-entry side-tracks, and evaluating the feasibility of repurposing old wells - originally targeted for the lower formations – for production from the Mauddud Reservoir. A critical aspect of this initiative involves the integration of all available data to confirm formation connectivity and developing a DFN model. This study presents an integrated 3D modeling approach that incorporates petrophysical, geophysical, geological, reservoir, and production data to optimize new well placement. A new fine static geological model was built for the Greater Burgan Field with a primary focus on the Mauddud formation, while the Wara and Upper Burgan formations were included at a broader scale. Several novel rock classification approaches were implemented, and image log analysis facilitated the identification of structural features and vertical heterogeneity within the formation. A supervised multivariate approach was employed to estimate the permeability model, allowing the integration of multi-domain datasets including wells logs and cores. Petrophysical rock typing, based on pore throat radius distribution, provided a detailed reservoir property characterization, improving well candidate assessment and placement optimization. Furthermore, capillary pressure-derived water saturation estimates were utilized to model the original oil in place (OOIP). At the conclusion of the comprehensive FDP study, two piloted horizontal wells were drilled and completed with multi-stage acid frac. The results of the DST were encouraging, validating the effectiveness of the revised FDP, and providing a foundation for the continued development of Mauddud formation, and paving the way for further additional wells in the future. The successful Implementation of the integrated study on the Mauddud reservoir in the Greater Burgan field, despite numerous specific uncertainties, serves as a pioneering example for future advancements in the development of challenging, geologically complex formations.