Characterizing Flow from Thin Carbonate Formation Integration of Oil Finger Print and Dynamic Data

Summary The complexity and heterogeneity of the thin, tight Mauddud carbonate in the Greater Burgan Field makes it challenging to characterize and develop this formation. In the study reported here, we have taken advantage of substantial advances in production data analysis and oil fingerprinting technology to conduct a more advanced reservoir analysis. The Mauddud carbonate reservoir is sandwiched between two massive clastic reservoirs, the Wara and the Burgan. The formation is mostly composed of calcarenitic limestone with intervals of 5–10 feet of good oil reservoir. Average porosity is 18% with low permeability ranging from 1 to 10 mD, characteristics which made this reservoir a candidate for horizontal drilling. However past production results have varied significantly among wells, a fact which previously raised the concern that perhaps the well paths of some lateral wells in this carbonate may be inadvertently tagging the adjacent, more permeable, clastic reservoirs. If that were the case, then production from the adjacent clastic reservoir could be augmenting the production from some of the wells intended to be completed solely in the carbonate. Considered in total, the results from previous development strategies for this reservoir did not meet expectations.