Abstract
Within a natural fractured Carbonate Reservoir a NOC's Overall production rates are constantly challenged with factors, such as high permeability streaks, poor macroscopic sweep efficiency, and low mobility ratios, all of which can dramatically impair production rates and reservoir oil recoveries.
This paper presents the experiences from managing said reservoir using traditional reservoir engineering sound practices and latest digital technologies of IDOF.
We describe in recent years how a collaborative and multi-disciplinary team implemented a series OF BEST PRACTICE reservoir-to-surface surveillance practices which include:
water flood-front monitoring through wellbore resistivity and seismic methods,
injector-producer connectivity mapping through tracer tests complemented with data-drive analytics, numeric and streamline simulation,
Well performance and productivity watching via real-time data processing, analysis, modeling and optimization,
Water flood displacement and volumetric efficiency following up through continuous reservoir shut-in pressure data capture or estimation via multi-rate testing and permanent down hole gauges installations.
Data and consistently applied work processes are orchestrated through digital technologies which include workflow management and integrated visualization, allow making well-informed, real time decisions to optimum reservoir recovery management.
These actions included
the identification of various infill drilling opportunities of vertical, horizontal and multilateral wells,
optimum allocation of water injection and production allowable and
recommendation for water-shut-off and water conformance jobs.
✓ Post-mortem analysis of results demonstrated production increases of 33% and increase recovery expectation above 13%.
✓ In closing we discuss challenges and lessons learned.
