El-Morgan Field was discovered in 1965 and is located offshore in the Gulf of Suez (GoS) approximately 160 miles south of Suez, Egypt. Peak Production was approximately 300,000 BOPD within only three years. El- Morgan is considered one of the giant fields since its STOOIP is estimated to be approximately 2.689 billion BO with an ultimate recoverable reserve around 1.439 billion BO. Over its history, more than 250 wells were drilled. Currently, 179 wells are operating (125 producers & 54 Injectors). El-Morgan is considered highly sophisticated field due to reservoir heterogeneity (Kareem reservoir), moderate stratification, limited aquifer support, high bubble-point pressure, low-permeability layers and its friable sand. Due to the high bubble-point pressure and high initial-rate (Pi=2,990psi & PB=2,269psi), the bubble-point pressure was encountered early in the field resulted in using peripheral injection to support reservoir pressure. In addition the reservoir heterogeneity while injecting peripherally, it is believed that significant oil reserves were being bypassed and were potentially unrecoverable. This paper presents an integrated approach to optimize the development for a complex field from both subsurface and operations views. It also shows studies conducted to maximize the asset value, explains how the development strategy have been revised over time, to augment oil ended by using an EOR method nowadays (BrightWaterTM). All of these studies are coupled to the economical calculations. Managing giant fields with a significant potential is very important since each incremental 1% in RF will increase the ultimate recovery by tens of millions oil barrels. Also through this paper you will assure importance of certain reservoir evaluation tools and how you can optimize them to increase ultimate recovery factor. Paper is an excellent example for reservoir management that resulted in more than 52% primary RF.
GUPCO (Gulf of Suez Petroleum Company) is the pioneer in Egypt and Middle East in applying conventional waterflooding projects fas a secondary recovery method, Starting from Morgan field, Ramadan, October and July field by injecting into different reservoirs such as Lower Rudies, Upper Rudies and Cretaceous. These successful examples have been done and still running to recover greater amount of oil utilizing more advanced techniques like BrightWater and LoSal.The Heavy oil block in July field which is located in the Gulf of Suez (GoS) was discovered in Jan. 1986 by appraisal well J53. Many tests were performed to get the extension, characteristics of the reservoir and the hydrocarbons as well. It was found that the API gravity of oil is 19 degree. Using Numerical Simulation, we could define different scenarios of depletion plans to maximize the recoverable oil, and hence a decision was taken to start and implement the optimum scenario. This paper will discuss different scenarios and the selected optimum depletion plan, and comparing between the forecast from the model versus the actual achievement addressing production performance, reservoir rock characteristics, Data gathered and surveillance plan for the reservoir since May 1996 followed by water injection using dual string completion in December 1996.The paper is a good example as a case study for the value of using the technology of 3D modeling to maximize the recovery from challenging reservoir like heavy oil reservoirs in addition to proving that waterflooding has successfully improved the recovery of 19 API degree oil in July field.
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