Horizontal and highly deviated wells are increasingly being used in oilfield developments worldwide. Large-bore horizontal wells can deliver significantly higher oil production rates than conventional completions, reducing field development costs by allowing reserves to be targeted with fewer wells Rudies formation in Belayim Land field is a bottom water-drive reservoir with a strong supporting aquifer. it is characterized by its great isotropy and heterogeneity where based on the analysis of SCAL data, it was found that the vertical permeability is nearly equal to horizontal permeability raising the problem of water coning(cresting), earlier water breakthrough situation and masking the oil production by water due to the great difference in mobility Based on calculation of the critical coning production rates and water control plots it was concluded that the horizontal wells drilled in Rudies formation which are produced with high production rates suffered from extreme water coning problems that raised the necessity for water shutoff procedure to be considered Field cases presented on this paper explain applications of internal casing packer and blank tubing as a tail pipe in accompanied with downgrading the production rates from horizontal wells for the purpose of zonal water control in the uppermost section of open hole and slotted liner completed horizontal wells in Petrobel Included in this paper are two different field cases for uncemented water shutoff in horizontal wells that succeeded in decreasing the water cut in the wells from the range of (90-95 %) to the range of (10-30%) implementing a huge increase in the gained net oil towards achieving the maximum recovery. Technical data including well configuration, production performance and casing string are included in the paper. Field operations and lesson learned from each application are also presentedinthispaper

Zohr field was discovered in 2015 by the Italian energy company Eni and is the largest ever natural gas found in the Mediterranean Sea, with around (30 trillion cubic feet) total gas in place. Belaim Petroleum Company (Petrobel) (JV with ENI) is the Egyptian Petroleum Corporation arm and the owner of the project. Production started in December 2017 and since then 18 wells have been drilled for production. This paper describes the criteria for material selection of the production strings for Zohr’s deep-water gas producers and how pre-tested and approved cost-effective alternatives are available for such a top-class project. The paper details the qualification and deployment of glass reinforced polymer (GRP) Lined Tubing as an alternative to 28%Chrome tubing, including the testing work that has been performed, and the operational aspects of running the referred-to alternative in several deep-water projects. The choice of Duoline lined tubing results from the need for a cost-effective solution delivering the same operational requirements of 28% Chrome production strings. And since the Duoline GRE system will be integrated with the steel tubing therefore this system has to be previously fully approved and certified by the manufacturing mill of the lined tubing so there would be not even minor modifications to the specifications and the sealing performance of the premium connections and tubing body. The paper indulges into describing the laboratory tests and the field experiences of the Duoline Lined tubing system in various fields globally, where this system has been tested in severe operating conditions with elevated levels of H2S, CO2, Salinity, dissolved Oxygen conditions to investigate the capability and service limits of the fiberglass liner at different temperatures. In addition to mentioning the erosion tests that were performed, mechanical tests such as pressure loop and make & break tests, how these various tests ended with good results and its comparison to the exotic high chrome joints performance. This fiberglass lined tubing system has been applied in gas production wells since the 1980s, and ENI has been utilizing this technology in their production and water wells since 2005 in the north Africa, middle east, Kashagan regions and Norway offshore wells. On the other side, the technology has been successfully used world-wide in more than 55,000 wells since 1960s in various applications besides gas production strings. The paper will present the past experience of ENI with fiberglass lined tubing, the laboratory tests, the field experiences, the economic evaluation of implementing this system in such a high-profile project, In addition to the pre-qualifications performed on this system by the OCTG mills and approvals granted to integrate this technology with the patent premium connection joints.

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The main seek for the whole oil industry is to find a way to prolong the economic life of the existing mature fields, as a result of the difficulty of finding new big assets. The waterflooding efficiency can be dramatically enhanced by the application of new technologies with the target of sweeping higher amounts of unswept oil. IOR/EOR methods are investigated to improve the oil production from the giant Belayim Onshore mature field located in Gulf of Suez, Egypt. The field was previously developed by using sea water peripheral injection. The existing water injection strategy is found not be the optimum strategy to increase the sweep efficiency and the recovery factor as a result of the huge lateral heterogeneity and different mobility ratio. This paper describes the work done to improve the efficiency of water injection by the application of different IOR/EOR technologies specifically Low Salinity water. First, Coreflooding experiments on porous medium have been performed in the tertiary mood to detect the effect of IOR compared to the sea water injection. It was found that LS can increase oil recovery nearly to 7% more. After finishing the lab phase, simulation runs have been performed to predict the enhancement on field scale. The coreflooding experiments have been simulated using a wettability alteration model to determine the LS parameters and the new relative permeability curves. These parameter were the input into a sector model of fine gridding. The model was history matched using the wells production and injection data for the LS pilot area under study. Different forecast scenarios have been run and the incremental increase in oil recovery was reported against the current water injection scheme A number of Single Well Tracer Tests have been performed to detect the effect of Low Salinity water flooding on well scale. The test was designed to incorporate a number of injection, production and shut in cycles in the pilot well with the aim determining the residual oil saturation with the current scheme of sea water injection and after switching into low salinity water. It was found that Low salinity water has achieved very promising results that produced a remarkable reduction in Sor at the range of (5-11) saturation units. In order to estimate the full-field effect of the LS waterflooding as a promising EOR method, all the major aspects have been taken into account including the expected reduction in residual oil saturation, permeability alteration as a result of possible fine migration or clay swell and the possible change in the sweeping efficiency. Finally, all the produced results from the experimental and simulation work have been incorporated into an economic study to determine the feasibility of constructing a desalination plant for the full-field application phase