Scimitar Production Egypt Ltd.

Egypt, Egypt

Scimitar Production Egypt Ltd.

Egypt, Egypt
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Shaheen T.,Schlumberger | Hassan W.,Scimitar Production Egypt Ltd. | Kamal S.,Scimitar Production Egypt Ltd. | Siddiqui M.I.U.H.,Scimitar Production Egypt Ltd.
74th European Association of Geoscientists and Engineers Conference and Exhibition 2012 Incorporating SPE EUROPEC 2012: Responsibly Securing Natural Resources | Year: 2012

The Issaran field located200 km east of Cairo-Egypt, is a heavy oil reservoir.The oil is of 8-12 degree API with viscosity of 4000 cps at standard conditions. Productivity of the wells has sharply declined due to increase in water cut and increase in the formation skin value. The problem is attributed to the heterogeneity of the reservoir together with presence of fractures which is causing poor sweep efficiency plus the accumulation of hydrocarbon deposits. The major challenge to remedy this situation was; Not only the creation of new extended flow channels, accurate placement of the treatment, diversion within the reservoir, and to provide sustain production increase but also the flow and the production of oil through the newly formed wormholes. A new innovative approach using a combination of acid based treating fluids and steam were used. Acid in combination with unique chemical diverting agent plus selective placement mechanism succeeded to open new production horizons and stimulate the existing one. The Addition of Steam has succeeded in reducing the viscosity and increasing the mobility of oil, and also in providing pressure support to the reservoir achieving further increase in the benefits of the acid stimulation. The results of the treatments carried out so far have provided a new dimension in the enhanced recovery process of the heavy oil. This paper explains the design, execution, evaluation and the recommended way forward of this world first acid & steam production enhancement initiative for the reservoir enhanced recovery process.


Joshi S.,Schlumberger | Thabet E.,Schlumberger | Abugreen Y.,Schlumberger | Samir M.,Scimitar Production Egypt Ltd. | And 2 more authors.
Proceedings - SPE Symposium on Improved Oil Recovery | Year: 2010

The Issaran field, situated in the Egyptian Eastern Desert, is one of the few heavy oil fractured carbonate reservoirs in the world (Refs.1 to 3). Oil production and recovery from such fractured heavy oil carbonate reservoirs is generally lower than conventional reservoirs, with primary recovery being as low as 1% in some cases, with ultimate recovery generally being lower than 30%, as per studies. lssaran is estimated to contain 700 MMBBLS of 10 - 12 degree API heavy and highly viscous crude in 3 main reservoirs. These are the Upper and Lower Dolomite reservoirs and the deeper Nukhul (fractured Dolomite) reservoir. The field produced 5000 STBOPD in 2008 and is forecasted to produce 8500 STBOPD in 2009 after further development. A Cyclic Steam Stimulation (CSS) program was started in the field in 2006. Scimitar planned to develop the Nukhul formation with cold production in vertical open-hole well completions, as the initial wells gave high liquid rates, possibly due to the high fracture permeability and gravity assisted drainage. However, these super-K layers also had the unwanted effect of channeling water very rapidly to the wellbores, resulting in fast increasing water cuts in the field. Also, if steam stimulation was attempted in these wells, then the steam rapidly channeled through the fractures and the heavy oil could not be heated effectively in order to reduce its viscosity. Viscosity reduction is a key factor in increasing recovery efficiency from such reservoirs. The first step in remediating the situation was to clearly diagnose the super-K layers in a dynamic flowing condition using production logs. Since the wells were producing under ESP's, Scimitar designed a special Y-tool that would enable production logging (PL) to be carried out. Normal PL density sensors will be unable to differentiate effectively between oil and water in this environment, as the heavy oil density is very close to the water density. Hence a special Production Services Platform (PSP*) tool containing electrical micro-probes was used to differentiate between oil and water and get an accurate estimate of the water holdup in the well. Production logging was successfully carried out in 3 wells of the field using the above toolstring. Surveys were carried out at different flowing rates in order to identify the high permeability layers dominating the production and calculate their pressures/productivity indices. The layerwise contribution of oil/water was calculated and layers producing high water rates were identified. Shutin surveys were successful in detecting crossflowing layers. The results matched well with surface measured production rates. The results calculated from production logging had a significant effect upon the lssaran field development plan. It was found that water was being produced from layers having high resistivities up to 30 ome. This led to an increase in the resistivity cutoff for hydrocarbon production and a reduction in watercut. Hydrocarbon producing zones were better identified and Scimitar decided to abandon open hole completions in future wells and go in for cased hole completions to control the water production. Copyright 2010, Society of Petroleum Engineers.


Rizkallah M.,Scimitar Production Egypt Ltd. | Alfy S.A.,Scimitar Production Egypt Ltd. | Basta G.S.,Scimitar Production Egypt Ltd. | Ghaleb A.A.,Scimitar Production Egypt Ltd. | Kortam W.T.,Scimitar Production Egypt Ltd.
Society of Petroleum Engineers - SPE International Heavy Oil Conference and Exhibition 2014: Heavy Oil Innovations Beyond Limitations | Year: 2014

This paper describes a field trial of an optimized Steam Pulse Injection (SPI) scheme in a heavy oil (10-12° API) dual porosity carbonate reservoir located in Egypt. The field is known as Issaran with approximately 1.2 billion barrels of oil in place. Up dip steam injection in selective wells has been applied since August 2009. The fracture network helps upward distribution of steam, heating of the matrix thus wettability change to water wet and release of oil towards the deeper "drainage off take" points. The steamflooding has worked well until the Instantaneous Steam Oil Ratio (ISOR) was getting closer to uneconomical limits. In December 2013, it was decided to test an optimized SPI scheme in the Upper Dolomite South development (old area). Presently the process is working efficiently with oil being drained towards selective low pressure drainage points and in a calculated fashion using IVRR (Instantaneous Voidage Replacement Ratio) controllers. The SPI scheme calls for "On & Off" injection modes. During the "On Mode" injection proceeds normally in all designated injectors. During the "Off Mode" injection continues in few selected injectors. The "Off Mode" injectors are selected on the basis of controlling IVRR around a fault, known as the "magic fault", with the surrounding wells being target withdrawal points for oil production. SPI was designed to reduce operational costs while also benefitting from the pressure release phenomenon, which releases trapped oil from the matrix towards the fracture system and producing wells. During the first 210 days of field trial approximately 823,610 bbls of steam were saved and the ISOR almost halved. The optimization of the SPI will continue and will undoubtedly allow for the extension of the economical life of the field. Copyright © (2014) by the Society of Petroleum Engineers All rights reserved.


Samir M.,Scimitar Production Egypt Ltd | Ela M.A.E.,WorleyParsons Engineers Egypt Ltd | Marsafy S.E.,Cairo University | Tayeb S.E.,Cairo University | Sayyouh H.,Cairo University
International Journal of Applied Chemistry | Year: 2010

An Egyptian Microbial Enhanced Oil Recovery (MEOR) project evaluated the degree of corrosion action which may result, on the production tube and casing and surface equipment, during the using of bacteria to improve the ultimate recovery in oil fields. The high resolution metal loss technique and several standard coupons of the carbon steel were used to evaluate the level of corrosion of the bioproduct of these bacteria. The coupons were chosen to have the same material as that of the casing, the production tubes and the other surface facilities that may be used during the different phases of the MEOR project. Four solutions that are used during the project phases were examined. The first solution is the sea water solution, which is used to preflush the reservoir. The second is a mixture of the nutrient and the sea water, which is used to incubate the bacteria inside the reservoir. The third one is the bacterial solution (a mixture of sea water, nutrient and the bacteria) that is injected into the reservoir in case of the incubation of bacteria outside the reservoir. The fourth solution is the effluent fluid that comes out from displacement tests on a pilot model which simulates the process of the MEOR. This effluent solution includes bacteria and its metabolism, nutrient, formation water, sea water, and oil. The results showed that sea water and nutrient solution has the lowest rate of corrosion while the effluent from the model has higher corrosion rate than the third solution of sea water, nutrient and bacteria. The most corrosive solution was the sea water. These results indicate that the presence of Pseudomonas Aeruginosa and its bio products do not represent a high corrosive media for the equipment used in the MEOR project. Resulting photographs by binocular microscope show that the occurrence of corrosion under the bacterial growth is a function of the bacterial type. It was found that some of species of bacteria cause minimum corrosion. This study contributes to the successful application of MEOR process. © Research India Publications.


Samir M.,Scimitar Production Egypt Ltd | Abu El Ela M.,WorleyParsons Engineers Egypt Ltd | El Marsafy S.,Cairo University | El Tayeb S.,Cairo University | And 2 more authors.
North Africa Technical Conference and Exhibition 2010, NATC 2010 - Energy Management in a Challenging Economy | Year: 2010

Laboratory studies show the existence of some strains of bacteria in field crude oils and formation waters. This work is concerned with studying the effect of the reservoir conditions such as temperature, salinity and lithology on the indigenous bacterial activities. Such study is an original contribution to the knowledge of microbial enhanced oil recovery (MEOR). Egyptian MEOR project at Cairo University succeeded to isolate a surfactant-producing microorganism "Pseudomonas Aeruginosa" from crude oil produced from an Egyptian oil field. Several displacement tests were conducted in sand pack model. A modified media was used to incubate and improve the growth rate, behavior and stimulation of Pseudomonas Aeruginosa. The results obtained from the current work showed that Pseudomonas Aeruginosa succeeded to increase the oil recovery by 20%. Pseudomonas Aeruginosa becomes able to resist the effect of temperature up to 70°C and salinity up to 150,000 ppm, when a specific incubation technique is applied. There is no significant effect on the behavior of the bacteria in the presence of the Dolomite and Kailinite inside the reservoir. The value of the oil recovery factor in case of incubation of the bacteria outside the model is greater than its value in case of incubation inside the model by about 5%. The results obtained are discussed and analyzed in terms of surface tension, hydrogen ion concentrations, viscosity, and conductivity of the effluent solutions. Copyright 2010, Society of Petroleum Engineers.


Samir M.,Scimitar Production Egypt Ltd. | Hassan W.,Scimitar Production Egypt Ltd. | Kamal S.,Scimitar Production Egypt Ltd. | Hassan A.,Halliburton Co. | And 2 more authors.
North Africa Technical Conference and Exhibition 2010, NATC 2010 - Energy Management in a Challenging Economy | Year: 2010

The Issaran field, a heavy oil reservoir with estimated original oil in place (OOIP) of approximately 1.6 billion bbl of oil, was discovered in 1981. The producing horizons are the carbonate formations of Miocene age occurring from depths of 1,000 to 2,000 ft. The oil is of 9 to 12 °API with viscosity of 4000 cP at standard conditions. It was not until early 2000, after the crude oil prices rose to favorable levels, that a concerted effort was made to develop this heavy oil. Cold production from the fractured carbonate Nukhul reservoir (depth approximately 2,000 ft) was first targeted and the production from the field increased from 170 barrels of oil per day (BOPD) in 1998 to more than 2,300 BOPD in 2002. However, the Upper Dolomite reservoir, at a depth of 1,000 ft, held more than 50% of the OOIP, but did not produce. Subsequently, a pilot project using cyclic steam injection was implemented on two openhole completions in the Dolomite reservoir and the production results far exceeded predictions, proving it to be commercially viable. This pilot scheme was expanded to two, seven-spot pattern wells and the total combined production from the lssaran field reached 5,000 BOPD in late 2008. Recently, however, the productivity of the Upper Dolomite wells has declined. The water cut has increased and the steam injection efficiency is becoming questionable. Because the steam temperatures of nearly 600°F exceed the operational limits of conventional production logging tools (PLTs), they cannot be used for steam injection profile monitoring. In addition, wellhead control and operational safety concerns become challenging issues. One effective solution to the problem was to run high temperature Memory PLT (MPLT). These tools are built for high temperature service and can be run on slickline, making this a more cost effective solution. The three wells selected for the preliminary run of the MPLT service were also the first applications of this technology in the Middle East area. The primary results have already shown deficiencies in the steam injection process because most of the steam is being preferentially injected into water-bearing zones. This paper provides a detailed review of the results from the PLT surveys and the completion strategy implemented to improve productivity and maintain project profitability. Copyright 2010, Society of Petroleum Engineers.


Basta G.S.,Scimitar Production Egypt Ltd. | Korany S.K.,Scimitar Production Egypt Ltd. | Kortam W.T.,Scimitar Production Egypt Ltd. | Shaker S.,Scimitar Production Egypt Ltd.
Society of Petroleum Engineers - SPE EOR Conference at Oil and Gas West Asia, OGWA 2016 | Year: 2016

Heavy oil reservoir management using thermal methods is different than conventional reservoir management, especially if the reservoir is highly heterogeneous with limited availability of data. This raises a lot challenges to deal with. One of these important challenges is timing the conversion of the project from the cyclic steam injection phase to the continuous steam flooding strategy, which allows the steam to contact a larger area of the reservoir, and thus enhancing oil recovery, while optimizing voidage replacement ratio (VRR.) This on the long run increases the project lifetime economically. Issaran is one of those challenging heavy oil shallow fields in the Middle East, containing reservoirs with heterogeneous properties. Its different reservoirs are managed with different steam strategies. Cyclic steam injection started in 2004 in one of the reservoirs, after that the strategy was converted to continuous steam injection in addition to small cycles in some of the producers to improve communication. Different selected time scenarios of conversion were implemented for each area to enhance sweep efficiency and heat distribution and overcome any undesirable reservoir response such as water encroachment, and deal with highly fractured, highly heterogeneous or low pressure zones. In this paper, actual field performances will be presented for each formation showing the cyclic steam injection stage and the timing of conversion to continuous steam strategy. A lot of factors will be presented for the steam cycle stage including: voidage replacement ratio (VRR), steam to oil ration (SOR), and the injectivity index performance from cycle to cycle. Then the conversion time from cyclic to continuous steam flooding will be discussed per each area. The relationship between this time with total VRR and the total steam injected in the cyclic stage will be introduced. Spacing between the wells will be mentioned and its effect on the conversion time identified. Generally the main factors that affect directly on the selected conversion time: communication between the wells, injectivity index and economic factors. The paper will focus on the first 2 factors. Copyright 2016, Society of Petroleum Engineers.


Korany S.K.,Scimitar Production Egypt Ltd | Hassan W.,Scimitar Production Egypt Ltd | Basta G.S.,Scimitar Production Egypt Ltd | Kortam W.T.,Scimitar Production Egypt Ltd | And 2 more authors.
Society of Petroleum Engineers - SPE North Africa Technical Conference and Exhibition 2015, NATC 2015 | Year: 2015

This paper describes a case study of cyclic group steaming of wells (CGSW) in a heavy oil (10-12 API) field located in Egypt. The field is known as Issaran with approximately 1.2 billion barrels of oil in place. CGSW was implemented in a pilot in a highly fractured limestone reservoir, with highly permeable fractures. During cyclic steam injection in the pilot, a negative effect was noticed during steam injection in some wells on surrounding wells; the gross production rate increased accompanied by an increase in water cut and wellhead temperature leading to loss in oil production. This meant that steam injection strategy needs some modifications To avoid this, CGSW was implemented by applying steam cycles in all the producers of the pilots simultaneously, allowing for a better distribution of heat around all the wells. Cyclic steam injection of all wells together implies pressurizing the reservoir, and hence increasing the reservoir energy along with decreasing the oil viscosity and enhancing the ultimate oil recovery. This, together with eliminating the negative effect of steam injection from the neighboring wells allowed the wells to show a better performance Comparison is made between some of the wells producing before and after CGSW. The results are shown along with a full description of the process. Copyright © 2015 Society of Petroleum Engineers.

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