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Shell Egypt and the joint Venture partners Vegas and GDF Suez are currently developing the Karam gas field by drilling 4 new wells, working over two existing wells and installing surface facilities to process and export this new production. The field is operated by Bapetco (a Shell/EGPC Joint Venture) on behalf of the Joint Venture Partners.
The Abu Roash G reservoir is approximately 4400 meters deep and with reservoir pressures and temperatures in excess of 9500 psi and 310 deg Fahrenheit respectively it is technically challenging. The reservoir is over pressured and Calcium Bromide brine was required to kill the wells for the work over activities.
Post-workover well productivity was significantly below expectations with very high well skins observed. The root cause for the productivity loss was believed to be from formation damage due to losses during the workover operations but relative permeability effects (water blocking) was also suspected as a potential productivity damage mechanism. Laboratory tests were carried out which showed the creation of a sever emulsion between the completion fluid used during the workover (CaBr, CaCl, CaCO3) and reservoir fluids.
A novel technical solution, a methanol Channel Fracturing treatment was developed to restore well productivity. This was a world first application of this treatment utilizing the Channel Fracturing treatment technology to reduce the required pump rate/pressure to place the treatment and methanol as the carrying fluid to minimize the water block effect.
The well was tested after the methanol Channel Fracturing stimulation at a constrained rate of 35 MMscf/d and 3000 bpd condensate compared to the pre-stimulation gas rate of 2 MMscf/d.
This paper will discuss planning, execution and production results making recommendations to improve the effectiveness of future Channel Fracturing applications.
Karam-3& 4wells were drilled as part of 4 wells campaign to explore and appraise the gas potential in Karam filed. The wells succeeded to find large gas volumes in Kharita reservoir which has high Co2 percentage. The wells also found sweet gas in Abu Roash G reservoir but with smaller volumes which could be produced through the existing facility.
Abu Roash G reservoir was tested in Karam 3 with an initial rate of 23 MMscf for few days and then the well was shut-in due to an integrity issue in the completion. The other well Karam 4 was tested only on Kharita formation and Abu Roash G formation was not tested due to an integrity issue also in the completion, however from log response it was expected that Abu Roash G in Karam 4 should produces at good initial rate similar to Karam 3 as the sand quality looks similar in both wells from the logging data. Fig.1 shows a correlation panel between Karam 3 & 4 and the sand quality in both wells.
Al-Kandari, Ibrahim (Kuwait Oil Company) | Al-Jadi, Manayer (Kuwait Oil Company) | Lefebvre, Christian (Beicip-Franlab) | Vigier, Louise (Beicip) | De Medeiros, Maitre (Beicip) | Dashti, Hameeda Hussain (Kuwait Oil Company) | Knight, Roger (KOC) | Al-Qattan, Abrar (KOC) | Chimmalgi, Vishvanath Shivappa (Kuwait Oil Company) | Datta, Kalyanbrata (KOC) | Hafez, Karam Mohamed (KOC) | Turkey, Laila (KOC) | Bond, Deryck John (Kuwait Oil Company)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Kuwait International Petroleum Conference and Exhibition held in Kuwait City, Kuwait, 10-12 December 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract A pilot water flood was carried out in the Marrat reservoir in the Magwa Field. The main aim of this pilot was to allow an assessment of the ability to sustain injection, better understand reservoir characteristics. A sector model was built to help with this task. An evaluation of the injectivity in Magwa Marrat reservoir was performed with particular attention to studying how injectivity varied as injected water quality was changed. This was done using modified Hall Plots, injection logs, flow logs and time lapse temperature logs. Data acquisition during the course of the pilot was used to better understand reservoir heterogeneity.