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Heterogeneity across the producing interval is typical in oil and gas wells; it is rare to find uniform production distribution or fluid injection across a substantially long interval. Hence, diversion during matrix acidizing is critical, especially if the downhole pressure and/or temperature are high. In two Kuwait Jurassic fields, two wells were completed in an over 100 ft producing interval across a carbonate reservoir. Reservoir temperature is 280°F, and the estimated reservoir pressure is 11,000 psi. Multiple matrix acidizing trials to enhance well productivity have been performed with conventional diversion techniques and, as indicated by the surface pressure response, were not effective. This requires an adequately engineered near wellbore diversion system that can overcome the challenge of these bottomhole conditions and form a uniform production distribution across a substantially long heterogeneous interval. A new methodology was applied in two Jurassic wells that combined a multimodal blend of biodegradable particulates and fibers as a chemical diverter, and emulsified acids as main fluids for a matrix stimulation. In each diversion stage, the change in surface pressure ranged from 800 to 1,000 psi after the diversion pill hit the perforation tunnel. Moreover, a clear signature of diversion was demonstrated in the instantaneous shutin pressures. In another Kuwait field, the diversion pill was tested by using injectivity logging tests to monitor the changes in injectivity across the perforated interval during an acid fracturing treatment in comparison to the earlier injection profile. A remarkable change in injection was observed and a total of 80% change in the injection profile was quantified from before and after the diversion. The diversion pill is relatively small in volume and is easy and safe to handle. Fibers help to maintain the carrying capacity and allow safe landing of the biodegradable material to the formation face. Only a few barrels are required to plug the opened or stimulated interval, and the method allows the following stimulation stage to treat the subsequent interval. The first well revealed a 330% and 110% production increase in gas and oil rates, respectively. The production was set as one of the highest producers in the field. The second well yielded a 320% increase in total production, which set the highest record for the field. The new method is proved to be highly effective in terms of wellbore coverage, and highest production records in the field after matrix acidizing treatments.
Heterogeneity across the producing interval is typical in oil and gas wells; it is rare to find uniform production distribution or fluid injection across a substantially long interval. Hence, diversion during matrix acidizing is critical, especially if the downhole pressure and/or temperature are high. In two Kuwait Jurassic fields, two wells were completed in an over 100 ft producing interval across a carbonate reservoir. Reservoir temperature is 280°F, and the estimated reservoir pressure is 11,000 psi. Multiple matrix acidizing trials to enhance well productivity have been performed with conventional diversion techniques and, as indicated by the surface pressure response, were not effective. This requires an adequately engineered near wellbore diversion system that can overcome the challenge of these bottomhole conditions and form a uniform production distribution across a substantially long heterogeneous interval. A new methodology was applied in two Jurassic wells that combined a multimodal blend of biodegradable particulates and fibers as a chemical diverter, and emulsified acids as main fluids for a matrix stimulation. In each diversion stage, the change in surface pressure ranged from 800 to 1,000 psi after the diversion pill hit the perforation tunnel. Moreover, a clear signature of diversion was demonstrated in the instantaneous shutin pressures. In another Kuwait field, the diversion pill was tested by using injectivity logging tests to monitor the changes in injectivity across the perforated interval during an acid fracturing treatment in comparison to the earlier injection profile. A remarkable change in injection was observed and a total of 80% change in the injection profile was quantified from before and after the diversion. The diversion pill is relatively small in volume and is easy and safe to handle. Fibers help to maintain the carrying capacity and allow safe landing of the biodegradable material to the formation face. Only a few barrels are required to plug the opened or stimulated interval, and the method allows the following stimulation stage to treat the subsequent interval. The first well revealed a 330% and 110% production increase in gas and oil rates, respectively. The production was set as one of the highest producers in the field. The second well yielded a 320% increase in total production, which set the highest record for the field. The new method is proved to be highly effective in terms of wellbore coverage, and highest production records in the field after matrix acidizing treatments.
The North Kuwait Jurassic Gas (NKJG) asset is highly complex. The main target zone is the dolomitic Marrat reservoirs that have been under differential depletion and production for several years. The Marrat are deep carbonates, naturally fractured with low matrix permeability and high conductivity contrasts. Reservoir fluid composition is sour gas condensate and volatile oil mix supported by a weak water primary drive mechanism. The Marrat reservoir is divided into flow units/flow zones with variations in reservoir properties. The variations in properties, conductivity contrasts, and the propensity to flow preferentially from the naturally fractured network cause effective stimulation of individual flow zones critical for productivity enhancement. Ideally, each flow zone must be stimulated separately to optimize the productivity of the well and to prevent unintended bypassing of the Jurassic hydrocarbons. A customized deployment method that is neither fracturing nor matrix stimulation along with a temporary plugging mechanism is required to ensure high-rate matrix acidizing (HRMA) treatments will stimulate multiple flow zones with conductivity differences that are greater than an order of magnitude. The alternative plug-perforate-stimulate-repeat process has been successfully implemented, but it incurs much higher costs than conventional methods and requires a high demand of well intervention operational resources. Placement control is obtained by perforating each flow zone separately and then stimulating prior to isolating with a millable mechanical isolation plug. All the plugs are milled out, and zones are cleaned out to contribute to the overall inflow. The key driving force for using the plug-perforate-stimulate method in a multizone well is the effectiveness of the stimulation in treating each zone individually. Other means of placement, such as coiled-tubing-deployed stimulations, are less frequently utilized due to the cost and limitations in pump rate and pump pressure through the coil. Degradable particulate diverters were adopted as a cost-effective diversion technique that retained much of the advantage of a pinpointed or focused stimulation. The asset team worked closely with the service providers to determine the size, type, and volume of degradable particulate diverter pill to be deployed. Fracturing rates and pressures were determined prior to each treatment to ensure an HRMA treatment could be designed and deployed effectively to pump the stimulation fluid train at as high rate as possible to create wellbore diversion while not fracturing any of the combination of the flow zones. This paper summarizes the latest optimization and successful placement cases from a multiwell project where the wellbore diverters were optimized and placed in HRMAs and acid fracturing treatments where the results significantly exceeded expectations. Technical details of the actual cases are disclosed, and the latest developments are presented with actual field data.
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