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Multi-Zone, Single-Trip (MZST) completions have significantly reduced the time to complete deep wells with long intervals and have been successfully used in Lower Tertiary formations in deep-water Gulf of Mexico (GOM) projects. MZST completion can be used to create the interface with the reservoir and to deliver stimulation treatments typically limited to up to single-digit zones. Additionally, the minimum spacing allowed by standard MZST completions limits the treated zone length. The Lower Tertiary formations encounter high-laminated pay zones, often hydraulically isolated, and with pressure variations across the small spacing length. Therefore, a treatment covering several compartments results in uneven treatment distribution across long intervals. These single-trip systems require a high proppant amount and pressure to complete the sizeable frac-pack jobs required in Lower Tertiary formations. Using ball-activated fracturing sleeves and dedicated fracturing ports, these completion systems allow a larger number of stages over multiple intervals. This method affords more precise placement of stages with reduced spacing down to single-digit feet between zones, a feature that also enables targeting specific pressure characteristics in the reservoir. Completion selection and well performance analysis were conducted to design a new completion system for production enhancement from Lower Tertiary formations. Design and selection of the lower completion system focused on multi-stage fracturing and potential sand control options, and their impact on production. The following systems were studied to estimate and predict the initial production rates: Multi-Zone Single-Trip (MZST) completion, Large Bore Multi-Zone (LBMZ) completion system and Ball-Activated Fracturing Completion System (BAFCS). This paper describes a high-level workflow developed for completion design and selection, fracture modeling to generate 3D fracture geometry and fracturing pressures, wellbore design including tubing stress and movement analysis for fracturing treatments and production systems analysis to generate vertical lift performance/inflow performance relationships (VLP/IPR), and to estimate the initial production rates and flowing bottomhole pressure for sand-free production. The proposed BAFCS used more fracture initiation points (up to 20 stages) in the Lower Tertiary formations when compared to eight individual stages (20 perforation intervals) with MZST and LBMZ completion systems. The more confined fracture geometries were created by using the new proposed multi-stage fracturing system. Predicted BAFCS production rates were higher than those of MZST and LBMZ completion systems. To attain higher production and recovery factors than those achievable with natural depletion, artificial lift options (electrical submersible pumping) were also examined for Lower Tertiary wells.
Multi-Zone, Single-Trip (MZST) completions have significantly reduced the time to complete deep wells with long intervals and have been successfully used in Lower Tertiary formations in deep-water Gulf of Mexico (GOM) projects. MZST completion can be used to create the interface with the reservoir and to deliver stimulation treatments typically limited to up to single-digit zones. Additionally, the minimum spacing allowed by standard MZST completions limits the treated zone length. The Lower Tertiary formations encounter high-laminated pay zones, often hydraulically isolated, and with pressure variations across the small spacing length. Therefore, a treatment covering several compartments results in uneven treatment distribution across long intervals. These single-trip systems require a high proppant amount and pressure to complete the sizeable frac-pack jobs required in Lower Tertiary formations. Using ball-activated fracturing sleeves and dedicated fracturing ports, these completion systems allow a larger number of stages over multiple intervals. This method affords more precise placement of stages with reduced spacing down to single-digit feet between zones, a feature that also enables targeting specific pressure characteristics in the reservoir. Completion selection and well performance analysis were conducted to design a new completion system for production enhancement from Lower Tertiary formations. Design and selection of the lower completion system focused on multi-stage fracturing and potential sand control options, and their impact on production. The following systems were studied to estimate and predict the initial production rates: Multi-Zone Single-Trip (MZST) completion, Large Bore Multi-Zone (LBMZ) completion system and Ball-Activated Fracturing Completion System (BAFCS). This paper describes a high-level workflow developed for completion design and selection, fracture modeling to generate 3D fracture geometry and fracturing pressures, wellbore design including tubing stress and movement analysis for fracturing treatments and production systems analysis to generate vertical lift performance/inflow performance relationships (VLP/IPR), and to estimate the initial production rates and flowing bottomhole pressure for sand-free production. The proposed BAFCS used more fracture initiation points (up to 20 stages) in the Lower Tertiary formations when compared to eight individual stages (20 perforation intervals) with MZST and LBMZ completion systems. The more confined fracture geometries were created by using the new proposed multi-stage fracturing system. Predicted BAFCS production rates were higher than those of MZST and LBMZ completion systems. To attain higher production and recovery factors than those achievable with natural depletion, artificial lift options (electrical submersible pumping) were also examined for Lower Tertiary wells.
High pressure stimulation of tight sandstone formations is occasionally combined with flowback of proppant and formation sand during the onset of production. This is generally attributed to characteristics of unconsolidated sandstones and their response to high pressure hydraulic stimulation. This brings an additional challenge to openhole multi-stage completion systems that now require a filtration mechanism as part of the completion design, to introduce a sand exclusion technology alongside the multi-stage ball activated frac sleeves. A novel openhole multistage fracturing system was developed combining the operational efficiency of ball activated frac sleeves with sand control efficiency of multi-membrane filtration sand screens. This combination of technologies deliver a robust completion design and a unique intervention-less solution to enable stimulation at high pressures and provide sand exclusion on production. The system comprises of a series of incrementally sized high strength disintegrating frac balls to activate and close stimulation frac sleeves while simultaneously also opening production sand control screens. The design allows for several production sand control screens in one stage to maximize reservoir contact for unrestricted production. The system allows to efficiently complete the frac treatment and start sand-free production of the well without any intermediate manipulation of downhole tools with coiled tubing (CT) or wireline. This technology brings substantial value by not only early sand-free production, but also flexibility to add additional sand screens within the stage without compromising stage count. The intervention-less design of the tools eliminates the need for coiled tubing (CT) manipulation of downhole tools and hence associated high intervention costs. Keeping in mind the increased need of high-pressure stimulation for unconventional and tight reservoirs, the system is designed to 15,000 psi rating. The sand screens are designed to be isolated from stimulation pressure while maximizing inflow area without compromising on sand control. Further, to enable full efficiency, the system includes high-strength disintegrating frac balls to enable an early production of the well. This paper encapsulates the design, functionality, and development testing of the intervention-less multistage fracturing sand control system. This novel technology is designed keeping in mind operator challenges associated with high cyclic stimulation pressure on completion tools, undesirable well intervention and associated high production costs.
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