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A major North Sea operator was looking to improve production from low permeable reservoirs in mature assets. Under-displaced, high proppant concentration fracs must be pumped in an efficient manner to unlock the value potential. A new single-trip, multistage stage proppant fracturing system was developed to tackle these operational constraints and reliably perform in challenging offshore environments. This paper presents the evolution of this system from a concept to field implementation on the Norwegian Continental Shelf. The developed solution, a frac sleeve (FS) system operated by a service tool assembly (STA) which can be run on drillpipe or coiled tubing. The unique feature of this system is that it allows multistage stimulation in a single trip without utilizing slips or packers, which could pose the risk of a stuck STA. Suited for both open-hole and cemented applications, the system is particularly beneficial for wells with limited slack-off capabilities. Key considerations of the design included operability in proppant-packed environments, erosion resistance, and multiple contingencies built into the STA to allow operational flexibility. An extensive qualification program was successfully executed to validate the system's functionality, particularly in hostile, proppant-packed environments, including an erosion test wherein 2,000 tons of proppant was pumped through the STA at 30 bbl/min. In preparation for field deployment, drillpipe and liner simulations were run, and operational planning and risk assessments were held. Following these assessments, the system was deployed for the North Sea operator in a trial well in summer 2021. During the stimulation program, an under-displaced, high rate, and high proppant concentration frac was pumped in each stage, followed by immediate closing of the sleeves prior to reversing out the remaining under displaced proppant. This paper captures the wins, challenges, and key learnings from the initial trial well, and how these learnings were used to optimize the second well. Also detailed is the lifecycle of a novel, patented proppant-stimulation technology starting from initial concept to downhole deployment. Enabling optimized, proppant fracturing in an operationally efficient manner plays a crucial role in improving the productivity and economic viability of a well, and allows for improved oil recovery (IOR) from existing offshore infrastructure. The findings and lessons learned in this paper will contribute to the state of knowledge regarding proppant fracturing on the Norwegian Continental Shelf.
A major North Sea operator was looking to improve production from low permeable reservoirs in mature assets. Under-displaced, high proppant concentration fracs must be pumped in an efficient manner to unlock the value potential. A new single-trip, multistage stage proppant fracturing system was developed to tackle these operational constraints and reliably perform in challenging offshore environments. This paper presents the evolution of this system from a concept to field implementation on the Norwegian Continental Shelf. The developed solution, a frac sleeve (FS) system operated by a service tool assembly (STA) which can be run on drillpipe or coiled tubing. The unique feature of this system is that it allows multistage stimulation in a single trip without utilizing slips or packers, which could pose the risk of a stuck STA. Suited for both open-hole and cemented applications, the system is particularly beneficial for wells with limited slack-off capabilities. Key considerations of the design included operability in proppant-packed environments, erosion resistance, and multiple contingencies built into the STA to allow operational flexibility. An extensive qualification program was successfully executed to validate the system's functionality, particularly in hostile, proppant-packed environments, including an erosion test wherein 2,000 tons of proppant was pumped through the STA at 30 bbl/min. In preparation for field deployment, drillpipe and liner simulations were run, and operational planning and risk assessments were held. Following these assessments, the system was deployed for the North Sea operator in a trial well in summer 2021. During the stimulation program, an under-displaced, high rate, and high proppant concentration frac was pumped in each stage, followed by immediate closing of the sleeves prior to reversing out the remaining under displaced proppant. This paper captures the wins, challenges, and key learnings from the initial trial well, and how these learnings were used to optimize the second well. Also detailed is the lifecycle of a novel, patented proppant-stimulation technology starting from initial concept to downhole deployment. Enabling optimized, proppant fracturing in an operationally efficient manner plays a crucial role in improving the productivity and economic viability of a well, and allows for improved oil recovery (IOR) from existing offshore infrastructure. The findings and lessons learned in this paper will contribute to the state of knowledge regarding proppant fracturing on the Norwegian Continental Shelf.
The liner shoe is a critical component of the lower completion architecture, allowing for auto-filling of the liner and enabling circulation during deployment, followed by closure to provide a closed system. Advancements in completion technologies have resulted in the development of an intelligent electronic liner shoe (ELS) that can be remotely operated without the need for intervention or pumping trigger devices downhole. The electronic liner shoe suited for deployment on 4½-in. liner was developed based on specific requirements from a major operator in the middle east. The electronic liner shoe was qualified per ISO 14998/API 19AC requirements up to 280°F. Additionally, the electronics module incorporated in the tool was vibration and shock tested at temperature. After an extensive qualification test program and thorough pre-job qualification and planning, candidate wells were chosen for the initial deployment of the ELS in Onshore wells. The ELS was first deployed in November 2020 in the Bab field in UAE. This paper highlights the excellent deployment performance using ELS for the onshore field development in UAE. This paper also presents the operational considerations for programming the remote activation mechanism, pre-job risk analysis, technology qualification, and post-job lessons from the first installation, resulting in the ELS’ successful deployment in six additional wells in the onshore fields. The paper also shares the unique benefits the ELS provided the operator towards enhancing operational efficiency, as well as reducing risk and costs associated with running liners.
As part of a strategic initiative to increase production from low-permeability mature assets on the Norwegian Continental Shelf, a single-trip, multistage proppant fracturing system was developed. A frac service tool assembly (STA) is deployed on a dedicated work string, and the fracs are pumped before installing the upper completion. With a new frac head concept, the system set a record for stage-to-stage frac time, achieving targets for reduced costs, operational time, and health, safety, and environmental (HSE) exposure. Following several successful single-stage frac jobs in the field, a horizontal well was planned in the lower part of a low-permeability formation. A higher permeability formation at the top of the reservoir would be drained through multiple transverse fractures. An uncemented liner with frac sleeves and open-hole packers was designed for the completion. Detailed pre-job meetings were held with all involved parties to establish the requirements for the multistage frac system and fracturing program and to build procedures and contingencies for various stages of the operation. The well was completed and stimulated in autumn 2022, with three proppant fracs placed in a single trip. The three stages were pumped as per the frac program. The under displaced slurry volume was reversed out before moving to the next zone. After stimulation, the upper completion was installed, and a wireline tractor was used to shift open the frac sleeves in a single trip. The new frac head stand was rigged-up and down in only 30 minutes, compared to 10 hours with a conventional frac head design. This greatly reduced time between stages and working at height and in the red zone. In addition, there were fewer potential leak paths, reducing the potential for downtime. The well was a successful proof of concept for stage efficiency, exceeding the target of performing two frac stages within a 24-hour period. Further efficiency gains could see stage time reduced to achieve up to four stages within a 24-hour period. A new well with seven stages is planned to be drilled and completed in the summer of 2024 using the same concept. This paper presents the successful use of a newly developed single-trip multi-frac system. The system demonstrated a proof of concept for the further development of tight and low-permeability mature assets. Several new wells, including subsea wells, are expected to use this technology.
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