- Conference Article
- 10.2118/231332-ms
Novel Fluid Placement Strategy: Lab-To-Field Execution for a Coiled Tubing Gas Shut-Off Treatment in a Highly Deviated Offshore Well
- Mar 17, 2026
- A Gomaa + 13 more +13
Abstract This paper presents a novel chemical gas shut-off solution for the Well A highly deviated well in the East Azeri field, addressing fluid placement challenges in high-inclination, multilayered gravel-pack completions. Novel crosslinked polymer systems, fluid modeling, and coiled tubing enabled selective gas shut off (GSO) and precise zonal isolation. The intervention significantly reduced gas production, preserved oil output, and sets a benchmark for future applications in complex Open Hole Gravel Packed (OHGP) wells. Well A, a multi-zone oil producer completed with OHGP, faced cyclic production due to gas handling limitations, suppressing output from Well A and nearby wells, with production rates of 1000 bopd and 40mmscfd in 2023. A PLT conducted in 2023 showed that Fasila B, the upper zone, contributed 57% of oil and 11% of gas, while Fasila D accounted for 84% of gas and 34% of oil. Hydraulic communication between Fasila B and Fasila D added significant complexity to targeting gas shut-off without impacting oil-producing zones, complicating intervention design and execution. To be able to shut off the gas from the lower zone without the polymer migrating to the upper zones leading to blockage, a novel chemical shut-off strategy was developed using XL-HEC gel formulations with tailored breaking profiles. A fast-breaking XL-HEC gel was designed for placement in the lower gas-producing zone, while a slow-breaking XL-HEC gel was used to protect the upper oil-producing zones. Once the fast-breaking gel degrades, a XL-Polymer based GSO chemical could be injected into the lower zone while the upper zones remained protected by the still-intact slow-breaking gel. Coiled Tubing Telemetry (CTT) technology and temperature logging aided in confirming hydraulic communication through the gravel pack and guided fluid paths, while fast and slow-breaking crosslinked systems were pumped as a pill train to protect Fasila B and target Fasila D. Fluid placement modeling optimized pump rates, coiled tubing placement, and penetration depth, ensuring selective gas shut-off in Fasila D using an organic crosslinked permanent sealing fluid system without impacting Fasila B, effectively addressing challenges in complex OHGP wells. Analysis of injection, pressure, and temperature data through coiled tubing (CT) enabled precise calibration of depths for optimized fluid placement, mitigating contamination and monitoring crossflow. Injection tests ensured radial distribution despite an eccentric coiled tubing configuration. The intervention achieved initial gas reduction from 47 mmscfd to 22 mmscfd. This job introduced a novel two crosslinked polymer system as a temporary isolation fluid for complex OHGP environments, utilizing temperature surveys and digital fluid placement modeling for precision. The approach creates a path for accurate zonal isolation, optimized intervention effectiveness, and addresses challenges in high-inclination, multi-zone completions. It sets a framework for future cases and demonstrates its applicability in similar complex well environments globally.
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