A major operator in onshore Middle East was planning to conduct a water shutoff intervention in an oil producer with very high water cut and a naturally fractured carbonate reservoir. The well was completed horizontal with 18 inflow control device (ICD) elements and 16 swell packers along the production liner and openhole section. The production tubing had an electrical submersible pump (ESP) and Y-tool to allow access to the horizontal section. Due to the complexity of the completion and limited access to the reservoir, an engineered approach combining a precise placement method with a reliable water conformance chemistry was necessary. The engineered approach relied on the use of coiled tubing (CT) equipped with real-time downhole measurements, high-pressure rotary jetting tool, backpressure valve, and through-tubing inflatable packer. Downhole readings included CT internal pressure, annulus pressure, annulus temperature, and casing collar locator (CCL). They were used both to achieve optimum use of the rest of the bottomhole assembly during the intervention, and to evaluate treatment effectiveness. The selected water conformance fluid system combined a medium-molecular-weight polyacrylamide crosslinked gel for fissure plugging with a nanoparticulate leak off control additive to keep most of the polyacrylamide gel within the fissure network. In horizontal wells, critical steps for water shutoff, such as proper wellbore conditioning, accurate placement technique and controlled fluid penetration, cannot be accomplished through conventional methods, especially in completions with flow control components, and innovative methodologies are required for efficient intervention. An evolved approach for water shutoff intervention relying on real-time downhole data was implemented for the first time in this field, reducing water production from 1300 B/D to 400 B/D, while increasing oil production from 180 B/D to 350 B/D. In the first run, high-pressure rotary jetting tool was used to condition the wellbore tubulars across the inflatable packer planned anchoring depth. In the second run, the through-tubing inflatable packer was set at the target depth, and the water shutoff treatment was pumped into the formation across the target ICDs. CT real-time downhole measurements were instrumental for accurate depth correlation, ensure optimum differential pressure across the high-pressure jetting tool, to control inflation and anchoring of the through-tubing inflatable packer, and to monitor the water shutoff treatment. This engineered approach, which leverages the use of real-time downhole data to accurately control the positioning and actuation of high-pressure jetting tools and through-tubing inflatable packers, enables critical interactions with formation and completion. This level of control is critical in water shutoff operations, for it enables the customization of original designs based on the changing downhole conditions to achieve maximum effectiveness of the sealing fluids.

Objectives/Scope: Operations in onshore fields at UAE are affected during the months of March through June by the weather, as sand storms are created and attack the area, there is always a need to plan abandonments to avoid harm to any personnel, environment and minimize damage to facilities. In March 2016, while executing a logging with coiled tubing operation on a well at one of ADCO fields with 1.75'' coiled tubing (CT), a message from the field's safety team was communicated to terminate all operations and lower all cranes due to a severe storm approaching the area. It was required to evacuate the area within two hours. A team was formed at the base communicating with the in-charge engineer onsite to safely secure the CT string at surface, which would allow for abandonment while maintaining well control (WC). Methods, Procedures, Process: During this process three options were analyzed: the first option was to add additional support to the injector head (IH) and leave the coiled tubing package rigged up; this option was rejected because it would not guarantee WC in the event that the storm takes down the crane along with IH. The second option was to secure the CT with lower Blow out Preventers (BOP), Combi type, then shear it and rig down the IH. This approach provided WC, but it created additional risk and limitations when resuming the retrieval operations after the storm. The third option was to secure the CT utilizing the upper BOP, Quad type, and keep the pipe held with the lower BOP while secured by the upper BOP. The removal of the IH would leave the section of pipe along with the logging tools held while the well is secured using the BOP provided WC. Furthermore, a cap was installed at the top of BOP and a pressure gauge was set to monitor pressure during retrieval of the pipe. Results, Observations, Conclusions: After analyzing available options, the third alternative was selected by the team; as this option addressed WC and allowed safe recovery by rigging down the top BOP, reconnecting the pipe through double end connector into the IH, and rigging up the required equipment to proceed with the pipe recovery operation. Novel/ Additive Information: Availability of two BOPs reduced the complexity of pipe recovery in addition of maintaining WC at all stages of the operation. Logging with CT is one of the most complicated rigless operations in terms of rig up and rig down, utilizing two BOPs provided the option of securing the well at any point of the operation with reduction in difficulties of pipe recovery. This paper illustrates contingency procedure for CT cut and recovery in abnormal situations through a certain rig up setup.