Enhancing Well Integrity and Efficiency: Deploying the 7-Inch Annulus Casing Packer (ACP) Tieback System for 9-5/8" Casing Remedial & Gas Lifting Completion Purpose in ADNOC Onshore Field

Abstract The deployment of the 7-inch Annulus Casing Packer (ACP) Tieback system in Field A's 9-5/8-inch casing remedial and gas lifting completion operations yields significant advantages. With its ISO 149998 V0 qualification, the ACP surpasses conventional Tieback methods, reducing the operation timeline by 5-7 days. This is achieved by incorporating design features such as cement passage ports, a V0 rated packer, and a Landing Collar with a non-shearable ball seat. The inclusion of a non-shearable ball seat obviates the need for a Bridge Plug or Acid Soluble Cement to isolate the open hole or perforation below the top of the liner, thereby eliminating the risk of cement slumping or falling into the reservoir instead of filling the annulus between the 9-5/8-inch casing and 7-inch Tieback. This enhancement not only strengthens well integrity but also leads to significant time and cost savings, representing a promising advancement in wellbore completion techniques. Our approach revolves around the implementation of the 7-inch Annulus Casing Packer (ACP) Tieback system with a cost-effective slurry design. The assessment of long-term well integrity necessitates the use of a stress simulation tool. Tieback casing and cementing represent remedial techniques designed to cover damaged intermediate casing above the top of an existing production liner or open hole. Furthermore, they adhere to company standards, especially when the Gas Lift Mandrel is required. Tieback installation and cementing under such conditions involve important distinctions and additional risks. The use of washes and spacers ahead of cement slurries is crucial to prevent cement contamination and mixing with the fluid in the wellbore, a critical consideration due to the potential incompatibility with the completion fluid or brine. Proper evaluation of the outer casing's condition is imperative. Applying safety factors to determine the outer casing burst pressure, selecting TOC, displacing fluid, cement density and rheology, accordingly, are essential steps to lower the maximum surface pressure. Drawing from the success of implementing this approach in 8 wells in Field A, it has significantly reduced operation timelines by 5-7 days, obviating the need for acid-soluble plugs or bridge plugs. The cost-effective slurry design, combined with stress simulation that optimizes well longevity by simulating pressure and temperature cycling during the well's lifespan, enhances wellbore integrity. This paper represents a novel solution for enhancing wellbore completion efficiency and integrity. As well as contribution in suitability initiative by reducing operation time 5-7 days. Practicing engineers can benefit from this advancement by streamlining their operations and achieving improved outcomes while reducing costs.