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An Abu Dhabi offshore field development plan comprises of ERD wells requiring intermediate / production casing depths of up to 23,000 ft with horizontal sail sections of approximately 10,000 ft of length. The original completion design involved drill pipe deployed intermediate completions, followed by a separate upper completion run with anchor latched seals. Over time, operational practices enabled the use of single-trip completions with tubing mounted packers, saving 2 – 3 rig days per well, but introduced some challenges. The objective was to maximize the usage of single-trip completions while continuing to leverage the advantages of an intermediate completion. Additionally, deployment enhancers such as lubricated fluid, low drag centralizers, and / or upsized tubing were included in the design to extend deployments deeper. A comprehensive application review was conducted covering the system technical limits during installation and well life cycle operations. Detailed testing and modelling were carried out to understand the impact of deployment enhancers. This paper will provide insight as to the detailed drivers and design of the lubricated fluid and low drag centralizers. Additionally, the strategy for well trials and their successful results will be covered. Several enhanced single-trip completion systems were successfully installed, confirming the efficiency gain of 2 – 3 rig days per well in high angle, deep casing ERD wells. The fluid lubrication provided 30 – 50% cased hole friction factor reduction. Additional long term well life cycle efficiencies were achieved, such as OPEX savings during future workover operations resulting from the anchor-latch feature and maintaining the same ID from the production packer down to the liner for future lower completion retrofit without requiring the production packer to be retrieved. While single-trip upper completion systems have been used in the past, achieving the two-trip completion system advantages with a single-trip system was not possible before. Additionally, deploying the enhanced system coupled with deployment enhancers has allowed the completion of high angle and deep casing ERD wells. Expectations are to extend application of this completion design to even deeper casing depths.
An Abu Dhabi offshore field development plan comprises of ERD wells requiring intermediate / production casing depths of up to 23,000 ft with horizontal sail sections of approximately 10,000 ft of length. The original completion design involved drill pipe deployed intermediate completions, followed by a separate upper completion run with anchor latched seals. Over time, operational practices enabled the use of single-trip completions with tubing mounted packers, saving 2 – 3 rig days per well, but introduced some challenges. The objective was to maximize the usage of single-trip completions while continuing to leverage the advantages of an intermediate completion. Additionally, deployment enhancers such as lubricated fluid, low drag centralizers, and / or upsized tubing were included in the design to extend deployments deeper. A comprehensive application review was conducted covering the system technical limits during installation and well life cycle operations. Detailed testing and modelling were carried out to understand the impact of deployment enhancers. This paper will provide insight as to the detailed drivers and design of the lubricated fluid and low drag centralizers. Additionally, the strategy for well trials and their successful results will be covered. Several enhanced single-trip completion systems were successfully installed, confirming the efficiency gain of 2 – 3 rig days per well in high angle, deep casing ERD wells. The fluid lubrication provided 30 – 50% cased hole friction factor reduction. Additional long term well life cycle efficiencies were achieved, such as OPEX savings during future workover operations resulting from the anchor-latch feature and maintaining the same ID from the production packer down to the liner for future lower completion retrofit without requiring the production packer to be retrieved. While single-trip upper completion systems have been used in the past, achieving the two-trip completion system advantages with a single-trip system was not possible before. Additionally, deploying the enhanced system coupled with deployment enhancers has allowed the completion of high angle and deep casing ERD wells. Expectations are to extend application of this completion design to even deeper casing depths.
Designing and executing open hole completions in extended reach wells pose challenges, especially with the multiple-zone isolation requirement and subnormal reservoir pressure. Successfully implementing correct and innovative technology and optimizing the completion design is instrumental in achieving well objectives. The design scope included pressure-activated gas-lift valves (GLVs) enabled without intervention and the in-situ auto gas lift (AGL) using formation gas to aid the lifting of bottom oil sands. The open hole lower completion design included multiple sand screens with integrated sliding sleeve doors (SSDs), slim swell packers for isolation, and a fluid loss control device. Unlike the historic upper completion, which had conventional GLVs requiring intervention for changeovers, the novel approach used casing pressure-activated shearable GLVs. This eliminated the need for electric-line (E-line) based tractor stroker intervention during installations/changeovers of GLVs from dummy valves at higher angles (greater than 65°). The design process involved a gas-lift design simulation for depth placement of pressure-activated GLVs (unloader and orifice) and orifice size selection. In addition, it included AGL solutions with variable choke positions and an integral screen for sand control in the upper completion, enhancing oil production. The casing pressure-activated shearable GLVs, initially installed as dummy valves in the upper completion, facilitated the completion test through the annulus against the packer. The fracture rod broke at the predetermined pressure, and the valves operated/converted as unloader/orifice valves. The innovative upper completion design provided the option to use the existing shallow gas zone behind the production casing by deploying AGL solutions between the liner hanger packer and production packer. This allowed flexibility by manipulating variable choke positions for gas-rate control, featuring its unique shroud-and-screen design that best fit sand control needs. The design optimization involved applying slim swell packers (reduced stop-ring diameter) to minimize drag forces and enable completion through an unstable shale section. The production borehole enlargement technique was adopted, with acceptable differential pressure across the swell packers to reduce equivalent circulating densities (ECDs) and ensure smoother conveyance. The completion rig time was reduced by eliminating the E-line tractor operation for GLV changeovers in the upper completion. The deployment of this technology and design optimization enabled the successful completion of three zones in an approximately 3,000-ft lateral section. The well was successfully completed, activated, and hooked up for production, resulting in a significant increase in incremental production in the field. This design, featuring multiple innovative solutions, is one of the most unique completion designs deployed in the field over the previous 20 years. It represents an innovative approach where flow assurance for later well life can be planned by using AGLs, which leverage existing shallow gas to sustain production. The AGLs can be activated through rigless tractor intervention when needed.
The planning and execution of an Extended Reach Drilling (ERD) project in the Cambay field presented numerous challenges due to the confined nature of the well and the objective of accessing previously untapped reserves. With a step-out ratio of 3:1, indicating a significant increase in complexity compared to conventional Drilling, careful consideration was given to the well path trajectory, casing seat selection, and open hole size selection during the initial planning phase. These critical aspects played a pivotal role in identifying and addressing the unique challenges inherent in ERD operations which necessitated the application of innovative techniques for mitigation. Given the intricate structure of the extended reach well, the key hurdles include torque and drag issues, hole cleaning, casing running, equivalent circulation density control, bottom hole assembly stuck, side tracking, wellbore stability, and well activation with coiled tubing and/or Eline based tractor stroker intervention. These challenges were overcome with deployment of cutting-edge technology in Drilling viz. application of drill pipe severing tool (DPST) & under reamer tool and in Completion viz, shearable gas lift valves, trimmed swell packers, auto lift gas technology, and tapered string coiled tubing. The well also witnessed some complex fishing operation to retrieve stuck Eline tractor tool which was a difficult undertaking. The paper will summarize the ERD project, outlining the methods, challenges, and technologies used while effectively Drilling and successful Completion of the longest ERD well in the offshore region along India's west coast, with a recorded measured depth of 3,830.79 meters. It will also provide vital insights and lessons acquired from the extensive Drilling and Completion procedures, adding to the knowledge base, and providing as a roadmap for future ERD initiatives of a similar nature.
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