Successful Offshore Coiled tubing Well Intervention in Mega-Reach Wells in the Russian Caspian: A 4-Well Case Study

Burdin, Konstantin; Mazitov, R.N.; Bravkov, P.V.; Lobov, M. A.; Kichigin, Anatoly; Stepanov, Vladimir; Eliseev, D.; Zemchihin, A.; Byakov, A.

doi:10.2118/173685-ms

Day 2 Wed, March 25, 2015 2015

DOI: 10.2118/173685-ms

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Successful Offshore Coiled tubing Well Intervention in Mega-Reach Wells in the Russian Caspian: A 4-Well Case Study

Konstantin Burdin

R.N. Mazitov

P.V. Bravkov

et al.

Abstract: Korchagin oilfield is located in the northern part of the Caspian Sea. Drilled wells are mega-reach (MD/TVD ratio greater than 3.0) with measured total depth (MD) up to 23,622 ft [7,200 m] and vertical depth of only 5,118 ft [1,560 m]. This presented a great challenge for coiled tubing (CT) well intervention even with the help of state-of-the-art hydraulic tractors. Limited working area, weight restrictions, challenging well geometry, completion features and lack of experience in offshore CT operations in the … Show more

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Cited by 3 publications

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Gas Shutoff Treatment in Mega Rich Horizontal Well With Coiled Tubing Inflatable Packer for North Caspian

et al. 2015

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The Caspian Sea region, which includes Russia, Azerbaijan, Kazakhstan, Turkmenistan, Uzbekistan, and Iran, is one of the oldest oil-producing areas in the world and is an increasingly important source of global energy production. The area has significant oil and natural gas reserves from both offshore deposits in the Caspian Sea itself and onshore fields in the region. Korchagin oilfield is located in the northern part of the Caspian Sea. Drilled wells are mega-reach (MD/TVD ratio greater than 3.0), with measured depths (MD) up to 23,622 ft and vertical depths of only 5,118 ft. This presents a great challenge for any well interventions, even for Coiled Tubing (CT) equipped with state-of-the-art hydraulic tractors. Limited working area, weight restrictions, challenging well geometry, completion features and lack of experience in offshore CT operations in the North Caspian Sea, required complex pre-job activities to optimize job design, select proper downhole tools and prepare a robust layout plan. This paper illustrates North Caspian project preparation challenges, on-the-job troubleshooting and workflow, supported by the well case studies and results from the first CT operation in North Caspian Offshore. Lessons learnt from the project, where all defined objectives were achieved with zero HSE (health, safety and environment) incidents, were also captured to assist in future campaigns with similar operational environment.

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Gas Shutoff Treatment in Mega Rich Horizontal Well With Coiled Tubing Inflatable Packer for North Caspian

et al. 2015

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Mega Reach Case Study, Saudi Arabia; The Application of Fluidic Oscillation Vibratory Tools in Tackling a Challenging Coiled Tubing Well Intervention

Duthie

Namlah

Abdulghani

et al. 2017

Day 2 Wed, March 22, 2017

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Every year, the complexity of horizontal wells grows, and matrix stimulation of these wells is key for maintaining production levels and improving the draw-down from producing formations. In the subject field, many wells are drilled as mega-reach with measured total depths up to 33,000 ft. The mega-reach represents a significant challenge for coiled tubing to reach the total depth (TD) and perform well interventions such as stimulation and logging. Coiled tubing (CT) may lock up before TD, and it can be challenging to understand the root cause. One difficulty is differentiating between lockups due to the well conditions and bottom-hole assembly (BHA) malfunctions. Electric submersible pump (ESP) completions contain bypass assemblies that impose an additional challenge introducing a restriction in tubing internal diameters. The restriction is less than 2.50" in the completion, increasing to 8-1/2" for the open hole, extending for at least 5,000 ft laterally in the producing formation. With the large variation in internal diameter (ID), the hydraulic tractor option is excluded from the mega-reach aid list, though it has proven reliable in extending the reach of CT for 6-1/8" openhole sizes in the same field. Therefore, the challenge here is to derive the maximum output possible from fluidic oscillation vibratory tools to achieve forces close enough to tractor forces and ultimately accomplishing the intervention objective. A combination of mechanical and chemical solutions was the designated approach to tackle the challenge. After reviewing all the possible solutions, tractors were excluded due to the extreme expansion ratio needed resulting in lower pulling forces. A fluidic oscillation tool inducing axial vibration of an absolute magnitude exceeding 1,600 lbf was yard tested and deployed as a solution in combination with a selection of friction and drag reducers. This paper will illustrate the reach challenges, analysis performed, and show how we could utilize the latest developments in fluidic oscillation vibratory tools. It will also include downhole real-time data acquisition assisting the understanding of lockup occurrence, as well as quantifying the improvements in the pre-job tubing force model simulation.

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An Improved Method for Shifting Sliding Sleeves on ICD Screen Completions in Extended- and Mega-Reach Applications Combining a Novel Shifting Tool with Coiled Tubing Well Tractor Technology

Mannil

Lobov

Buyanov

et al. 2017

Day 2 Wed, March 22, 2017

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Korchagina and Filanovskoe oil fields in the north Caspian Sea have many extended- and mega-reach wells that uses inflow control device (ICD) screen completions with sliding sleeves. This completion technique empowers the operator with the ability to shut off unwanted water/gas breakthrough and allows for more control of injection or inflow with unlimited number of stages or zones. This paper describes a new verified workflow to successfully intervene these wells and manipulate (open/close) these sliding sleeves using coiled tubing (CT). It has proven challenging to shift these sliding sleeves using conventional methods with CT owing to the limitation of available weight on bit (WOB) at the toe end of those extended-reach wells, even when using large-size CT strings. The new proposed workflow uses a well tractor operated in tandem with a hydraulic shifting tool to generate the required shifting force downhole. The bottomhole assembly (BHA) also includes a novel flow control sub, assembled between the shifting tool and the tractor, with the ability to control the flow to selectively activate the tractor, the shifting tool, or both, based on surface commands by manipulating pump rate. To verify the methodology, a realistic well scenario was simulated at a test site by installing two ICD screens with sliding sleeves at the end of a 1,000-ft-long horizontal flow loop. The sleeves on each ICD screen required approximately 4,000 lbf set-down force to open. The available WOB at the end of horizontal loop with 2-in. CT was only 1,000 lbf; applying more than 1,000 lbf set-down load could have detrimental effects, including CT buckling. The 3⅞-in. OD well tractor used for the job was able to generate 6,000 lbf of pulling force downhole, which was more than enough to shift the sleeves open. Both sleeves were successfully opened by tractoring down while maintaining both the tractor and the shifting tool in the on position, which was achieved by manipulating the flow control sub using pump rate cycles. Both sleeves were then successfully closed, one after the other, by pulling with the CT with the tractor turned off while maintaining the shifting tool in the on position, again achieved by manipulating the flow control sub. Live downhole pressure and force measurements were key in confirming proper functionality of the tractor and identifying different tool modes. Having real-time data is also crucial for proper depth correlation using casing collar locators (CCL) or gamma ray measurements to ensure activating the correct sleeves. This marks the first time that a workflow was verified on the use of pull force generated by a well tractor to manipulate completion accessories in extended-reach well interventions using CT. The technology, preparation, results, and prospects of implementation are discussed in this paper.

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Successful Offshore Coiled tubing Well Intervention in Mega-Reach Wells in the Russian Caspian: A 4-Well Case Study

Cited by 3 publications

References 3 publications

Gas Shutoff Treatment in Mega Rich Horizontal Well With Coiled Tubing Inflatable Packer for North Caspian

Gas Shutoff Treatment in Mega Rich Horizontal Well With Coiled Tubing Inflatable Packer for North Caspian

Mega Reach Case Study, Saudi Arabia; The Application of Fluidic Oscillation Vibratory Tools in Tackling a Challenging Coiled Tubing Well Intervention

An Improved Method for Shifting Sliding Sleeves on ICD Screen Completions in Extended- and Mega-Reach Applications Combining a Novel Shifting Tool with Coiled Tubing Well Tractor Technology

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