Large-Diameter Coiled Tubing Becomes Available Safely Offshore Through a Newly Developed Spoolable Connector: Case Histories and Field Implementation

2005 ◽  
Author(s):  
Lyle E. Laun ◽  
Lindsay Robert Link ◽  
Kjell Tore Nesvik ◽  
Henning Boge
Keyword(s):  
Large Diameter ◽  
Case Histories ◽  
Coiled Tubing

Simple but Effective: A Case History Demonstrating Enhanced Performance and Simplified Logistics from New Rotary Steerable

2021 ◽  
Author(s):  
Marco A Aburto Perez ◽  
Anurag S Yadav ◽  
Steven R Farley
Keyword(s):  
Middle East ◽  
Large Diameter ◽  
Lessons Learned ◽  
Modular Construction ◽  
Case Histories ◽  
Design Elements ◽  
Local Content ◽  
Local Supply ◽  
Manufacturing Assembly ◽  
Target Depth

Abstract Based on input from key operators in the Middle East region, a new rotary steerable system (RSS) was launched after a compressed development schedule. This paper describes the development and introduction of the larger tool sizes needed for both onshore and offshore hole sections, including hole sizes from 12 in. and up, in the Middle East. It also outlines the deliberate design of the tool for local assembly and repair. Large diameter (9-1/2 and 11 in.) RSS designs used an existing, smaller design for Middle East applications in both offshore and onshore wells as a basis. When designing these new sizes, engineers took note of lessons learned with smaller sizes of the tool and incorporated design elements for local manufacturing, assembly, and repair. The resulting simple, modular construction enables increased levels of local content and provides for significant reductions in transportation, and therefore associated emissions. Of course, although local content and sustainability are highly desirable, performance is essential, and this paper describes case histories demonstrating how well the new tool worked in real-world Middle East applications. In one notable example, the newly introduced 9 1/2-in. diameter RSS was used to drill an offshore section in the Gulf of Arabia. The tool was mobilized after two older generation RSS had become stuck for days. Consisting primarily of argillaceous limestone, the formation had a history of stuck-pipe events. The new RSS was recommended for this application because of a slicker construction, with a fully rotational bias unit, minimal bottom hole assembly (BHA) stabilization, and an optimized junk slot area, which together help to reduce stuck-pipe risks. The tool drilled to the target depth in a single run, thereby achieving all directional requirements. Notably, after reaching the target depth, the assembly was tripped out of the hole without any requirement for backreaming. This seamless exit, in turn, indicated achieving a smooth wellbore. Other case histories demonstrate results with both new sizes of this tool. The paper also discusses in detail the ability to repair locally and engage the local supply chain. Specifically with Middle East applications in mind, a new, simple RSS design in large diameter versions has demonstrated success in offshore and onshore applications across the region. The design has also proven capabilities for manufacturing and repair local to operations, which enables maximizing in-country value, optimizing use of the tools, and energizing local supply chains.

Technology Focus: Coiled Tubing (June 2021)

2021 ◽  
Vol 73 (06) ◽  
pp. 41-41
Author(s):  
Alex Crabtree
Keyword(s):  
Large Diameter ◽  
Pressure Control ◽  
Operating Conditions ◽  
Business Analytics ◽  
Work Related ◽  
The Past ◽  
Coiled Tubing ◽  
Tight Carbonate ◽  
Geothermal Wells ◽  
Safety Considerations

Last year, this feature opened, almost inevitably, with comments on the effects the COVID-19 pandemic might have on our industry. Unfortunately, a year later, we probably have all experienced the effects, both personal and work-related. One of these effects is that there has been re-evaluation of what’s important. To understand what is important takes some reflection and evaluation of the past. In previous features, the focus has been on what is new or reimagined. Therefore, I thought that, in selecting papers for this year’s feature, it would be useful to select ones that look at coiled tubing operations performed and that have been evaluated in one way or another. From Bolivia comes a paper that reviews some 25 well interventions performed. Most of these operations are of a type that will be familiar to the reader. Also, some of the challenges that were faced in performing these coiled tubing operations will be familiar. These operations used a range of established types of coiled tubing operations and blended the techniques to meet particular operating conditions, especially location and logistics challenges. All conclusions and best practices that resulted, however, may not be familiar to all readers. During the past few years, many coiled tubing papers have focused on the use of coiled tubing in multizone fracturing operations, especially plug milling. An area of coiled tubing use in fracturing operations that has had less of an audience recently has been the use of coiled tubing in annular fracturing operations. This activity is still routinely being performed, particularly in Canada. The question has long existed about how the pipe is being eroded. In the related paper in this feature, the authors explain how they have tried to answer that question and have shared some of their review insights. In the past decade, coiled tubing size, weight, and grade all have continued to increase. Looking back at this trend and thinking about its effect on pressure control equipment led the developers in the third of this year’s papers to work on solutions for shear rams. This is particularly relevant after having just passed the 11th anniversary of the tragic Macondo disaster. Again, this year, I ask everyone to stay well. Recommended additional reading at OnePetro: www.onepetro.org. OTC 30408 Design and Safety Considerations To Perform Coiled Tubing Operations in Large-Diameter, High-Temperature Geothermal Wells by Ishaan Singh, Schlumberger, et al. SPE 204446 Implementing Business Analytics Software To Optimize Coiled Tubing Operations: A Digital Approach to Operations Efficiency by Xaymaca Bautista Alarcon, Royal Oaks Energy Services, et al. SPE 203272 The Reinvention of a Well-Established Coiled Tubing Intervention Work Flow Creates New Perspectives for Acidizing Openhole Horizontal Tight Carbonate Water Injectors by Sameer Punnapala, ADNOC, et al.

Increasing Lubricity of Downhole Fluids for Coiled-Tubing Operations

SPE Journal ◽  
2014 ◽  
Vol 20 (02) ◽  
pp. 396-404 ◽  
Author(s):  
Silviu Livescu ◽  
Steven Craig
Keyword(s):  
Laboratory Data ◽  
Real Life ◽  
Friction Reduction ◽  
The Other ◽  
Case Histories ◽  
Measuring Device ◽  
Coiled Tubing ◽  
General Terms ◽  
Metal On Metal ◽  
Offshore Crane

Summary The requirement for intervention operations in long-reach lateral wells continues to grow. In the US, it is not uncommon to be asked to run coiled tubing (CT) in 10,000-ft laterals. In general terms, a 2-in. CT typically has enough weight reserves to perform work to approximately half such a lateral. Even though increasing the CT diameter remains a theoretical option to improve reach, practically, it creates logistical challenges with both road transport and offshore crane-lifting/deck-loading limitations. Although fluid-hammer tools and downhole tractors have extended the reasonable operational range of CT significantly, they also increase circulating pressures and operational complexity. To reach a 10,000-ft lateral, the use of metal-on-metal lubricants will be required to work in conjunction with the other systems. Obviously, the use of lubricants is not new. Typical real-life results of current systems are approximately a 15 to 20% reduction in the coefficient of friction (CoF) from a generic 0.24 to 0.19. Occasionally, one could obtain smaller CoF values in the field. However, these actual results compare poorly to laboratory testing with a high-pressure rotational friction test. An extensive set of laboratory measurements was carried out with a linear-friction measuring device to understand and quantify the mechanical, chemical, and thermal metal-on-metal wet frictional effects. Particular attention was paid to the synergy between lubricants and the other commonly circulated brines and fluid friction reducers. Other tests, such as regained-permeability and aging tests were also performed. Arising from the trials is a new lubricant that reduced the linear CoF by approximately 40 to 60% (0.10 to 0.12) under downhole conditions. Friction reduction of this magnitude is expected to make it feasible to run CT in 10,000-ft laterals without the use of fluid-hammer tools or tractors. The paper details the new testing method, technical background of frictional drag, existing lubricant case histories, the new laboratory data, details of compatibility tests, and two new-lubricant case histories.

Design and Safety Considerations for Coiled Tubing Operations in Geothermal Wells

2021 ◽  
Vol 73 (07) ◽  
pp. 51-52
Author(s):  
Chris Carpenter
Keyword(s):  
High Temperature ◽  
High Surface ◽  
Large Diameter ◽  
Pressure Control ◽  
Coiled Tubing ◽  
Geothermal Wells ◽  
High Temperature Steam ◽  
Safety Considerations ◽  
Cooling Loop ◽  
Flow Cross

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 30408, “Design and Safety Considerations To Perform Coiled Tubing Operations in Large-Diameter, High-Temperature Geothermal Wells,” by Ishaan Singh, SPE, Danny Aryo Wijoseno, SPE, and Kellen Wolf, Schlumberger, et al., prepared for the 2020 Offshore Technology Conference Asia, originally scheduled to be held in Kuala Lumpur, 17–19 August. The paper has not been peer reviewed. Copyright 2020 Offshore Technology Conference. Reproduced by permission. The productive section in a high-pressure, high-temperature (HP/HT) geothermal Field A in the Philippines features shallow and deep reservoirs separated by a low-permeability formation. However, recent years have seen a reduction in production levels. To activate and enhance well production, coiled tubing (CT) nitrogen-lift operations were required. CT simulations were combined with simulations from the geothermal reservoir to overcome modeling limitations. The outcome helped the design of a new cooling-loop system and allowed optimization of the nitrogen-lift technique. As a result, two large-diameter geothermal wells were lifted safely with 2-in. CT. Introduction This study describes design and safety considerations in performing CT operations in high-temperature, large- diameter geothermal wells. The customized high-temperature-grade seal material was chosen to withstand high bottomhole temperatures (BHT) (600°F), and a heat exchanger riser system was designed and tested on the job to handle high-surface-temperature steam (350–400°F), thus mitigating potential well-control incidents. Challenges of Seal Damage Caused by High Surface Temperatures in Live Well Intervention The CT interventions in quenched HP/HT geothermal wells reduce the risk of surface equipment failure. The seal material readily available in the market is rated to 250°F, but, if quenching is not possible, the high-temperature steam (approximately 350–400°F) may flow into the pressure-control equipment, leading to seal damage and CT contingencies. At high temperatures (400°F), these seals are unusable. It becomes essential to use a surface heat exchange riser (HER) system to prevent this issue. Design and Execution of HER Systems in Field A To avoid any well contingency and to keep pressure-control equipment safe, HER systems can be used. Some basic designs for HERs are described in the complete paper. For this study, a customized 4.06-in. HER cooling system (Design 1, shown in Fig. 1) was designed to accommodate 2-in. CT pipe. Design 1 was chosen from an evaluation of three design candidates outlined in the complete paper. The wellhead stack featured seal elements rated to high temperatures (400°F). To prevent high- temperature steam from entering the wellhead stack, the blowout preventer, and other surface- equipment elements, an efficient HER system was designed wherein, while the CT is still in the well performing CT operations, the cold water can be pumped into the CT-stack annulus from the top flow cross through the cooling riser to the bottom flow cross and back to the return tank. The temperature of the cooling loop was continuously monitored to ensure that it was well below 212°F (the boiling point of water).

Well Cutting Without Explosives with Multiple Cuts on a Single Run

2021 ◽  
Author(s):  
Hanan Ghannam ◽  
Houssam Mourani ◽  
Brian Joseph Schwanitz
Keyword(s):  
Drill Pipe ◽  
Case Histories ◽  
Critical Part ◽  
Coiled Tubing ◽  
Electric Line ◽  
New Generation ◽  
Deviated Wells

Abstract Pipe cutting operations are often a critical part of stuck pipe situations, well interventions and plug and abandon operations which all need to remove cut sections of pipe from the well. Unlike traditional ‘blade’ style e-line cutters, which can jam under pipe compression or explosive pipe cutters, which need to dress-over the jagged cut by the rig, a new electric line mechanical cutter's unique design enables performance even if the pipe is under compression, in tension or is neutral. It can also perform multiple cuts in the same run, while creating a clean and machined cut with tool-entry friendly shape. This paper will describe the technology of the new generation cutter, present two case histories; one of multiple cuts of stuck drill pipe, per each run in hole, from Germany and one of a critical tubing cut from a subsea well in Nigeria, using electric wireline and tractor conveyed services for many tasks traditionally performed with coiled tubing in highly deviated wells. These "light vs heavy" solutions can often be done off-line from the rig.

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