bluuebunny/crossref_metadata_2025_split huggingface dataset:
Concentric Coiled Tubing Technology for Well Cleaning and Evaluation in Complex Horizontal Wells: A 3 Wells Case Study from Heavy Oil Field, Kuwait
Authors: Kothari Nikita , Ababou Mounir , Rao Srinivas , Garcia Jose Gregorio 
Published: March 2019

Abstract
A few horizontal wells were drilled in Kuwait, heavy oil field, as a part of cold production testing. Various workover interventions were performed on these wells. However, some of the wells showed sharp production decline and were producing below expectations. It was suspected that formation damage may have occurred in these ultra-low reservoir pressure wellbores due to the overbalance of the fluids used during interventions.
Concentric coiled tubing (CCT) technology comprising of a downhole jet pump, was recently employed for the first time in Kuwait and was determined to be an effective method to clean the horizontal sections and investigate the reasons for the production problems. The single phase cleanout fluid is circulated down the inner string to power the jet pump, creating a localized drawdown that vacuums the formation solids or fluids out of the wellbore and the combined sand/fluid stream returns via the CCT annulus. The multiple operating modes provided the benefit of cleaning and treating the wellbore in the same run.
This specialized system was successfully utilized to remove sand, evaluate the formation damage and enhance production; meeting all objectives in a single well intervention. Pressure and temperature gauges run below the tool on two wells recorded bottomhole pressure of only 150 psi. Post-production results has pushed the boundaries of the well interventions in heavy oil field in Kuwait and has unlocked several wellbore cleanout and formation damage evaluation opportunities using the CCT technology.
This paper reviews the benefits of the concentric coiled tubing technology and provides a comprehensive case study of the first three horizontal wells. The analysis of the sand and fluid influx profiles obtained during the vacuuming process assisted in to evaluating well production provided crucial data in formulating a management strategy.
Optimizing Coiled Tubing Extended Reach Operations with Real Time Simulations
Authors: Larrondo Adrian , Ranieri Juan Pablo , Marozzini Diego Alejandro 
Published: March 2019

Abstract
With the objective of increasing productivity and achieving an economically sustainable development of the non-conventional reservoirs in Argentina, the oil and gas (O&G) energy companies are focused on drilling horizontal wells with lateral extensions between 2500 m (8,200 ft) to 3000 m (9,840 ft) in length. In order to produce commercial volumes of hydrocarbons, it is mandatory to fracture-stimulate multiple zones.
The "plug and perf" method continues to be the most common completion technique in the field. Once the stimulation is completed, a coiled tubing (CT) milling operation is undertaken to remove the frac plugs. Critical to achieving a successful operation is reaching total depth (TD) in the well with the coiled tubing. The precise determination of the operational coefficient of friction (CoF) between the coiled tubing string and the production casing, could be the difference between failure and success, affecting both the technical and economical results of the project.
The goal of this paper is to share the lessons learned after more than forty extended reach operations and the experience earned on the utilization of real time simulations to define both, the tensile load exerted for an extended reach tool and the coefficient of friction found during coiled tubing operations. Also demonstrate, by analyzing real life applications, how the implementation of this technology and new working methodology, allows to anticipate deviations with respect to the "normal" values of friction, achieve a better understanding of the influence of solids in the completion to the coefficient of friction and obtain a more efficient use of the metal-metal lubricant utilized during the milling operations.
In-Line Quench and Temper Technology Applied to CT Improves Safety and Reliability in Extended Reach U.S. Shale Operations
Authors: Galvan I. I. , McClelland G. , Gagen E. , Piller G. 
Published: March 2019

Abstract
In unconventional resource plays across the United States, lateral well sections are being extended beyond 10,000-ft. The increased application of larger coiled tubing (CT) in 2.375-in and 2.625-in diameter for operations in wells with mid-to-high pressure has pushed the reliability envelope for conventional CT strings. Lower expected life, while the tubing remained within safe working limits, restricted the Operator's completion and clean out options, which acted as a potential barrier to longer lateral intervention.
The performance of CT Interventions in complex extended reach wells with 10,000-ft+ laterals is presented in field case studies detailing extended lateral reach, average service life with statistics at retirement, and common failure modes.
The manufacturing of CT strings with improved reliability, life, and reach capabilities has been paramount to extending the limits of CT applications. Well Operators and Service Companies have embraced newer CT technologies and highly engineered string designs that can perform safely in challenging well conditions. The latest technological innovation in the CT manufacturing industry is the implementation of an in-line quench and temper (Q&T) process. The Q&T process enhances the overall CT life and predictability by producing tubing with more uniform microstructure throughout its entire length, increased material strength, and improved bend fatigue performance.
When the Q&T product is combined with rapid-taper strip technology and iterative CT design methodology, unique CT string configurations can be produced that achieve unprecedented well lateral reach with improved service life. The combination of these factors enables the safe application of CT with greater diameter to wall thickness ratios (D/t) and increased wall thicknesses. Heavy CT walls including0.276-in which is the thickest used historically in CT interventions, are being deployed, all while satisfying weight constraints, pressure ratings, tensional load limits, and fatigue performance requirements.
Actual field operations using this Q&T CT technology have experienced overall increased average running footages of 40%-60% compared to conventional grade strings. This performance has resulted in lower CT replacement rates, creating a cost- effective and time-saving solution for well intervention and drilling operations.
As new horizontal drilling and completion technologies are developed and utilized in the industry, CT manufacturers and Service Companies will continue to innovate and provide engineered solutions that enable coiled tubing to be a robust, safe and reliable technology in the toughest environments and on the most critical projects.
Phased Array Ultrasonic Tools Provide Precise Measurement of Geometrically Complex Components Such as Nipple Profiles Downhole, Confirming Safety Critical Dimensions.
Authors: Troup Duncan 
Published: March 2019

Abstract
Many components used in completions are geometrically complex and machined to tight tolerances. Precisely measuring the internal profile dimensions of these items after installation is impossible using mechanical means such as calipers due to the sharp ID changes precluding good finger contact. This paper will discuss the use of a precision ultrasonic tool that allows accurate measurements to be taken without physical contact, and to detail a case study of inspecting a landing nipple profile.
Mechanical finger type caliper devices cannot measure internal diameters unless physically in contact with the surface and this is not possible at all times. An alternative to physical measurement is to reflect a projected beam of acoustic energy from the target and, knowing the speed of sound of the well fluid, calculate an ID measurement. Using a number of ultrasonic transducers allows beamforming techniques to precisely focus the sound to produce good resolution. The ultrasound tool uses a circumferentially arranged band of 288 sensors that operate in a phased array to determine accurate ID of even very complex profiles.
A landing nipple is a component that is designed for the installation of flow control devices in a well completion and comprises a seal area and a lock profile. The dimensions of these faces are very precisely controlled during manufacture because the device being installed, such a safety valve, must fit perfectly in order to provide a seal and mechanical attachment. If the lock profile, for example, becomes damaged or eroded than there is a chance of the safety valve being ejected from the nipple. The 288 transducer array of the ultrasound tool provides a circumferential spacing of 1.25° between measurements; ensuring even small defects can be detected. Following a laboratory test of a representative landing nipple under controlled conditions to verify the tool performance, a number of landing nipples were inspected in a field where erosion was suspected. The tool was able to accurately map the complex locking profile and to measure the dimensions to within a hundredth of an inch in each case, giving the operator confidence that the correct locks were being used to install the safety valves.
The unique properties of focused ultrasound allow the mapping and verification of even complex machined components while they are still downhole. With 288 circumferential readings, high resolution measurements are possible to an accuracy of a fraction of a millimetre raising the possibility of engineering a solution to a given problem rather than resorting to the expensive option of replacing the completion.
Wireline Electromechanical Shifting Tool with Large Expansion Ratio and Fully Controllable High-Force Capability
Authors: Mauchien Thomas , Christa Brandon , Olivio Amanda , Vander Poorten Ryan , Sheiretov Todor 
Published: March 2019

Abstract
New electromechanical anchoring and shifting mechanisms for a 2 1/8-in. wireline shifting tool employ innovative linkage designs to enable passage through 2.2-in.-diameter restrictions and deployment in casings up to 5.0-in. inner diameter. The anchoring system delivers 60,000-lbf force through the entire opening range, and the tool provides more than 16,000 lbf of linear actuation force to the pressure- activated shifter.
Using wireline shifting tools for sliding sleeves, pulling plugs, fishing, and other operations requiring high axial forces is becoming more common because the tools generate forces comparable with surface- controlled pipe-conveyed devices while offering excellent operational control and real-time feedback downhole. Because operations may include going through a small-diameter restriction before shifting in a larger borehole, tools must open to a large diameter, a property known as the expansion ratio. However, as the expansion ratio increases, the ability of conventional tools for generating large linear forces diminishes. New anchor and shifting designs feature large expansion ratios while preserving the ability to deliver large linear loads.
Solutions are presented to the numerous challenges of the design for a wireline toolstring typically including an anchor, linear actuator, and shifting tool. The anchoring system has the capability to apply constant radial force that is independent of the borehole size. As with all intervention tools, it cannot stick to the tubular and must be fail-safe and fully retractable within the tool outside diameter (OD) in case of a power loss, even in high-debris environments. Integrity of the tubular where the anchor is set must be maintained. The anchoring force must not be influenced by the axial push/pull force of the linear actuator. Self-centralization of the anchoring system is needed to eliminate the large bending forces that would otherwise occur from the linear actuator action. Both the anchor and shifting tool must have features that enable pulling them out of hole reliably, even through a restriction. Force and opening displacement sensors are important in giving real-time feedback of the state of the system. In combination with integrated firmware, this enables the system to react to events in the hundred-milliseconds range for effective, high-accuracy operations. Examples are presented for tool usage for specific applications.
The novel designs presented in this paper expand the operating envelope of mechanical services on wireline to operations in wells that were previously not serviceable by such tools. Wider application of wireline tools will lead to reduced operational time and bring an increased success rate and intervention reliability on a lower cost conveyance platform.
Rarefaction Shock Cleanup and Stimulation with a Water Hammer Tool
Authors: Kolle Jack 
Published: March 2019

Abstract
Water hammer shock pulses are generated when the flow in a length of tubing is interrupted in a time that is much shorter than the pulse duration. Water hammer tools used for well intervention incorporate a poppet valve that closes very quickly and a pilot valve that then causes the valve to open so that the flow is stopped periodically. The upstream water hammer shock generates an impulsive mechanical load on the bottom hole assembly (BHA) that can be used for milling or other applications. The intense axial vibration also extends the reach of tubing in long tortuous completions. These tools also generate a significant rarefaction shock downstream of the tool, comprising a sudden drop in pressure that can extend over 100's of meters of wellbore. The rarefaction pulse propagates into the dead volume beneath the tool and upstream into the annulus. The rarefaction shock causes flow to surge into and out of the formation. The extent and duration of these pulses has been observed in surface tests. Case histories of well cleaning and stimulation applications are described. Best practices for operation include squeezing treatment fluids into the formation followed by flow circulation to shock surge the completions.
Downhole Leak Detection: Introducing A New Wireline Array Noise Tool
Authors: Yang Qinshan , Zhao Jinsong , Rourke Marvin 
Published: March 2019

Abstract
This paper will introduce a new generation wireline Array Noise Tool (ANT). This tool is used to detect downhole acoustic / vibration activities originating from fluid-structure friction flow. One of main applications in Well Integrity (WI) and Plug & Abandonment (P&A) for ANT is to locate leak sources in well completions and tubulars. The innovative sensor matrix and system configuration together with three novel data processing methods are studied and developed to address the following primary challenges; Tiny acoustic leakage signals (-30dB to -60dB), for example, the minor leaks behind pipes or even inside the formation matrix,Strong road-noise acoustic signal contamination from tool motion while dynamic logging,Nonstationary and/or nonlinear signal distortions because of tool flexural vibrations, andDownhole seismic noise.
The tool can be operated both in stationary logging and in dynamic logging.
The wide-band sensor matrix is designed with a unique configurable technique to form different measurement arrays. As a result, the tool can simultaneously acquire absolute and differential acoustic signals. By using this sensor matrix we are able to improve Signal-to-Noise Ratio (SNR) by up to 20 to 30dB. From the acquired data, we employ a multi-dimensional machine learning (ML) classification module, cascaded with cluster iteration to separate real leak signatures from other unwanted noise signals. After a data conditioning process, the wave velocity-domain decomposition method is utilized to further distinguish the leak signal propagation characteristics against other noise propagations to enhance overall SNR for leak detectability. Lastly we use a Bayesian likelihood analysis to identify the leak depth locations with a confidence index based on the information contained in both signal energy and signal velocity. We are able to achieve 15dB to 20dB SNR improvement from this data processing methodology. The system design goal is to eliminate unwanted acoustic noise that is not associated with leaks, while maintaining sufficient sensitivity to pick up minor leaks.
The tool has been logged commercially in the US, Middle East, East Asia, and Latin America. The tool performance has been validated through simulation, lab tests, and field logs. Field logging examples are demonstrating a leak detection success rate above 95%. Field cases include multi-annulus, low flow rate, and gas well field examples. Field results will be presented in this paper.
ANT instrument technology and the associated advanced processing methods are a new solution for detecting the leak source locations and monitor leak paths, especially, in Well Integrity (WI), Plug and Abandonment (P&A), and many other well applications.
A Novel Approach: Williston Basin Coil Tubing Fluid Shows Significant Process Improvement
Authors: Redburn Mike , Cernosek Cole , Norton George 
Published: March 2019

Abstract
The successful development of an oil and gas field relies upon the application of technology. Utilizing data-driven results improves drilling efficiency in extended-reach wells. Horizontal drilling of these wells is necessary for oil recovery due to the very low permeability of the reservoir and the presence of natural vertical fractures found in the Williston Basin. The reservoirs within the Williston Basin are generally tight with a relatively high pore pressure. A novel additive used during the drilling phase of the well was implemented and improved for coil tubing milling and cleanout procedure.
Coil tubing application requires the use of robust fluid products due to the demanding environment. The novel additive was used to increase the lubricity improving friction on metal to metal contact where excess torque and drag led to the use of multiple tool runs and several short trips to decrease the drag forces.
Novel water-based drilling fluid enhancer used in varying concentrations maximizes the performance, reducing the need for excessive short trips and an increase in tool life. This paper will highlight the planning phase for the engineering design, the equipment used, friction factor matching, and the challenges encountered using the additive during coil tubing applications. Operators have seen noticeable reductions in days reducing the amount of flat time with prior conventional application. The application case history shows introduction in the Williston Basin and lessons learned when introduced into the Permian.
Under Pressure Perforating Deployment System Leads to a Six-Fold Reduction in Wireline Runs and a Three-Fold Reduction of Rig Time
Authors: Hillier Jill , Guedes Carlos Eduardo , Baumann Carlos , Torres Abraham , Sarian Serko , Aboelnaga Sharif 
Published: March 2019

Abstract
The perforating deployment system significantly reduces rig time while maximizing the perforation length per run as compared with traditional systems, both on land and offshore, for rig or rigless interventions with very limited rig-up height.
In limited rig-up height interventions, such as installations with short rig-up height or small cranes, to perforate long intervals it is necessary to use multiple short gun runs. To reduce the number of runs, short gun subassemblies are connected using a sealed ballistic transfer connector. The sealed ballistic transfer connector provides surface wellhead pressure containment sealing capability within the gunstring while also ensuring downhole ballistic transfer between guns subassemblies and the added value of optimizing perforating underbalance conditions. There is no limit on the number of sealed ballistic transfer connectors that can be used in one string. The sealed ballistic transfer connector allows deployment and reverse deployment under pressure in wells up to 103 Mpa, and it is qualified for H2S environments.
The application of this technology allows significant rig-time savings and reduces personnel exposure via a remote operational console that enables personnel to connect and disconnect the guns under pressure from a safer distance. To date many jobs have been completed with this proven technology. One example presented in this paper is a horizontal well perforated from an offshore installation with an extremely short rig-up height, where there was only 16 m available to deploy wireline toolstrings. The limited height meant that a conventional wireline with tractor would allow deploying only a single 6-m-long gun carrier per trip. Using sealed ballistic transfer connectors enabled a 53-m gunstring (seven 6-m and one 3-m carrier plus adaptations) to be deployed in a single run using eight sealed ballistic transfer connectors. This was a record for the deployment conditions. More than 100 deployment and reverse deployment insertions were successfully conducted during this perforating job, reducing the required number of wireline runs from 59 to 10, and saving 51 days of operation and rig time.
This paper demonstrates how the integrated application of the perforating sealed ballistic transfer connector technology, tractors, and polymer-encapsulated cables can reduce time in long perforating jobs with short rig-up heights both on land and offshore. In another presented example, the operator saved days of rig time, in addition to large economic and production time savings, and also reduced the exposure of personnel to lengthy, riskier tasks.