bluuebunny/crossref_metadata_2025_split huggingface dataset:
Leveraging The Unique Properties Of A Carbon Composite Rod Deployment System To Push The Boundaries Of Perforation Procedures, Bringing Time And Cost Savings To Standard Operations As Well As Allowing New Techniques When Compared To Conventional Wireline
Authors: Troup Duncan 
Published: March 2019

Abstract
Ballistic perforation remains a fundamental part of the process of producing valuable hydrocarbon deposits. The basic technique of lowering a gun containing shaped charges into a well is essentially unchanged since the 1930's, but the method of deployment has undergone many improvements. This paper intends to examine the benefits and advantages of using new carbon composite materials technology in increasing the efficiency and effectiveness of perforation.
The semi-stiff carbon rod is very strong, rigid, has low friction and contains an electrical conductor. These factors all combine to confer significant advantages over wireline for deploying perforation guns. The simplest benefit is that the strength of the rod makes rigging up and running very long and heavy gun strings feasible, reducing the number of runs in hole required to perforate a given interval. The rigidity of the rod reduces the risk of being blown up-hole by pressure differentials, thus allowing more potential underbalance than when using wireline while the conductor allows the use of addressable select fire systems.
Economic management of a well will almost certainly involve some intervention during its lifetime. A not uncommon example is a well where depletion has moved reservoir contacts and re-perforation becomes desirable to maximise recovery. If deviation is high, as in a recent well in the North Sea, a tractor intervention will be required and due to the constraints of a conventional cable deployment, gun lengths will be limited resulting in multiple runs. The carbon composite rod system was able to halve the number of runs required to perforate the new interval resulting in a considerable saving.
Many wells may not be horizontal but have a sustained section at high angle which precludes the use of wireline alone. The low friction of the rod and the ability to push it into hole allows access without recourse to a tractor, while the stiffness prevents movement of the string uphole after shooting, allowing significant underbalance to be applied with all the attendant benefits to reservoir performance. Combining new developments in selective firing and flexible gun systems with the attributes of the rod allow access to zones below known restrictions which are currently impassable by tractor or any other conventional deployment system.
Demonstrating the ability of the carbon composite rod system to save time and perforate longer sections more economically allows optimised planning. Eliminating concerns over gun lift, especially in high deviations, gives far more flexibility for planning underbalance perforation with all its intrinsic advantages. The electrical conductor in the rod enables the use of addressable select fire systems and head tension devices that, along with the ability to push the BHA, allows entry through otherwise impassable restrictions.
Disposable Intervention Tool for Production Logging
Authors: Bostick F. X. , Purkis Dan , Feherty Craig , Rose Kevin , Hitchcock Doug 
Published: March 2019

Abstract
Fiber optics can be readily introduced into wells to gather data at very low cost by using a novel, disposable deployment method called FiberLine Intervention (FLI). To date, FLI technology has been used to cost-effectively install bare optical fiber in wellbores to collect distributed sensing data, such as distributed temperature sensing (DTS) and distributed acoustic sensing (DAS). In this ‘passive’ sensing mode a variety of applications have been demonstrated, for example, cement assurance, leak detection, injection monitoring and vertical seismic profiling.
The FLI technology has now been expanded to include "active" elements which provide additional, discrete, electronic sensing functions from within the deployed probe. This capability enables the combination of single point data with distributed sensing information to provide enhanced well intelligence and assist with a wider variety of production logging applications, including evaluating well and reservoir performance and completion effectiveness.
To deploy FLI, the probe is configured on the wellhead in a small, pressure containing launcher. This releases the probe which free-falls downhole laying the fiber into the well. Following the development of "Active FLI", the probe can now be configured to house a suite of low cost, expendable electronic sensors such as a pressure gauge, a temperature sensor and a casing collar locator (CCL). The fiber transmits the digitized sensor data - in real time - to a miniature surface data acquisition system. Following completion of sensing and monitoring operations, which typically last several hours to a few days, the probe and fiber are then disposed of in the well.
The active electronic sensors collect data during the probe's descent into the well and can continue with ongoing monitoring when the tool reaches its final depth. The sensors can be deactivated on demand and the same fiber can then be utilized for distributed sensing. Alternatively, two fibers can be deployed allowing for the simultaneous collection of single-point data and ongoing distributed sensing throughout the wellbore.
Active FLI technology will be described in this paper and data from a representative field trial will be presented. The solution remains disposable, thereby resulting in a low cost, low risk and minimal impact method for obtaining key wellbore information during shut in, production and injection operations.
A Novel Approach to Wireline Debris Removal
Authors: Gourmelon Pierre-Olivier , Wiesenborn Kyle , Chochua Gocha 
Published: March 2019

Abstract
A new type of wireline-powered debris removal system that efficiently captures and retains a wide variety of wellbore debris types is presented. The system's unique benefits and performance are demonstrated through modeling and testing in controlled conditions.
Wireline-powered debris removal technology uses localized fluid circulation generated downhole to vacuum debris into bailers for capture. Challenges with conventional systems are related to the ability to continuously mobilize and separate a variety of debris including fine particulates and cohesive debris-binder mixtures. The new wireline debris removal system improves on previous technology by addressing the specific challenges of each of the debris types. This performance improvement is enabled by using a progressing cavity pump (PCP) to create powerful bidirectional suction pressure and a staged bailer configuration with parallel flow filters for maximum fill efficiency.
Pump performance is compared analytically for a centrifugal pump and a PCP to demonstrate the benefits of the PCP for debris collection applications. These benefits include reverse pumping ability for unsticking the toolstring when operating in debris-filled wellbores. This pump analysis defines a suction pressure budget, which is used to analyze the performance and capabilities of the staged bailer system. The pressure losses and debris accumulation profile of the new top-fed parallel flow filter bailers is determined by using fluid dynamics models. Results of an extensive testing campaign are presented to validate model results. Actual collection performance is presented for a wide variety of debris types using the new debris removal system.
The new wireline debris removal system's use of a PCP to generate the necessary vacuum and provide bidirectional capabilities for operational flexibility in combination with maximum debris recovery provided by staged bailers with parallel flow filters will bring new efficiencies and reliability to intervention operations.
Pushing the Limits of Damage Identification with Coiled Tubing in Extreme Conditions: A Success Story from Japan
Authors: Yoshida Nozomu , Teshima Satoshi , Yamada Ryo , Aybar Umut , Ramondenc Pierre 
Published: March 2019

Abstract
The success of water conformance operations often depends on clear identification of the water production mechanism. Such assessment can be complicated significantly when formation damage is also occurring. Coiled tubing (CT) and distributed temperature sensing (DTS) were combined to overcome challenging conditions (high temperature, low injectivity, high deviation, long perforated intervals, and wellbore damage) to identify damaged oil zones and suspected water-bearing zones in an onshore well in Japan.
The subject well experienced unexpected contamination of oil-based mud and completion brine which generated tight emulsions in the wellbore during the completion phase. Despite a thorough cleanout and perforations, severe damage was observed and mostly water was produced. With the presence of persistent damage in the wellbore preventing any logging tool use, DTS was selected as main diagnostic method, with the fiber optics being deployed with CT to ensure full coverage of the interval. Acquired temperature surveys were processed and matched with simulated profiles, which tested various scenarios of damage. Ultimately, results were used to drive the design of remedial actions.
The following operational sequence was implemented: temperature baseline measurements (6 hr), brine bullheading through CT-tubing annulus at 0.2 bbl/min (22 hr), and shut-in (6 hr) for warmback. The long injection stage was required to ensure enough fluid was being injected across the entire interval while keeping the downhole pressure below fracturing pressure. Real-time DTS data during pumping and warmback indicated the presence of a high-intake zone in the middle of the interval. Below that section, only marginal temperature changes were observed, which may be a direct consequence of the low injection rate limitation. Post-job processing using numerical temperature simulation was performed to complement that analysis and quantify intake along the well. Temperature inversion against DTS response was conducted independently using two different simulators, both of which yielded similar profiles, confirming the soundness of this approach. The results not only supported the presence of high intake in the middle interval, they also showed that the bottom zone most likely took some fluid. Complementary information eventually pointed to the high-intake interval being the primary water-bearing zone. This analysis led to the selection of the remedial actions to be performed in damaged oil zones.
This study demonstrates how integrated use of data from design, to job execution, to interpretation can change the perception of a well and how DTS can be a viable alternative to damage and water-production diagnostics in some extreme conditions when production logging tools cannot be used. Results of the DTS quantitative analysis provided local damage profiles along the well, which were critical to the subsequent planning of remedial activities.
Enabling High-Temperature High-Power 2 1/8-in. Tractor and Intervention Services on Long Cables with Telemetry
Authors: Dai Wei , Lee John , Yang Xuedong 
Published: March 2019

Abstract
A new family of 2 1/8-in. wireline tractor and intervention tools has been developed to enable logging and intervention services in high-temperature deviated or horizontal wells while providing high power levels and maintaining excellent surface communication over long cables.
In many horizontal or highly deviated wells, wireline tractors are a cost-effective solution for conveying logging tools, perforating guns, and intervention tools in comparison with other conveyance options such as coiled tubing. However, performing these logging and intervention services has become increasingly challenging, as well lengths increase and well temperatures rise. Providing the necessary high-power levels and maintaining real-time communication with the wireline tractor, payload, and other conveyed services from surface as operating conditions deteriorate are also problematic. Difficult operating conditions can be sustanined exposure to high temperature, long lossy logging cable, or combination of both. We assessed these challenges in developing key electronic, firmware, and software technologies for the new tractor and tools.
To achieve robust tractor operation at high temperatures, the electrical hardware is designed to withstand operating temperatures of up to 180°C while minimize heat generation. Temperature sensors are placed throughout the tool to monitor system health during operation. Surface-downhole telemetry is optimized to ensure compatibility with long cables. The tool algorithm was developed to maximize mechanical power delivery based on operating conditions. Results are presented from lab-based system level integration tests of the 2 1/8-in. wheeled tractor and intervention tools at temperatures of up to 175°C and delivering more than 1 kW of power on 30,000 ft of logging cables while maintaining communication with the payload.
The technologies described in this paper allow the 2 1/8-in. wireline tractor to perform high power interventions and logging while tractoring in wells previously inaccessible due to depth or temperature constraints.
A New Approach To Cement Evaluation Using Passive Acoustic Methods Directly Analyses The Performance Of The Barrier By Detecting Leakage Rather Than Its Physical Presence And Apparent Condition
Authors: Troup Duncan 
Published: March 2019

Abstract
A cement barrier in an oil well is intended to prevent any movement of fluid along the wellbore. If there is movement of fluid, acoustic energy will be produced and may be detected by a suitably sensitive sensor. This paper describes the controlled testing and real world application of a new passive acoustic tool and the benefits it brings to evaluation of even very small fluid migration issues.
Traditional methods of cement analysis rely on evaluating the placement and condition of a cement barrier, which may confirm the presence of cement behind the casing or liner. There are innumerable examples of cemented annuli that exhibit sustained annular pressure at surface – an indication of fluid migration from a charging source downhole – despite a good cement condition log having been acquired. In such cases there will be acoustic energy generated by the movement of even small amounts of fluid, the presence of which may be used to indicate a failure of performance of the cement.
A number of test cells were used to recreate realistic downhole scenarios of fluid flow, the cases including free-pipe, a single small channel, an exterior micro-annulus and "good" cement. The sealing performance of the annular barrier was tested against both gas and liquid over a range of flowrates and pressure differentials to best simulate the downhole environment. Reliable detection of annular flow at rates as low as 0.03 litres per minutes was recorded for liquid, while gas migration was detectable even at very low differential pressure. The latter case is of great interest in wells planned for permanent abandonment where even slow annular pressure build-ups are unacceptable. A logging campaign covering 8 wells was subsequently performed; rig-less and with production tubing still in place; to identify the source of B-annulus charging. The new technique was able to successfully identify areas of gas migration in each of the wells allowing detailed planning to be conducted prior to bringing in a rig.
The analysis of cement from the perspective of absolute performance as opposed to the traditional approach investigating the condition allows very detailed analysis of well barriers. This is especially useful in operations for permanent abandonment of wells were any leakage is unacceptable. The ability to map the fluid migration from source to surface is a powerful tool in the efficient design of remediation programs.
Highly Engineered 2.375-in CT Provides Effective and Reliable Interventions in 30,000-ft Mega Reach Wells in Offshore Abu Dhabi
Authors: Galvan Irma Galvan , Jimenez Jose Jimenez , Ulloa Joel Ulloa , Wheatley Edward Wheatley , McClelland Garry McClelland 
Published: March 2019

Abstract
With the aim of long-term sustainable production in the Persian Gulf, wells are being developed on artificial islands to maximize reservoir contact using extended reach drilling technologies with liner completions. This drilling strategy has many advantages and efficiencies, albeit, it results in complex 3-D well trajectories which challenge service operations throughout the well's life cycle. The ability to perform interventions in these wells with challenging laterals using Coiled Tubing (CT) is critical for achieving field development goals.
With well cleanouts and stimulation as the primary scope of work, a CT string was custom-engineered to maximize reach capabilities and injection rates, in well trajectories of up to 4.5:1 MD/TVD ratios that extend up to ~20,000-ft laterals through the reservoir. The challenging operating requirements incorporate several constraints, including accessibility of +30,000-ft target depths, minimizing the use of high cost extended reach tools, and achieving injection rates of at least 5 BPM, all within acceptable pressure limits to maximize CT service life, without exceeding surface equipment capabilities available in the area.
An iterative CT design methodology that incorporated the use of patented CT manufacturer strip technology, extensive tubing forces and hydraulics analyses, traction-force generating tool capabilities, fatigue simulations, and improved operation practices, enabled safe and successful deployment of 70-T (155,000-lbs) 2.375-in CT strings with 31,500-ft continuous length on the artificial islands.
CT strings reached target depths, with the bottom-hole assembly (BHA) generating 7,500-lbf of traction force in the most difficult wells, while delivering up to 5 BPM injection rates during the stimulation operations. These extended reach CT strings are the largest (by weight) ever produced and deployed on the artificial islands, which enabled the well operator to maximize well performance and productivity in ultra-long lateral wells.
This paper demonstrates the extensive design process to provide support and custom-engineer CT strings to perform complex operations - including matrix stimulation, mechanical isolation, scale inhibition, water control, and well cleanouts. Analysis of the field data, and performance of the strings will also be discussed to demonstrate increased efficiencies achieved by the well operator.
As future wells are being designed with greater laterals, further development in downhole tools technology will allow the deployment of +35,000-ft CT in continuous length to economically and efficiently achieve extended reach CT operational goals in the field. Engineered solutions for 2.375-in CT over 36,500-ft are currently in the design stage. These strings are expected to surpass the 73 T (tube only) weight -becoming a future milestone for CT interventions.
An Analysis of Coiled Tubing Performance
Authors: Brown Paul , Gunby Brian , Torres Carlos 
Published: March 2019

Abstract
The performance of coiled tubing pipe in real-world conditions is a topic of interest and frequent discussion within the industry. With pipe cost routinely exceeding $250,000 per string, service companies want to know if they are achieving the maximum return on their investment, and how their utilization compares with their competitors. However, industry-wide information is not readily available, especially for newer pipe grades, while published data tends to be specific to a particular company, region, or type of operation. As a result, policies regarding pipe life and criteria for retirement are largely set by each company, and industry practices can be slow to adapt as new products and procedures emerge.
An online system has been in place since 2010 where service companies upload, track and evaluate pipe and job data for the purposes of their own string management and operation planning. With records for over 5,200 strings and 146,550 jobs at the time of writing, this database has the potential to generate in-depth analysis of pipe performance. However, the data entered by each participant is confidential to that company, and is not usually available for general analysis. An initiative has therefore been developed whereby companies can choose to make certain data available, appropriately anonymized to protect commercial interests, which can be used to generate statistics of interest to the industry at large.
To illustrate the potential benefits, this paper will present a sample analysis of string performance based on cumulative running feet (or meters) at the time of pipe retirement. Since most coiled tubing operations are billed at least in part on running feet, this can be considered as a proxy for revenue. Total running feet will be compared with modeled pipe fatigue to see which metric better anticipates working life in real-world conditions. The paper will show how, when a large quantity of data is available, a statistically meaningful distribution of outcomes can be determined for each pipe diameter and grade, thus making it possible to compare grades, and quantify whether a given string has exceeded or fallen short of expectation, relative to the industry as a whole and not just the company concerned. The importance of taking into account all relevant factors, including the operating pressures and environment that the string has been exposed to during its working life, will be discussed.
In conclusion, an approach to increase the amount of available data, taking into account legitimate confidentiality concerns, will be proposed.