bluuebunny/crossref_metadata_2025_split huggingface dataset:
Vacuum Insulated Tubing Design and Performance Evaluation for Deepwater Completions
Authors: Nowinka Jaroslaw , Xie Jueren , Kis Peter , Hensley Rodney , Gonzalez Manuel , Williams Darryl 
Published: December 2007

Abstract
This paper presents a methodology and a software program for mechanical design of vacuum insulated tubing (VIT) strings. It also presents findings of a technical and experimental evaluation of a VIT candidate product under conditions typical for ChevronTexaco's Tahiti project in the Gulf of Mexico.
The design-and-evaluation methodology consisted of an initial feasibility study of VIT thermal properties and service loading conditions, a closed-form solution of the VIT stress-strain state under combined loading, a parametric finite element analysis (FEA) with simulation of interactions within VIT end connections, and a full-scale test of a VIT specimen under cyclic thermal and mechanical loads that were anticipated in field service.
A complex experimental set-up was developed to apply the required combined loads to a full-length VIT joint. The test specimen was instrumented with strain gauges to measure the VIT deformation in a fully submerged environment.
The paper presents examples of data acquired in all phases of this design-and-evaluation program. The results were used for assessment of structural integrity, sealability, and thermal insulation performance of the VIT candidate product. The experimental data agreed well with analytical and numerical predictions. The paper also shows how these results were further used to develop a VIT string design program, which calculated stresses and safety factors in function of VIT geometry and loading conditions.
The conclusions of this paper include recommendations for VIT design and performance verification. Following these recommendations should result in higher reliability and more cost effective wells in completion programs utilizing VIT for deepwater applications.
Development and Field Results of a Unique Drilling Fluid Designed for Heavy Oil Sands Drilling
Authors: Warren B. K. , Baltoiu L. V. , Dyck R. G. 
Published: December 2007

Abstract
Drilling Heavy Oil Sands are traditionally fraught with many technical challenges. Stability of the wellbore, accretion of the tar on drill string and solids control equipment, torque-drag considerations, extreme temperature conditions, as well as the handling of oily solids are just some of the challenges that need to be met.
This paper describes the development and testing of a new drilling fluid designed to meet these challenges. The water-based fluid is based upon two guiding principles, the ability to incorporate the bitumen into the mud itself, and the capability of the system to later break the bitumen from the mud system. Incorporation of the bitumen into the mud is via a direct emulsification and results in zero accretion, virtually oil-free sand from the solids control equipment, fast drilling rates and good hole stability. The post drilling breaker allows for the oil/bitumen/tar to be skimmed from the surface of the drilling fluid allowing for conventional disposal of the liquid fraction.
Data from a six well horizontal heavy oil program in Northeastern Alberta shows the robustness and effectiveness of the system. The new oil in water direct emulsion system drilled 1100 meter average horizontal wells 35% faster, when compared to conventional inhibition salt technology based drilling fluids. Highlights include sand from centrifuging operation containing &lt; 0.5% oil, elimination of accretion and common foaming problems, fluid reuse from well-to-well, as well as simple land disposal of liquid mud wastes. Total well costs, drilling fluids costs and disposal costs were significantly less than those wells drilled with conventionally inhibited drilling fluid systems.
Intelligent Drill String Field Trials Demonstrate Technology Functionality
Authors: Reeves Michael E. , Payne Michael L. , Ismayilov Anar G. , Jellison Michael J. 
Published: December 2007

Abstract
Intelligent drill string components capable of transmitting data at rates up to 2-megabits per second have been developed and successfully tested in commercial drilling applications.
This paper details the lessons learned during intelligent drill string field trials, with focus on the overall network performance during drilling operations, physical handling ease and integration of existing down-hole measurement tools into the network.
This is the first publication of information from such field trials, and the first discussion of down-hole tool data transmission through the intelligent drill string network.
The paper includes discussion regarding the potential impact of intelligent drill string technology on the drilling and completion process.
This new technology can improve well productivity, reduce drilling time/costs and enhance well control safety. The paper addresses these issues and provides a forward-looking view regarding large-scale introduction of the system and the anticipated time-line for commercial availability.
The intelligent drill string system incorporates a high-speed data cable protected in a high-pressure conduit that runs the length of each joint. The cable terminates at inductive coils that are installed in grooves machined in the secondary torque shoulders of double-shoulder connections at each end of the joints.
The system's design supports high-speed, high-volume, bi-directional data transmission to and from hundreds of discrete measurement nodes. As a result the system offers an opportunity to capture critical data along the full length of a drill string, not just at the bit, in addition to supporting the use of high-resolution LWD tools and providing instantaneous control of down-hole mechanical devices. The system offers robust, reliable operation and is virtually transparent to standard rig procedures.
Operational Aspects of Formation Pressure Measurements While Drilling
Authors: Pop Julian , Laastad Harald , Eriksen Kåre Otto , O'Keefe Michael , Follini Jean-Marc , Dahle Tone 
Published: December 2007

Abstract
The emergence of formation pressure measurements in the Logging-While-Drilling (LWD) market has highlighted the challenge of analyzing and interpreting the pressures acquired. The dynamic condition of the borehole and the freshly built mudcake add new variables to the problem and contribute in making the measurement more complex to interpret compared with measurements made by conventional wireline-conveyed methods.
This paper presents several formation-pressure-while-drilling case studies conducted in the North Sea. Formation pressure measurements were repeatedly performed under different well conditions and at different times after the bit penetrated the formation. The impact on the measurement of various parameters is analyzed, most notably, the time after drilling and changes in the measurement sequence.
The results obtained with the formation pressure while drilling tool are compared to measurements performed with conventional wireline formation testers (WFTs) conducted at the same depths and at various times after drilling. Analysis of formation cores taken in the same intervals as the pressure tests were performed allows a better understanding of the while drilling-derived mobility measurements. Suggestions are made on how to improve the quality and accuracy of the measurements.
Reservoir-Geomechanics Coupled Simulations: A Powerful Tool for Well Design and Operation in an HP-HT Environment
Authors: Marchina P. , Onaisi A. 
Published: December 2007

Abstract
The unusual stress and depletion levels encountered in HP-HT fields make engineering wells in such an environment a technical challenge. The major reason for this is that all the aspects of the well's life, from well design and completion issues to operating philosophy, are significantly impacted by the mechanical behaviour of the reservoir. It is therefore important to be able to assess with accuracy the evolution with depletion of the in-situ stresses and rock deformations across the entire field, in order to optimise the design of the development wells. In that context, the use of reservoir-geomechanics coupled simulations becomes a corner stone to the well engineering philosophy.
In this paper, numerous well design issues will be presented that could be successfully addressed thanks to a reliable prediction of the state of stress throughout the depletion history of the reservoir. They include basic mud weight window (MWW) calculations, the optimisation of well trajectories across faults, the risk of casing failure and most importantly the determination of the allowable time window for drilling wells. The benefits of the availability of the results of the coupled simulations for other aspects of the field development having a strong impact on the development strategy and planning, such as sanding risk assessment, will also be briefly discussed.
Eliminating the Need for Manriding Operations in Drilling Operations
Authors: Cadigan Mike , Croft Sam , Dalgarno Kevin , Korver Johan 
Published: December 2007

Abstract
Manriding operations, hoisting personnel above or below the rig floor with a winch to perform rig maintenance, are considered a part of normal routine operations by many companies in the drilling industry. However, Noble Corporation believes that this practice is inherently high risk and has focused significant efforts on eliminating the need for manriding in its operations and hoisting personnel only when no other safe alternative exists.
This paper discusses the creative techniques that Noble has employed to avoid manriding operations in select locations, as well as its worldwide efforts to improve the safety of manriding when it is unavoidable. These efforts include standardizing worldwide on dedicated manriding winches and developing strict policies and procedures for use of the winches. The paper also describes the techniques that Noble Corporation's European Division has employed to reduce the need for manriding in select locations and provides statistics on the success of these operations to date. Some of these practices include:
Installing access platforms to eliminate the need for manriding above the rig floor. Relocating remote equipment to areas that provide access through existing platforms and walkways. Installing special scaffolds and platforms to eliminate the need for manriding around blowout preventers.
Because of the dramatic results of these operations, and the reduction in both the number and duration of manriding lifts, Noble Corporation is implementing these practices throughout its entire fleet, further reinforcing its core safety values.
Unique ROP Predictor Using Bit-specific Coefficient of Sliding Friction and Mechanical Efficiency as a Function of Confined Compressive Strength Impacts Drilling Performance
Authors: Caicedo Hector U. , Calhoun William M. , Ewy Russ T. 
Published: December 2007

Abstract
It has become standard practice to plan wells and analyze bit performance by using log-based rock strength analysis and/or the specific energy theory. The most widely used characterization of rock strength is unconfined compressive strength (UCS), but this is somewhat problematic because the apparent strength of the rock to the bit is typically different than UCS. Those who understand bit performance are aware of this problem, but to date there is not an industry standard or widely used methodology to address it. The specific energy theory has been used for bit performance assessment for years. One of the challenges of application of the specific energy theory, however, is uncertainty or lack of consistency in reasonable values for the input variables.
Globally applicable solutions and methods to address these problems have been developed and implemented by ChevronTexaco. A new method to calculate rock confined compressive strength (CCS), based on both conventional and somewhat innovative rock mechanics principles, has been developed. A new method to determine input variables for bit performance prediction based on the specific energy theory and CCS has been developed. These have been integrated to provide new capability for rapid and accurate log-based determination of the expected or achievable rate of penetration and operating parameters for all bit types. The new models have proved valuable, improving drilling performance and reducing well cost by improving bit performance prediction, bit selection, and the determination of optimum drilling parameters. The methods are robust, based on fundamental and/or first principles, and require little or no calibration. Any required calibration is intuitive and simple. This document presents background, theory, research results, new methodolo gies, and field and lab data that validate and illustrate the methods.
Advanced Safety Leadership, A Safety Course Designed Specifically for Well Site Leaders
Authors: Werngren O. , Stewart D. , Staley B. , West P. , Sawaryn S. J. 
Published: December 2007

Abstract
During discussions prompted by their contractors, Shell and BP well engineering managers agreed that to further improve performance, safety had to become personal. Early in 2003 the companies established a joint working group to develop common expectations of Safety Leaders involved in Well Engineering activities. The group comprised Drilling, Well Services and HSE representatives from BP, Shell and the key contractors supported by an independent safety consultant.
Over the course of several months the safety leadership expectations were condensed to straightforward and achievable standards of personal safety behaviour and communication skills. These built on the industry STEP change "Leading for Safety" guidelines and were used to develop a two day workshop where participants explore what it takes to be a safety leader. The program was titled Advanced Safety Leadership (ASL) and has been in place since December 2003. To date over 1100 of the Shell/BP Well Engineering community have participated.
The ASL programme builds on the fundamentals of good leadership by exploring safety leadership requirements in a personal way. Training aspects are highly interactive. Through team leader participation, personal action plans and follow-up coaching it provides long term sustainability in creating an environment in which unsafe acts are challenged and safe behaviours are promoted – a workplace without harm.
Feedback from both staff and contractors attending the course has been very positive. Initial metrics suggest the course is strongly influencing behaviours, helping to reduce incident rates. In parallel, BP and Shell are also sponsoring a PhD project at Aberdeen University to help assess and improve the effectiveness of the course.
This paper describes why such a course is needed and summarises its contents and delivery. The paper will be of interest to all managers and supervisors in companies or businesses wishing to build a belief based safety environment.
Using Proven Milling Technologies and New Methodologies to Create Simple Level 4 Multilateral Wells
Authors: Pasicznyk Adam , Redlinger Thomas , Saras Ivan Jesus , Martin Renaldo , Bruzual Guillermo , Nessier Daniel 
Published: December 2007

Abstract
Traditional Level 4 multilateral technology has focused on high-end applications with the intent of creating a foundation for conversion to Level 5 functionality. The Level 4 junctions are typically evaluated on three core capabilities: connectivity, isolation, and accessibility. As the evaluation criteria focuses on junction performance, little attention has been spent on reducing installation risks, junction hardware, and complexity. Recently, the effort to re-invent the Level 4 multilateral junction as a simple, low cost, low risk installation has been initiated. This new, back-to-basics approach to constructing a cemented junction has been developed by reverting to proven milling & completion techniques.
This paper will introduce this new method for installing a Level 4 junction by detailing the lessons learned from a Venezuelan field trial. The paper will show how standard milling and completion techniques can be used innovatively and reliably to create simple multilateral junctions. In addition, it will explore the extensive testing and simulations needed to ensure consistent mainbore access creation while emphasizing installation simplicity. Lastly, the field trial will be compared to other Level 4 installations in the region.
Solid Expandable Tubular Technology: The Value of Planned Installation Vs. Contingency
Authors: Carstens Chris , Blasingame Kate 
Published: December 2007

Abstract
Narrow pore pressure/fracture gradient windows often necessitate additional casing strings to reach deeper objective depths. Operators are constrained by the number of strings of conventional casing that they can run through subsea or surface wellhead equipment. Planning solid expandable tubulars into the well design allows the operator to run additional casing strings and drill to deeper objectives.
Using a solid expandable tubular system in the upper sections of the well design preserves hole size from the onset and allows more casing strings to be run without having to push casing points to the frac-gradient limit. Preserving hole size contributes to drilling efficiency, reduces equivalent circulation density (ECD), and minimizes risk associated with small hole size in deeper sections of the wellbore.
Another application for solid expandable tubulars is with surface stack technology. Early surface stack systems were designed around a subsea stack blowout preventer (BOP) system placed on top of a 13-3/8 in. drilling riser. After setting the 13-3/8 in. riser, only one or two casing strings could be run through the riser, which precluded reaching deeper geologic objectives.
This paper will look at two case histories. The first case history compares two deepwater offset wells in Mississippi Canyon. One well used expandable casing as a contingency, and the other well incorporated the casing as part of the base design. The second case history will evaluate a well where solid expandable tubular technology allowed up to three additional casing strings to be run in a surface stack application. This paper discusses how combining solid expandable tubular technology with surface stack technology has pushed the technical limits of surface stack drilling into deeper water and deeper formations.
Modeling Ultra-Deepwater Blowouts and Dynamic Kills and the Resulting Blowout Control Best Practices Recommendations
Authors: Noynaert Samuel F. , Schubert Jerome J. 
Published: December 2007

Abstract
In response to the drilling industry breaching new frontiers, specifically ultra-deep waters (5,000 ft or more of water depth), new blowout control measures are necessary. This paper outlines a study into the control of ultra-deepwater blowouts using the dynamic kill technique.1
The study was conducted using a newly developed dynamic kill simulator, COMASim, to model blowout initial conditions and blowout control in simple wellbore geometries. The simulator was validated theoretically through textbook examples.1
The simulation runs first entailed initial condition analyses of the various blowout conditions for an array of wild well conditions. Next, the simulator was used to determine the dynamic kill requirements to control these blowouts based on a range of relief well parameters.1
The results showed that ultra-deep waters definitely have an effect on the blowing conditions due to the increased hydrostatic pressure of the water. Initial conditions were also significantly affected by the length of openhole section.1
The dynamic kill requirements were adversely affected as the projected relief wells became longer. In addition to relief well parameters and blowout flowrate, the dynamic kill requirements were also related to the wild wellbore drillstring status.1
This study has highlighted several key trends and interesting future research topics in the area of ultra-deepwater blowouts and control of these blowouts.1
Urban Operations: Drilling and Completing a Gas Well on a Downtown University Campus
Authors: Spady D. W. , Poole J. Michael 
Published: December 2007

Abstract
It started as a simple concept: donate to the local university a wellbore, through which they can produce their own gas to offset rising utility bills. The final result - a successful well which required a tenuous journey through geological identification, regulatory hurdles, resident opposition, logistical restrictions, location stability concerns, drilling surprises and reclamation procedures. The process brought together a regional independent gas producer and six of its major vendor partners, each donating their portion to a project that earned strong community support. This paper will journal the steps of the process, as well as outlining a template for future projects in sensitive environments.
Compaction Considerations for the Gulf of Mexico Deepwater King West Field Completion Design
Authors: Li Xu , Tinker Steven J. , Bruno Mike , Willson Stephen M. 
Published: December 2007

Abstract
This paper summarizes reservoir compaction and long-term well integrity studies conducted for the deepwater Gulf of Mexico King West Field. These studies were undertaken to: ensure a robust completion design to withstand the compaction load throughout the economic life of the well; andprovide one of the key inputs, i.e. the mechanical well life, for the optimization of the overall reserves recovery strategy for the field.
A large part of the work presented follows an established work flow for assessing compaction, subsidence and long term well integrity1. In addition, a numerical model was built to simulate a 600ft long section of formation, casing, and completion. The purpose of this simulation model was to further address the following concerns: How does differential depletion between the reservoir sand and inter-bedded shale impact the casing and completion?Is the telescoping joint effective in relieving the compaction strain in the completion throughout the well life?What steel-strength rating is needed for the screen and base pipe materials?
The study results indicated the King West production well has a moderate to low risk of compaction related completion integrity problems because of the moderate (2600 psi) depletion and relatively homogeneous pay intervals. By using a telescoping joint and a high crushing resistance screen design, 13Cr-95 base pipe was deemed sufficient to maintain the integrity of the completion throughout the economical well life of this well. The high strength corrosion resistant alloy (CRA-125) was not necessary. This prevented the unnecessary spending on high cost CRA base pipe with an incremental cost of about $50,000 for this well.
The study provided a technical basis for completion engineers to make informed decisions in terms of mitigating compaction risk, while at the same time avoiding unnecessary over-design conservatism. It also provided valuable input for assessing the overall economics of the field, in addition to well operation and intervention strategies.