bluuebunny/crossref_metadata_2025_split huggingface dataset:
Collapse Data Analysis and Coiled Tubing Limits
Authors: Avakov Vladamir 
Published: December 2007

Abstract
The paper presents a mathematical model of coiled tubing (CT) collapse pressure (CP), related combined stress, and safety factor evaluation. More than 2,000 collapse-test results for round and long steel tubes were collected from various publications and the API data bank. These data were statistically analyzed and defined to determine the following points about collapse pressure:–CP is a random variable.–CP variation obeys the law of extreme value distribution (not normal distribution) with a definite minimum limit.–CP can be expressed by one relatively simple formula that covers the full practical range of the D/t ratio.–CP can be defined at any required reliability or even at 100% reliability when using the distribution minimum limit.
Derived collapse pressure formulas (CPF's) and the stress factor (safety factor) are supported by test statistics, and therefore enable greater accuracy in CT-collapse prediction.
P. 43
Catastrophic Buckling of Coiled Tubing in the Injector
Authors: Newman Ken , Aasen Jan 
Published: December 2007

Abstract
A series of tests were performed to determine the compressive load at which CT will catastrophically buckle between the bottom of the chains and the top of the stripper in the injector. This paper documents these tests and discusses analytical calculations of the buckling load. An equation for calculating the buckling load is given.
Weight on Bit in Coiled Tubing Drilling: Collection and Analysis of Field Data
Authors: Blount C. G. , Hearn D. D. , Payne M. L. , Sathuvalli U. B. , Livesay R. 
Published: December 2007

Abstract
This paper analyzes representative samples of downhole and surface measurements collected during a sidetrack operation with a coiled tubing drilling unit. The downhole data are classified into operational windows such as drill ahead, running in hole and pulling out of hole. They are correlated with drilling reports and surface measurements of hook load, pumping pressures, flow rates, and slackoff. Correlations between the surface and downhole data are used to understand force transmission during set-down, pick-up and drilling operations.
Results From NDE Inspections of Coiled Tubing
Authors: Stanley Roderic K. 
Published: December 2007

Abstract
Service Centre nondestructive inspections of used coiled tubing are being performed in Scotland. This paper outlines the development of an NDE tool for coiled tubing inspection, explaining the principles of operation and presenting some interesting results from several recent inspections, including results on a recent certification test. The current tool performs the following operations for 100% of the tube: detects ID and OD pitting, transverse OD damage and longitudinal damage; locates the areas of heavy cycling; measures ovality and local wall thickness. All detections and measurements are performed by non-contact electromagnetic methods which include magnetic reluctance (MR), magnetic flux leakage (MFL), and eddy current methods for longitudinal flaws, ovality, and the detection of heavily cycled areas. Technique sensitivities are presented.
Data from each inspection can be saved for comparison with future inspections. Such full length NDE, along with fatigue cycling results from flaw removal regions have per- milled strings to be managed by removal of isolated flaws or flawed/worn areas.
Ancillary techniques such as compression wave wall thickness measurement, ultrasonic shear wave and radiographic techniques for the volumetric checking of tube-to- tube welds, and magnetic particle and liquid penetrant techniques for two dimension imperfection detection are also discussed. Evaluation of NDE results will feed into a proposed new API Recommended Practice for Care, Maintenance and Inspection of Used Coiled Tubing in order to provide for standard ways of managing used coiled tubing.
P. 91
Development of an Internal Coiled Tubing Connector Utilizing Permanent Packer Technology
Authors: Coronado Martin P. 
Published: December 2007

Abstract
Connecting tool strings to the end of coiled tubing (CT) workstrings has been performed since the advent of CT itself. Early connectors were of the roll-on design, which simply deforms the CT into recessed grooves on the outside of the connector, relying on an interference fit to secure the tool string. As CT applications became more demanding, such as conveying inflatable packers, milling plugs in landing nipples, fishing and drilling operations, the need for higher performance connectors became necessary.
Initial mechanical connectors used set screws inserted through the connector and into the CT and/or external slips which were driven into the outer surface of the tubing to effect an anchor point. These connector designs have proven to be sufficient for normal CT applications, but since they seal and anchor on the outside surface of the tubing they are frequently the largest diameter component of the tool string. This can in many circumstances limit the CT size that can be used.
This paper will describe a new connector design which anchors and seals on the inside wall of the CT, thus allowing the connector to be the same outside diameter (OD) as the tool string, or the CT itself. This eliminates the OD limitation at the connector, and possibly allows larger CT to be used in a specific application, which may offer substantial increases in job efficiency and capabilities (hydraulic horsepower, CT strength, etc.).
The internal connector utilizes permanent packer technology in the seal and slip design, providing high performance. A second generation connector will also be described which allows torque-locking capabilities (connector torsionally locked to the CT), which makes it compatible with CT drilling and milling operations using a mud motor.
P. 139
Remote Coiled Tubing Operation Monitoring
Authors: Rosen Patrick M.A. 
Published: December 2007

Abstract
To carry out safe, economical and successful on-and offshore coiled tubing operations it is vital to have at any time access to real time data concerning the physical condition of the coiled tubing as well as information about operational data. Gathering and processing these data on-line with a fully automated coiled tubing operation monitoring system provides the basis for visualizing, managing and sharing necessary information during operations.
This paper discusses the concept for real time coiled tubing data acquisition, evaluation and visualization. It outlines the opportunities and the capabilities of using Internet technology to simultaneous share real timecoiled tubing data among the experts whether on site or at any other place on the globe.
P. 163
Corrosion Issues with Underbalanced Drilling In H2S Reservoirs
Authors: Chitty Greg H. 
Published: December 2007

Abstract
There have been documented and undocumented corrosion problems in Canada concerning the drilling of oil and gas reservoirs that have H2S content. In the realm of underbalanced drilling, liquid nitrogen has typically been used as the gaseous medium to reduce hydrostatics for underbalanced drilling fluids. Liquid nitrogen does an excellent job of inserting the drill fluid and reducing corrosion potential. Membrane gas, which is generated using membrane fiber technology and air compression/boosting equipment, is an effective means to reducing hydrostatics. This paper will discuss typical corrosion mechanisms and H2S corrosion mechanisms that are a concern in underbalanced drilling based on laboratory experiments. The goal of the paper being to explain trends in corrosion and show the effectiveness of membrane gas for underbalanced drilling applications, with coil tubing.
P. 155
Down Hole CT Tools, A Key to the Future
Authors: Norris Robert M. 
Published: December 2007

Abstract
This paper traces the development of downhole coiled tubing tools over the past few years and examines how the developments in coiled tubing down hole tools has directly influenced the acceptance and capability of the coiled tubing industry with the end users.
We trace how the coiled tubing tooling has developed from slick wireline tools and slim hole drilling tools into the present day flow activated coiled tubing tools.
The paper also discusses established and new techniques for using flow activated tools and how these techniques are improving the performance of the coiled tubing industry on a daily basis.
By removing the need to drop balls or darts to activate tools, and also the removal of shear pins in tools, the coiled tubing industry now has tooling specifically designed and available for the day-to-day well intervention work which historically was carried out with wireline.
The paper also presents how these developments in coiled tubing downhole tooling allows for access into highly deviated and horizontal wells and how equipment specially designed for these wells is being used to improve the overall performance that coiled tubing offers.
Included in the discussion are specific problems encountered in horizontal wells and how they can be resolved, for example the issue of well debris and manipulation of tools at extended reach.
The paper concludes by extrapolating the development timeline so we can glance into a future with multi function tooling systems where coil is only a carrier of equipment and manipulation is carried out with devices of the future.
Planning For Underbalanced Drilling With Coiled Tubing? The feasibility study and compter modeling.
Authors: Graham Robert A. 
Published: December 2007

Abstract
Coiled tubing drilling technology has advanced significantly over the last 2 - 3 years and while there are still questions, the technical feasibility of this technology is no longer questioned. Coiled tubing drilling technology may not be the technology of choice for drilling surface hole or for large diameter wellbores, except in exceptional cases, but may be the best technology for managing the drilling environment within the reservoir, especially in horizontal wells. The growing proliferation of "hybrid" drilling/coiled tubing rigs would tend to support this belief.
Since coiled tubing has typically been implemented as a live well intervention tool, this technology has always been linked with underbalanced drilling. However, crossroads have been reached and the process of implementing this technology in a commercially viable manner has begun. Of course, there is still a need for projects which push the envelope and help define the outer limits of the technology, but there is a growing need for the establishment of criteria to aid in the selection of the best technology to complete a given task.
One of the first steps to be completed is the technical feasibility study. This is the science of determining whether the underbalanced drilling objectives can be met within the framework of existing equipment.
The purpose of this paper is to discuss the cause and effect relationships of the independent and dependent variables which must be considered when performing a technical feasibility study, particularly when multi-phase flow is involved. Topics such as hole cleaning, weight on bit profiles and wellbore geometry are studied for their effects on drilling performance. The use of computer modeling is highlighted as a powerful tool to complete this initial study phase.
P. 181
Coiled Tubing Drilling on the North Cormorant Platform
Authors: Lord D.J. , Brinkhorst J.G. , Robertson T.J. , Martin R.H. 
Published: December 2007

Abstract
In May 1997, a second well was drilled and completed on the North Cormorant platform using Coiled Tubing (CT). The project has marked a significant step towards introducing a comprehensive and independent Coiled Tubing Drilling (CTD) system for offshore platforms. All the operations carried out on the well CN3O were conducted concurrently with a CTD system, whilst the platform rig was drilling a conventional sidetrack on CN 18. Operations with CT included window milling, drilling a 3-7/8" hole, open hole logging and completion of the well with a 2-7/8" liner. The well has just been perforated with CT and is currently producing 13,000 barrels of dry oil per day.
P. 191
Applications Update - Advanced Composite Coiled Tubing
Authors: Fowler S.H. , Feechan M. , Berning S.A. 
Published: December 2007

Abstract
Composite Spoolable Pipe for use in the Oil and Gas Industry is a new emerging technology. Enabling benefits include increased corrosion resistance, major weight reduction over steel as well as increased fatigue resistance. One company is close to commercial introduction of composite spoolable pipe for both well servicing and well completion operations. This paper will detail the latest application developments achieved at the time of the conference. It will cover the advancements made since the last update, SPE paper No. 38414 "Update on Composite Spoolable Pipe Developments" presented at the 2nd North America Coiled Tubing roundtable in April 1997. The focus will be on the application of this technology in its first commercial operations.
P. 215
A Case History: Completion and Stimulation of Horizontal Wells with Multiple Transverse Hydraulic Fractures in the Lost Hills Diatomite
Authors: Emanuele M.A. , Minner W.A. , Weijers L. , Broussard E.J. , Blevens D.M. , Taylor B.T. 
Published: December 2007

Abstract
The Lost Hills Field Diatomite has traditionally been developed using vertical wells completed with multiple propped hydraulic fracture treatment stages. As the main portion of the field is nearing fall development at 2 1/2 acres per producer, the search for additional reserves has moved out to the flanks of the field's anticlinal structure. Due to limited pay thickness, these flank portions of the field will not support economic vertical well development. The use of horizontal wells was determined to have the best chance to economically develop these areas of the field. To evaluate this development concept, three horizontal wells were drilled and completed over the time period from November 1996 to December 1997.
To assist with the horizontal well design and evaluation, several vertical data wells were drilled offset and parallel to the intended well path of each horizontal well. Additionally, two vertical core wells were drilled in line with the toe and heel of the horizontal well paths. These data wells were utilized to estimate properties such as in-situ stress profiles, pore pressure gradients, rock properties and fluid saturations, and to determine horizontal well vertical depth placement. The horizontal wells were then drilled in the direction of minimum horizontal stress (transverse to the preferred hydraulic fracture orientation) and completed with multiple- staged propped hydraulic fracture treatments.
During the completion of the three horizontal wells, hydraulic fracture growth behavior was characterized using surface tiltmeter fracture mapping and real-time fracture pressure analysis. In the third horizontal well, downhole tiltmeter fracture mapping was also used. This combination of fracture diagnostics provided significant insights into hydraulic fracture behavior, allowing diagnosis of anomalous fracture growth behavior and evaluation of remediation measures. Fracture diagnostics during the first horizontal well revealed an unexpectedly complex near-wellbore fracture geometry, a result of fracture initiation problems. These problems slowed the completion process and severely harmed the effectiveness of the fracture-to-wellbore connection. In the subsequent horizontal wells, a number of design and execution changes were made which resulted in simpler near-wellbore fracture geometry and a greatly improved production response.
The paper provides an overview of the completion and stimulation of all three horizontal wells, describes the lessons learned along the way, and discusses the implications for future Lost Hills horizontal well development.
Injection Profile Control Using Dual String with a Downhole Flow Splitter
Authors: Juprasert Max S. , Muscha Craig D. 
Published: December 2007

Abstract
Steam injection is the most common thermal oil recovery process. It has been used extensively in California heavy oil fields. Uniform steam distribution in multiple-zone, long completion interval, injection wells is extremely difficult to achieve. Consequently, many sands are not effectively heated and produced. Mechanical means for controlling injected fluid are often needed when using a single wellbore. Several techniques have been developed to deal with the steam distribution problem, e.g., concentric injection, limited-entry perforations, dual string injection, and slim-hole injection wells. These techniques have had varying degrees of success.
Dual string injection normally separates injected steam into individual zones by using tandem isolation packers. A modification of this design, utilizing a downhole flow splitter, eliminates the need for packers and maintains effective vertical coverage. This paper emphasizes the present design which can provide an economically attractive alternative to the traditional dual string injection and open-ended tubing in cyclic steam stimulation. In addition, the role of foamy oil expansion drive, an important recovery mechanism in the steam injection process, on profile controlling optimization will be discussed.
An Experimental Study of Single-Phase and Two-Phase Fluid Flow in Horizontal Wells
Authors: Ouyang Liang-Biao , Petalas Nicholas , Arbabi Sepehr , Schroeder Donald E. , Aziz Khalid 
Published: December 2007

Abstract
A brief overview of the 5-year Stanford horizontal wellbore experimental program is presented. Different existing mechanistic flow models, simplified flow models as well as empirical correlations are applied to analyze the 1995, 1996 and 1997 Stanford horizontal wellbore experiments. Comparisons between measurement and prediction are performed, which lead to the conclusion that none of the existing models can predict, with sufficient accuracy, pressure drops for gas-liquid wellbore flow with radial influx.
Improved Production Log Interpretation in Horizontal Wells Using a Combination of Pulsed Neutron Logs, Quantitative Temperature Log Analysis, Time Lapse LWD Resistivity Logs and Borehole Gravity
Authors: Brady J.L. , Watson B.A. , Warner D.W. , North R.J. , Sommer D.M. , Colson J.L. , Kleinberg R.L. , Sezginer A. 
Published: December 2007

Abstract
A novel combination of logs and their unique interpretations are used to improve the understanding of production in horizontal wells on the North Slope of Alaska. Two techniques using Pulse Neutron Capture (PNC) logs to identify and quantify liquid productive intervals were previously presented in a paper by Brady et. al. These techniques are compared and combined with two additional techniques:the use of time lapse LWD resistivity to determine productive intervals and liquid flow profiles while drilling, anda non trial-and-error method to determine quantitative gas production using temperature logs in a two-phase flow.
Finally, modeling shows borehole gravity logs can be used to track the vertical movement of gas or water tens of feet above or below horizontal wells.
Integrating the time lapse differences between the shallow LWD resistivity logs run while drilling and logs run several hours after drilling shows a strong correlation with PNC liquid flow profiles for wells producing at solution GOR. Additionally, combining a quantitative gas flow rate analysis from the temperature log with the liquid profiles provides a complete analysis of the production profile for two-phase flow in horizontal wells. Finally by combining the production profile analysis from a horizontal well with the modeled time- lapse borehole gravity data, a complete understanding of the fluid movements in the well borehole as well as tens to two hundred feet into the formation can be obtained.
These techniques can be applied to both horizontal and vertical wells with both slotted liner and cemented perforated completions to obtain a quantitative production profile. The LWD resistivity data is collected while drilling to better understand the productive reservoir rock before the well is completed. Time lapse borehole gravity provides an understanding of the reservoir fluid movements affecting the wellbore flow profiles after the well has been put on production.
Hydraulic Release J-tool Developed for Horizontal Well Remediation
Authors: Koehler K. D. , Bowyer R. K. , Dover C. M. 
Published: December 2007

Abstract
A new J-tool has been built that enhances an operator's ability to deliver an inner liner into the lateral of a horizontal well. A hydraulic release built into the J-tool allows the work string to be pulled straight out of the inner liner should un-jaying become difficult or uncertain. The J-tool can be re-used with minimal redress.
An Integrated Team Approach Improves Productivity: Case History of the Antelope Shale, Cymric East Welport Field
Authors: Mueller Fred , Richter Pete , Livingston Neal , Craley Greg , Pickens Dave 
Published: December 2007

Abstract
This paper summarizes an integrated team approach used to develop the Antelope Shale in the Cymric - East Welport field. The Cymric - East Welport field was obtained by Nuevo Energy in their acquisition of Unocal's California properties. Production from this field has increased from 300 BOPD in January 1997 to 2150 BOPD in December 1997. A team of engineers and geo-scientist representing the operator and service company worked together to maximize the productivity of this field. An improved stimulation process was realized through a synergistic approach between the different disciplines of each company.
The importance of each individual discipline such as geologic interpretation, electrical log interpretation, and the fracturing process cannot be dismissed. By looking beyond the standard boundaries of each discipline, the contribution of the whole can be greater than the sum of the individual parts.
Diagnostic Application of Reservoir Simulation to 31S Structure Stevens Reservoirs-Elk Hills Oil Field, California.
Authors: Ezekwe Nnaemeka , Echols Don , Hudgens Paul 
Published: December 2007

Abstract
A full field reservoir simulation model was constructed for the 31S Structure Stevens reservoirs. The size of the model is 29,070 grid cells with 26,889 active cells. Results from history matching the model show that all the Stevens reservoirs on the 31S Structure are in communication. This paper illustrates the use of reservoir simulation technology as a tool to diagnose the performance of a system of complex, multiple and conjugate reservoirs and quantify the extent of fluid migration that may have occurred among them.
Application of Geostatistical Methods Improves Results of Reservoir Engineering Study for Northwest Feature, Hemlock Reservoir, McArthur River Field, Alaska
Authors: Wang Shie-Way , Bailey L.E. , Smetanka J.W. 
Published: December 2007

Abstract
Previously published engineering studies especially have not been successful in predicting water production at the individual well level, due to geological complexity in the Hemlock Conglomerate at McArthur River Field, Cook Inlet, Alaska. Newly developed geostatistical methods were used to determine the 3D structure of the reservoir, distributions of lithofacies, porosity, and permeability in the Northwest Feature of the Hemlock reservoir. Only one set of relative permeability curves of each lithofacies was used in simulation. The results of this study show improvement in matching oil and water production of individual wells over a history match of 28 years. Presence of a flow barrier can also be inferred from this study. This study also includes a comparison of this geostatistical model to a previous full field model, and details factors contributing to the success of the current model.