bluuebunny/crossref_metadata_2025_split huggingface dataset:
High Speed Telemetry Drill Pipe Network Optimizes Drilling Dynamics and Wellbore Placement
Authors: Ali T. H. , Sas M. , Hood J. A. , Lemke S. R. , Srinivasan A. , McKay J. , Fereday K. S. , Mondragon C. , Townsend S. C. , Edwards S. T. , Hernandez M. , Reeves M. 
Published: March 2008

Abstract
This paper discusses the successes and lessons learned during the first deployment of a High Speed Telemetry Drill Pipe Network with a Rotary Closed Loop System (RCLS) and Triple Combo suite in North America. The paper details the operational experience while drilling a lateral well with an emphasis on drilling optimization and LWD processing; given the ability to receive real-time, memory quality, data via a telemetry drill pipe network.
Recent advances in Logging While Drilling technologies call for broader bandwidths and faster telemetry data rates for full utilization of data available downhole. In addition to the improvements in LWD technologies, there has been a remarkable development of downhole drilling dynamics and optimization tools. A telemetry drill pipe network that delivers real-time memory quality data at 57,000 bps transmission rates, provides a step change in capability for the industry – dramatically changing the decisions that can be made in real-time
The major lessons learned during the project were i. Real-time monitoring is a valuable tool for controlling and mitigating dynamic dysfunctions downhole resulting in immediate ROP improvements; ii. High volume of real-time memory data imposes new challenges on surface software systems; iii. High resolution bore hole images via telemetry drill pipe facilitate real-time on-site dip picking and analysis of downhole conditions; iv. Handling of telemetry drill pipe at surface plays a key role in improving the efficiency of overall drilling operation.
With a telemetry drill pipe network, the present generation of drilling engineers can have high quality down-hole dynamics information and mechanical specific energy (MSE) data real-time while drilling. Likewise, the geologists and petrophysicists can have access to 8 sector gamma images and 16 sector density images, real-time via telemetry drill pipe. The success of the project has provided the industry with an impetus to pursue this technology as a ground-breaking path towards making real-time informed decisions while drilling.
Novel Automation Interface Improves Drilling Efficiency and Reliability
Authors: Florence F. , Guggari M. , Koederitz W. L. , Rodriguez H. , O'Kelly C. , Russell D. 
Published: March 2008

Abstract
Automation of drilling operations to date requires substantial capital investment and major construction or renovation to implement the technology. A new method has been developed using a small electronic controller coupled to the existing control system of conventional rigs, land and offshore. This simple, reliable controller is a conduit for service companies and operators to apply the latest algorithms to drilling operations employing mechanical or electrical rigs of many different designs. This will inevitably lead to experts directly controlling drilling operations which will mitigate the shortage of experienced personnel forecasted for the next decade.
Such a system is commercially available as a mud pump controller. To date, it has been used on a variety of land installations and on a deepwater drillship in the Gulf of Mexico. Complex command sequences for downhole tools are easily implemented from pull-down menus. Downlinking to rotary steerable tools continues with virtually no mis-runs and often at depths, speeds and differential pressures/flow rates unattainable when done manually. It was also successfully field tested with rotary tables and drawworks brakes. In this application, it was also used to limit the driller's speed settings to prevent inexperienced personnel from inadvertently damaging the wellbore or surface equipment.
This paper examines laboratory data, field tests and results from initial commercial applications to quantify risk reduction available from the new system. Offshore operations have seen 24 hour time reduction per hole section with the potential to increase this another 72 hours per well. Land operations should see proportional savings.
This new drilling automation system will radically change the way wells are drilled in the future. It will be the delivery mechanism to implement complex commands to streamline and safeguard drilling operations for existing drilling rigs. The industry can focus on algorithms to apply new drilling techniques to reduce drillstring vibrations and fatigue and, more importantly, to minimize wellbore stresses and the expensive trouble time that results.
Application of Connection Productline Evaluation
Authors: Powers James P. , Baker David A. , Chelf Michael S. 
Published: March 2008

Abstract
Premium threaded casing and tubing connections are expected to maintain structural integrity and sealability performance throughout the life of the well. Industry and various company standards for evaluating connection performance via physical testing on specific size/weight/grade combinations have been optimized. The industry now seeks methods to infer performance for combinations that have not been tested, based on completed tests. Time and cost savings are realized by extending test results within a family compared with multiple individual evaluation programs.
One operator has implemented an approach to evaluating a family of premium connection designs across a range of size/weight/grade combinations. This approach includes a comprehensive review of the threading specifications within the family to provide a consistent design approach, finite element analysis of all of the family members within the range under extreme tolerance and load conditions to evaluate the consistency of performance, and rigorous physical testing of combinations representing the boundaries of the range or worst cases within the range.
The operator has confidently assigned performance envelopes for several premium connection design families. Physical testing and finite element analysis evaluations assessed design and performance consistency, and established specific design-family-specific performance criteria. This paper will describe the process implemented to provide appropriate performance assessment of a connection product family for which all size/weight/grade combinations were not tested.
A Systematic Approach to a Better Understanding of the Concentric Hole-Opening Process Utilizing Drilling Mechanics and Drilling Dynamics Measurements Recorded Above and Below the Reamer
Authors: Thomson Ian , Radford Steven , Powers Jim , Shale Les , Jenkins Mark 
Published: March 2008

Abstract
Well known in the oil and gas industry is the importance of understanding drilling system vibrations and bit-reamer weight transfer when drilling with hole openers.
A field testing program was carried out on a full-scale experimental test rig in the state of Oklahoma, USA, with known lithological formations, in order to evaluate underreaming system designs. In this context, the underreaming system comprised the bit, the drive system, and the underreaming element.
To fully understand how the system interacts with the formation and reacts to inputs from the surface, drilling mechanics measurements were taken above and below the reamer element. Drilling dynamics measurements were also taken at three places in the BHA, with two drilling dynamics packages spaced out below the reamer and one positioned directly above it. That way, dynamics on the bit and reamer could be studied separately to understand how bit and reamer performance affect each other and the overall system dynamics.
The first well was directionally drilled with a rotary steerable system, concentric reamer, and vibration monitoring equipment set up in an industry-standard arrangement. This paper will describe how the findings and learning from the initial field test led to bit redesign and operational techniques implemented to enhance the drilling system stability. Another borehole was then drilled through identical formations with this improved system, offering a unique detailed comparison between the two field tests. The new bit design allowed the bit to control the drilling rate with better weight distribution between bit and reamer, significantly reducing vibration, and in this study, without impacting penetration rate.
A concentric reaming tool new to the drilling industry was used in both wells as a part of this study and will also be described. This tool demonstrated good steerability with a rotary steerable tool system and operated properly, drilling closed, activating, reaming, and finally, closing for retrieval from the hole.
Drilling Vibrations Modeling and Field Validation
Authors: Bailey J. R. , Biediger E. A. O. , Gupta V. , Ertas D. , Elks W. C. , Dupriest F. E. 
Published: March 2008

Abstract
A modeling tool has been developed that enables drilling engineers to design vibration resistant bottom hole assemblies (BHA's), given tool placement constraints and desired directional objectives. This model can be applied to configurations with the majority of common components, including rotary steerables, bi-center bits, roller-reamers, hole openers, and eccentric mass stabilizers. Modeling results have been validated in large, intermediate, and small hole sizes. In these applications, predicted behavior and field observations have compared well. Redesign has resulted in improved drilling results, including increased on-bottom drilling time, longer tool life, higher Rate of Penetration (ROP), reduced non-productive time associated with tripping, and even better hole quality.
As use of the operator's ROP management process has spread through the company (Dupriest, 2005), downhole vibrations have been identified as one of the most significant factors limiting further ROP and footage improvements. Rig site personnel use vibrations data from downhole sensors and Mechanical Specific Energy (MSE) diagnostics to achieve the minimum vibrational levels possible with the existing assembly. The nature of the remaining vibrations is identified, and the BHA is then redesigned in a way that addresses the specific form of vibration that is limiting performance. The field assessment of the vibrational limiter and the redesign process are repeated from well to well.
Vibrations mitigation is posed more as a design problem than an analytical one. The model characterizes the lateral vibration, or whirl, tendencies of BHA's, enabling quick and easy comparison of potential BHA design candidates. A BHA can be designed to minimize vibrational tendencies for a given set of operating parameters, or the optimal operating parameters can be predicted for a given BHA configuration. The model has unique displays to support both pre-drill vibrations forecasting and post-drill hind casting. Several case studies are provided to illustrate the value of this technology.
Present and Future Well Intervention on Subsea Wells
Authors: Jøssang Siri Nordbø , Friedberg Robert , Buset Per , Gramstad Bernt 
Published: March 2008

Abstract
World wide there are more than 3000 subsea wells and the number is growing. To increase the oil recovery from these wells there is a demand for an efficient subsea light well intervention service, which includes repair, scale removal, installation and manipulation of mechanical devices (valves, plugs, screens etc.), re-perforations, zone isolation, fluid sampling, PLT, chemical treatment, well abandonment etc. Traditionally, this type of work has been done by semisubmersible drilling rigs. Light Well Intervention technology makes this type of service possible from a monohull vessel. The technology reduces the intervention cost significantly, enabling more intervention work and resulting in better exploitation of subsea wells. The long term objective is to increase the oil recovery from subsea wells in the North Sea from average 45% to 55%.
An Alliance of a vessel owner, a wireline operator and a well control company offers a complete LWI (Light Well Intervention) service. The Alliance has performed LWI services on the UK- and Norwegian sector since spring 2005 and made interventions on more than 30 wells, after succeeding to land a long-term contract. Continuous operations have resulted in ongoing improvement of systems and operation, and provided important contributions to design and construction of new LWI vessels and systems.
This paper will discuss the LWI service in general, present challenges met, experiences made, and lessons learned during the 2006 and 2007 campaigns. Focus will be held on the umbilical-, deployment- and handling systems, weather limitations and scope of work. Another important issue is providing an integrated service team and to establish onboard the vessel a safe and efficient working environment. The service is continuously being improved and new technology being developed. Coil tubing service, as added well intervention functionality, will further be introduced on a light well intervention vessel in 2009, and presented in the paper.
Challenges of Directional Drilling Through Salt in Deepwater Gulf of Mexico
Authors: Israel R. R. , D'Ambrosio P. , Leavitt A. D. , Shaughnessey J. M. , Sanclemente J. 
Published: March 2008

Abstract
As an increasing number of 6000-ft plus deepwater developments come on stream in the Gulf of Mexico (GoM), project economics dictate that fewer subsurface drill centers be used to develop these fields. This in turn requires longer step-out wells, pushing kickoff points higher up the wellbore, often occurring within extensive salt bodies. Salt drilling is still a relatively new practice and presents operators with many drilling challenges that are still not totally understood. Adding a directional component to drilling through salt not only magnifies the issues of traditional salt drilling, but introduces new challenges that require different approaches to ensure successful delivery. This paper will discuss the challenges faced and the lessons learned by two major deepwater GoM operators along with the directional service company in drilling directionally through the salt. Together, these companies have drilled over 100,000-ft of salt in the GoM and are considered pioneers in deepwater salt drilling. They have encountered and managed many of the challenges that extend past the traditional predrill and real-time directional issues, into the post drilling phase with issues such as casing and cement design for managing salt loading and ensuring long term wellbore viability.
This paper presents several case studies that investigate and discuss directional drilling through salt, comparing variables such as hole size, bottomhole assembly (BHA) configuration, under-reamer selection, wellbore trajectory and directional control. The importance of geomechanics in the predrill planning of these directional salt wells is also discussed, and its link to casing design and cementing issues will be examined. The paper concludes by identifying critical areas for success in drilling directionally through salt, and will attempt to identify current technical drilling limits for pushing this envelope even further.
Concurrent Rotary-Steerable Directional Drilling and Hole Enlargement Applied Successfully: Case Studies in North Sea, Mediterranean Sea, and Nile Delta
Authors: Jones Steve , Sugiura Junichi 
Published: March 2008

AbstractConcurrent rotary-steerable directional drilling and hole enlargement utilizing concentric underreamers is becoming more commonplace. Significant cost savings can be obtained enlarging the hole while drilling with a rotary-steerable system (RSS) as opposed to using a designated hole-opener run after the pilot has been drilled. However, RSS underreamer assemblies are often challenged with BHA instability, excessive vibration and stick-slip problems when the two different cutting structures (bit and underreamer) interact with significantly different formations.This paper describes case histories of directional wells that have been drilled with both point-the-bit and push-the-bit RSS underreamer assemblies in the North Sea, Mediterranean Sea and Nile Delta (Egypt). In particular, RSS underreamer assemblies opening from 13″ to as large as 17 ½", using 12 ¼" pilot holes will be discussed.A unique sensor system, integrated into this specific RSS provides measurements of near-bit borehole caliper, stick-slip and vibration. While drilling, borehole quality and downhole vibrations were monitored in real-time at the rig site and from a remote operating center. The real-time data was used to optimize drilling parameters and provide enhanced performance from the RSS underreamer assembly. The RSS solution to simultaneous wellbore enlargement has been analyzed in terms of vibration, efficiency, performance, directional objectives and cost.The physical components, operational aspects and limitations of RSS underreamer technology will be discussed. The combination of a specific RSS and underreamer with a balanced cutting structure has resulted in excellent ROP and directional control, while reducing reaming-related vibration and potential failures. Further, an automated directional drilling feature and real-time drilling process monitor have enabled optimum directional drilling performance.
What Really Happens to High Strength Drillpipe When Taking a Sour-Gas Kick?
Authors: Spoerker H. F. , Havlik W. , Jellison M. J. 
Published: March 2008

Abstract
Sour gas and high-strength steel are generally accepted to be incompatible. However when drilling beyond 20000ft S135 and higher steel grades become necessary to support their own weight, and due to the elevated down hole pressures in the range of 15–20ksi, even minimal concentrations of H2S result in partial pressures that are considered hostile for these steel grades. The paper presents initial results from a joint industry project exposing S-grade drill pipe samples to various H2S concentrations in temperature ranges from 70–170°C and exposure times of 1–3 hours, representing typical conditions when circulating a gas kick to surface. Test conditions have been designed to closely recreate actual down hole conditions, with actual potassium carbonate drilling fluids saturated with hydrogen sulphide and an additional free gas phase. After exposure to the sour environment, the samples have then been taken to fatigue testing to evaluate actual damage against undamaged base-line fatigue results.
A New Mud Pulse Telemetry System for Enhanced MWD/LWD Applications
Authors: Klotz C. , Bond P. , Wasserman I. , Priegnitz S. 
Published: March 2008

Abstract
Mud Pulse Telemetry systems in drilling operations have enabled the industry to gather valuable directional and formation data while drilling the well, and to optimize the drilling process. This makes drilling operations more cost efficient and allows the drilling of complex wells.
In recent years, new LWD technologies have dramatically increased the amount of information collected downhole. This increasing demand for realtime bandwidth is a major challenge for conventional Mud Pulse Telemetry, which has data rates that are normally below 3 bits per second.
This paper describes a system for downhole-to-surface Mud Pulse Telemetry that uses baseband or carrier modulated pressure signals generated by a novel mud pulser design and a surface data acquisition unit with advanced signal processing capabilities. The new system is able of handling the complex and continuously varying properties of the transmission channel (the pipe bore filled with flowing drilling mud) by optimizing the transmission signal and the surface processing algorithms in realtime. Under a given scenario, higher data rates can be achieved that, from a log-quality standpoint, result in high log-densities for improved realtime decision making.
Surface processing algorithms include active pump noise cancellation, dual pressure transducer processing, signal filtering and signal decoding.
In addition, the system contains an automated calibration routine that after turning pumps-on measures the characteristics of the transmission channel. This novel feature assures that the latest knowledge about the transmission channel is available in the processing algorithms.
The new system has been successfully run in field-trials in the United States, North Sea, South America and the Middle East. During these deployments, data rates could be substantially increased compared to previous offset runs. The focus in this paper will be on a description of the system and its impact on both MWD and LWD realtime services.
Automatic Measurement of Drilling Fluid and Drill Cuttings Properties
Authors: Saasen A. , Omland T. H. , Ekrene S. , Breviere J. , Villard E. , Kaageson-Loe N. , Tehrani A. , Cameron J. , Freeman M. , Growcock F. , Patrick A. , Stock T. , Jørgensen T. , Reinholt F. , Scholz N. , Amundsen H. E. F. , Steele A. , Meeten G. 
Published: March 2008

Abstract
In order to remotely control the drilling process it is necessary to measure several drilling fluid parameters automatically. This will increase objectivity of the measurements as well as make it possible to immediately react to changes. The current paper describes in detail the design for an integrated tool combination and the results of a full size yard test of such a combined set of tools for measuring drilling fluid parameters and formation properties automatically. Some of the automated tools have been tested on rig site operations. Results from these individual tests are also presented.
The automatic drilling fluid analysis includes viscosity, fluid loss, electric stability measurements and chemical properties like pH. Full viscosity curves for the drilling fluid are measured using configurations and shear rates similar to those suggested by API procedures. Since gel formation curves and fluid loss properties require some sort of controlled static periods, these measurements are made semi-continuous. However, they are automatic and are measured as frequently as possible.
An automatic system is included to measure the particle size distribution, concentration and morphology. Knowledge of these parameters is necessary, especially when drilling in depleted reservoirs where particles are added for increasing the wellbore strength.
The produced cuttings volume is measured. An automatic system is adapted that determines, with accuracy comparable to that of visual analysis, whether the particles separated at the shaker screens are drill cuttings or cavings produced by an unstable formation. The mineralogy of the cuttings is analysed automatically using Raman spectroscopy, making it possible to evaluate continuously the different formations being drilled.