bluuebunny/crossref_metadata_2025_split huggingface dataset:
OMV—Benchmark for 8-1/2" Hole Section with One Bit in Sawan Field of Pakistan
Authors: Preining Peter , Khan Asif M. , Ali Muhammad , Syed Mustafa 
Published: August 2008

Abstract
OMV Pakistan applied an original design of Genesis XT fixed cutter bit with improved features for bit stability to drill the 8.5″ section of Sawan-11 development gas well in southern Pakistan. Multiple vertical wells were drilled in this field with similar parameters and operating conditions. Latest proven technology was applied successfully to drill the 1760m of 8.5″ section with record ROP of 25 m/hr which is more than twice as fast compared to previous wells records. Instantaneous rates in excess of 70 m/hr were also recorded while drilling this section. This section was previously drilled with multiple bit runs using multiple roller cone and PDC bits. Later, this was reduced to 2-3 PDC bits and now the complete section has been drilled with one PDC bit (HC 606Z). Dull grading comparison with bits used in the offset wells will also be discussed. The lithology of the drilled section consists of Ranikot formation (dominating claystone with inter bedded sandstone and siltstone). Throughout this zone bit stability and optimized drilling parameters of the bit were key factors affecting its performance. Below this zone Upper Goru (UG) and Lower Goru (LG) formations are found. UG Member mainly consists of marl with streaks of limestone having an UCS of &gt; 35 kpsi in its contact with the Ranikot formation. This type of formation is generally the most difficult to drill. LG Member comprises of claystone and siltstone with occasional traces of pyrite having UCS of 20-25 kpsi. Towards the end of section, last 400m witness increased percentage of abrasive siltstone which affects cutter's sharpness and reduces the ROP. Offset data conforms that around this point bits quit drilling. However, at Sawan-11 bit maintained its sharpness and good ROP till the end of this section.
Delivering Steering Success in Problematic Soft Formation Directional Wells
Authors: Barton Steven , Card Kirk , Pierce Garrett 
Published: August 2008

Abstract
Development and diversification of directional drilling tools continues, as do the applications in which they operate. As a result, there is continual demand for development and refinement of drill bits and string tools to meet the latest challenges and issues faced. One such challenge is the ability to reliably deliver consistent directional performance in very soft formation applications. Issues such as hole washout, inappropriate drilling parameters, stabilization, and hole quality can all contribute to poor directional drilling performance.
Several commercial projects are reviewed where technical merit has justified use of Rotary Steerable Systems (RSS), but due to the very soft lithologies, these systems have been unable to deliver the required directional control. In each example, a separate engineered solution is introduced. These include; An innovative concentric string reamer, featuring a mid-reamer section that enables effective stabilization of the reamer even if the pilot borehole is of poor quality or is over gaugeA soft formation fixed cutter drill bit design with an engineered hydraulic configuration to avoid hole washout and extended circumferential gauge geometryA near-bit stabilizer incorporating a full ring gauge that delivers 360 degree circumferential coverage, thus providing greater contact with the wellbore and higher potential for deviationA specific Bi-center design that utilizes a secondary component configuration on the face of the pilot to enable appropriate drilling parameters to be utilized for efficient directional control. The gauge geometry and profile is also tailored to suit soft formation drilling.
Global case studies document where these solutions, in combination with both Push and Point RSS, have proven extremely successful. These have provided greater flexibility with regard to tool selection, well planning options, and delivering lower cost per foot in RS projects.
Fluctuation of Equivalent Circulating Density in Extended Reach Drilling with Repeated Formation and Erosion of Cuttings Bed
Authors: Naganawa Shigemi , Okatsu Komei 
Published: August 2008

Abstract
Management of equivalent circulating density (ECD) is one of the key issues in designing and drilling extended reach well (ERW). The paper focuses on ECD fluctuation occurred while repeated formation and erosion of cuttings deposit bed in drilling ERW. Numerical studies of hydraulics calculation were carried out in combination with cuttings transport model along the whole trajectory of ERW. While the cause of ECD fluctuation is primarily thought to be the mud pumps being turned on and off, our calculations showed that repeated formation and erosion of cuttings deposit bed, due to the repetition of drilling and drilling interruption for making a connection, causes a significant level of irregular fluctuation of ECD. To avoid severe unexpected ECD fluctuation in drilling ERW, the authors recommend that the schedule of mud circulation operations for hole cleaning and ROP management should be carefully designed by hydraulics calculations in consideration of transient behavior of cuttings transport.
Wireline Tractor Technology Supports Fast Tracking New Well Design
Authors: Shiong Lam Fei , Collins Joseph Paul , Schwanitz Brian 
Published: August 2008

Abstract
As well completions are becoming more and more complex, alternatives to traditional well intervention technologies surface.
A way of optimizing mechanical interventions, while also providing a value-creating alternative, is the utilization of established down hole wireline tractor technology. The manipulation and/or replacement of down hole hardware components in conjunction with wireline stroker and wireline key (intelligent shifting tool) applications makes it possible to perform reliable, economical, and flexible interventions such as opening/closing sliding sleeve doors (SSD) or valves, setting and retrieving plugs, straddles and gas lift valves (GLV), even in horizontal and extended reach drilled (ERD) wells.
Various successful applications in the industry of this down hole shifting system proves the reliability and practicability of these technologies as a cost effective alternative to traditional intervention methods.
One example was the successful application of a tool string combination comprising of a wireline tractor with a stroking tool and a key tool used to close a 5-1/2" SSD located in a section of the well at more than 70° angle in the midst of various operational constraints including tight allowable deck space, allowable personnel-on-board (POB) and allowable project time frame. Despite these challenges, the entire operation saved the operator 4.5 days and approximately USD 650,000 in costs as compared to traditional intervention methods.
Another example was the successful application of the wireline tractor and wireline stroker in a newly drilled well being prepared for production from three of the production zones in the reservoir. The wireline tractor and wireline stroker successfully sat a deep set plug, shifted close an SSD and retrieved the deep set plug with zero personnel injury and zero hour lost time.
Third example was the application of the wireline tractor and wireline stroker to repair a well completion in an old producing well by isolating a stuck SSD with a 22-meter multi-section straddle and then isolate holes in the tubing with an 8-meter single straddle. Well optimization was remarkable with Q oil increased by 900% and water cut reduced from 85% to less than 5%.
With the wireline tractor, wireline stroker and wireline key tool technology, and the case histories that prove the reliability and advantages associated to these technologies, well and completion designers' creativity are now less restricted by the concerns of the feasibility and economical constraint of future well interventions in highly deviated, horizontal or ERD wells, thus fast tracking of new well designs is possible.
A New Mud Pulse Telemetry System Reduces Risks When Drilling Complex Extended Reach Wells
Authors: Klotz C. , Kaniappan A. , Thorsen A. K. , Nathan E. , Jahangir M. , Lie L. 
Published: August 2008

Abstract
Mud Pulse Telemetry (MPT) is the most common down hole-to-surface communication technology utilized by MWD/LWD systems. Compared to alternative technologies, MPT systems are characterized by a proven record of high reliability in a wide range of operating environments. Reliable data delivery is feasible in a variety of scenarios ranging from shallow vertical to complex, deep water wells in all types of drilling fluid media.
Recent years have seen the introduction of many new LWD technologies which are providing unparalleled amounts of wire line quality evaluation data in realtime. Access to high quality, complete, evaluation data sets whilst drilling is enabling geologists and engineers to make decisions with higher confidence based on more and higher quality datasets, consequently enabling wells to become more complex and fulfill multiple objectives. The ever increasing volume of information generated by these new technologies has begun to exceed the bandwidth transmission capacity that traditional MPT technology can deliver. To fully capitalize on the LWD technological advances being implemented, an increase in data transmission speeds is required.
This paper discusses a new telemetry system that delivers data rates in excess of 6 bits per second (bps). The system has been deployed in a number of complex 3D extended reach offshore wells in Norway. During operations, the system reliably delivered high data rates of up to 20 bps, resulting in improved drilling efficiency, and reduced operational risk due to enhanced realtime decision quality based on the improved quality of FE and downhole diagnostics data.
New Steel Tooth Cutting Structure Breaks Multiple Records in Australasia
Authors: Bunton Steve , Sim Natalie , Grimes Bobby 
Published: August 2008

Abstract
Approximately 90% of the large diameter holes in Australasia (Indonesia, Australia, PNG and New Zealand) are drilled with steel tooth roller cone bits. A new steel tooth bit design has proven to significantly improve the drilling economics in these applications. This paper describes the drilling challenges posed by these applications, details the new bit design features, and presents case studies showing the performance improvements these new bits provide when compared with conventional steel tooth bits.
The new design bits feature a novel cutting structure with pyramid-shaped teeth, additional rows of teeth, wide grooves between rows, anti-tracking row(s) with tight pitches, thick hardfacing deposits, and a bar trimmer type gauge design. The result is a steel tooth bit that delivers significantly higher ROP and longer life than current designs, with high reliability, and predictable steering behavior for directional applications. Hole sections can often be completed with fewer bits, which further improves drilling economics. These bits achieve ROPs faster than even that of large diameter PDC bits in the Australasian applications, thus the reason that steel tooth bits are primarily used.
An operator in Balikpapan, Indonesia drilled a long S-shaped hole with a new 17 1/2-in. steel tooth bit at 40% higher ROP than the best of nine direct offsets that were drilled with conventional steel tooth bits. Another operator offshore Western Australia conducted a head-to-head comparison of a new 16-in. steel tooth bit against a conventional steel tooth bit in identical hole sections. The new bit drilled over 70% faster and over 25% farther than the regular bit. A third operator in the Northwest Shelf area off Western Australia employed a new 17 ½-in. steel tooth bit to complete a section normally drilled with 12 ¼-in. PDC bits. The new steel tooth bit drilled over 25% faster than the fastest PDC offset run. Additional case studies will be presented further documenting these positive field results.
Evolution of Innovative Test Methodology for Evaluation of Hardfacing Materials in both Cased and Open Hole Environments
Authors: Chan Alvaro , Hannahs Dan , Waters Scott 
Published: August 2008

Abstract
Extensive development has been made in the field of wear evaluation of hardfacing materials for downhole applications. These improvements have been industry driven to optimize drilling operations and reduce cost. Previous testing methods such as DEA-42 presented multiple hardware and process deficiencies which recorded results which were inaccurate, unreliable and not repeatable. An evolution of both hardware and processes for hardfacing material testing was developed over a 36-month period through laboratory testing and data evaluation.
This new methodology has been applied to the evaluation of hardfacing materials in both open and cased hole environments. Not only does it provide more reliable data, it also provides the flexibility to test different fluids, casing grades and varying open hole media. Actual material properties such as friction factors and wear rates have been successfully and accurately measured. It has also been used to identify break-in periods for different hardfacing materials.
The methodology has demonstrated repeatable and accurate results for wear characteristics for hardfacing materials under various conditions. Multiple hardfacing materials have been evaluated and their performance compared through this methodology. This methodology greatly surpasses previously established and outdated industry standards. This methodology was employed to engineer and develop a fourth-generation casing friendly hardfacing material currently in service.
This novel approach provides reliable wear characteristics data for available hardfacing materials. It provides a benchmark for industry evaluation of hardfacing materials previously not available in the industry. The use of this technology will aid in the development, selection, and performance evaluation of hardfacing materials for modern and complex well programs. It will improve downhole drilling performance by providing better selection of hardfacing materials.
Deep Salt Formation Wells Successfully Drilled with Integrated Techniques in Tahe Oilfield
Authors: Zhong Liguo , Cong Haiyang , Wang Shiqing , Zhao Defu , Wang Zhifeng , Yang Guang 
Published: August 2008

Abstract
The most challenging drilling problems encountered in Tahe Oilfield occurred in the deep salt formations. Most holes lost are caused by stuck drilling strings, stuck casing, and collapsed casing because of the special salt formations. Particular research is conducted to solve these problems. At first, the occurrence arose in salt formations are identified in detail. Then the components of typical salt rocks are analyzed, and properties such as plasticity, solubility, stability, and stress sensibility measured, some new techniques evaluated, and integrated techniques developed. As a result of implementation of the integrated drilling techniques, deep salt formations drilling in Tahe Oilfield has been substantially improved.
The main researching results presented in this paper are attached to the discussion of the salt formation problems, laboratory measuring and testing of the salt rock and evaluated techniques, and field drilling application. Integrated techniques recommended are particularized, such as borehole structure, salt water based mud system, expanding drilling and drilling string assemblies optimized.
Working Smarter On Well Intervention Operations
Authors: McNicol Jim , Joppe Bart 
Published: August 2008

Abstract
This paper describes a new intelligent well intervention performance system. One that contains a variety of sensors and electronics to gather critical downhole measurements, analyze them, and transmit them to surface for viewing in real time.
It confirms that many well intervention operations, especially those that get into difficulty, suffer from a lack of accurate information about true downhole conditions, and that actual downhole conditions in deep, high-angle wells differ significantly from what is indicated by traditional physical measurements taken at surface alone. The parameters measured downhole include RPM, torque, tension and compression, stick-slip, bending stress, dogleg severity, and many others.
Extensive field integration testing and early commercial deployment show how downhole tool performance information provides parametric information physically characterizing the true downhole environment. This real time information, never before seen at surface, demonstrates the potential to enable more efficient and more reliable well intervention operations while significantly reducing uncertainty and risk exposure.
Several case histories are presented where the smart tool was integrated into well intervention BHA's and operations were improved by a better understanding of what is really happening downhole.
Casing Drilling Technology as the Alternative of Drilling Efficiency
Authors: Buntoro Aris 
Published: August 2008

Abstract
The drilling technology was developed to increase the drilling efficiency based on 3 basic reasons, i.e.: safety, minimum cost, and usable hole. Casing drilling is one of drilling technology which it has been applied in many oil fields in Indonesia.
The casing drilling is classified into 3 methods, i.e.: Retractable Bit, Liner Drilling, and Drilling with Casing, where each method can be applied in certain condition. Recently, the drilling technology has reached efficiency significantly, both in engineering and economical aspects, especially in the formation which is difficult to drill with conventional drilling method, for examples: ❑Abnormal/subnormal zone❑Thief/loss zone❑Unstable formation
Generally, the drilling efficiency can be formulated based on statistic trend from the field data. Thus, casing drilling can be developed to reach the drilling efficiency according to the field experiences.
Early Detection of Drillstring Washouts Based on Downhole Turbine RPM Monitoring Prevents Twist-offs in Challenging Drilling Environment in India
Authors: A. Daison Paul , Belavadi Mukund N. 
Published: August 2008

Abstract
The rising need for hydrocarbon forces operators to drill more aggressively even in harsh formations and to drill well profiles with ever-increasing directional complexity. As a result, drillstrings are increasingly exposed to tough drilling conditions causing mechanical fatigue due to vibrations and bending stress cycles in tortuous wellbores. Additional challenges are posed by high torque and drag situations, corrosive drilling mud environments, abrasive formations, high temperature, high pressure and other unconventional drilling practices. On the economical side the situation is worsened by limited supply capacity and high prices for new drillstrings, forcing operators to rely on older drill pipes in critical applications.
Mechanical fatigue, corrosion or abrasion makes a drillstring vulnerable to wash-out, allowing mud to flow from the inside of a drillpipe through an initially small leak in the pipe wall into the annulus. If not detected in time, the leak will wash out rapidly and eventually cause a drill string twist-off which can be catastrophic. The result will be significant non-productive time for fishing operations or, in worst case, loss of an expensive BHA or even an entire well section. Presence of radioactive sources in such a situation can compound the problems many fold.
This paper presents a method to detect wash-outs at a very early stage where it is not possible yet to identify the wash-out from classic surface measurements such as stand pipe pressure. This is based on real-time transmission and close monitoring of the rotary speed of a downhole turbine positioned in the MWD BHA close to the bit. The effectiveness of the method was demonstrated recently on a year long period of a drilling campaign in a difficult drilling environment in India. A total of 9 washouts were detected, but not one twist-off occurred on these 9 runs. Not a single washout was found at the surface that was not indicated earlier by a reduction in MWD turbine RPM.
The paper starts with an overview of the washout detection concept and presents several data examples to illustrate the method in detail. The case study from India describes the implementation and the effectiveness of the method that has resulted in a 100% success ratio in washout detection in this application. After this services were introduced to the operator, the operator has made the requirement of washout detection services a standard part of its job planning.
Dynamic Pre-Modeling of MPD Operations Enabled Optimal Procedures and Operations
Authors: Petersen Johnny , Bjorkevoll Knut S. , Rommetveit Rolv 
Published: August 2008

AbstractOutlineAn advanced dynamic flow and temperature model was used to optimize and control MPD operations at Kvitebjørn. This paper describes in detail pre-simulations done to prepare for operations and develop detailed procedures, and post-analysis of real time data done to improve performance with respect to upcoming MPD operations at Kvitebjørn. The paper gives details on: Pre-simulations of drilling operations including temperature effectsExtra offline simulations during operationsPost-simulations with analysis of model-data deviationsResults and observationsThe paper discusses in details critical operations with main focus on sequences with multiple fluids in the well. These include setting of a balanced mud pill, tripping out and in with the pill in the hole, circulating out the pill, and cementing. Comparison with data taken when testing in cased hole is discussed, and it is described how good pressure control was obtained in real operations after having drilled into the reservoir.Applications and conclusionsThe paper gives useful input to the use of advanced dynamic models for MPD operations. It gives a good impression of current status as well as possibilities and limitations for future operations.
Dynamics and Torque Considerations Involved in Top Drive Casing Running Operations
Authors: Abrahamsen E. 
Published: August 2008

Abstract
This paper addresses important and largely overlooked challenges that exist when making up premium casing connections with a top drive and it describes how these issues can be controlled. To investigate them, tests were performed both in the Test Lab and in the field to examine the accuracy of torque measuring equipment normally associated with top drive casing make up tools (TDCM) when considering the following situations: ￭ Dynamic Torque – since the TDCM and the top drive are mechanically connected to the top of the casing or tubing joint during make up, their combined rotating mass represents kinetic energy. This in turn adds dynamic torque to the connection being made up when rotation comes to a sudden stop – i.e. when the connection reaches a shoulder contact.￭ "Backswing" – When the applied top drive make up torque is released abruptly, torsion generated static energy stored in the joint accelerates the above mentioned masses in the breakout direction. This translates to kinetic energy which applies breakout torque or "backswing" to the connection which can be significant depending on how rapidly the top drive make up torque is released.
The test results identified these forces conclusively and also lead to the conclusion that standard top drive torque measurement systems are not capable of measuring either of them.
In this paper the author will discuss these torque situations and present the results of the tests performed. He will conclude that both of these torque anomalies do in fact exist and that, though the response time of standard top drive torque measuring systems is sufficient for general drilling operations, it will in many cases be too slow for shouldered connections. He will also conclude that without alternative torque measuring systems the final make up speed of the top drive for premium connections must be drastically reduced to avoid the possibility of damage.