bluuebunny/crossref_metadata_2025_split huggingface dataset:
Rank Wildcat Drilling Risks & Drilling Time Reduced in Ultra Deepwater Offshore Namibia with the Application of Seismic & Formation Pressure While Drilling Technology
Authors: Jervis Anthony , Kemper Julia , Richards Martin , Taylor Mathew , Clarke Colin , Turner Marcus , Kelsall Neil , Puech Jean Claude 
Published: March 2013

Abstract
Rank wildcat wells in Ultra deepwaterD- present some of the greatest challenges today. Decision making during drilling is challenging due to a lack of offset well data. 3D Surface seismic data has significant uncertainty from the translation of two-way time to horizon depths which further induces risk into the predrill pore pressure model.
This paper looks in detail at how the utilization of a high-tech logging while drilling suite in the execution of a rank wildcat enabled key drilling decisions to be made, reducing risk and time vs. depth plan the well.
Seismic while drilling technology guided drilling in each section from spudding to total depth by allowing up to 600 m look ahead. This reduced target depths uncertainty from +/-100 meters to less than +/-5meters. Furthermore it permittedallowed this complex S-shaped well trajectory to avoid accidental penetration into the first target avoiding well control situation, placing the 13 3/8?? casing shoe safely above the first target, 80m shallower than planned. This ensured an increased mud weight window for the 12.25?? section.
In the 12.25?? section, Formation Pressure While Drilling Technology was added to the Seismic and Sonic technologies to calibrate the pre drill pore pressure model. This was critical due to a narrow mud weight. The acquired formation pressures coupled with while drilling petrophysical data allowed for the pore pressure to velocity transform and normal compaction trend lines to be calibrated reducing the uncertainty in the pore pressure model ahead of the bit. Uncertainty in depth of targets and modeled pressure ramps ahead of the bit were further reduced with the Seismic data.
Pointing Towards Improved PDC Bit Performance: Innovative Conical Shaped Polycrystalline Diamond Element Achieves Higher ROP and Total Footage
Authors: Azar Michael , White Allen , Segal Steven , Velvaluri Suman , Garcia Gary , Taylor Malcolm 
Published: March 2013

Abstract
Vibration induced impact damage can significantly reduce PDC bit/cutter life in hard/abrasive and interbedded formations. To develop a more stable fixed cutter bit for these difficult lithologies, an R&D initiative was launched to investigate new cutter designs and experiment with their count/placement to improve drilling efficiency and mitigate vibration. The research yielded an innovative cutting structure and a conical shaped polycrystalline diamond element (CDE) with an ultra-thick synthetic diamond layer.
The element is positioned at bit center with the conical tip pointing vertically down towards the rock. The location of the conical element combined with the optimized placement of the conventional PDC cutters allows an uncut rock column to develop. The stress relieved rock column is continuously crushed by the centrally positioned conical element. This enables the bit to deliver faster ROP and reduce the potential for vibration.
The conical element has undergone extensive laboratory testing to evaluate its potential to improve ROP. Using a single cutter test apparatus, engineers measured the element's ability to fracture rock at varying depths-of-cut. They determined the new CDE exhibits up to a 70% increase in cutting efficiency compared to standard PDC cutters. An existing PDC bit was modified to include the new CDE at bit center. A Mi616 type bit was fitted with CDE and run in North Dakota and Utah through a highly mixed sequence of formations, where the objective was to increase ROP and to reach KOP in one run. The bit improved ROP over a longer interval drilled compared to benchmark PDCs used in offsets. Subsequent field testing has substantiated the CDE's potential and how it can be used to improve PDC bit performance.
Pivot Stabilizer Innovations for Point the Bit Rotary Steerable Systems Result in Improved Drilling Performance for Specific Applications
Authors: Jeffery Christopher , Coss Michael , Rivera Richard , Botton Benoit 
Published: March 2013

Abstract
To achieve optimal directional response and maintain superior stability in specific applications, pivot stabilizer design, selection, and evaluation are crucial when used as a near-bit pivot on point the bit rotary steerable systems. This paper describes the progression of stabilizer design through simulations, facility testing, field testing, and in-service performance tracking. Extensive testing and performance evaluation has allowed development of predictable directional response, bit/drill string stability, and other drilling performance metrics of specific stabilizer designs to be rationally chronicled for continual innovation in pivot stabilizer design.
Field testing has provided direction for stabilizer characteristics specific to the application. Furthermore, Downhole Drilling Data Recorders (DDDR) have been utilized to monitor and provide a precise record of lateral and torsional vibration. Other measurement tools were required to monitor the directional response of the system. These developments in DDDR technologically have enabled an iterative scientific approach to stabilizer geometric design, yielding in hydraulics optimization and directional response.
Stabilizer geometry characteristics are paramount when designing a bottom hole assembly (BHA) for particular formation and operating parameters with identifiable challenges. A fundamental understanding of the impact of pivot stabilizer geometry characteristics is necessary to yield improvements in tool performance and reliability while overcoming these challenges. This knowledge will consequently provide higher drilling efficiency and lower drilling costs.
Post run analysis has confirmed unique stabilizer design characteristics are necessary to achieve optimum drilling performance. The design progression chronicled will quantitatively compare the effects of stabilizer design characteristics against field performance. Additionally, the evidence outlined in this document will enhance the industry's understanding of pivot stabilizer's design importance and offer advice for selecting pivot stabilizers on point the bit rotary steerable BHAs.
BOP Performance - Developments and Consequences in a Post-Macondo World
Authors: Sattler Jeffry P. 
Published: March 2013

Abstract
BOP equipment and systems have predictably changed as a result of the Macondo incident. While these changes have been driven by regulatory impetus, additional progress has also occurred as a result of risk and financial pressures. The combination of these drivers has resulted in noticeable progress to date, and is expected to continue to generate improvements at an increasing pace in the near term. Thus far, advances in processes and procedures represent the most significant category, but ongoing work on the equipment, which takes longer to engineer, test, and implement, will also result in much improved reliability for this critical safety system.
Deepwater Well Control - An Important Way Forwards
Authors: Leach Colin , Mounteer Jim 
Published: March 2013

Abstract
Following Macondo (and some other well control incidents), great strides have been made with respect to well control and much discussion and reflection has taken place.
Successful well control can be considered to depend upon:
Establishing 2 barriers including the condition of the barriers and understanding what such barriers will see during the life of a well Establishing what is normal with respect to fluids going into and coming from a well and devising ways and means to measure and control these flows such that control is maintained
This paper focuses on this second area, i.e. "establishing what is normal". It is a harder subject in some respects (nontangible) than the focus on barriers, but if successful, significantly lowers the risk envelope and reduces the overall chance of a catastrophic well event. Predicting and understanding what is happening downhole is the best way of ensuring that no harm comes to the environment crews, or equipment.
This paper looks at the processes that must be conducted and gives examples of these. To be successful, this requires a deep understanding of the interactions of real reservoir fluids (gas, volatile oil) with typical drilling mud which will be oil based. Examples of what will be seen for these combinations are given along with the resultant detailed solutions/approaches/procedures. Of particular interest was "ballooning" and gas in the riser.
In doing this work, it became apparent that existing (typical) rig instrumentation may require modification or upgrade for some of these tasks. One example is how to identify a (previously unidentified) hydrocarbon influx which is moving through the subsea BOP in a deepwater drilling operation and into the drilling riser. The paper identifies what is required and provides suggestions as to how this may be achieved.
From Research to Practice: A Story of an Actionable Safety Leading Indicator Index
Authors: Stough Joe , Robinson Nathan 
Published: March 2013

Abstract
For the past several years, a group of global Energy companies, including nearly all of the super majors, has been working on a research initiative with a common mission to find an actionable leading indicator index to drive Safety and eventually overall Operational Excellence performance.
This group has been collaborating to provide a large multi-year data set, which contains millions of data records from events such as incidents, investigations, near misses, audits, observations, assessments, and many other routine field-level activities. Since 2008, a rigorous statistical analysis process has been iteratively applied to this data to identify the mix of leading metrics which most effectively predict Safety performance outcomes.
This paper will review the leading indicator research findings drawn from analyzing this large Energy industry data set. It will reveal the key components of an actionable leading index which has been found to be uniquely strong in organizations who continue to sustain top-level Safety lagging performance.
From the analytical research and careful review with this consortium of industry QHSE executives and Subject Matter Experts, the index that was found to best predict the Safety outcome performance of an organization included measurements of (a) proactive event reporting (Reporting Culture), (b) the discipline and consistency in execution of QHSE business processes, (c) the timeliness in closure of important corrective / preventive actions, and finally (d) the responsiveness of supervisors and line managers.
The paper will provide an overview of the analytical process that produced these results and will outline alternatives for applying these insights on leadership performance dashboards. Although the leading indicator research and analytics activities continue annually to strengthen the effectiveness of the leading indices, companies are applying the index to provide actionable leading metrics on executive scorecards. We will outline a sample process for implementing practical, "actionable" leading metrics in each key area to drive line manager / leadership behaviour and ultimately improve QHSE performance outcomes.
Energy Storage for Natural Gas Fueled Electric Drilling Rigs
Authors: Thompson Richard , Murphy Brian , Williams Kevin , Giberson Hugh , Garaghty Jim , Pace Gary 
Published: March 2013

Abstract
The drilling industry is in search of an environmental and economical solution to rising fuel costs and tightening emissions regulations. Alternative engine technologies have been deployed and are challenging the conventional compression ignition diesel engine for drilling operations power generation. This includes the spark ignition natural gas engine generator which operates on processed natural gas (LNG or CNG), field gas, pipeline gas, or combinations of these. Compared to a diesel powered drilling operation, annual fuel cost savings of today's natural gas powered drilling operation can be expected to range from $300K when using processed LNG or CNG to $1.5 million when using field gas. Natural gas engine generators offer significant fuel cost savings and sizeable reductions in emissions. However, diesel engines have much better load characteristics compared to natural gas engines and respond more reliably to dynamic loads dictated by abruptly changing drilling functions. Combining energy storage with a natural gas engine generator results in a hybridized drill rig that offers both improved performance and fuel economy. An adequately sized energy storage system provides the operator of a natural gas fueled, land drilling rig with reliability and responsiveness superior to a diesel rig. Use of resistive load banks, excess generator capacity, and backup generators are minimized or even eliminated. UPS powered ride-through ensures electrical power quality with less vulnerability of generator output to variations in field gas flow rate and methane content. In addition to boosting rig performance, this hybrid rig technology offers economic benefits: • reduced natural gas fuel consumption by operating the engine at a higher more fuel efficient load and through less use or even elimination of the resistive load bank • less frequent maintenance and longer engine life as a result of operating more consistently at higher loads • reduced engine generator costs through rig operation primarily with one engine generator Compared to a diesel powered drilling operation, annual fuel cost savings of the hybrid natural gas powered drilling operation with energy storage are projected to range from $920K when using processed LNG or CNG to $1.7 million when using field gas. With performance driven beyond diesel rig levels combined with the significant fuel savings and emissions reductions, natural gas powered drilling rigs are expected to see greater acceptance with the hybrid electric approach.
Expandable Liner Hanger Milling: North Sea Case Histories
Authors: Berge Thomas , Mathisen Kim Daniel , Storebø Olav , Muir Michael 
Published: March 2013

Abstract
Liner hangers are designed to provide seal and anchoring capability for installation of casing. The expandable liner hanger has a uniform body with no moving parts that will expand into the parent casing and provide a permanent and reliable seal. Unfortunately, drilling a well can be problematic in certain situations, resulting in loss of a section or the entire wellbore. This leads to additional well construction costs from milling casing, running a sidetrack, or drilling a new section. Retrieving sections of the installed casing can reduce the cost but may require removal of the liner hanger. While milling conventional hanger systems has been performed before, there has been little experience with milling an expandable liner hanger.
This paper discusses the first two cases in the North Sea where expandable liner hangers required milling because of drilling issues below the liners. The milling of the expandable hanger bodies provided several benefits when compared to the milling of conventional liner hanger systems. The benefits included reduced rig time and non-productive time (NPT), less well debris than when milling movable parts/slips, and no parent-casing slip damage.
In the first case, during running of an expandable liner hanger, the hanger disconnected and was lost. A backup hanger was run, cemented, and set. Options for correcting the situation will be discussed in this paper along with why milling was considered the most feasible option. In the actual job, 10.5 feet of hanger were milled out in less time than anticipated. In the second case, a liner and expandable hanger were set in a long, extended mature reservoir.
During drilling of the next section, the drill string became stuck, requiring a sidetrack. Milling of the expandable liner hanger system enabled the operator to pull the liner and perform the needed sidetrack.
Pipe-Handling Integration in Land Drilling Operations - Safety Review, Operational Drivers, and Field Performance Feedback
Authors: Heinen Joel , Yost Tom , Garvin Mike 
Published: March 2013

Abstract
The value of safety is critical to our industry, and technology is adopted when all the stakeholders meet their needs. In drilling operations, the drilling contractor needs reliable systems with consistent performance that competes with current operations performance, in contrast the crew are looking for tools that they can understand and help them carry out their task better than before. The critical role of the derrickman is one that has a high standard to mechanize and meet the needs of the crew and contractor. A fingerboard mounted pipe handling system has been introduced, which differs from previous attempts to eliminate the manual interaction of a derrickman in land drilling operations. The machine was the outcome of unique consensus between the designer and the drilling contractor and provides a solution equivalent to manual tripping speeds that is strongly accepted by the drill crew. Critical to operational success was tripping speed, simplicity, and following the process that a manual operation is comfortable with. Eliminating the existing gripping devices and hoisting systems were one of many steps taken to improve the acceptance of a safety support tool on a working drilling rig. This paper will examine a case study with Patterson UTI and an equipment manufacturer which will show the performance feedback from a field proven solution. This will address the barriers that hold this advancement back and has the possibility of greatly increasing safety in drilling operations.
Hydrogen production by steam reforming of glycerol over Ni/Ce/Cu hydroxyapatite-supported catalysts
Authors: Hakim Lukman , Yaakob Zahira , Ismail Manal , Daud Wan , Sari Ratna 
Published: March 2013

AbstractHydroxyapatite-supported Ni-Ce-Cu catalysts were synthesised and tested to study their potential for use in the steam reforming of glycerol to produce hydrogen. The catalysts were prepared by the deposition-precipitation method with variable nickel, cerium, and copper loadings. The performance of the catalysts was evaluated in terms of hydrogen yield at 600°C in a tubular fixed-bed microreactor. All catalysts were characterised by the BET surface area, XRD, TPR, TEM, and FE-SEM techniques. The reaction time was 240 min in a fixed-bed reactor at 600°C and atmospheric pressure with a water-to-glycerol feed molar ratio of 8: 1. It was found that the Ni-Ce-Cu (3 mass %-7.5 mass %-7.5 mass %) hydroxyapatite-supported catalyst afforded the highest hydrogen yield (57.5 %), with a glycerol conversion rate of 97.3 %. The results indicate that Ni/Ce/Cu/hydroxyapatite has great potential as a catalyst for hydrogen production by steam reforming of glycerol.
Synthesis and HPLC Enantioseparation of Derivatives of the 3-hydroxyphenylethanone
Authors: Čižmáriková R. , Némethy A. , Valentová J. , Hroboňová K. , Bruchatá K. 
Published: March 2013

AbstractWithin the framework of the study of the synthesis and high-performance liquid chromatography (HPLC) enantioseparation the series of 9 derivatives of 3-hydroxyphenylethanone was prepared by a well-tried method. The structure of the prepared compounds was confirmed on the basis of interpretation of the IR, UV, 1H NMR and 13C NMR spectra. An enantioseparation of prepared compounds was performed using HPLC on a native teicoplanin (Chirobiotic T) and the amylose tris (3,5-dimethylphenylcarbamate) (Chiralpak AD) chiral stationary phases, which is more suitable for the enantioseparation of all prepared compounds especially with heterocycles in the basic part of a molecule.
2012 JOSPT Award Recipients Highlight Early Injury Detection
Authors: Simoneau Guy G. 
Published: March 2013

During the American Physical Therapy Association's Combined Sections Meeting in San Diego in January 2013, JOSPT recognized the authors of the most outstanding research and clinical practice manuscripts published in JOSPT during the 2012 calendar year. The 2012 JOSPT Excellence in Research Award was presented to Ivan Mulligan, Mark Boland, and Justin Payette for their paper titled “Prevalence of Neurocognitive and Balance Deficits in Collegiate Football Players Without Clinically Diagnosed Concussion.” The 2012 George J. Davies-James A. Gould Excellence in Clinical Inquiry Award was presented to Richard B. Souza, Thomas Baum, Samuel Wu, Brian T. Feeley, Nancy Kadel, Xiaojuan Li, Thomas M. Link, and Sharmila Majumdar for their work titled “Effects of Unloading on Knee Articular Cartilage T1rho and T2 Magnetic Resonance Imaging Relaxation Times: A Case Series.” J Orthop Sports Phys Ther 2013;43(3):115–116. doi: 10.2519/jospt.2013.0102
Effect of previous botulinum neurotoxin treatment on microvascular decompression for hemifacial spasm
Authors: Wang Xuhui , Thirumala Parthasarathy D. , Shah Aalap , Gardner Paul , Habeych Miguel , Crammond Donald J. , Balzer Jeffrey , Horowitz Michael 
Published: March 2013

Object
The objective of this study was to investigate the clinical characteristics, intraoperative findings, complications, and outcomes after the first microvascular decompression (MVD) in patients with and without previous botulinum neurotoxin treatment for hemifacial spasm (HFS).

Methods
The authors analyzed 246 MVDs performed at the University of Pittsburgh Medical Center between January 1, 2000, and December 31, 2007. One hundred and seventy-six patients with HFS underwent botulinum neurotoxin injection treatment prior to first MVD (Group I), and 70 patients underwent their first MVD without previous botulinum neurotoxin treatment (Group II). Clinical outcome data were obtained immediately after the operation, at discharge, and at follow-up. Follow-up data were collected from 177 patients with a minimum follow-up period of 9 months (mean 54.48 ± 27.84 months).

Results
In 246 patients, 89.4% experienced immediate postoperative relief of spasm, 91.1% experienced relief at discharge, and 92.7% experienced relief at follow-up. There was no significant difference in outcomes and complications between Group I and Group II (p > 0.05). Preoperatively, patients in Group I had higher rates of facial weakness, tinnitus, tonus, and platysmal involvement as compared with Group II (p < 0.05). The posterior inferior cerebellar artery and vertebral artery were intraoperatively identified as the offending vessels in cases of vasculature compression in a significantly greater number of patients in Group II compared with Group I (p = 0.008 and p = 0.005, respectively, for each vessel). The lateral spread response (LSR) disappeared in 60.48% of the patients in Group I as compared with 74.19% in Group II (p > 0.05). No significant differences in complications were noted between the 2 groups.

Conclusions
Microvascular decompression is an effective and safe procedure for patients with HFS previously treated using botulinum neurotoxin. Intraoperative monitoring with LSR is an effective tool for evaluating adequate decompression.