bluuebunny/crossref_metadata_2025 huggingface dataset:
Engineering institutions and networking in nineteenth-century Belgium and Britain
Authors: Linssen Willemijne , Raymaekers Pieter
Published: March 2013

The paper provides a comparative analysis of two engineering institutions in nineteenth-century Belgium and Britain, the pioneer nations of the industrial revolution situated on each side of the North Sea. The Association des ingénieurs sortis de l'école de Liège is examined in parallel with the pioneer engineering association, the Institution of Civil Engineers. The authors look at the key issues involved in running a flourishing engineering society in a Western capitalist industrial nation during the nineteenth century. They conclude that they depend, to a large extent, on the national context in which the engineering profession was allowed to develop. Although there were clearly major national divergences in the fields of education, institutional proliferation and membership, there were similarities regarding their mission statement, chairmanship, field of expertise and internationalisation.
Partner Abuse Worldwide
Authors: Esquivel-Santoveña Esteban Eugenio , Lambert Teri L. , Hamel John
Published: March 2013

Research on partner abuse has lagged in much of the world where attention has been on other problems (such as famine and war) and other crimes against women (e.g., honor killings, genital mutilation). We conducted a sweeping review of scholarly articles published in peer-reviewed journals and by government agencies outside of the United States and English-speaking developed nations that provided quantitative data on physical, psychological, and sexual abuse of intimate partners as well as consequences, risk factors, and attitudes. One hundred sixty-two articles reporting on more than 200 studies in Asia, the Middle East, Africa, Latin America, and Europe met the inclusion criteria from various types of samples. Most of the studies reported on female victimization only, but 73 reported on both male and female victimization.

We also conducted an analysis of data from our literature review, including 1 major cross-national study, to determine the relationship among prevalence of abuse, social factors, and women’s empowerment. Results indicate that partner abuse is a widespread problem around the world, with multiple causes. Overall prevalence of abuse is higher in Third World countries compared to the United States, and rates for physical and psychological abuse are comparable across gender in most countries when all types of samples are considered. No significant association was found between rates of partner violence (PV) and a nation’s level of human development. However, a significant relationship was found between a nation’s level of gender empowerment and rates of PV by both males and females but only for university dating samples from the International Dating Violence Study (IDVS). In addition, an analysis of the IDVS indicates that efforts by 1 partner to dominate the other are positively correlated with physical abuse perpetration for women, but not for men. Among the limitations of this review was the relatively few numbers of large population studies that ask about both male and female perpetration and victimization and the consequences and context of PV. Implications of the findings include the need for a broader conceptualization of PV as not merely a gender problem but also (and perhaps primarily) a human problem.
Living the HSE Vision and Values - Delivering success in an Environment of Significant Change; inside and outside the Organization
Authors: Siokos George , Karish John
Published: March 2013

Ensco plc is an international drilling contractor which has experienced significant growth since its creation only 25 years ago to its current position as the second largest offshore drilling organization worldwide. It has recently doubled its size through the acquisition of another similarly sized drilling organization.

Despite this significant growth, and while being challenged by many issues from inside such as integration, and from the outside such as having to do business in a difficult market and in many different national cultures, it has achieved acknowledged excellent performance. Ensco plc was voted as the number one performer by major operators in an independent customer survey in 2010 and in 2011.

What processes and leadership has Ensco utilized to achieve this?

This paper will describe these processes and the leadership that has driven this success. They are not new; what Ensco has done is integrate existing and well known concepts in a way that has led to this success.

They involve an unshakeable belief in Ensco's Vision and Core Values, visible leadership that understands it and the organization has to continual change to adapt to an ever changing world. Its leadership also acts on making the Vision and Core Values come to life, a drive for consistent use of systems, and a belief and a preparedness to invest in the development of its people in competencies critical for its long term success.

These things underpin the creation of an organizational culture where people are more likely to accept the accountability and responsibility to do their personal best.

We will describe how the above was achieved and the steps followed to ensure sustainable performance. Key considerations in the strategy, whether consciously adopted or ortherwise by virture of the leadership programs exposed to Ensco's people included.
Application of Targeted Bit Speed (TBS) Technology to Optimize Bakken Shale Drilling
Authors: Bassarath Wendell D , Maranuk Christopher A.
Published: March 2013

Since 2010, shale drilling in the North Dakota sector of the Bakken has seen an industry changeover to long laterals (> 7,500 ft) with the majority being closer to 10,000 ft. These longer laterals require a tremendous engineering effort and create several issues with hole cleaning, ledging and reduced rate of penetration. In order to improve performance in these laterals, operators have long been looking for an economic alternative to rotary steerable systems, while maintaining their inherent benefits.

A new system to achieve 3D directional control has been developed to improve drilling efficiency using Targeted Bit Speed (TBS) technology. The system uses a conventional positive displacement motor with a bent housing and a measurement-whiledrilling (MWD) tool that mimics many of the features offered by a rotary steerable system. The steering technique is achieved by accurately modulating the flow of the drilling fluid through the drillstring. This allows rapid variations in the drilling parameters to accurately control the bit speed along the desired toolface setting. If the wellbore objectives cannot be achieved in rotary mode using TBS technology, then the mud motor can be oriented in a conventional manner to follow the well plan.

This paper examines the results of two horizontal wells drilled in North Dakota. The first well was drilled to the planned total depth (TD) using TBS technology; the second well (not using TBS technology) had to be terminated prematurely, due to high torque and drag. This paper focuses on showing the improvement in the drilling process that this new technology offers by way of key metrics, such as reduced drilling time and improved wellbore geometry, with consequent cost savings.
Exploration and Appraisal Drilling Operations in the South Atlantic
Authors: Jenner J. W. , Morrison A. , Lyons R. , Phillips L. , McBean l.
Published: March 2013

The paper describes how the teamwork and continuity provided by utilising a drilling project management company based in Aberdeen and a single drilling contractor enabled two small UK operating companies, with limited in-house operational resources, to conduct offshore drilling campaigns in an area remote from established support centres.

It will summarise the geological conditions encountered in the North Falklands Basin and discuss the drilling engineering and well planning. It will also discuss the importance of the logistics planning and supply chain management, which included the enhancement of limited onshore support facilities in Port Stanley and the introduction of industry standard safe operating procedures. The paper will also review the day to day drilling operations and interaction with the local authorities.

On Saturday 17 March 2012, the Ocean Guardian semi-submersible drilling unit returned to Invergordon on the Cromarty Firth at the end of an 8000 mile ocean tow from the South Atlantic. The rig left the firth in November 2009 to make the journey south, arriving on its first location north of the Falkland Islands in February 2010. In the intervening period it successfully worked for three different operators, drilling nine exploration wells (including one in the southern basin) and seven appraisal wells, two of which were tested, discovering and delineating the Sea Lion oil field. Water depths, with the one exception in the southern basin, were up to 450m.

The paper will demonstrate that with detailed and careful planning, inclusive management and modern communications technology, drilling operations in remote locations can be conducted safely and efficiently.
Torsional Resonance - An Understanding Based on Field and Laboratory Tests with Latest Generation Point-the-Bit Rotary Steerable System
Authors: Lines L. A. , Stroud D. R. , Coveney V. A.
Published: March 2013

Torsional dynamics can be extremely damaging to downhole drilling tools and can significantly affect drilling efficiency. Industry focus on combating this has led to the development of various downhole mitigation tools, improved bit technologies, BHA designs and better management of drilling parameters. The aforementioned focus primarily on combating stick-slip, or at least the conventional form of it, with its distinctive stick and slip phases.

This paper outlines two lesser known types of torsional dynamics observed whilst drilling inter-bedded carbonate formations in the middle-east with the latest generation in point-the-bit Rotary Steerable Systems (RSS). One of these phenomena has the potential to be extremely damaging, more so than conventional stick-slip, and is of such high frequency that conventional logging rates are incapable of detecting it.

This paper highlights the presence of a low frequency (<0.5Hz) and a high frequency (~70Hz) periodic oscillation in rpm observed using one of the industries most advanced downhole dynamics sensors. The low frequency oscillation was found to occur at the fundamental torsional natural frequency of the drillstring, with RPM fluctuating harmonically by as much as three times the average surface rpm. The high frequency torsional oscillation, attributed to a torsional resonance within the bottom hole assembly (BHA) itself, resulted in extremely damaging high frequency, high magnitude (10,000rad/s2) torsional oscillations. The loading environment resulting from this high frequency torsional resonance has the ability to fatigue downhole tools in a matter of hours!

This paper outlines findings from both field and laboratory tests, attempting to better understand both the low and high frequency torsional phenomenon. This paper goes one step further than existing literature by attibuting the high frequency torsional oscillations to structural resonances within the BHA. This is substantiated both analytically and experimentally. Understanding the underlying characteristics of these phenomena paves the way for new, more effective, prevention systems.

The paper concludes with the development of a unique sensor which monitors subtle changes in the industry standard Stick-slip Index to detect different torsional dynamic modes in realtime and send a text based description and severity rating to surface.
Automated Decision Support to Enhance While-Drilling Decision Making: Where Does it fit Within Drilling Automation?
Authors: Sadlier Andreas , Says Ian , Hanson Ryan
Published: March 2013

Our industry has been advancing drilling automation concepts to increase safety, reduce drilling risk, and improve the overall repeatability of the drilling process. At the same time, increased drilling costs, available expertise shortage, and safety-related issues with personnel at the wellsite, have prompted the need to provide interpretation and advice remotely.

Remote centers enable subject matter experts (SMEs) to work on multiple, geographically dispersed wellsite operations concurrently without having to be on location. These centers facilitate the ability of multiple experts to assemble quickly and collaborate to solve complex challenges without adding the HS&E risk of additional personnel at the wellsite. However, the increased volume of information available from technologies like wired-pipe, combined with the shortage of experienced SMEs to quickly interpret datasets, create new challenges.

Digital oilfield applications have challenged operators and service providers to leverage remote capabilities to aggregate huge data volumes and provide expert knowledge for multiple operations. Focusing attention of personnel on the most important information to make accurate and timely decisions requires new techniques. New systems require automation so that risk recognition and advice can be automatically delivered to the right experts to streamline while-drilling decision-making.

New cased-based reasoning technologies can compare the current drilling situation to similar previous case histories where problems occurred. This real-time decision automation enables identification of similar events that led to drilling problems on similar wells drilled in the past. From those historical cases, similar solutions are presented to avoid potential drilling problems before they occur. This while-drilling response provides the automated real-time connection between previous experiences and current operations that reduce drilling risk and ensure greater repeatability.

A case history is presented on the use of case-based reasoning to enhance automated advice by identifying hazardous situations in advance that enabled successful corrective action implementation.
Accounting for Lost Circulation and NAF Compressibility - Impacts on Cement Placement
Authors: Shine J. M. , Chaudhary S. A. , Felio A. J. , Martin R. S.
Published: March 2013

Most cementing simulators do not account for lost circulation events or the compression/expansion behavior of non-aqueous fluids (NAF) during cement placement. As a result, their output can be unreliable, resulting in potentially poor recommendations and operational performance – in potentially critical well-cementing situations. When isolating potential flow zones and/or performing zonal isolation in high-temperature/high-pressure (HT/HP) and/or deepwater environments for example, accounting for lost circulation and compressibility of non-aqueous fluids can make the difference between a successful cementing operation and a very expensive failure. In addition, overall reliability compared to existing simulators is improved operationally and technically assuring the objectives of the cement placement can be met while complying with new regulations as they can apply to zonal isolation.

This paper will explain the theory and methods behind the advanced cementing simulator inputs and resultant outputs with case histories demonstrating some of the field validation of the new simulator's reliability. Also, existing technology in the simulator will be highlighted summarizing the robust package available to meet the objectives of cementing job placement in light of recent industry changing events.
Case Study of Rotating Expandable Reamer Across Whipstock and Drilling Ahead over 8,000 ft Reduces Drilling Time
Authors: Radford S , Desselle S , Enterline D , Allain M , Oliveire J , Pearl B , Palmer J
Published: March 2013

In today's oil and gas industry, reducing drilling time and cost has become more and more important as wells have been drilled deeper and costs have risen. This paper will describe a case study of a well drilled in the Main Pass area of the Gulf of Mexico for a major operator. In this job, in order to eliminate a trip and significantly reduced costs, it was required to rotate a bottomhole assembly (BHA), including an expandable reamer, across a whipstock.

This well contained several unusual challenges that will be described, including a shallow kick off and a subsequent extended-hole section to reach a proposed total depth (TD) in excess of 10,000 ft, drilling through sand and shale.

The paper will describe the team process, coordination and communication required between the operator and service companies to make this unique job successful. Offsets will be compared with respect to drilling dysfunction, vibrations, time, costs, and the like.

To reduce cost and non-productive time (NPT), it was decided to forgo drilling a long rathole out of the whipstock and proceed immediately with reaming on the next trip in. This approach required rotating the closed reamer across the whipstock, necessitating a series of analyses to limit the risk while performing this unusual feat. Extra trips were eliminated by using innovative well planning, procuring downhole tools with reputation of toughness and reliability, and finally requiring excellent cooperation between all involved parties. This job was confirmed to have saved the operator 29 hours of rig time and in excess of $250,000, while reducing the drilling plan by two days.
Macondo Litigation and its Impact on the Offshore Industry -- What Every Operator, Driller, Service and Supply Company Needs to Know
Authors: Moomjian C.
Published: March 2013

Macondo is a "game changer" that will substantially impact the oil and gas industry from an operational, contractual and risk management perspective.

Decisions in the Macondo litigation that is pending in a U.S. District Court in New Orleans will impact operators, drillers, service and supply companies in respect of pollution liability in general and contractual indemnity/release provisions in particular.

This paper primarily reviews and analyzes landmark Court decisions on summary judgment motions regarding interpretation, applicability and enforceability of the indemnification provisions and releases in the drilling and cementing contracts that were applicable to the Macondo well.

In January 2012 rulings on summary judgment motions involving the drilling and cementing contracts, the Court determined that contractual indemnification may apply even in the event of gross negligence or strict liability but will not be applicable to protect a party against intentional wrongdoing as a matter of public policy. The Court also ruled that the scope of indemnification excludes punitive damages as a matter of public policy. The Court held that contractual indemnification may apply to protect an indemnified party from penalties assessed under the Oil Pollution Act of 1990 ("OPA'90") but not under the Clean Water Act ("CWA"). The Court deferred ruling on whether a material breach of contract would invalidate indemnity protection. In the decision relating to the cementing contract, the Court also ruled that indemnities will be invalidated by fraudulent acts that constitute intentional wrongdoing and deferred ruling on whether penalties or fines under the Outer Continental Shelf Act ("OCSLA") are subject to contractual indemnity.

This paper reviews these rulings in detail and includes the author's commentary on the decisions and the interpretation (or, perhaps more accurately, misinterpretation) of certain of the drilling contract provisions based upon over 35 years of drilling industry experience primarily as an executive overseeing legal, contracts and risk management activities.

The Court rulings in the Macondo litigation will have a profound impact upon the offshore industry, especially with respect to contract terms, risk management and insurance. While U.S.-centric and primarily applicable to U.S. maritime law, the litigation and other ramifications of Macondo are expected to ultimately have considerable global impact both offshore and onshore.
Innovative Hybrid Bit Mitigates Geological Uncertainties, Improves Drilling Performance in Brazilian Pre-Salt Formations
Authors: Hbaieb Slim , Azar Michael , Bits Smith
Published: March 2013

An innovative hybrid bit design has been successfully applied offshore Brazil to mitigate geological/formation uncertainties in pre-salt formations and eliminate several trips for new bits. In the application, PDC bits can drill these carbonates effectively until the cutters are damaged by problematic chert inclusions. The hybrid bit is capable of similar ROP and run lengths as standard PDC and allows the operator to achieve a long run at high ROP when no silicate inclusions are present. However, the hybrid bit also provides the added benefit of continued drilling at reasonable ROP when a nodule is encountered with its secondary and tertiary cutting elements.

The unique hybrid design utilizes grit hot-pressed inserts combined with alternating PDC shearing elements and wedge shaped TSPs all set in an impregnated post-on-blade design. Extended bit life is achieved when the cutting mechanism changes from shearing to grinding as the PDC/TSP elements are worn away. When the PDC cutting structure is worn down to 50%, the bit still has 75% of life remaining.

The paper will focus on case studies where pre-salt carbonate lithology is non-uniform with a high occurrence of silicate inclusions. The authors will discuss drive system and drilling parameters selection that were critical to achieving the desired performance. When used with the appropriate BHA and drilling parameters, the hybrid bit displayed good ROP performance and total footage capabilities. Lower cost/meter was achieved because the hybrid bit had faster initial ROP compared to PDC and stayed on bottom drilling longer due to improved durability with TSP then impregnated cutting structures. Cuttings size and resulting lithology analysis will also be discussed. Engineers are currently working on a real-time surface/downhole data processing system to detect when the impregnated cutting structure engages formation in order to make changes in operating parameters to maximize drilling efficiency and penetration rates.
The Application of UBD and MPD Techniques to Solve Challenges and Optimize Drilling in the Quintuco and Vaca Muerta Formations in the Neuquén Basin
Authors: Leon Ricardo , Benedetti Juan , Poletzky Isabel C. , Gomez Vicent Nemesio E.
Published: March 2013

The Neuquén basin is located in the Neuquén province in Argentina and comprises the Loma La Lata, Bajo Añelo, and Orejano fields (Fig. 1). The target formations in this project are the Quintuco and Vaca Muerta, which are composed of limestones and marlstones, respectively. Formation pressures range from 1.25 g/cm3 to 1.75 g/cm3 in the Quintuco and up to 2.20 g/cm3 in the Vaca Muerta. Abnormal pressure gradients have been encountered at relatively shallow depths. These characteristics present several challenges when using conventional techniques to drill through these formations, including kicks, fluid losses and associated formation damage, and wellbore instability in the marlstones, all resulting in increased nonproductive time (NPT).

The implementation of underbalanced (UBD) and managed-pressure drilling (MPD) techniques has enabled safe production of the hydrocarbon reserves in the Neuquén basin fields. These techniques allow for the immediate adjustment of bottomhole pressure (BHP) when a change in the formation pressure is detected by increasing or decreasing the applied surface-back pressure (SBP) and safely controlling hydrocarbon production to the desired volume at surface. A pressurized closed-loop system, which includes a rotating control device (RCD), choke manifold, 3-phase separation system, and data-acquisition system, enables precise control of bottomhole pressure.

Fourteen wells have been drilled in the Neuquén basin, using UBD and MPD techniques. This paper describes the implementation of these techniques when drilling the 8-½-in. and 6-1/8-in. sections, along with results, including the evaluation of reservoir potential while drilling, estimation of formation pressures, minimizing formation damage, as lower-density drilling fluids are being used, reduction of NPT, and being able to safely reach the planned depth. Field data is used to illustrate the challenges encountered and results obtained. Lessons learned and how the drilling process has been optimized are also discussed.
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

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

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

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

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

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

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

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

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

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.
Meaning of the Death of an Elderly Father: Two Sisters' Perspectives
Authors: Moss Miriam S. , Moss Sidney Z.
Published: March 2013

Multiple bereaved adult children, as siblings, have rarely been studied. We expand the paradigm of bereavement research to explore the ways that two sisters describe the experience and meaning of the death of their elderly father. The two sisters each participated in two separate qualitative ethnographic interviews, followed by standard qualitative analyses of the transcribed narratives. The findings yield contrasting perspectives of the sisters' disparate views of their family, of their father, and their views of each other, that provide insight into the complexity of the sharp differences in their reactions to their father's death. Their views of their father's death reflected their particular relationship with their father, their non-shared experiences over the life course, and their personal world views. Differences and contradictions in the views of multiple siblings can broaden our understanding of bereavement and of the processes central to parent-child ties at the end of life.
Psychometric Characteristics of Chinese Version of Barratt Impulsiveness Scale-11 in Suicides and Living Controls of Rural China
Authors: Lu Chang-Fei , Jia Cun-Xian , Xu Ai-Qiang , Dai Ai-Ying , Qin Ping
Published: March 2013

The Barratt Impulsiveness Scale-11 (BIS-11) is an important tool for measuring impulsivity in suicide research. This study aimed to assess psychometric characteristics of Chinese version of BIS-11 in suicides and controls of rural China. Data of 200 pairs of suicide cases and living controls were collected by psychological autopsy method. The Cronbach's alpha coefficients of BIS-11 were 0.936 for suicides, and 0.892 for living controls. Convergent validity analysis demonstrated a significantly positive correlation between the scores of BIS-11 with the scores of Beck Hopelessness Scale and Trait Anxiety Inventory. Confirmatory factor analyses indicated that the BIS-11 structure was basically suitable in rural China. With its high reliability, few items in BIS-11 may need a modification in order to further improve the construct validity of this instrument for suicide research in rural China.
Loss and Grief in the Workplace: The Challenge of Leadership
Authors: Tehan Mary , Thompson Neil
Published: March 2013

There is no part of human existence that loss and grief do not reach, and the workplace is no exception to this. This article is therefore concerned with some of the implications of loss and grief in work settings in general and for workplace leaders in particular. By way of example, it explores in particular the needs of bereaved caregivers returning to work and the potential for stigma to emerge in relation to employment and bereavement. Central to the article is an argument in favor of the need for change within the workplace, specifically within the structures and systems that support bereaved caregivers returning to work. This article critically reflects on the leadership management challenge of supporting bereaved caregivers returning to, or seeking, work and addressing the problem of stigma in relation to employment and bereavement. Some structural and policy changes are highlighted to assist employers and bereaved caregivers faced with this situation.
Next Generation Sequencing Reveals the Association of DRB3*02:02 With Type 1 Diabetes
Authors: Erlich Henry A. , Valdes Ana Maria , McDevitt Shana L. , Simen Birgitte B. , Blake Lisbeth A. , McGowan Kim R. , Todd John A. , Rich Stephen S. , Noble Janelle A. ,   for the Type 1 Diabetes Genetics Consortium (T1DGC)
Published: March 2013

The primary associations of the HLA class II genes, HLA-DRB1 and HLA-DQB1, and the class I genes, HLA-A and HLA-B, with type 1 diabetes (T1D) are well established. However, the role of polymorphism at the HLA-DRB3, HLA-DRB4, and HLA-DRB5 loci remains unclear. In two separate studies, one of 500 subjects and 500 control subjects and one of 366 DRB1*03:01–positive samples from selected multiplex T1D families, we used Roche 454 sequencing with Conexio Genomics ASSIGN ATF 454 HLA genotyping software analysis to analyze sequence variation at these three HLA-DRB loci. Association analyses were performed on the two HLA-DRB loci haplotypes (DRB1-DRB3, -DRB4, or -DRB5). Three common HLA-DRB3 alleles (*01:01, *02:02, *03:01) were observed. DRB1*03:01 haplotypes carrying DRB3*02:02 conferred a higher T1D risk than did DRB1*03:01 haplotypes carrying DRB3*01:01 in DRB1*03:01/*03:01 homozygotes with two DRB3*01:01 alleles (odds ratio [OR] 3.4 [95% CI 1.46–8.09]), compared with those carrying one or two DRB3*02:02 alleles (OR 25.5 [3.43–189.2]) (P = 0.033). For DRB1*03:01/*04:01 heterozygotes, however, the HLA-DRB3 allele did not significantly modify the T1D risk of the DRB1*03:01 haplotype (OR 7.7 for *02:02; 6.8 for *01:01). These observations were confirmed by sequence analysis of HLA-DRB3 exon 2 in a targeted replication study of 281 informative T1D family members and 86 affected family-based association control (AFBAC) haplotypes. The frequency of DRB3*02:02 was 42.9% in the DRB1*03:01/*03:01 patients and 27.6% in the DRB1*03:01/*04 (P = 0.005) compared with 22.6% in AFBAC DRB1*03:01 chromosomes (P = 0.001). Analysis of T1D-associated alleles at other HLA loci (HLA-A, HLA-B, and HLA-DPB1) on DRB1*03:01 haplotypes suggests that DRB3*02:02 on the DRB1*03:01 haplotype can contribute to T1D risk.