bluuebunny/crossref_metadata_2025_split huggingface dataset:
Limitations of Postless Hip Arthroscopy for a Patient with Coxa Profunda
Authors: Meek Wendy M. , Abraham Paul F. , Kucharik Michael P. , Martin Scott D. 
Published: March 2021

Case:
A 27-year-old man with coxa profunda and a right acetabular labral tear presented for surgical re-evaluation after a postless arthroscopic labral repair was attempted at an outside institution and aborted because of inadequate distraction during portal placement. Arthroscopic labral repair with a perineal post was subsequently performed without complications.

Conclusion:
Indications and limitations of postless hip distraction are seldom discussed in the literature. This report examines possible limitations of postless hip distraction for a patient with coxa profunda. Careful radiographic evaluation of hip anatomy may be essential for patients with deep hip sockets to determine the best-suited distraction technique.
The Snorre A 2004 Blowout and Its Impact on Drilling and Well Operations Today
Authors: van der Zwaag Claas H. , Paulsen Thor 
Published: March 2021

Abstract
The Snorre A blowout on well P-31 A on November 28, 2004, was a well control incident that sent percussions into our national and corporate HSE management systems. These percussions still resonate in our everyday work as a part of a comprehensive set of rules which encompass national regulations, industry standards, corporate functional, technical, or work requirements, as well as an integrated governing work process management system. Some of these rules have been embraced with a positive attitude and are now a natural part of our day-to-day work. They prepare for technical, organizational, and operational barriers that secure the safety of all personnel, shield the value of our investments and assets, and protect the environment. Some of these rules, however, may be perceived as dead weight and barriers in the sense of hindrances that may hamper an efficient workday and fill our agenda with many formal demands and obligations.
This paper pinpoints and reviews "the change in rules" that the Snorre incident caused regarding planning, execution, and follow-up of drilling and well (D+W) operations on government, industry, and corporate level. The major failures that the investigations of the incident revealed have been handled diligently in our corporate system. In this paper, we track how management involvement, management of change, and "compliance and leadership" work in practice. The day-to-day tasks to prepare for safe D+W operations and to secure the integrity of wells in operations are explained. As an illustrative exercise, we are setting up a hypothetical plan for Snorre P-31 A as the D+W operations would have been planned today. This is done by outlining well barrier schematics, risk assessments, and the processes to handle deviations from technical or work requirements.
Our objective is to explain that risk management in the planning and the execution of D+W operations and for wells in operations is coherent. To avoid the recurrence of incidents such as Snorre P-31 A, a systematic and rigorous approach is in use that makes it likely to capture inadequate well integrity conditions. This approach links high-end government regulations to sharp-end detailed operational risk management in our HSE management system.
Successful Installations and Predictable Performance of Solid Expandable Drilling Liner in Greater Ekofisk Field, Offshore North Sea
Authors: Fitnawan Eko Awan , Holien Bjørn , Nevøy Harald 
Published: March 2021

Abstract
Drilling the lower overburden section in specific parts of the Greater Ekofisk Area (GEA) fields can be very troublesome. Wells in these parts may intersect shales with high gas content in the upper section (requiring high mud weight) and unstable zones with massive lost circulation risk (requiring low mud weight) near the base of the interval. These challenges have raised the need for a contingency drilling liner to "split" the section in two parts. Rather than changing the basic well design, the operator fronted the development of an 8-5/8″ expandable drilling liner with high collapse resistance for this purpose. This string provides 8.514″ post-expansion drift ID that accommodate an 8 ½″ bit size for the reservoir section, which is critical for GEA well design strategy.
In the past five years, the operator has successfully installed 31 800 ft of 8-5/8″ expandable liner in 27 different wellbores with near perfect track record. The average liner length installed is 1 140 ft per wellbore, with an average installation time of 2.8 rig days. The solid expandable tubular (SET) drilling liner has been utilized both as part of the planned well design and as contingency liner. It has, on occasions, been worked down with parameters outside the stated specifications and still been successfully expanded afterwards.
The 8-5/8″ expandable liner is now a proven system and has been one of the key enablers to achieve well objectives by maintaining hole size in a predictable manner. It provides a better drilling window for reservoir drilling and reservoir liner cementing compared to a conventional 7-3/4″ liner alternative. It also enables further contingency solutions in case other difficulties arise in the reservoir section.
This technical paper describes how the operator in the overcame a significant geological challenge by working with an expandable pipe supplier to develop a unique size and strength of expandable liner that fits with the base case GEA well design. The paper also reviews the installation experiences, associated risks, performance, and key learnings with expandable liners.
Buoyancy Force on a Plain or Perforated Portion of a Pipe
Authors: Cayeux Eric , Stokka Sigmund 
Published: March 2021

Abstract
Torque and drag models have been used for many decades to calculate tensions and torques along drill-strings, casing strings and liner strings. However, when applied to sand-screens, it is important to check that all the initial hypotheses used for torque and drag calculations are still valid. In particular, it should be checked whether the buoyancy force on a perforated tube may differ from the one applied to a plain tube.
The buoyancy force applied on a pipe, contributes to the sum of efforts at the contact between the pipe and the borehole and therefore influences torque and drag calculations. This contact force is local and should account for localized effects as well as the material internal forces, torques and moments on each side of the contact. As the buoyancy force is the result of the gravitational component of the pressure gradient on the surface of the pipe that is in contact with the fluid, the presence of holes in the pipe also influences the buoyancy force.
When applied to a portion of a pipe, buoyancy does not have contributions at the end caps of that portion of the drill-stem since these end caps are not in contact with the fluid, except at positions with a change of diameter. Therefore, one shall be cautious when calculating the local buoyancy force either on a plain or a perforated tube. The paper describes how to calculate the local buoyancy force on a portion of a drill-stem by application of the Gauss theorem accounting for the necessary corrections arising from the end caps not being exposed to the fluid.
An experimental setup has been built to verify that the tension inside a pipe subject to buoyancy does follow the derived mathematical calculations.
With complex well construction operations, for instance during extended reach drilling or when drilling very shallow wells with high kick-off rates, the slightest error in torques and drag calculations may end up in jeopardizing the chance of success of the drilling operation. It is therefore important to check that all initial calculation hypotheses are still valid in those contexts and that for instance, sand-screens may be run in hole safely after a successful drilling operation.
Development Field First - Directionally Drilling Through Challenging Muderong Shale and Highly Depleted Reservoir Sand with HPWBM
Authors: Lambert Tylan John , Mj Shiv Aanand , Clark Courtney 
Published: March 2021

Abstract
Advancement in High Performance Water Based Mud (HPWBM) coupled with a deeper understanding of shale and chemical interaction has taken a leap in recent years enabling the drilling of challenging wells whilst replacing Synthetic Based Mud (SBM) as the preferred technical option. The exceptional inhibition properties, versatility to chemical manipulation and stability, as well as being an environmentally beneficial alternative to SBM, HPWBM has proven to be a robust solution for drilling the challenging Muderong shale and highly depleted reservoir sands in the field.
Through a detailed field wide offset review focusing on wellbore stability and shale reactivity relationship observations, time dependent shale reactivity and an engineered bridging package was the basis of a successful fluid formulation and selection which then resulted in a flawless execution of the challenging well. Various testing of shale cuttings from the field paired with an offset review was key to understanding the extent of shale reactivity in relation to the type of shale being drilled and cause of shale instability in the area. These results were imperative in providing technical justification to utilise HPWBM for drilling through the Muderong shale. Applying detailed reservoir drilling fluid analysis to the overburden drilling fluids design and incorporating previous offset fluid design learnings, provided a robust and versatile drilling fluid system.
This paper will review the steps undertaken to validate the selection of HPWBM over SBM through detailed analysis of wellbore stability, shale reactivity, permeability assessment, pore throat sizing and pore pressure transmission. It will present the misnomer of comingling the wellbore stability requirement, primarily mud weight, with shale reactivity in the field as well as the relation between the plateauing of shale reactivity curves to near well wellbore swelling. Extensive laboratory testing was performed to formulate and demonstrate the efficacy of the bridging package in addressing differential sticking, losses and wellbore strengthening in highly depleted sands. In addition, this paper will also present actual field results on stability of the fluid properties along with resultant torque and drag throughout drilling of a directional well with no requirement for lubricants.
This paper should be of interest to all engineers and technologists who are involved in shale reactivity analysis, well design, drilling fluids design, selection and interaction as well as highly depleted reservoir sand drilling.
Well Design for Subsea Exploration Drilling in Shallow Formations of Barents Sea
Authors: Stanislawek Mikolaj 
Published: March 2021

Abstract
Subsea exploration drilling in relatively new and not yet fully recognized frontiers like Barents Sea continues to be a focus for Oil & Gas Companies. Safety and robust well barriers are important as ever. This paper describes well design process and execution of a challenging subsea exploration well in shallow formations of Barents Sea by Equinor.
Case study for planning and well design process is presented, followed by drilling experiences during execution. Several well design concepts and contingency scenarios that were evaluated and risk assessed in the planning phase are presented, which required extra focus on well design and well barriers. Compensating measures along with high focus on well control and well barriers in shallow drilling environment of Barents Sea were developed during planning phase of this well, and reviewed with planning and execution teams. Design approach encompasses casing design in shallow reservoir well with narrow margin between required formation integrity and fracture pressures, low kick tolerance, drilling in unstable formations, low temperature and pressures.
Robust well design in shallow and weak formations is feasible with conventional casing design approach, and well challenges can be overcome by proper planning and contingency measures involving additional preparation of drilling crew, and by use of advanced drilling technology and procedures. Safety and well control is the most important factor in well design. Relevant contingency scenarios should be prepared with equipment and procedures in place. Importance of drilling a pilot hole in unrecognized area near main well and its influence on main well design is crucial.
This is a good example of planning and drilling process for challenging well in unrecognized area with limited reference well data, challenging logistics, and weather conditions of Barents Sea. It will demonstrate how many contingency scenarios were fully prepared in planning phase and their rationale, versus encountered drilling experiences, to be a more precise reference for future wells in the area.
Improving Employee Wellbeing through a Five-Phase Psychological Model to Reduce Risk and Improve Performance
Authors: Seaton Simon , Jelley Thomas , Carthy Daphné 
Published: March 2021

Abstract
In its latest US Oil & Gas workplace safety report, the American Petroleum Institute (API) noted that the industry's incidence rate has decreased by 41% since 2008 due to an increased focus on the industry-wide goal of zero incidents (American Petroleum Institute, 2020). However, there continues to be a significant number of serious incidents directly related to human behaviours rather than a lack of control or processes. In a high-risk environment such as Oil & Gas sites, onshore or offshore, it is imperative to have a healthy workforce - both physically and mentally - and there is a link between worker wellbeing, stress, overall performance, and safety attitudes.
Many segments of the Oil & Gas industry require workers to leave home and family for extended periods, and this can have a significant impact on an employee's psychological wellbeing. This paper aims to inform individuals and organisations so they can better understand the effects of the experience of being away and increase the chances of maintaining their workers’ psychological wellbeing.
A five-phase model - from preparing to leave home through to being back at home - has been developed in consultation with academics, trade unions, expert insight from oil and gas, military and education sector perspectives. This model offers a new and practical way to think about and manage potential adverse impacts on psychological wellbeing while away in order to reduce risk. It was first set out by Seaton and Jelley (2015) and additional research has since been completed with new data that demonstrates the impact of the five-phase model.
The five-phase model has been tested among international students at universities in the UK (Smith, Smith and Jelley 2018) and in 2019 among foreign workers at an on-shore location in the United Arab Emirates (UAE). Consistent with findings in the university context, the results of the latest field research suggest that greater use of strategies to cope with working away from home is associated with (a) greater positive wellbeing (happiness, life satisfaction) in life generally (b) a better quality of working life (c) more efficient operational performance.
Using Continuous Circulation in Geothermal Wells to Improve Drilling Performance and Reduce NPT Related to Wellbore Stability
Authors: Petrie Scott William , Doll Rick 
Published: March 2021

Abstract
Continuous Circulation Systems (CCS) have been used in the past to help drill wells where interactions between the mud weight and theformation may increaserisks, thereby allowing the well to be drilledwithout encountering drilling problems or damaging the formation, whilst reaching total depth in the planned time. Previous systems have,however,relied on people working in the red zone. This paper discusses the process of making drill pipe connections, with continuous circulation,utilising a fully automatic deployment system to add value by removing the risk of people around the drill pipe during the connection, working in conjunction with other automated rig systems todeliver the advantages of continuously circulation over each connection.
The continuous circulation subs are installed in every stand of drill pipe to be used in the drilled interval and facilitate circulation while the next stand is picked up and made up to the stump. A valve manifold is utilised to divert flow from the pumps to the subs, instead of the top drive, during the connection. During each connection, circulation is maintained down the drill string, from bit to surface, at drilling rates. Once the connection has been made the continuous circulation surface equipment is disconnected from the drill string allowing drilling to resume.
After deploying the continuous circulation system on a number of geothermal projects, the results of using the system for top hole and intermediate sections suggest that while drilling with low rheology water-based mud systems,a high percentage of cuttings are returned to surface while the next stand of drill pipe is being picked up,limiting any hole loading and allowing the driller to increase the rate of penetration (ROP) through these sections. Fewer hole collapse issues were observed while drilling through volcanic tuff and ash, where wellbore stability is low due to poorly consolidated rock formations, thereby reducing non-productive time associated with stuck pipe and the costs of lost bottom hole assemblies (BHA's) and sidetracks. Most Geothermal projects work on very tight budgets and geothermal exploration costs need to be kept low. Improved drilling performance has improved the viability of these projects and increased the number of exploration wells that can be drilled in a campaign by reducing the days versus depth P90 estimate, that being the 90% probability of the rig matching the days v's depth curve predicted.
A Novel Use of Digital Technologies for More Effective Multi-Party Well Planning and Execution
Authors: Isbell Matthew Ray , Manocha Malini Raman , Mangold Brian Rodney , Laing Moray Lamond , Boone Scott , Annaiyappa Pradeep 
Published: March 2021

Abstract
Operators, service providers, and contractors are improving the well construction system using transformative digital technologies across multiple companies and within levels of disparate organizations. Well plans are managed in a new way with the creation,execution and continuous improvement of processes to materially deliver value from the onset.
A typical operator’s well planning process involves developing a well program across multiple internal and external entities in the design and plan stages while various requirements and details are considered and confirmed. As the well gets closer to being drilled, the well plan must also consider the capabilities and technologies supported by the service companies and drilling contractor.This people-based process leads to variability in assumptions and objectives in standardized plans which can result in execution risk and variations in safety, quality, delivery, and cost (SQDC) performance. One major variability source occurs because of the disconnected nature in which people move data between one another in well planning documents and then to field operations. The authors propose a new way to manage this process across organization and discipline boundaries to reduce this variability. This paper details how digital technologies were incorporated into an agile pilot program to create a common framework for the exchange and management of the well plan. It follows the plan from its development to implementation in a unified, seamless process. Further the authors will demonstrate how the solution was developed across multiple organizations to deliver material value to all parties.
Three companies created a collaborative business model to deliver a new digital system enhancing well construction planning and execution in terms of speed and completeness of data transfer, ease of access,and availability for building new data-based workflows and reporting. This business model continues to drive alignment throughout the companies’ well delivery business functions.
This paper illustrates, "What is the value that digital transformation brings to my organization or job function".The simple answer is that if executed effectively, the transformation should produce a material improvement or outcome for the business. Digital technology creates material business value as a project management tool directly coupled with wellsite technologies. This approach, in turn, will enable improvement of the well design and SQDC performance in the delivery of the well plan.
A Way to Reduce the Uncertainties, Optimize and Reduce Time During the Multistage Cut and Retrieve Operations for Surface Plug Placement
Authors: Volkov Maxim , Evans Mal , Haggart Garry , Gaifutdinov Ruslan , Beagrie Robert 
Published: March 2021

Abstract
Planning and execution of the well plug and abandonment(P&A) requires detailed knowledge of the downhole barrier's integrity status and position of its downhole completion elements.[Maxim Volkov] This input is utilized for the determination of zones for permanent plugs, casing cuts and retrieval procedures. The last one can be significantly optimized if conducted across the zones with minimal total wall thickness. Cutting the casing across casing collars, fins or casing decentralization may extend the operation requiring more time and resources to achieve success.
However, the detailed completion information is not always available due to several well handover. This may result in casing cut performed blindly, based on the position of the first casing collars revealed by caliper or ultrasound surveys. This may result in an increase of the RIG operation timing from few hours to few days.
The paper shows results of downhole scanning during three subsea wells P&A campaign at the stage of environmental plug deployment. This included cutting and pulling out of casing wellhead elements (casing stumps) after milling works, before setting environmental cement plug in seabed zone. Casing wellhead design may include the first 13 3/8" and 20" casing joint welded fins to centralize casings. Typical casing joint with fins (rigid type) is shown in figure 1. The abandonment program included milling of these casings and the cutting through the minimal or nominal wall thicknesses with avoiding fins and collars of the casings. The depth of the cutting window initially was set from the available well diagrams, which were not available in all the wells. Thus, the main role of the scanning was to verify and optimize the casings cut window depth to perform the process with minimal issues.
Figure 1 Casing joint with rigid centralizers-fins.