bluuebunny/crossref_metadata_2025_split huggingface dataset:
Declining Rate of International Medical Graduates Matching Into Orthopedic Surgery Residency Programs in the United States
Authors: Tyagi Anisha , Sudah Suleiman Y. , Whitelaw Kathryn , Haislup Brett D. , Joshi Tej , Sanchez-Urgelles Pablo , Sanchez-Sotelo Joaquin , Menendez Mariano E. 
Published: September 2024

Introduction:
International medical graduates (IMGs) continue to play an important role in the US health care system, but little is known about their trends of matching into highly competitive residencies such as orthopedic surgery. The purpose of this study was to analyze temporal trends of IMG applicants matching into US orthopedic residency programs between 2008 and 2024 and compare them with US allopathic (MD) and osteopathic (DO) graduates.

Methods:
Orthopedic residency specific data for years 2008 to 2024 was obtained from the National Resident Match Program and Electronic Residency Application Service. Variables collected included total number of programs, total positions offered, number of applicants (MD, DO, and IMG), positions filled, and fill rate for each group. Trends were examined using simple linear regression modeling.

Results:
The number of orthopedic residency programs increased from 160 (2008) to 218 (2024), with total positions increasing from 636 (2008) to 916 (2024). The IMG fill rate decreased from 2.99% in 2008 to 0.87% in 2024 (p < 0.01 for linear trend; β −0.069). This corresponds to an absolute number decrease of 19 IMGs in 2008 to 8 in 2024. More specifically, the proportion of US IMGs decreased from 0.94% to 0.66%, and the proportion of non-US IMGs decreased from 2.04% to 0.21%. Over the 17-year study period, a total of 105 US IMGs and 110 non-US IMGs matched into orthopedic surgery. The US MD applicant fill rate decreased significantly from 96.5% to 85.0% (p < 0.001; β −0.944). The DO applicant fill rate increased significantly from 0.31% to 13.97% (p < 0.0001; β 0.990).

Conclusion:
The declining rate of IMGs matching into orthopedic residency programs in the United States underscores the growing challenges faced by IMGs in accessing training in this competitive specialty. The notable increase in DO graduates securing orthopedic residency positions likely reflects the integration of a unified accreditation system for MD and DO residency programs established in 2020.

Level of Evidence:
Retrospective Cohort Study; IV
When Conventional ESP Meets the Unconventional Limit: Putting More Power Downhole Safely
Authors: Harris D. , Partington B. , Gamboa J. A. , Paiva L. 
Published: September 2024

Permanent magnet motors (PMM) have been around for two decades in the electrical submersible pumps (ESP) industry. PMM are shorter-lighter-higher power density in design and offer more than just energy savings with reduced carbon footprint; it is a technology enabler to achieve asset optimization and yet is underutilized. This paper discusses the early reporting on the first company organic PMM safely installed in a Permian Basin unconventional resource well to extract more reservoir production. The benefit to the reader is stronger confidence to apply this green technology in their wells safely and economically.
To achieve sustainable first use of PMM, the ESP design and safety implications required collaboration of disciplines involving teams of Instrumentation & Electrical, Production and Completion engineers, the ESP Center of Excellence, the Technical Center, Health-Safety-Environmental, and a variety of vendors over a 2-year period. Pump design and drawdown scenarios were examined while multiple safety trainings were conducted, including live demonstrations with PPE, proving the safe mitigation of hazardous voltage through proper shunting, grounding, and isolating standard operating procedures. Additionally, multiple safety devices were added (surface and subsurface) to manage the safety aspects of this technology. A final risk assessment was conducted and approved to clear the way for PMM installation.
Compared to the conventional induction motor, the PMM enabled nearly 50% more power downhole for equal fluid density, comparable production and water cut without a change in pump design. Energy savings and carbon footprint reduction is 19%. Since installation, the ESP system has reduced head pressure more than 300 psi and continues to see increased production. Standard operating procedures for PMM were executed successfully and safely without incident using the free hub second source power mitigator.
Four electrical technologies are included in this paper for safety of personnel and the asset as PMM bring the risk of electrical shock due to two sources of power: planned power from the grid and unplanned power from the well; the latter case the PMM is a generator and this risk is mitigated with the use of both completion and production tools such as the free hub. Additionally, the non-intrusive power measurement technology at the surface keeps personnel safe from arc-flash and electrical shock without the use of cumbersome CAT-2 PPE, a health risk in hot climates. A contactor switch at the surface helps to protect life and asset. Lastly, a common mode filter was run for carrier frequencies less than 4000 Hz to reduce or eliminate high frequency induced failures such as bearing fluting.
A Permian Microgrid Case Study - Keys to Successful Implementations
Authors: Martinez A. Dominguez 
Published: September 2024

Abstract
As the oil and gas industry's interest in more electrified solutions continues to grow, the demand for more complex power management systems is on the rise.
While utilizing utility power to energize a wellsite can help lower emissions, the utility's power typically isn't sufficient to meet a wellsite's high-power demands. Additionally, some applications have very aggressive loads which can conflict with utility companies' aims to keep power steady 24/7. Given these dynamics, understanding the different options available when selecting a power source for a wellsite is imperative to maximize the benefit of all available resources without impacting operations.
This paper examines key considerations for successfully erecting a microgrid system in the oilfield that includes a variety of distributed energy resources (DER) such as gensets and energy storage systems interconnected to a power grid, as well as the option of not only importing power from the grid but also exporting power if needed. Approaches to customize a microgrid to fulfill a wellsite's unique requirements will also be highlighted.
A case study of a wellsite in the Permian powered by a microgrid will be shared. This example will explain how the wellsite, which can require up to 25 megawatts (MW) of power, can successfully operate on 10 MW from the utility with 15 MW supplemented by gas-fueled gensets. It will also cover how the power management system allowed the operator to reduce the need for on-site power generation by 40% by replacing that power demand with grid power.
Autonomous Enhanced Wellbore Directional Control
Authors: Armani A. , Wibowo V. K. , Wicaksana D. A. , Maw N. , Panwar N. , Kereshanan M. , Mokhti M. A. , Zurhan S. , Murad M. A. 
Published: September 2024

Preparing the industry toward the future may prove to be the most important outcome of the application as Automation in Directional Drilling is the ability to operate a system with minimum human intervention while automating most analytical repetitive tasks. The principal approach for introducing Automation was to bring revolution in age old directional drilling practices. In this project, downhole automation was utilized with surface automation at an operating rig. The paper focuses on analyzing the results achieved, with the aim of evaluating the methodology and solution's effectiveness, performance, and its impact on drilling operations.
An AI powered downhole autonomous directional drilling system was utilized to drill all zones of well plan, autonomously with minimum interruption from surface. The downhole automation system uses a goal-based approach to handle changes suggested from surface. An automation system that is integrated into the rig control system was also deployed to control the top-drive, drawworks, mud pumps, auto-driller, and downhole tools, to autonomously execute drilling activities.
It focuses on two salient points, the first will be the downhole automation technology and second will be the automation system assisting rig in Drill a stand workflow. There were multiple parties involved in the execution and to make it work, every party must come on same platform for workflows to communicate with each other.
Automation surpassed all the targets set before starting the project. Client believed in the system as it showed how digitization can help to enhance operational efficiency while making the process safer and smoother.
Transforming Pneumatic Methane Emissions Mitigation While Leveraging IRA Energy Credit
Authors: Schaefferkoetter R. , Kukkamaa T. , Dismukes J. 
Published: September 2024

Abstract
Natural gas-driven pneumatic controllers used in onshore oil and gas operations account for approximately 43% of all production-related methane emissions in the U.S., primarily due to their deployment in remote areas without access to electric grids. These controllers, essential for process flow and overpressure prevention, have historically lacked technological advancements and commercial solutions for methane emission reduction due to their widespread and remote distribution, the absence of readily available power sources, and the critical impact on operational integrity. The EPA's NSPS OOOO(b) and OOOO(c) regulations, effective as of May 2024, impose strict standards on methane and VOC emissions from pneumatic devices and pumps. The regulations require new and modified pneumatic controllers to achieve zero emissions, with specific guidelines for existing sources, emphasizing monitoring, recordkeeping, and advanced leak detection technologies. These regulations reflect a significant shift towards mitigating the environmental impact of methane emissions from these devices.
Current technologies for emission reduction, including compressed instrument air, electrically powered pneumatic devices, vapor recovery units, and liquified nitrogen, often fall short due to high costs, efficiency losses, and reliance on environmentally harmful energy sources. Renewable energy solutions, though promising, face economic and efficiency barriers, particularly in remote locations. To address the gaps, Blue Mountain Operations developed a new generation of solar-powered instrument air compressors and pumps leveraging high-efficiency Permanent Magnet Synchronous AC (PMAC) motors and VFD controller. This system achieves high electromechanical efficiency and reliability, significantly reducing methane emissions and operational costs while ensuring robust performance in remote settings.
The Inflation Reduction Act (IRA) of 2022 enhanced the Federal Investment Tax Credit (ITC), providing substantial financial incentives for renewable energy projects. In 2023, an oil and gas operator in the Uintah Basin implemented the above-mentioned solar solutions replacing 905 methane-emitting pneumatic pumps in a USD 10.5 million project. This transition qualified for the full 30% ITC and an additional 10% bonus, generated USD 2.8 million in tax credits and demonstrated a viable path for the oil and gas industry to achieve substantial financial and environmental benefits.
Two case studies presented in the paper illustrate the deployment and performance of the PMAC compressor solutions in the Permian and Uintah Basins, demonstrating significant methane emission reductions, cost savings, and enhanced operational efficiency. These projects, supported by financial incentives such as the Federal Investment Tax Credit (ITC) and the Inflation Reduction Act, highlight the economic and environmental benefits of transitioning to sustainable technologies in the oil and gas industry.
Novel Case History: Managed Pressure Cementing Record Under HT-HP Conditions
Authors: Shine J. M. , Sowailem A. W. , Villalobos J. G. , Mousa A. A. , Adebiyi I. A. 
Published: September 2024

Abstract
The managed pressure cementing technique is new in relative terms to the past 100 years of industry cementing experience (e.g., circa 2008 with first publication). The technique is becoming more prevalent to overcome challenging well integrity requirements which should help the industry achieve zonal isolation for applications previously deemed too difficult to isolate with cement. A literature review of managed pressure cementing (e.g., MPC) success documented in the public domain shows, at the time of the manuscript preparation, the subject case history is the deepest, hottest, and heaviest application. The same literature review identifies several case histories deeper, not hotter or heavier as well as heavier not deeper or hotter. The manuscript shares the challenges faced and success factors to overcome the deployment risks helping to isolate a challenging openhole section using managed pressure cementing.
Lessons Learnt and Evolution of Liner While Drilling Technology from a Pilot Project in India
Authors: Pawandeep Singh Bagga , Srikanth Thanvi , Kjetil Holden , Sarang Pethe 
Published: September 2024

Abstract

Objectives/Scope
The Mumbai High field, India, indeed poses significant challenges for drilling and liner running operations due to the problematic heterogenous formation and unstable sub hydrostatic loss prone zones. They can contain cavities, faults, and variable rock properties, making it challenging to predict the formation's behavior accurately. The formation pressure prediction is also tough due to depleted condition.

Methods, Procedures, Process
Using "Liner While Drilling" technology as a pilot project to drill in troublesome formations was seen as a promising approach to address the unique challenges presented by such formations. Deploying this technology as a pilot project demonstrated the commitment to innovation and a proactive approach to address drilling problems by the operator. It was important to ensure that the technology was well-integrated into the drilling program and that the personnel involved were adequately trained to make the most of the real-time data and capabilities it offers. The success of the pilot project may inform future drilling strategies in the field and potentially lead to more efficient and cost-effective drilling practices.

Results, Observations, Conclusions
The liner while drilling service is a sustainable technology which combines 4.75in rotary steerable system BHA (Bottom Hole Assembly) with various logging tools, 8.75inhole opener/reamer, a mud motor, and a 7inliner with 8.5in reamer bit to help overcome the challenges while drilling in zones with low formation pressure and unstable formations. Running the liner while drilling helps maintain wellbore stability and reduces open hole exposure. It is also beneficial in reducing the time required by eliminating extra trips as the liner is installed at Target Depth in the first run. Additional runs ensure Cementing the well and then Setting of Hanger along with packer for well completion.

Novel/Additive Information
A multidisciplinary team used an intense Prejob planning process to examine all potential risks, including liner fatigue, LCM in the drilling mud, BHA Design and Stability, Drilling Dynamics etc. Numerous simulations and analyses of torque and drag, pressure, hydraulics, and maximum bending fatigue were conducted to identify the optimal equipment and Drilling Parameters. The paper discusses details of Liner while Drilling Technology and its evolution in India from Three Trip System to Two Trip System Benefitting the operator for superior and faster well Delivery. The paper also covers lessons learnt from the project and an evaluation of how Liner While Drilling Technology can help operator to deliver the complicated wells.
Haynesville Shale: 16-Year Review of Activity and Well Performance
Authors: Vera Fabian , Mire P.E. Kurt 
Published: September 2024

Abstract
Sixteen (16) years of Haynesville Shale development activity has been analyzed. Type curves (production normalized to year zero) were created to understand well performance for various areas, operators and time periods. Changes in well design and production performance trends each year were documented for the top producing counties/parishes and the top thirteen (13) well operators. Drilling activity peaked in 2011 and the current rig count of thirty-three (33) is on a down trend. This analysis shows that well performance trends have reached a maximum point and are now declining. New well reserves peaked in 2019 at 12.5 BCF per well and initial production rates peaked in 2022 at 22,600 MCFD. Current new well drilling economics were also investigated. With current well costs and gas prices, drilling investments show a robust internal rate of return of 30%, a return on investment of 1.6 to 1 and a net present value (PV10%) of over $4.2 million.
Leveraging Large Language Models for Cost Management and Supply Chain Optimization
Authors: Shahini Maryam , Wang Carina Yu , Roeder Marc A. , Pethe Sanjay , Coffman Sarah W. , Howard Preston , Hu Bo , Wasserman Hannah N. , Arnwine Joshua 
Published: September 2024

Abstract
In this paper, we introduce a cutting-edge solution to the complex challenge of managing operational costs in unconventional asset development, particularly concerning continuous well drilling, completion, and field maintenance operations within the oil and gas sector. These complicated field operations involve hundreds of service providers and incur vast volumes of invoices every year. Tremendous values are lost due to missed opportunities to improve contracting strategy, optimize material and equipment supplies, and identify cost-prohibitive design elements during drilling, completion, production, and plant maintenance through proper spend categorization.
Leveraging the power of a machine learning solution, Large Language Model (LLM), and an interactive user interface, we automate the challenging task of categorizing millions of invoices from diverse service providers. Techniques including sentence transformation embedding, transfer learning, fine-tuning, and re-training process are employed to enhance model performance and adaptability to diverse invoice types.
Through rigorous model training and iterative refinement facilitated by the user interface, our approach attains an impressive accuracy exceeding 90% across all regions. Results prove that the Large Language Model has a wide application in business optimization during unconventional asset development. This automated algorithm provides real-time insights through spending and significantly reduces the turnaround time. This study also enables direct identification of cost-saving opportunities such as potential reductions in fuel expenses related to drilling and completion activities. The advanced analytics capabilities following the modeling effort allow engineers and analysts in multiple functions to identify cost-saving opportunities through customizing visualization tools in various areas.
This paper presents original methodology to adopt the Artificial Intelligence, i.e., Large Language Model, in the oil and gas industry and demonstrate its values with case histories.
Initial Start-Up of India's First Deepwater Oil Field - Addressing Flow Assurance Challenges with Innovative Strategies
Authors: Ansari Adnan Z. , Bandaru S. , Rathod P. R , Nischal R. 
Published: September 2024

Abstract
The M-field development plan involves an FPSO located in 400 meters of water, with five subsea oil wells connected through a 10-inch dual flowline system in a daisy chain configuration tied back to the FPSO using flexible risers. This paper describes the flow assurance challenges associated with the start-up of deepwater oil field in India, as well as presenting the novel approaches utilized to overcome these to ensure the successful commencement of oil production.
Initial start-up strategy involves a phased approach to opening four wells, employing a gradual opening and well bean-up strategy over a period of 32-36 hours to achieve the desired ramped-up production rates. Transient simulations using OLGA model to predict flow behaviors in various field sections and address flow assurance challenges during the initial well start-up phase. Simulations identified a significant risk of slugging, characterized by cyclic zero-gas arrival at the FPSO. Additionally, the simulations indicated possibility of temperatures remaining below the treated pour point during the well bean-up process, which could lead to wax gelation within the network.
Transient simulations were utilized to develop a flow assurance strategy to address challenges encountered during the start-up phase. It was deemed essential that mitigating slugging would not only guarantee uninterrupted operations at the FPSO but also reduce the likelihood of wax deposition. The primary objective of flow assurance is to uphold the design flow conditions from the onset of production, thereby keeping the subsea system temperature above the Wax Appearing Temperature (WAT). As part of the standard operating procedure, the circulation of hot diesel in the dual pipeline system through the FPSO is established to pre-heat the pipelines before initiating well start-up. Nevertheless, a significant challenge that remains unresolved is the occurrence of slugging during the ramp-up phase, leading to rapid cooling in the pipeline system. To address this issue and ensure the maintenance of design flow conditions from the outset, continuous circulation of hot diesel along with topside choke optimization at FPSO during the initial start-up phase until production reaches the desired level will not only alleviate slug flow condition but also eliminate low-temperature conditions in the subsea system. This approach will consequently reduce the propensity for wax deposition and promote a seamless commencement of operations.
With implementation of this strategy, successful commencement of the oil production from the country's first deepwater field is achieved. The lessons learned during start-up operation are a combination of work-around, benchmarking of field data with predicted simulation results, and general operational experiences related to flow assurance.
Syncytia Formation Promotes Virus Resistance to Interferon and Neutralizing Antibodies
Authors: Yewdell Jon W. , Li Tiansheng , Kang Insung , Hu Zhe , Gibbs James , Ye Chengjin , Kosik Ivan , Shi Guoli , Holly Jaroslav , Kosikova Martina , Compton Alex , Sobrido-Martinez Luis , Johnson Reed , Xie Hang 
Published: September 2024

Abstract

SARS-CoV-2, like many viruses, generates syncytia. Using SARS-CoV-2 and Spike (S) expressing recombinant vesicular stomatitis and influenza A viruses, we show that S-mediated syncytia formation provides resistance to interferons in cultured cells, human small airway-derived air-liquid interface cultures and hACE2 transgenic mice. Amino acid substitutions that modulate fusogenicity in Delta- and Omicron-derived S have parallel effects on viral interferon resistance. Syncytia formation also decreases antibody virus neutralization activity in cultured cells. These findings explain the continued selection of fusogenic variants during SARS-CoV-2 evolution in humans and, more generally, the evolution of fusogenic viruses despite the adverse effects of syncytia formation on viral replication in the absence of innate or adaptive immune pressure.