bluuebunny/crossref_metadata_2025 huggingface dataset:
Pain Relief After Total Knee Arthroplasty with Intravenous and Periarticular Corticosteroid
Authors: Chan P.K. , Chan T.C.W. , Mak C.Y.H. , Chan T.H.M. , Chan S.H.W. , Wong S.S.C. , Fu H. , Cheung A. , Chan V.W.K. , Cheung M.H. , Cheung C.W. , Chiu K.Y.
Published: May 2023

Background:

Total knee arthroplasty (TKA) is a cost-effective procedure, but it is also associated with substantial postoperative pain. The present study aimed to compare pain relief and functional recovery after TKA among groups that received intravenous corticosteroids, periarticular corticosteroids, or a combination of both.

Methods:

This randomized, double-blinded clinical trial in a local institution in Hong Kong recruited 178 patients who underwent primary unilateral TKA. Six of these patients were excluded because of changes in surgical technique; 4, because of their hepatitis B status; 2, because of a history of peptic ulcer; and 2, because they declined to participate in the study. Patients were randomized 1:1:1:1 to receive placebo (P), intravenous corticosteroids (IVS), periarticular corticosteroids (PAS), or a combination of intravenous and periarticular corticosteroids (IVSPAS).

Results:

The pain scores at rest were significantly lower in the IVSPAS group than in the P group over the first 48 hours (p = 0.034) and 72 hours (p = 0.043) postoperatively. The pain scores during movement were also significantly lower in the IVS and IVSPAS groups than in the P group over the first 24, 48, and 72 hours (p ≤ 0.023 for all). The flexion range of the operatively treated knee was significantly better in the IVSPAS group than in the P group on postoperative day 3 (p = 0.027). Quadriceps power was also greater in the IVSPAS group than in the P group on postoperative days 2 (p = 0.005) and 3 (p = 0.007). Patients in the IVSPAS group were able to walk significantly further than patients in the P group in the first 3 postoperative days (p ≤ 0.003). Patients in the IVSPAS group also had a higher score on the Elderly Mobility Scale than those in the P group (p = 0.036).

Conclusions:

IVS and IVSPAS yielded similar pain relief, but IVSPAS yielded a larger number of rehabilitation parameters that were significantly better than those in the P group. This study provides new insights into pain management and postoperative rehabilitation following TKA.

Level of Evidence:

TherapeuticLevel I. See Instructions for Authors for a complete description of levels of evidence.
AOA Critical Issues Symposium: Leadership and Education During and After COVID-19
Authors: Plancher K.D. , Morrey B.F. , McMahon G.T. , Ruch D.S. , Petterson S.C.
Published: May 2023

The devastating impact of COVID-19 has reshaped how we lead and train our future surgeons in the field of orthopaedics. Overnight, leaders in our field had to dramatically shift their mindset to continue to lead a hospital, department, journal, or residency or fellowship program in the face of an unprecedented level of adversity in the history of the United States. This symposium discusses the role of physician leadership during and after a pandemic, as well as the adoption of technology for training surgeons in the field of orthopaedics.
Changes in Inflation and Exchange Rates on Investment Decisions in Sectoral Shares on the Indonesia Stock Exchange
Authors: Herlando Aldhi , Sishadiyati Sishadiyati
Published: May 2023

This research was conducted on the basis of different perceptions regarding the influence of domestic macroeconomics on stock prices. The independent variables used in this study are inflation and exchange rates, while the dependent variable used is the share price of the Indonesia Stock Exchange's Sectoral Index. This study uses monthly data from January 2018 to December 2020. The analysis technique used is multiple regression analysis. There are three findings in this research. First, inflation has a partial effect on most of the sectoral indices except for the Basic Industry Sector Index, the Financial Sector Index and the Trade Sector Index. Second, the Exchange Rate has a partial effect on most of the Sectoral Indices except for the Mining Sector Index and the Trade Sector Index. Third, inflation is the most dominant variable affecting the eight sectoral indices, while the rest is dominated by exchange rates.
The Effect of Quality of Human Resources on Economic Growth in Malang Regency
Authors: Rismawati Rismawati
Published: May 2023

Performance as one of the main points in the economic development of a country, this is also known as growth. The expected economic growth must of course be of quality, where there is a growth that occurs and has a sensitivity to unemployment and existing poverty. This study aims to determine the influence of the Quality of Human Resources in Economic Growth in Malang Regency. This study uses secondary data analysis which aims to provide an explanation of the role of the quality of human resources on economic growth in Malang district in the 2011 to 2020 fiscal year. The secondary data consists of (1) economic growth seen from constant price GRDP, (2) population in productive age, (3) the proportion of the population aged 10 years who have a high school education and, (4) Life Rate and Expectations at birth. The data is processed using Multiple Linear Regression. The results in the study show that (1) the proportion of the population of productive age has a positive and insignificant effect on economic growth, (2) high school education and above has a positive and significant effect on economic growth, (3) health life expectancy has no significant effect on economic growth. The quality of human resources as measured by using three variables as independent variables has a significant effect on economic growth. The influence of these three variables is very significant both in their position as individual variables (independently) or jointly or simultaneously has a significant effect on economic growth.
Analysis of Economic Inequality In Banyuwangi Regency
Authors: Puspita Yeni , Wicaksono Galih , Wahyudi Edy
Published: May 2023

Banyuwangi Regency is one of the regencies in East Java that has a higher economic growth rate than East Java's economic growth. Likewise, the poverty rate in Banyuwangi in 2019 was 7.52 percent, this figure is much lower than the East Java Province average of 10.2 percent (Central Statistics Agency, 2019). Poverty in Banyuwangi Regency is contributed by several sub-districts, namely Kalibaru, Licin, Songgon, and Glenmore, where the percentage of poverty is above 10%, while other sub-districts such as Giri, Tegaldimo, and Sempu the percentage of the number of poor people is below 6%. This indicates the occurrence of economic inequality, where there are vertical and horizontal differences that cause disparities or uneven development. This study aims to see how the economic inequality in Banyuwangi Regency. The method used in this research is descriptive qualitative. The object of this research is all sub-districts in Banyuwangi Regency. The data is obtained by distributing questionnaires and conducting interviews with the Office which is directly related to indicators of economic inequality. The results of the study found that there were several sub-districts that still lacked the availability of health facilities and educational facilities, the Stunting Rate was still high in some sub-districts, the distribution of UMKM in the Banyuwangi district was evenly distributed, and there were several sub-districts whose UMKM had not yet developed, the number of unemployed was still scattered in several districts, The provision of social assistance still has the problem of mistargeting so that the achievement of the goal of social assistance is not achieved.
Digital Implementation and Data Analytic for OCTG Running as Tool to Control Non-Expected Operational Cost and Enhance Efficiency in Drilling Operations for Operator Company in Abu Dhabi
Authors: Amorocho A. , Elkasrawi A. , Abdelazim A. , AlRashdi A. , Shamlam A. Bin , Nuaimi M. Al , Nunez Y. , Blanpied C. , Cavanha T. , Blues S.
Published: May 2023

Responding to requirements of Operator Company in Abu Dhabi to automate and strengthen processes of running casing and tubing, a patented digital solution has been implemented, which timestamps all key phases of the tubulars’ lifecycle from rig receipt to running then to rig return, while enabling continuous improvement through post-running data analytics.

The solution relies on unique individual pipe traceability, through a combination of different methods of marking such as – data matrix, RFID & barcodes. These markings are read using a variety of digital tools including – smartphones, tablets & cameras.

The solution has already been deployed in North & South America, Europe, and Asia, totaling over 100 successful jobs worldwide. Operator Company in Abu Dhabi was the first operator in the Middle East to try the solution in 2022.

The below section summarizes the solution results based on the feedback from the first three wells piloted by Abu Dhabi Oil Company. The value chain is broken down into three key categories as follows:

– Pre-running: the solution brought an increased level of quality control paired with an automatically generated pre-tally list. Further to this, an increase in personnel is safety assisted by a reduction in tubular handling and removal of personnel from high-risk positions. – During running: the accuracy of the running sequence was ensured by the utilization of the solution ‘‘Watchdog Alerts’. These highlighted to the user any deviation from the original plan, preventing error and minimizing any downtime generated. All of this was made available in real-time in a cloud environment to anyone within the Operator Company with credentials for accessing the system. – Post-running: monitor and compare rig performances through digitally enabled data analytics

In conclusion, significant cost reduction (from 15 to 45 k$ per job for a 70k$ rig day rate), mitigating risks of non-productive time by reducing human errors (from 5 to 15 hours per job), ensuring safety and integrity of the well and enabling operators to track its assets and monitor running operations in real-time.
Sustainable Chemicals Development for Drilling Fluid Application
Authors: Ramasamy J. , Al-Arfaj M. K.
Published: May 2023

In oil and gas drilling industry, drilling fluid plays a vital role and is being circulated through out the drilling operation from spudding to completion. Drilling fluid provides hydrostatic stability to wellbore. It is also used to cool down the downhole tools. In addition to the above mentioned functions, drilling fluid is responsible to carry cuttings to surface, provide lubricity and stabilize shale formation. There are variety of chemicals added to drilling fluid to provide properties viscosity, density, emulsion stability, lubricity and fluid loss control. Developing environmentally friendly additives. Development of drilling fluid chemicals that are sustainable and benign to environment to provide the aforementioned properties is a significant step towards achieving sustainability and reducing carbon footprint besides suitability for drilling across aquifers and offshore environments. We have studied the applicability of used cooking oil to obtain fatty acid and their derivatives and evaluated its performance as emulsifiers and lubricants for drilling fluid applications.
A Holistic Approach to Achieve Zonal Isolation Improvements Across 8 1 2 Inch Hole On the in an Offshore Field
Authors: Hassan Azza El , Abdelatif Mohamed Samir , Hamidzada Ahmedagha , Andrews Kerron , Toki Takahiro
Published: May 2023

In an Offshore field, off the coast of Abu Dhabi, well integrity objectives are becoming more difficult to achieve as open hole sections become deeper, laterally longer and more highly deviated. In this mature field, one of the main challenges of well construction is successfully cementing long production-casing strings covering multiple reservoirs across the 8½-in sections. This paper describes some of the techniques and best practices that were applied on these wells to achieve the required zonal isolation.

Achieving zonal isolation across multiple reservoirs through a single or multi-lateral configuration is a major challenge in this field. The reservoir formation is porous and requires a special gas tight design or impermeable cement system. Inadequate hole cleaning due to poor standoff attributed to complex well design is another main limitation, resulting in insufficient mud removal leading to an uneven cement distribution around the casing. Additionally multiple pressure-testing cycles are required post cement-setting and during the completion phase, a practice that can destabilize the cement system causing it to fail. Moreover, controlling loss circulation while running or after landing casing is another challenge in this field.

To overcome these challenges a series of customized improvements were applied subsequently through continuous improvement and implementing lessons learnt from previous operations. The elements of this approach included introducing higher density cement systems to cover the horizontal sections, while retaining the ECD within the required margins. Another element utilized was that of two cement slurries; Lead and tail, which were designed to achieve controlled ECD. An additional element which was also implemented addressed enhancing the flexible expandable gas tight slurry by adding Latex to achieve a fit for purpose solution. The last element of this strategy included improving hole cleaning and mud removal efficiency by optimizing spacer design and volumes in addition to the loss circulation additives in the spacer systems.

Throughout the operation, the cement jobs were executed successfully with no losses. Cement jobs were evaluated through running job design simulation Vs execution parameters comparison. The approach resulted in substantial improvement on log responses. Additionally, after implementing the approach, logs were compared to offset wells from the same field to track the improvement done.

The paper reviews enhanced practices implemented to overcome challenges faced during well cementing. Being able to find a solution to this complex problem, delivering a comprehensive cement quality, and improving cementing integrity on these wells resulted in expanding this approach to the rest of the fields. The improvement measures that were developed are now being adopted across all jobs to yield a similar outcome.
Three-Dimensional Positional Uncertainty Based on Along-Hole Depth, Inclination and Azimuth Accuracies
Authors: Bolt Harald , Harbidge Philip
Published: May 2023

Along-hole Depth (AHD) is the most fundamental subsurface wellbore measurement made. Well depth is the main descriptor of wellbore position, measured from zero depth point (ZDP). This is translated into vertical depth (V) using inclination (I). V is the main descriptor subsurface wellbore events and then North (N) and East (E) act as the Qualifying descriptions of V.

Well depth is commonly described as measured depth (MD) and is used to describe well construction, navigation and collision avoidance, drilled geologies, reservoir properties, fluid gradients and interfaces, production, and subsurface positioning of well services. AHD is a calibrated and corrected well depth measurement defined using a specific rig-state and can deliver improved subsurface position and positional uncertainty.

Well depth, I and azimuth (A) are used to calculate subsurface 3D position. Well depth is measured at surface, represented by drillpipe or wireline length. I and A are subsurface measurements referenced to the provided well depth. These together provide the navigation information required to arrive at the 3D positions of N, E, and V. These positions are used to define the location of subsurface events such as well placement, geological horizons and fluid contacts.

This paper outlines a method ("3D method") for defining 3D subsurface positional locations using "way-points" (Bolt 2021). Way-points represent a sequential series of specific, calibrated, 3D positional locations each defined by calibrated and corrected AHD. Based on Pythagorean geometry using AHD, I, and A measurements, these are converted into N, E, and V positions. Each way-point has a specific N, E, and V positional uncertainty.

Four component accuracies are used to describe the individual AHD, I and A measurement uncertainties at each way-point: calibration and observation, applied correction, model-fit, and a fixed-term applicable to all observations. AHD, I, and A measurement uncertainties which are converted into individual interval N, E, and V positional uncertainties and sequentially concatenated.

The method provides a simplified yet accurate solution to 3D positional and positional uncertainty. The calculations demonstrate the dependency of the positional and positional uncertainty results on both interval spacing between way-points and measurement accuracy. The example results demonstrate that each well has its own specific and unique N, E and V positional uncertainty description. Specific positional uncertainty requirements of operators can be answered to through instrumentation accuracies and way-point interval spacing defined in the well survey program. Well placement can be more easily portrayed, reservoir characteristics more confidently reported, and asset volume estimation improved.
Multiphase Fluid Erosion Modeling for Rapid Development of Shunt Tube Isolation Valve for Openhole Gravel Pack
Authors: Omer Farhan , Rudic Aleksandar , Song Lijun , Gupta Susheel Kumar , Kamath Raghuram
Published: May 2023

This paper presents the effective use of computational fluid dynamics (CFD)-based erosion modeling to optimize the development of gravel-pack completion equipment, in this case a shunt tube isolation valve (STIV), which enables total zonal isolation following gravel-packing operations. A novel erosion- and debris-resistant approach to the design of the STIV was developed. The product development methodology incorporated the use of an iterative CFD erosion model to quantify the erosion rates on a proposed novel STIV flow conduit for gravel packing. The erosion model simulated a typical gravel-pack treatment using a multiphase fluid model of carrier fluid (8.5-ppg density) with 100,000 lbm of 30/50 proppant at 5 ppa pumped at 10 bbl/min. Multiple iterations of the flow conduit were designed and analyzed to minimize the pressure drop, the flow velocity, the erosion rate, and recirculation. This design methodology enabled a successful qualification using a full-scale erosion test, followed by successful closing and pressure tests. Expensive retesting was eliminated; post-test correlations demonstrated that the CFD model accurately predicted areas of high erosion, and the quantity of material loss was within practical limits. The development approach and modeling method provide a reliable tool for the development of new gravel-pack completion equipment and comparable products, saving time and avoiding expensive delays, failure investigations, and retesting costs.
Effect of Hydrogen on Mechanical Properties of Completion Pipeline API Steels
Authors: Perozo N. , Amirhosseini S. Fazel , Tavakoli M. , Holzmann J. , Neubert V. , Jaeger P.
Published: May 2023

The main objective of the presented work is to evaluate the effect of hydrogen service conditions on the mechanical properties of API steel grades used for well completions. The evaluation methodology implies a preconditioning of the steel specimens to long-term exposures under high-pressure hydrogen atmospheres and compare the results of subsequent mechanical tests with those of steels not being exposed to this gas. The aim of this research is to compare the performance of different API grades when subjected to hydrogen service. The outcomings of the study will help to evaluate long-term integrity of completion systems and materials compatibility for hydrogen storage applications. Mechanical tests like notched-tensile tests, hardness determination and impact tests were performed, in order to detect the embrittlement of the metals by comparing results between specimens not previously charged with hydrogen and specimens being subjected to a hydrogen atmosphere under high-pressure. The notch tensile specimens were pre-stressed to 80% of the nominal yield strength, in order to force and assure the hydrogen diffusion into the notch area where localized increased tensile stresses are concentrated. Furthermore, by means of carrier gas hot extraction analysis the hydrogen content in the samples was measured, to give an indication of the absorption capacity of these grades under the stated conditions. The API grades L80, P110 and Q125 have been selected to represent a wide and popular selection of ductility and yield strength. All samples were subjected to a series of mechanical tests to determine the presence of hydrogen embrittlement. The results show different behavior of the materials after being exposed to a hydrogen atmosphere, from the noticeable decrease to even a "no effect" on the mechanical properties. The results of notch tensile tests of the steels L80 and Q125 are showing some level of hydrogen embrittlement, compared to P110, being the one least affected by the presence of this gas. The measurement of hydrogen content in the samples delivers similar results for all the grades. Microscopic analysis shows the structure of the crystal lattice of the steels studied, helping to understand, together with the state of stress, how sensitive the material is to be affected by hydrogen embrittlement. There is no literature that describes the hydrogen effect on the mechanical properties of API steels used for tubings and casings in well completions, nor their sensitivity to hydrogen embrittlement. The results of this research are of great importance to give an idea of the compatibility of the steels that can be used for high-pressure hydrogen operations, such as hydrogen underground storage as well as to evaluate the potential recompletion or use of existing wells.
Curing Hydrodynamic Instability During Balanced Plug Cementing
Authors: Harestad K. , Karimfazli I. , Ghazal A. , Harestad M. , Saasen A.
Published: May 2023

It is shown how the flow from pumping cement through an open-ended pipe very quickly turns direction and the cement flows upwards. This rapid change in flow direction indicates that a diverter tool, which leads the cement slurry perpendicular out of a closed ended pipe does not have any function. The placement of a balanced plug is feasible. However, a high-density fluid above a lighter fluid is not stable. The phenomenon is known as Rayleigh-Taylor instability. In principle, to be reasonably stable, the interface must be horizontal. The longer the interface is, the more unstable is this case. Thus, it is difficult, or sometimes impossible, to create a stable situation in a deviated well section; especially if the well section diameter is large. Observations show that it is possible to modify density differences, thickening time and viscosity differences such that the success rate can be between 40 and 60%. Using a floatable cement foundation tool, this success rate will increase to more than 95% as shown by North Sea success values. The use of such a tool is described and its performance is justified by numerical analysis of cement flow.
Curing Hydrodynamic Instability During Balanced Plug Cementing
Authors: Harestad K. , Karimfazli I. , Ghazal A. , Harestad M. , Saasen A.
Published: May 2023

It is shown how the flow from pumping cement through an open-ended pipe very quickly changes direction and the cement flows upward. This rapid change in flow direction indicates that a diverter tool, which leads the cement slurry perpendicularly out of a closed-ended pipe, does not have any function. The placement of a balanced plug is feasible. However, a high-density fluid above a lighter fluid is not stable. The phenomenon is known as Rayleigh-Taylor instability. In principle, to be reasonably stable, the interface must be horizontal. The longer the interface is, the more unstable is this case. Thus, it is difficult, or sometimes impossible, to create a stable situation in a deviated well section, especially if the well section diameter is large. Observations show that it is possible to modify density differences, thickening time, and viscosity differences such that the success rate can be between 40% and 60%. Using a floatable cement foundation tool, this success rate increased to more than 95% in North Sea applications. The use of such a tool is described, and its performance is justified by a numerical analysis of cement flow.
A New Method of Kick Evaluation Based on Energy Analysis
Authors: Ye Yuguang , Fan Honghai , Liu Yuhan , Tao Zhenyu , Diao Haoyu , Zhou Fei
Published: May 2023

With the gradual progress of drilling to the deep layer, the formation conditions become more and more complex. The safe density window of drilling fluid is narrow, and well kick and overflow occur frequently. Aiming at this problem, this paper proposes an overflow evaluation index - overflow formation energy. From the perspective of energy analysis, overflow is regarded as the process of formation fluid doing work on the wellbore, and the power of overflow work can reflect the strength of overflow, so this power is defined as the overflow formation energy. Based on the model established in this paper, the effects of different types of overflow fluid, invasion rate of overflow fluid, drilling fluid density and formation pressure coefficient on overflow formation energy are analyzed. The overflow formation energy of gas is the highest. As the invasion rate of overflow fluid increases, the energy of overflow formation gradually increases. The data of 7 overflow wells are analyzed, and the corresponding overflow formation energy is calculated. It is found that the throttling circulating well killing method is more appropriate when the overflow formation energy is small. The overflow formation energy can quickly evaluate the overflow situation, provide theoretical basis for well control operation, and reduce the probability of well control operation risk.
Rising to the Challenge of Drilling Through Depleted Reservoirs
Authors: Pedersen Roar , Zapata Bermudez Fernando
Published: May 2023

To overcome the challenges of drilling depleted reservoirs, a new technology was needed as part of a cost-effective solution. An innovation campaign was facilitated by a major oil company R&T (research and technology) department in the North Sea to identify concepts enabling high depletion in drilling through reservoirs. Several concepts were evaluated, and a packer in the drillstring was defined as a necessity by the major oil company. Drilling through depleted reservoirs has become more and more common in operations run by both oil operators and drilling companies, in fields that have matured. Drilling these wells introduces an increased risk for crossflow and losses and a series of mitigating actions have been put in place to obtain an acceptable risk level.

This paper will focus on describing the steps taken to develop a packer that provides a seal between the drillpipe and the production casing, being part of the drilling BHA and spaced out to stay inside the casing. It's large bore through allows high flow rates and deployment of intervention tools through it. By setting the packer, it becomes a qualified V3-barrier, validated as per ISO14310 and/or API11D1, enabling the operator to cement and sidetrack efficiently, saving additional trips and rig time. This successful technology cooperation will help oil operators and drilling companies to expand its capabilities for drilling depleted and complex reservoirs and further increase the overall recovery factor for its mature fields.

Rising to the challenge, means to improve the confidence in drilling with limited drilling window and avoid uncontrolled risks by using a Drillstring Annulus Sealing Packer that when set, provides a seal between the drillpipe and the casing, the packer activation is meant to be the last option in a series of mitigating measures as the wellbore will be abandoned if activated.
Pipe Feeder Robot for Land Drilling Rigs
Authors: Mikalsen Kenneth , Raunholt Lars , Tawfik George
Published: May 2023

The objective of this paper is to present a new and innovative fully automated tubular handling robot that can feed drill pipe and casing from pipe storage on ground to the well center of a land drilling rig in a fast, accurate and all-in-one operation.

In recent years, experience has been gained with large electric robots for pipe handling both offshore and onshore. As reliability is confirmed, the robotic operations on rigs are expanded. The most recent development is a Pipe Feeder Robot for handling of pipe and subs all the way from pipe storage on the ground to the well center of the land rig, including spinning into the stick-up. The technology is based on qualified heavy-duty electric robots for pipe handling, but the new machine is configured in a way so that it can be transported from rig to rig without large interfacing work.

The industry has great expectations with the introduction of robotics for red zone management and eliminating manual operations and human exposure to heavy machinery. Expected value would be a substantial saving in rig days due to fast, precise and consistent operations and removal of people out of harm's way. In addition to improved safety, reduced OPEX, less downtime and faster installation, the Pipe Feeder Robot lowers the noise and the carbon footprint due to higher energy efficiency and less GHG emissions. Also, the precise motion control of the robot enables digitalization of the drilling process.

The paper will present performance data and results from test operations. The Pipe Feeder Robot picks up pipe (or casing), rotates from horizontal to vertical, and spins into the stick up in one operation, whereby hazardous handovers are avoided and a hands-free handling operation is created, replacing the work of four conventional operations. Reliability of robots in hostile environment will be analyzed with regards to field experience of similar technology from land rig drilling operations. Finally, the value to the users will be substantiated.

The paper will provide test results and experience from the tests of a heavy-duty all-electric Pipe Feeder Robot. It will provide valuable input for decisions for the future use of industrialized robots in the oil and gas upstream industry.
Field Deployment of a Real-Time Bit Pull Advisory System
Authors: Yi M. , Ashok P. , Ramos D. , Pearce J. , Hickin G. , Peroyea T. , White S. , Thetford T. , Behounek M.
Published: May 2023

During well construction, it is important to know when a bit is damaged to the point where it must be tripped out and replaced with a new bit. Continuing to drill with a damaged bit or pulling out a bit prematurely are both bad decisions leading to increased drilling costs. A bit pull advisory system was therefore developed and deployed in the field to help the rig crew make better informed bit pull decisions.

A bit degradation metric was first developed to estimate the wear on the drill bit as it is drilling. This bit degradation metric utilized a physics-based model to be generalizable both for vertical as well as horizontal wells. Next this metric along with other trends in data were combined using a Bayesian network to arrive at a bit effectiveness belief. This was then further combined with calculations of the time to trip out a damaged bit and replace it with a new bit, to arrive at bit pull beliefs for various scenarios of expected future ROP and distance to total depth (TD).

The bit degradation metric was first applied offline on 80 historical wells that consisted of wells drilled in Egypt, North Sea and the US land, and verified to a high degree of accuracy. It was then integrated into a drilling data aggregator and deployed in the field. The physics-based model utilized in the calculation of the bit degradation metric required contextual data, which was automatically routed to the data aggregator from various data sources. The bit pull beliefs for a range of expected ROPs and distance to TD were made available both as channels that can be visualized in vertical charts as well as a heat map. When a bit pull belief suggested a trip out, the driller was first asked to monitor for drilling dysfunctions such as stick slip, bit balling, whirl, etc., and attempt to correct it. Failing that, the bit was to be pulled out. This system is now operational on rigs in Egypt, North Sea and the US, and the response from the field personnel has been positive to date.

This is the first drill bit damage tracking advisory that has been deployed on a rig site data aggregator. Using the bit degradation metric and the bit pull beliefs, the rig site team is always able to determine the extent of damage to the bit and whether the bit must be pulled out or not. The system thus helps in reducing ILT and NPT costs by reducing the time drilled with damaged bits and eliminating premature trips out.
Real Time Well Engineering: String (Drillstring/ Casing/Completion) Runnability Monitor While Drilling
Authors: Samuel Robello , Kumar Kiran
Published: May 2023

The objective of this study is to monitor and forecast how well the casing string can be run during the drilling of the well's particular hole section. The runnability of the casing is measured by the use of a comprehensive index supported by real-time monitoring of multiple features with estimated indicators. The methodology developed by combining geometrical and mechanical calculations provides an assessment of whether the casing can be run without a short landing. This provides more opportunities for adjustments that can be made during drilling itself. In general, the "smoothness" that connects the wellbore geometry and mechanical system is related to the borehole quality utilized to run the casing. With real-time drilling parameters and complex equations represented with common sense, it is possible to assess the runnability of the casing for a given hole size. When taken together, wellbore tortuosity, borehole torsion, wellprofile energy, well curvature passage through force, margin of slack off force and overpull margin support the evaluation of a proposed wellpath to determine the casing's runnability. Combining operational experience and trajectory metrics in a methodology has proven to be effective in assessing operational risk for tasks like running casing in curve construction sections or to total depth on prolonged laterals. In addition, this paper discusses how the runnability metrics can help to anticipate or diagnose other challenges such as complex stimulation work, artificial lift performance and possible well servicing complications that may arise because of unwanted curvature, borehole torsion and wellbore drift. Presently there is no method to predict the runnability of casing to bottom while the well is being drilled. A new and practical method of quantifying the runnability of casing during drilling has been analyzed and proposed in this paper.
Successful Sidetrack in Challenging Formation Resulted in CAPEX Reduction
Authors: Al-Raml Haidar , Ufondu Kenechukwu , Widjaja Danang , Almasri Abdulrakeeb
Published: May 2023

This paper discusses the added value of a new approach to exiting an existing wellbore, where the normal practice forces the plug and abandonment (P&A) of the existing lateral before cutting the window into a new lateral, particularly when an off-bottom cemented (OBC) liner is required. The new approach includes the construction of a Technology Advancement of Multilaterals Level 4 (TAML 4) junction to maintain well integrity and the successful development of a re-entry window that allows access to both the existing and the new slim wells. Not only has this technique unlocked massive potential, but it has also led to an enhancement in the utility and reduction in capital expenditure (CAPEX).

The successful Level 4 sidetrack and re-entry window deployment is directly related to the robust system design. The application developed includes an anchor with a guide and high-torque capability, a TAML Level 4 junction created in a shape that will lead to smooth, repeatable access in the future, and a customized re-entry window system to further maximize the well potential. The true value is in allowing access to both the existing and the newly drilled lateral without using a rig or decompleting the well. Such operations use tubing exit whipstock (TEW) and pressure isolation sleeves, both of which can be run and retrieved in a rigless manner. The rigless access has allowed the existing lateral to be used as an observation well. Using permanent downhole gauges (PDHGs) enables real-time monitoring of the pressure and temperature and periodic logging to evaluate the reservoir. The newly drilled lateral can be the primary producing lateral; rigless access equally helps recover the well in case of any production challenges.

The newly designed multilateral is a game changer for both mature and new developments because it maximizes reservoir production and helps reduce CAPEX by requiring fewer wells to be drilled. The improved well integrity minimizes well workover operations, which creates cost savings.

This paper discusses the following aspects:A successful Level 4 junction construction from a slim re-entry existing/mature well.Repeatable accessibility to the lateral and motherbore.Meeting the motherbore objective as required.Delivering an OBC lateral liner and maintaining the well integrity.
Leveraging Flexible Digital Approach to Enhance Wellbore Survey Data Management and Collision Avoidance in Offshore Fields, Abu Dhabi
Authors: Ness K. , Kolakkodan S. , Toader L. , Zamin S. A. , Mahmoud K. Z. , Rabis P. J. M. G. , Al Ameri S. M. , Al Marzooqi A. A.
Published: May 2023

This paper aim to identify potential for improving the process of gathering trajectory directional survey data, recalculating of current wellbore position based on new information by automating the process, performing collision avoidance analysis scanning and providing feedback by using machine recognition of risk while minimizing human interaction with the dataset.

The envisioned result was seen as a system where wellbore survey data would flow seamlessly from acquisition at rig site into company directional survey calculation system, where programming would use the dataset to update the definitive survey listing, update forward planned surveys, run collision avoidance scan on updated planned surveys against identified offset wellbores and verify current position in relation to plan and possible deviation to same based on company policies for survey and collision avoidance and produce output for end user(s).

The project outcome was a software that acts as an intermediate between field data set repository and company directional survey software package. When data set becomes available in repository, a 30-second interval repeating query recognizes the change and updated directional survey data is moved to correct wellbore, used in defining trajectory and original plan is modified allowing collision avoidance verification to run based on new wellbore survey information. The project outcome also included machine review of the collision avoidance results based on programmed company policy values, which added to the process. The project saw substantial time delay during creation due to issues identified in the challenges part below but is now running full time for company covering all offshore rigs and associated wellbore surveying activities.

Learnings during the execution of the project showed both short comings of current systems, inconsistent API (Application Programming Interface) support for legacy software, and several opportunities for further improvements to the originally identified goal and potential for creating an advisory system based on current policies, further reducing the sometimes-arbitrary decision making which can result from large variation in experience levels related to understanding risk associated with directional surveying and directional drilling.
Green Dry Powder Friction Reducers Improve Environmental Aspects and Reduce Hydraulic Fracturing Costs
Authors: Imqam Abdulmohsin , Liu Echo , Shi Haitao , Andrianov Alexey , Belhaj Hadi
Published: May 2023

The dry powder delivery operations of polyacrylamide (PAM) polymers have recently received great attention due to their hydraulic fracturing efficiency operations and low health, safety, and environmental (HSE) risks. This paper aims to evaluate the performance of a Green Dry Friction Reducer (GDFR) in high salinity-produced water. It also describes GDFR delivery processes and the field operations advantages over the liquid versions of FRs. Five dosages at 0.25, 0.4, 1, 2, and 4 gpt of GDFR were investigated at surface and reservoir temperature (152 °F) conditions. Premier Corex lab flow loop with a tubing size of 0.5 inch was used to determine the friction reduction performance. A rheometer was used to determine the viscosity profiles of GDFR and its compatibility with formation-produced water and reservoir crude oil. Proppant settling studies using ceramic 40/70 mesh sizes were also conducted using different dosages of GDFR. The performance of GDFR was compared with three commercial FRs. GDFR shows fast hydration and superior friction reduction in tested brine conditions even at very low dosages of 0.25 gpt. A stable friction reduction rate was observed at 80% across 11 minutes of testing. Superior viscosity and high thermal stability performance were observed with a slight drop in viscosity profile at high reservoir temperature conditions. GDFR suspended the proppant for very long periods of time, in low salinity water GDFR can keep the proppant fully suspended in the solution without deposition for a couple of hours. GDFR was shown better rheological and proppant transport performance than all the three tested commercial FRs. UltraX Dry on the Fly System Unit enables using the GDFR on the field. With the increasing demand for re-cycled and flow-back water use in fracturing fluid systems, GDFR has shown unique advantages in these harsh brine salinity environments. The development of GDFR will lead to several unique advantages including cost savings, improved HSE, and better fracturing treatment performance.
A Novel Conveyance Technology, Allied with an Analytical Approach, Unlocks Significant Reserves
Authors: Mokhtar M. Khaidir B. M. , Leong C. H. , Intang E. D. , Chii Seen H. , Ho Y. Y. , Angelis Y. , Mitchell D. , Carroll V. R. , Carroll B.
Published: May 2023

Intervening in wells with challenging geometry is costly, often to the point that marginal producing wells may be prematurely shut-in. This paper details a novel, cost-effective approach taken when planning to intervene in a highly challenging well with the objective of bringing it back on-line after an extended shut-in period.

The methods used for conveying intervention tool string into oil and gas wells have developed significantly during the last forty years. As well geometry became ever-more-complex due to the adoption of directional drilling, it became apparent there very few options available in a toolbox to ensure delivery of intervention tool string to Target Depth (TD) in a cost-effective manner.

In response to this emerging challenge, a host of well service techniques and technologies have been introduced. One methodology that has delivered a real step-change, in terms of reducing well intervention expenditure and risk, has been the use of gravity-deploy mechanical roller systems. This lighter well intervention technique is now widely adopted by Industry and proven to reduce the use of more costly solutions such as wireline tractor and coiled tubing for pure conveyance reasons.

The paper details the impact of selecting a ‘next-generation’ gravity-deployed mechanical roller technology to undertake a remedial sand control well-intervention programme in a particularly challenging, highly deviated, dual oil producing well using slickline. The well had been shut-in for two-and-a half years with recent attempts to intervene using conventional roller tools proving unsuccessful.

The paper will inform the reader of technology selection based on the ability of a highly efficient rolling system to convey toolstring to target dept, containing no fastners, therefore reducing overall risk to asset. Other critical factors included pre-job conveyance modelling, tool string design and a highly-successful collaboration between well owner, service company and technology provider through their regional partner.

As well as significant challenges that were overcome to convey tool string to the high-deviation target, critical impact force was also delivered when in-situ, to ensure successful setting of sand screen assembly. Key to success was a willingness to rapidly adjust the well intervention plan by adopting industry best practice through lessons learned on a run-by-run basis. This resulted in successful setting of thru’ tubing sand screens in a cost-effective manner, ensuring that a valuable well was brought back on to production once again, delivering significant addition to recoverable field reserves.

The success of this intervention programme has led to wider adoption of next-generation conveyance technology using slickline methodology, before considering the use of wireline tractor or coiled tubing to undertake the same programme of work.
A Randomized Clinical Trial Comparing N-acetylcysteine and Bromhexine in Outpatients with COVID-19
Authors: Ghayour Anahita Eslami , Nazari Sasan , Keramat Fariba , Shahbazi Fatemeh , Ghayour Arash Eslami
Published: May 2023

This study aimed to compare the effects of N-acetylcysteine and Bromhexine on the recovery rate and prevention of hospitalization in outpatients with COVID-19. PCR-confirmed COVID-19 patients were divided into three groups: N-acetylcysteine group, Bromhexine group, and control group. Patients were followed up on the seventh and fourteenth days of the disease, and hospitalization and mortality rates were evaluated after one month. The study found that both N-acetylcysteine and Bromhexine can effectively reduce hospitalization rates and mortality and shorten the duration of hospitalization. The third visit of patients who received N-acetylcysteine showed an increase of 1.33% in oxygen saturation compared to their first visit, and in patients who received Bromhexine, this increase was 1.19%. The mortality rate was 9.33% in the control group and zero in both groups of patients who received medication. This study provides evidence for the early initiation of N-acetylcysteine and Bromhexine in outpatients with COVID-19. Clinical trial code: IRCT20220302054167N1, ethics code: IR.UMSHA.REC.1400.957.
Keloid pathogenesis and fibroproliferative properties are dependent on stem cells regulated by the HEDGEHOG-GLI1 pathway
Authors: Tosa Mamiko , Abe Yoshinori , Egawa Seiko , Hatakeyama Tomoka , Iwaguro Chihiro , Mitsugi Ryotaro , Morishita Ayaka , Sano Takumi , Ogawa Rei , Tanaka Nobuyuki
Published: May 2023

Keloids are benign fibroproliferative skin tumors caused by aberrant wound healing that can negatively impact patient quality of life. The lack of animal models has limited research on pathogenesis or developing effective treatments, and the etiology of keloids remains unknown. Here, we found that the characteristics of stem cells from keloid lesions and the surrounding dermis differ from those of normal skin. Furthermore, the HEDGEHOG (HH) signal and its downstream transcription factor GLI1 were upregulated in keloid patient–derived stem cells. Inhibition of the HH-GLI1 pathway reduced the expression of genes involved in keloids and fibrosis-inducing cytokines, including osteopontin. Moreover, the HH signal inhibitor vismodegib reduced keloid reconstituted tumor size and keloid-related gene expression in nude mice and the collagen bundle and expression of cytokines characteristic for keloids in ex vivo culture of keloid tissues. These results implicate the HH-GLI1 pathway in keloid pathogenesis and suggest therapeutic targets of keloids.