bluuebunny/crossref_metadata_2025 huggingface dataset:
Does the Universe Have Its Own Mass?
Authors: Gorobey Natalia , Lukyanenko Alexander , Goltsev Alexander V
Published: May 2023

Within the framework of the previously proposed formulation of the quantum theory of gravity in terms of world histories, it was suggested that the universe has its own mass. This quantity is analogous to the mass of a particle in relativistic mechanics. The mass of the universe is a distribution of non-zero values of gravitational constraints, which arises and changes in time as a consequence of the initial conditions for fundamental dynamic variables. A formulation of the Euclidean quantum theory of gravity is also proposed to determine the initial state, which can be the source of the universe’s own mass. Being unrelated to ordinary matter, the distribution of its own mass affects the geometry of space and forms a dedicated frame of reference. The existence of selected reference systems is taken into account by the corresponding modification of the system of quantum gravitational constraints. A variant of such a modification of the Wheeler-De Witt equation is the operator representation of gravitational constraints, which, together with the state of the universe, determines the parameters of the reference system in the form of a distribution of the spinor field on a spatial section.
A digitális bennszülöttek nyomában. Bemutatkozik az ELTE Alfa Generáció Labor
Authors: Liszkai-Peres Krisztina , Konok Veronika
Published: May 2023

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Beszámoló a Nagy J. Béla helyesírási verseny Kárpát-medencei döntőjéről
Authors: Márku Anita
Published: May 2023

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Determinants of the Human Development Index (HDI) in Indonesia, 2014 - 2021
Authors: Tyas Dwi Palupi Panglipuring , Sukartini Ni Made
Published: May 2023

Human development is a process of community change in improving the welfare andprosperity of their lives which includes aspects of health, education, economic andsocial aspects. This study aims to analyze the effect of protein intake, early marriage,health and educational facilities, unemployment, and MSMEs on HDI in Indonesia.The OLS and FEM model are used to estimate Indonesia’s 34 provinces panel dataset from 2014 in 2021. The study results show the life expectancy was affected byprotein consumption, number of hospitals, and health centers. The average length ofschooling is affected by the number of elementary, high school, and vocational schools and is influenced by the number of elementary and vocational school teachers. Gross Domestic Regional Product (GRDP) per capita is affected by unemployment rate and MSMEs. The increasing of protein consumption, early marriages evidences, number of health care provision, number of school are correlated on HDI. Furthermore, HDI is also affectef by the reduction of unemployment and number of MSMEs.
Analysis of Poverty Determination in Madura 2010 - 2019
Authors: Kamilah Kamilah , Priyono Teguh Hadi , Yunitasari Duwi , Wibisono Sunlip , Somaji Rafael Purtomo , Istiyani Nanik , Santoso Edy
Published: May 2023

One of the largest’s poverty percentage in East Java Province is on Madura insland.The average percentage of poverty in district on Madura Island is higher than thepercentage of poverty in East Java Province. Based on this, it is known that the poverty rate in Madura is above East Java Province, reaching more than 20 percent. 2022This study aims to determine the effect of the independent variables of economicgrowth, Unemployment Rate, Inequality of Income Distribution on Poverty Levelson Madura Island. In this case, the data used is panel data which is a combinationof the time series, namely 2010 – 2019 and the latitude series of 4 districts inMadura. The data analysis method used in this research is panel data regression.The results of this study are the variable economic growth (X1) has a negative andsignificant effect on poverty in Madura Island. The Variable Unemployment Rate(X2) has a positive and insignificant effect on poverty in Madura Island. Incomedistribution inequality variable (X3) has a negative and significant effect on povertyin Madura Island
Characteristics and Determinants Of Precarious Employment In Indonesia
Authors: Utomo Oni Prasetyo , Sugiharti Lilik
Published: May 2023

Precarious employment is indicator of non-standard work that describes workers in a vulnerable position to lose their jobs which can lead to poverty and can hinder sustainable development. The rapid growth of precarious employment rate is a serious challenge for a developing country. This study aims to analyze the factors that affect precarious workers in Indonesia. The data used in this study is Sakernas August 2019. The analytical method used in this study is logistic regression, where the independent variables are the demographic and employment characteristics of individuals along with macro conditions of regional employment. The findings of this study are that young workers, male, low-educated, unmarried status, and living in urban areas, tend to be precarious workers. Those who work in the manufacturing industry and less than one year of work experience are more likely to become precarious workers. High unemployment rates and low regional average wages also put individuals at greater risk of becoming precarious workers.
The Role Of Information Technology In Improving The Competitiveness Of Small And Medium Enterprises In Gowa District
Authors: Radjab Enny , Tjambolang Tjare A
Published: May 2023

The Ministry of Cooperatives and MSMEs of the Republic of Indonesia stated that the number of MSMEs (Micro, Small, and Medium Enterprises) has a market of up to 99.99% or around 62.9 million business units from all business actors nationally which absorbs labor up to 97% of the total employment. work proportionally. The development of MSMEs is a big change that is felt during the Covid-19 pandemic. During the Covid-19 pandemic, MSME actors must think about surviving for the sake of their business continuity. This condition limits the movement of community activities so that all consumer needs during the pandemic are transferred online. Digital marketing is one way to open communication between potential consumers and sellers, which is done without real-time restrictions. In the current digital era, many business actors do not have a shop directly, but they trade online or through internet media. The contribution of MSMEs to employment, both in developed and developing countries, including Indonesia, has a significant role in overcoming the problem of unemployment. In the current global economic era, business actors are required to make changes to increase their competitiveness. One of the most important factors is an information technology (IT). The use of IT can enhance business transformation with the speed, accuracy, and efficiency of exchanging information on a large scale. MSMEs are said to have global competitiveness if they can carry out their business operations in a reliable, balanced, and high-standard manner.
The Effect of Organizational Commitment, Competence on Satisfaction and Performance of Lecturers at the Makassar South Sulawesi Maritime Polytechnic
Authors: Zulaikah Siti , Hamid Mulyadi , Muin Sri Adrianti
Published: May 2023

This study aims to determine and analyze the effect of commitment, competence on the satisfaction and performance of the lecturers of the Makassar South Sulawesi Shipping Science Polytechnic.The research approach used in this study is a quantitative method with an explanatory approach. From the total population data, the slovin formula was used to obtain a sample of 100 respondents.These results indicate that the path coefficient between the variables, namely job satisfaction has no positive and significant effect on lecturer performance, organizational commitment directly affects lecturer job satisfaction, organizational commitment has a positive and significant effect on lecturer performance, competence directly has a positive and significant effect on satisfaction work and competence did not have a positive and significant effect on the performance of lecturers at the Makassar South Sulawesi Shipping Polytechnic
Digital Well Integrity Solution Helps Support BP Oman's Sustainability Objectives
Authors: Al Hadhrami I. , Al Harrasi S. , Copping S. R.
Published: May 2023

BP has had a presence in Oman since 2007 and stands as a major investor within the country. BP is one of the world's pioneers in tight gas production, harnessing technology and experience to develop one of the Middle East's largest unconventional gas resources in the Sultanate's Block 61. BP Oman's overall goal is to create a sustainable legacy that supports Oman's strategic goals for energy security and long-term economic diversification.

Production from Phase 1 of Block 61, Khazzan, started in 2017 (Fig. 1). In October 2020, production from Phase 2, Ghazeer also started (Fig. 2). Combined, Khazzan and Ghazeer produce 1.5 billion cubic ft of gas/d and more than 65,000 bbl/d of associated condensate. With an estimated 10.5 trillion cubic ft of recoverable gas resources, the block has the capacity to deliver approximately 35% of Oman's total gas demand.
Improving Accessibility of Technical Drilling Applications via Wells on Cloud-based Platform
Authors: Mak W. J. , Aziz M. L. A. , Hamid M. R. , Hashim M. M. H. Meor
Published: May 2023

Technical engineering applications have long been an important tool for engineers in the well design process. The nature of being on-prem in individual devices has posed several issues, where lengthy installation processes often lead to a large amount of time consumption and disrupts the engineers’ work efficiency. As the industry moves into the era of digitalization, the Wells on Cloud solution is introduced. The migration of current on-prem applications into a SaaS Cloud-based solution aims to mitigate the issues encountered by users via the elimination of installation processes and automatic push updates. The WoC solution aligns with Wells Digital Roadmap to act as a central hub and a single source of truth while focusing on three key principles. It aspires to cater to solutions from different vendors, capitalize on established Cloud-based infrastructure to host the solution platform and facilitate data transparency. Being a Cloud-based solution, all updates can be implemented and pushed to the user's devices, and users can access their data with a device anytime and anywhere. Direct links to the Open-End Community are incorporated into the solution. Moving on, the WoC's security system consists of active detection of anomalies, protecting against these issues, and comprehensive strategies to respond to any potential breakdown. To measure the value creation resulting from this initiative, the quantitative process cycle efficiency and qualitative feedback survey are conducted. PCE improvements demonstrated the timeline improvement brought by this solution, along with the positive comments shared by heavy users of these applications. The successful deployment of the Wells on Cloud solution has equipped engineers with the tools to unlock the full capability of technical engineering applications right at their fingertips. It also opened the avenues for business agility and scalability to match business requirements, reducing the Total Cost of Ownership and leading to savings. This solution sets the path for Cloud-based working and drives the industry to move towards digitally enabled businesses.
Gas Completion Design Strategy Enabling One trip Upper Completion in Onshore UAE E&P UAE
Authors: Varma Esha Narendra , Bin Sumaida Ali Sulaiman , Ahmed Mohammad Hussain , Anyanwu Jude Chukwunenye , Al Assi Abdulla Eyad , Azher Muhammad
Published: May 2023

Objective

This paper conducts the technical process on optimization of gas wells completion string design/equipment used in Onshore UAE E&P. The traditional Gas completion comprised of using Polished Bore Receptacle (PBR) which was then optimized using tubing move simulation and by introducing packer of higher envelop. This is a step change because it reduce cost, hazards and operational time for well completion.

Methods, Procedures, Process

Currently in Onshore UAE E&P there is a practice of using Polished Bore Receptacle (PBR) for all gas wells (Injectors and Producer). This results in higher casing additional cost, completion cost and operational risk to well completion compared to oil completion. The proposal is to remove the PBR based on tube moving analysis, introducing packer with wide envelop, reviewing and analyzing Worldwide History. The process included selecting the candidate wells with various injectors and producers profiles, gathering the data, carryout tube moving analysis for different packers and based on the results, the PBR's can removed or included in the completion string.

The basic function of the PBR is to accommodate the effect of extreme well conditions (temperature and pressure) during well treatment and production/injection. The two main components of PBR system are the polished bore itself and a seal assembly. It is pinned in a shear up position, assembled on the completion string, and run in the well above the Packer. The pins are sheared by application of upper forces during completion operation; there by making completion running operation complex, increasing hazards and risk factors, and increased operational time. During well life the PBR can be a possible cause of Sustained Annulus Pressure (SAP A) in case of failure of seal assembly. Limiting the use of PBR based on tube moving simulation resulted in reducing equipment and operational cost of the well completion and additionally reducing a potential risk factor of SAP A during well life.
Cloud-Based Real-Time Well Engineering: An Intelligent and Modular Multi-Engineering Modeling and Prediction
Authors: Chi Y. , Kemajou V. , Rajan A. , Samuel R.
Published: May 2023

Nowadays, the increasing drilling difficulties due to limited access to conventional reservoirs and high drilling costs put extra emphasis on drilling performance and safety. The advancement of real-time measurements and cloud computing make it possible to automate the monitoring, detection, and prediction processes, therefore trigger alarms before drilling issues even occur. In this paper, a scalable cloud-based real-time well engineering system was developed to monitor and forecast drilling operations by integrating multiple drilling model workflows such as torque and drag modeling, bit wear prediction, early kick loss prediction, hydraulics, swab and surge, anti-collision, stuck pipe avoidance. As demonstrated, this workflow can efficiently handle large and complex datasets in real-time and make real-time analysis and predictions. Moreover, this can be scaled up to support more users and wells. This cloud-based architecture makes it easier for the development team to apply hotfixes or major releases with no down time, and this new workflow makes it possible for drilling engineers to monitor live drilling wells anywhere and anytime while enabling the rig personnel to make significant improvement to operations and make timely and accurate decisions.
Simplifying SCR to AC Rig Conversions to Deploy Digital and Automated Drilling Technologies
Authors: Reddy P. P. , Lee D.
Published: May 2023

Advancements in drilling control system technologies enable gains in efficiency and repeatability. Recent developments also frequently include automation. To achieve these improvements, the industry is developing and introducing new control tools with rapid speed. However, not all drilling contractors are able to leverage these new advancements in machine controls.

Capitalizing on the new technologies requires that drilling rigs are running current generation Alternating Current (AC) drawworks and are fitted with controls system architecture suitable for this generation of hardware. Simply put, the industry is not developing Digital and Automated Drilling Control technology for dated, legacy drawworks run by direct current (DC) silicon-controlled rectifier (SCR) systems. This is a problem for many rigs in the fleet.

Because these rigs have antiquated hardware, they cannot be outfitted with the latest control systems without being upgraded with AC hardware platforms and equipment. This leaves many rigs lacking features and technologies that make them more capable and more competitive. Upgrades require an investment, and the cost and time associated with making hardware changes has been a barrier to entry for drilling contractors eager to capitalize on the new controls system technologies.

Historically, converting an SCR rig to AC technology required that the rig be rebuilt entirely. There are obvious incentives for upgrading ageing rigs, but the traditional approach to carrying out an upgrade is too time- and cost-intensive. The industry needs an affordable way to upgrade outmoded assets that can be implemented without resulting in extensive non-productive time (NPT) or lost revenue.

A new approach has been introduced to simplify the process. By swapping the existing direct current (DC) top drive and DC drawworks with AC models and adding a compact driller's cabin equipped with built-in drives to power and control the top drive and drawworks, an upgrade can be performed during a rig move. Using this upgrade method, an older rig can be outfitted to interface with new technologies to capture efficiency gains within a significantly shortened timeline.

This solution is feasible, but to enable execution, all upgrades must be tailored specifically to the rig layout. Before any work can be undertaken, thorough pre-planning discussions must take place among the parties involved, including management, finance, engineering, operations, and project execution teams.

A recent upgrade carried out during a rig move for a 2,000-horsepower class rig working in Saudi Arabia demonstrates how a field- retrofit solution makes it possible to quickly and cost-effectively convert any SCR drilling rig to AC without incurring extensive NPT.
Controlling a Valve Actuator and the Flow of Fluids with Interpreted Brain Signals
Authors: Alrajeh N. A. , Divine K. W. , Sullivan T. P. , Bukhari N. M.
Published: May 2023

The ability to control machines and equipment with just one's thoughts is a concept that has been explored in the field of neuroscience for decades. The development of brain-computer interfaces (BCIs) has made it possible to translate electrical signals generated by the brain into machine commands. In recent years, the field of BCI has made significant advancements in non-intrusive technology, which has the potential to revolutionize the way we interact with machines and equipment in a variety of fields. The objective of this project is to merge non-intrusive BCI technology with personal protective equipment (PPE) and control the flow of fluids through human sensory and peripheral signals in field environments.

A revolutionary system application was developed and tested by paper authors Kyle W. Divine, Thomas P. Sullivan, Nawaf A. Alrajeh and Nabil M. Bukhari from Saudi Aramco. This proposed system involves the use of a BCI with Electroencephalography (EEG) mounted within a traditional hardhat. The electrical signals generated from the thoughts of the wearer are used to train a Convolutional Neural Network (CNN) and modeled to recognize the wearer's imagined words, primarily open, close, push, pull, turn left, or turn right. These interpreted electrical signals are then relayed to the valve through a Micro Controller device resulting in the operation of the valve and the successful control of fluids with simple thought commands.
First Successful Deployment of Liner While Drilling Technology in Depleted Reservoir of Western Offshore India
Authors: Bagga Pawandeep , Pethe Sarang , Gupta Rakesh , Gupta Arpit
Published: May 2023

The Mumbai High field in Western offshore of India presents major challenges to both drilling and liner running operations, because of reservoir being depleted and severe lost circulation conditions. Thus Liner while drilling, a new technology was deployed as a pilot Project to drill in these troublesome carbonate reservoir. The operator had previously experienced severe losses in the zone leading to big loss of rig days and damage to Reservoir due to LCM (Loss Circulation Materials) Pills.

The liner while drilling service is a sustainable technology which combines 4.75in rotary steerable system BHA (Bottom Hole Assembly) with various logging tools, 8.75in hole opener/reamer, a mud motor, and a 7in liner 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. It is important to understand that Drilling with a mud motor and low RPM from surface is stressing the formation much less than conventional Rotary steerable BHA.

Losses were contained with special mud additives. Plastering & smearing effect across the well bore added value in curing the Losses. This Technology Reduced formation damage by avoiding repeated LCM pills. Post Drilling, the inner string was Pulled out of hole leaving the liner at bottom which was later cemented with Cement Retainer. The technology proved to be Sustainable and with reduced HSE risk for the operator.

The Paper will discuss in detail about the field of application, Prejob planning for Liner while Drilling Job, Onsite Execution and Successful completion of the well. This technology Successfully drilled, lowered, and Cemented 7in Liner at Target Depth saving rig time for the operator.
Quantum Leap in Intervention, Rectification of High Annulus Pressure (HAP) at Offshore Malaysia Using a Novel Annulus Intervention System- Operator Case Study
Authors: Osman Abdul Afif , Azman Aulfah , Sipangkui Rayner Brian , Sujavudin M. Ridhuwanuddin , Ahmad Sy M. Shahril Sy , Shafie Shar Kawi Hazim , Nor M. Abshar M. , Nazirmuddin M. Nazrul Shahril
Published: May 2023

Through recent years, there have been an increase of well integrity issues arising from the build-up of pressure in a well's casing annulus, or Sustained Annulus Pressure (SAP). The casing annulus (the volume between 2 concentric casings) are typically not designed for intervention and are only accessible from the casing valves at surface. While the A-annulus (the volume immediately next to the production tubing) may have limited accessibility from the tubing itself, for B- and C- annulus, this access is non-existent. Up until now, this has been the primary challenge in rectifying SAP issue in casings. Current well intervention technologies or methodologies are unable to rectify SAP issues and the wells had to be shut-in (production deferment) or required bleed-off facilities installed (additional CAPEX and OPEX). A breakthrough technology and methodology is required to resolve SAP issues and prevent risk escalation and production deferment. The desired solution should have the following characteristics: Ability to enter casing annulus, effectively lubricate the annulus, practicable at offshore and cost effective.

Based on the objectives, a technology selection process was performed concurrently with development of the execution methodology. This resulted in the selection and vetting of the Annulus Intervention System (AIS) Wellspring which utilizes a compact and flexible conveyance system known as ‘wellspring’ to be installed at the casing gate valve, ability to deliver fluid up to 400m away from pumping point and have integrated well control barrier for safe intervention into a live condition well. In addition, a suppression fluid placement methodology was designed using a heavy (14.8 ppg) brine system to replace the existing (lighter) casing annulus fluid. This was calculated to have a net pressure downwards and therefore suppressing the SAP.

With systematic process and procedure in place, team managed to prove the AIS can be conveyed through the casing head valve, passthrough the casing hanger and entered the B-annulus. The suppression fluid which is 14.8ppg brine also was able to be pump into the annulus to replace the degraded water-based mud with an optimum pumping rate and operating pressure. By achieving that, the team manage to suppress the SAP which ultimately safeguard the production from the well.

This paper shall discuss the process of identification, diagnostic and subsequently the step-by-step method that has been taken by the team to ensure the AIS system is well suited to rectify the sustained annulus pressure. It will also discuss the execution strategy, technical challenges faced and lesson learnt during the execution of the project.
Successful Smart Completion Deployment of Autonomous Inflow Control Valve with 13 Open Hole Segmentation Lower Completion Using a Light Workover Rig
Authors: Alakberi R. S. , Igein O. F. , Aljasmi S. A.
Published: May 2023

This paper presents a case study of the successful lower completion deployment of 13 swellable packers and Autonomous Inflow Control Valves (AICVs) into a 2227 ft open hole using a light workover rig in ADNOC Onshore (AON).

The objective of the well was to reduce the well's high Gas to Oil Ratio (GOR) and increase production efficiency and profitability. The main concern as Drilling & Completion team was to recover the single oil producer completion and run it with lower completion safely to the Target Depth (TD) and meet the Asset team objective and requirements.

The workover rig of 750 HP can reach up to 12,000’ target depth and the maximum overpull is 210 klbs where the planned target depth is 12,127’ MD/ 8922’ TVD. A pilot study was done on this well since the production team observed an increase in the GOR where the maximum value reached 2800 scf/bbl from 2016 to 2022.

Despite the challenges presented by the light workover rig capacity limitations, deployment of 2227 ft lower completion with 13 swell packers in open hole with assurance of proper isolation, a dedicated engineering study, simulations and risk assessment were concluded during the planning phase focusing on these challenges and set the proper engineering solution through a Torque and Drag simulation and checking the feasibility of deploying lower completion using the 750 HP light workover rig. In addition, a proper hole cleaning was planned with the combined trip of open hole drift and scrapper. Furthermore, for wellbore segmentation isolation, two runs of mechanical caliper logs were conducted to guarantee optimal placement of swell packers and strive for proper isolation of each segment, which eventually supported the successful completion of the well as per plan. The study provides insights into the design, execution, and monitoring of maintenance work for workover wells that aim to retain their production rates.

One of the major challenges of the well was the limitations of the rig capacity which will be highlighted in the study along with the methods used to address these limitations. Also, the use of AICVs, 13 swell packer deployment, equipment selection, real-time monitoring, expertise, pre-planning, torque and drag performance, design modelling, and simulations during the planning phase are some of the steps taken to eventually execute a flawless completion. A proper well cleanout and dedicated drift run were among some of the things carried out to make the deployment of the lower completion successful. The eventual results showed that the use of these techniques not only helped reduced the well's high GOR and thereby increased production efficiency and profitability but also was the main reason we were able to successfully get the lower completion to target depth. It is significant to highlight that one of the lightest WO rigs in the AON field successfully completed the well as Workover well.
Cloud-Based Data Integration Between Geology & Drilling Software Using Python Tools
Authors: Mwansa P. , Hernandez B. C. H. R. , Grebe S. , Hassan M. A. , Torsæter A. , Jenssen F.
Published: May 2023

The oil and gas industry generates vast amounts of data throughout its operations, from exploration to production. Collecting, connecting, and optimally utilizing this data is key to maximizing efficiency, accuracy, and access to new disruptive technologies.

In a typical well-planning cycle, an engineer will spend significant amount of time looking for the data they require to do their jobs efficiently. The data are typically locked away in silos - trajectories in one data platform, Pore Pressure Gradient, Fracture Gradient or Targets in another, and so on.

A major Middle Eastern NOC and Two Norwegian software service companies teamed up to develop Proof of Concept (PoC) for a new workflow that integrates subsurface and drilling data between on-premises Geology E&P software and Drilling software through a proprietary Python Tool plug-in and Python library. This integration enables a streamlined connection to a cloud-based drilling and well planning software, facilitating collaboration among teams involved in well planning. The project's key challenges are the lack of a standardized communication, integration, and automation of data flows between subsurface and drilling teams, as well as the inability of engineers to access necessary data due to scattered information and access restrictions. The project utilizes a proprietary data science suite, named Cegal's Prizm, which allows easy configuration to integrate data from various applications, sources, and platforms. A proprietary Python Tool is used to merge data from various application silos and data sources, enabling enriched investigation. The process involves connecting to the Geology E&P software retrieving domain objects using the proprietary Python Tool, and converting these domain data objects into common Python data structures. The project aims to develop an innovative workflow that provides easier access to data for experts throughout the organization, leading to better decision-making during the well-planning cycle. This not only makes it easier, but it also ensures collaboration between the G&G and Drilling teams involved in new well planning
A Holistic Approach to Consider for Slot Recovery Based on a Failure Incident in North Sea Operations
Authors: Ioan T. , Bull R. L.
Published: May 2023

An oilfield service company was awarded the scope by an operator in the North Sea to recover three slots from an existing offshore platform and redrill the HPHT wells to tap into unreached reservoir resources on a gas field. This paper covers the holistic approach of analysing the slot recovery operations strategy, plug and abandon the original wellbore, and how to avoid tunnel vision in the decision-making process to achieve the goals.

Cut and pull operations have one of the highest financial impacts on slot recovery and can lead to loss of the well in unfortunate circumstances. After slot recovery operations, including the cutting and milling of the 10-3/4″ × 10″ casing, the 13-3/8″ casing failed the pressure test. The incident triggered a Cause Analysis Tree Diagram of the well conditions that led to the discovery of a hole in the 13-3/8″ casing. The investigation highlighted the tunnel vision of the decision-making process where ‘stop points’ were bypassed or not efficiently identified, contributing to operational delays and potential loss of the wellbore.

The investigation concluded that insufficient information on the well was obtained during the planning phase and the financial decision tree analysis was incorrectly defined to proceed with the preparation of the contingency plans. In this process, all existing logs were re-evaluated to identify the solids behind casing, ovality, centralization, and casing-on-casing contact points. The original plan was to cut and pull the casing and then mill ~374ft of casing, with a shallow sidetrack option as contingency. However, during the execution, due to height of the top of solids encountered behind the casing, it was required to start milling from a shallower depth, with a total of ~ 1,500 ft of casing to be milled. At this stage in the operations, a fishbone diagram should have been created to perform a detailed analysis of the technical risks and cost impacts and to decide whether to continue milling or to proceed with the contingency option to sidetrack from a shallower depth. However due to peer pressure, tunnel vision goal seeking (Gasaway, n.d.), and phycological safety the multi-factor decision ‘stop points’ were not considered leading to an expensive, lengthy, and unsuccessful operations.

This paper summarizes the decisions and ‘stop points’ in the process of slot recovery operations and highlights the potential outcomes of incorrect technical risks and cost analysis. Further reviewing the utilization of the engineering analysis, and economical aspects through preparation of a fishbone diagram to manage stakeholders’ expectation on upfront commitment to continue with challenging slot recovery operations on a major decision-making point. The example and process provided in this paper will benefit the industry by helping to recognize a ‘stop points’ in the operations, highlighting the risks of having catastrophic event.
Stuckpipe Prediction Model to Detect and Notify Rig Crew Based on Drilling Parameters and Physical Models Outputs
Authors: Malki Mohammed A. , Abughaban Mahmoud F , Guimaraes Thiago T , Alshawabkeh Albara' A
Published: May 2023

Effective stuckpipe prediction becomes more challenging and requires real-time advanced analysis of all available drilling data. This paper presents an innovative model to predict stuckpipe incidents. A machine-learning model based on intensive feature-engineering integrated with physical models has been developed. It automates real-time drilling data collection, analysis, and detects the patterns for the most dominating drilling parameters values to achieve the success criteria of early warning signs of stuckpipe incidents. It has been applied on two equal sets of wells either stuck or non-stuck incidents. The model triggers alarms reliably and early before the stuckpipe incidents happen and therefore corrective actions could be taken properly in advance.
A Systematic Approach to Fracture Propagation Simulation with the Integrated Natural Fracture and Geomechanical Model
Authors: Guan Xu , Zhu Deyu , Tang Qingsong , Wang Xiaojuan , Wang Haixia , Zhang Shaomin , Deng Qingyuan , Yu Peng , Yu Kai , Huang Xingning , Xu Hanbing
Published: May 2023

In recent years, tight sandstone gas as one of the important types of unconventional resources, has been rapid explored and developed. There are large-scale tight sandstone gas production in Sichuan Basin, Ordos Basin, Bohai Bay Basin, Songliao Basin and other basins, and it has become a key part in the area of increasing gas reserves and production in China. Due to the influence of the reservoir characteristics, tight gas reservoirs have low porosity and permeability, and the tight gas can only be effectively developed by improving the conductivity around the wellbore. Therefore, it is required to perform hydraulic fracturing after the completion of horizontal well drilling to improve the permeability of reservoir. It can be seen that hydraulic fracturing is the core technology for efficient development of tight gas resources. The implementation of hydraulic fracturing scheme directly determines the horizontal well production and EUR. This paper describes the workflow of 3D geomechanical modeling, technical application for Well YQ 3-3-H4 reservoir stimulation treatment, and carries out hydraulic fracture propagation simulation research based on 3D geomechanical model. This paper also compares the micro-seismic data with the simulation results, and the comparison results show that the propagation model is consistent with the micro-seismic monitoring data, which verifies the accuracy of the model. This paper clarifies the distribution law of hydraulic fractures in the three-dimensional space of horizontal wells in YQ 3 block, and the research results can be used to provide guidance and suggestions for the optimization of fracturing design of horizontal wells in tight gas of Sichuan Basin.
Well Simulator Technology Overview and Results for Onshore, Offshore and Subsea Drilling Operations
Authors: Santoro D. , Forno L. Dal , Ferrara P. , Bianchini L. P. , Bartucci G. , Bianchi L. , Lahou K. , Nabavi J. , Huseynov P. , Gocmen E. B. , Lye J. , Loh J.
Published: May 2023

Well simulator technologies have become an ever more important part of Well Construction design and Drilling Operations follow-up worldwide. Adopted initially by Company to support personnel training through virtual environment applications, they were then used for planning, real time support and post job analysis for drilling operations, being integrated in all engineering processes. This paper presents an overview of its current use and procedures, highlights current and potential benefits and suggestions for future developments.

Selected wells are configured inside the well simulator which is then latched to mud log data streams. Dynamic models calibration is performed by adjusting dedicated coefficients to reach an overlap between simulated and measured drilling parameters. The degree of drift between curves allows to identify well operations-related issues. Outputs are mostly time-based, in mud log and driller-cabin-like layouts fashion. Depth-based plots, such as roadmaps for axial and torsional friction factors are also available and can be used as input for advanced analyses for both planning and post job phases.

Systematic application of the well simulator was started early 2021 with real time monitoring for North Sea and Africa offshore/subsea operations. Deployment along 2022 spread out across several other business units in various operated countries, for onshore, offshore and subsea drilling operations. Experience gained in a number of relevant case histories, dedicated to both real time support and what-if post-analyses, allowed to provide earlier feedbacks on drilling operations good practice but also to predict, avoid and mitigate consequences of wellbore problems and equipment malfunctions, boosting interest for further developments. Nowadays, well simulator technologies constitute a fundamental step towards drilling automation, since their dynamic modelling approach allows the definition of drilling parameter envelopes inside which robotic tools can operate and generate alerts if envelopes are overridden. Anomalous behavior of the drilling parameters can be recognized and governed. Automatic configuration and calibration of real time driven models are key enablers of real time optimization of operational drilling parameters and contactless operations, reducing back-office support to minimum.

Well simulator solutions that have been tested and deployed in our operations allow adaptability to a variety of existing platforms from both the operators and service companies side. The new upgrades, for data input and results visualization, are prone for user-friendly application, reducing the amount of training required for operative personnel to familiarize themselves with the tool and apply it during drilling operations.
A Hybrid Physical and Machine Learning Model to Diagnose Failures in Electrical Submersible Pumps
Authors: Al-Ballam S. , Karami H. , Devegowda D.
Published: May 2023

Electrical submersible pumps (ESPs) are among the most common artificial lift techniques in highly productive oil wells. The ESP failures are extremely costly to the producers and must be minimized. This study proposes a hybrid approach utilizing multi-class classification machine learning (ML) models to identify various specific failure modes (SFMs) of an ESP. A comprehensive dataset and various ML algorithms are utilized, considering the physics of fluid flow through the ESP.

The ML models are based on field data gathered from the surface and downhole ESP monitoring equipment over five years of production of 10 wells. The dataset includes the failure cause, duration of downtime, the corresponding high-frequency (per minute) pump data, and well-production data. The prediction periods of 3 hours to 7 days before the failure are evaluated to minimize false alarms and predict the true events. Four modeling designs are used to handle the data and predict ESP failure. These designs differ in the input parameters used for the model and signify the effect of including the physical parameters in failure prediction. Several ML models are tested and evaluated using precision, recall, and F1-score performance measures. The K-Nearest Neighbor (KNN) model outperforms the other algorithms in forecasting ESP failures. Some other tested models are Random Forest (RF), Decision Tree (DT), Multilayer Perceptron (MLP) Neural Network, etc.

According to the data, most ESP operational failures are characterized as electrical failures. The ML models show similarly good performances with high true prediction rates in predicting ESP failures for all the tested designs. The design that integrates the effects of gas presence and pump efficiency while minimizing the number of input variables is suggested for general use. Increasing the prediction period up to 3 days results in a negligible drop in the model’s performance, showing that the model can predict ESP failures accurately three days before their occurrences. However, the forecasts show increases in missed failures and false alarms for prediction periods of more than three days, making three days the selected prediction period. These ML models will aid operators in avoiding undesirable events, reducing downtime, and extending the lifespan of ESPs.

ESP failures are unanticipated but common occurrences in oil and gas wells. It is necessary to detect the onset of failures early and prevent excessive downtime. This study’s model allows engineers to detect failures early, diagnose potential causes, and propose preventive actions. It is crucial in transitioning from a reactive event-based to proactive and predictive maintenance of artificial lift operations.
Cost-Effective Development Mode for Marginal Oil fields – Best Practice of CNPC
Authors: Wu Bohong , Nie Zhen , Li Yong , Deng Xili , Ma Ruicheng , Xu Jiacheng
Published: May 2023

Marginal reserves are an important play in future energy development. Based on the statistics of China National Petroleum Corporation (CNPC), the low permeability and unconventional reservoirs occupied 92% of newly found proven reserves in China. To overcome challenges such as poor reservoir conditions, weak natural energy, low displacement efficiency, and insufficient single well production, CNPC has conducted years of research and operation to cost-effectively develop China's marginal reserves.

To develop the marginal fields economically, it is required to maximize single well production, recovery and reservoir sweep with minimum CAPEX and OPEX reasonably. The production enhancement is realized by 3 key technologies, namely, sweet spot identification, multi-layered 3D short spacing horizontal well pattern, and volumetric fracturing techniques. The cost reduction is achieved by the full life cycle practice of utilizing "large cluster, factory" well design and field operation, drilling prognosis optimization, integrated intelligent surface system, and unmanned operation.

CNPC cost-effective development mode is practical and successful, marginal fields characterized with heterogeneous, multi-layered oil-bearing intervals with poor continuity are being economically developed in China. By comprehensive geological study, fit-for-purpose technologies application, and geoscience-to-engineering integration, the fracture control degree of horizontal wells increased from 60% to more than 90% based on micro-seismic events, stimulated reservoir volume (SRV) increased by 46.8%, average cumulative oil production per well is more than 100 times than original production in the field. Fast and early cash flow is realized by minimum production facilities. The average drilling cycle is shortened by 61%, the surface facility construction time is reduced by 65%, and the average single well investment is reduced by 42%.
Sour Rated 10,000-psi System High Temperature Gas Development Wells: A Journey of Optimization in North Malays Basin While Sustaining the Nation Gas Demand
Authors: Jong Siaw Chuan , Aziz Khairil Faiz Abdul , Goo Jia Jun , Hiew Ronnie , Strickland Kenny , Hussin Arief , Yusof Khazimad , Macleod Andy , Yusoff Syukur , Chung Chay Yoeng , Liew Alex
Published: May 2023

High temperature, high carbon dioxide coupled with hydrogen sulfide contents, and rapid PPFG pressure ramp increase gas development well tends to cause high well capex for Operator. This well type typically needs high CRA material with at least a 10,000-psi rated system to complete. Offshore peninsular Malaysia’s North Malay Basin (NMB)’s deep reservoirs also fall into the described category.

This paper aims to share the optimization journey, applications, and learnings of the company’s H.T. sour-rated 10Ksi gas development wells through several phases, besides fulfilling the gas delivery need for the country. In addition, engineering and operational optimizations are identified to reduce the well’s time and cost without sacrificing the crew’s safety as the team focus.

The company wells engineering team applied Lean approaches encompassing the complete Plan-Do-Check-Adjust cycle to achieve the optimization. Well data usage, lessons learned, collaboration, continuity, and striving for continuous improvements are the key factors to ensure good optimization results. Fit-for-purpose drilling and completions equipment design and application, rig offline capabilities planning, wellhead dummy hanger plug design for offline cementing, intervention-less production packer setting device, offline annulus nitrogen cushion fluids displacement and other applications will be explained in the paper.

The paper explained the operational challenges, how and what optimizations applied to achieve excellent well performance compared to targets and previous campaigns. The wells team optimizations spread out from engineering to execution stages, including rolling out in-house talent of digitization and digitalization of well performance surveillance, in line with the industry's way forward. The recent campaign post optimization concluded with no safety incidents, below budgeted time and cost, low overall NPTs, and achieved first gas to meet the country's power generation demand. Open, collaborative, and proactive cross departments communications are the catalysts that contributed to the positive optimization journey's results.
An Incidence of Superior Mesenteric Venous Thrombosis in Mild COVID-19
Authors: Batra Sakshi , Nair Asha G , Syal Kirtimaan
Published: May 2023

SARS-CoV-2, an etiological agent of COVID-19, has been reported to inflict remarkably diverse manifestations in different subjects across the globe. Though patients with COVID-19 predominantly have fever, respiratory and constitutional symptoms, atypical presentations are becoming increasingly evident. COVID-19 may predispose to both venous and arterial thromboembolism due to excessive inflammation, hypoxia, immobilization, and diffuse intravascular coagulation in moderate to severe symptomatic cases. In this case report, we are reporting thromboembolic complications of COVID-19 in a mild symptomatic subject incidentally diagnosed with mesenteric venous occlusion with no abdominal symptoms. Early recognition of the abdominal symptoms, diagnosis, initiation of anticoagulants, and timely surgical intervention may improvise the outcome in a patient with COVID-19 Infection-induced mesenteric thrombosis. Superior mesenteric artery and venous thrombosis may lead to subsequent ischemia necessitating emergency laparotomy. Thus, the usage of low-dose anticoagulants in all the patients of COVID-19 irrespective of the categorization into mild, moderate, and severe COVID-19 disease should be considered.