bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Increase of Clean in-House Power Generation Through Collaborative Inter-Disciplinary Steam Feed Study
Authors: Alkhoujah K. , Al Qaydi J. 
Published: October 2023

Abstract
This paper will present the successful enhancement of In-house power generation in a sour gas plant through overcoming the limitations and constraints of increasing the steam feed into the main steam turbine generators. The study included multi-disciplinary design reviews and various adequacy checks resulting in exploring a new increased safe and sustainable steam feed in the steam turbine generators and hence, increasing in-house power generation. The results of the test showed that the steam feed can be increased safely given that all structure reinforcement is done as per the recommendation of the piping experts. The steam increase has resulted in cost savings of over 70,000,000 USD for the lifetime of the plant (approximated of additional 20 years) and it will ensure reduction of greenhouse gases emissions of 35,478 tons per year.
Calculating Invisible Loss Time (ILT) Index Values & Predictive Analysis Using Bayesian Approach to Improve Drilling Operational Efficiency: Adopting Best Practices
Authors: Dubey Pranav , Garg Rachit , Kumar Prateek , Tyagi Akash , Jain Aditi , Chakraborty Pramit , Chabbra Sameer 
Published: October 2023

Abstract
Contribution in reducing Invisible Loss Time (ILT) towards operational efficiency has been a significant approach towards adopting best practices in drilling operations but predicting ILT using mathematical models accurately has been an additional challenge due to multiple factors contributing towards ILT. This paper sketches an algorithm for calculating the ILT Index value and then uses the Bayesian approach for predicting the invisible loss time (ILT) index value over other existing statistical methods. Digital Oilfield architecture processes along with data management systems have worked in synchrony for streaming data for analytics in real-time well engineering solutions. Defined KPIs of Invisible Loss Time (ILT) were evaluated in small sets of datasets with a Bayesian Optimisation approach using a probability model for the likeness of event occurrence. The performance of this model is evaluated based on a comparison of actual vs predicted ILT index values. Benchmarked (BM) values were calculated based on the best performance for the quarter, month, and week to understand the randomness of values. Real-time data generated were packeted for small sets as per KPIs defined for probability analysis. Sets of data made available for calculation were used to feed in the probability model for forecasting the values. Results from the predictive models showcased that batch drilling activities had a significant reduction in variance amongst the ILT values. Reduced ILT while operational activity due to adaptive learning can be calculated to quantify that cost component. Weighted percentages of KPIs in decreasing order of their significance were calculated.
Moving Towards Automation and Artificial Intelligence in Managing HSE Risks and Incidents
Authors: Go C. H. , Agusalim F. , Wan Hussin W. , Chang E. J. T. , Gonasergar V. , Abd Kahar N. S. , Syd Hamdan S. I. , Sazali O. R. 
Published: October 2023

Abstract
As society and the economy gravitates toward cleaner and renewable energy, the energy sector continues to diversify and increase in complexity, leading to a ‘never normal’ business portfolio and project delivery. On top of safeguarding On Time, On Budget, and On Scope delivery, this constant state of change also warrants new ways of managing Health, Safety and Environment (HSE). At PETRONAS, new ways of working is synonymous with digital transformation. Hence, this paper will outline how PETRONAS leverages digital technologies in managing HSE risks in project delivery. Since 2019, the project delivery arm of PETRONAS has invested in developing an artificial intelligence (AI) predictive model to predict future HSE risks and incidents based on historical HSE incident big data. Coupled with real-time data visualization and prescription of control measures, this digital solution has greatly enabled the organization to rationalize resources and implement informed, risk-based interventions. Considerable efforts have been made to operationalize the predictive tool, which includes stakeholder management, change management, as well as work process enhancement to incorporate automation and have end-to-end oversight on risk mitigation and intervention. This provides a HSE management framework that focuses on data-driven decision-making, which translates to targeted intervention with pace. As a result, PETRONAS project delivery arm has seen incident reduction of more than 55% for both injurious and non-injurious incidents in 2022 in comparison to the preceding three-year average. In addition, the implementation of the digital solution has enabled an improved process cycle efficiency of HSE risk management from 32% to 97%, with a reduction of total mantime of 143 hours.
Insights into CH4/CO2 Adsorption and Mechanisms Enhanced CH4 Recovery in Kerogen Slit Nanopores by Innovative Molecular Dynamics
Authors: Li Jiawei , Wang Rui , Dai Xu , Rahman Sheikh S 
Published: October 2023

Abstract
CO2 injection into shale reservoirs to enhance methane (CH4) production is treated as a better way to promote gas recovery efficiency as well as easing carbon emission by CO2 sequestration and storage. Most CH4 is adsorbed inside the organic micropores and mesopores (≤ 50 nm), which hold large surface areas and enormous adsorption sites. And another key structure characteristic in shale reservoir is the slit, which is usually treated as a significant sequestration medium. To better understand the microscopic mechanism of enhanced CH4 recovery by CO2 in nanopores and slit becomes necessary in shale reservoirs owing to the geological and physical properties. Laboratory experiments show challenges in observation of molecular adsorption and displacement processes inside the nanoscale pores, and also present restrains in achieving high temperature and high pressure simultaneously. Thereby, Molecular Dynamics simulation (MD) method supports a solid foundation for constructing the nanosized kerogen frameworks to investigate the gas adsorption behavior on the kerogen-accessible surface. This study innovatively introduced a new method of constructing kerogen slit nanopores, making the model more practical and approaching real underground environments. The grand canonical Monte Carlo (GCMC) method is employed to reveal the gas adsorption and sequestration in the kerogen nanopores and slit at various subsurface conditions. According to our results, the slit overlooked by previous studies particularly impacts gas adsorption process and CH4 recovery efficiency, owing to the space facilities the free gas resides. This study also examines the widespread water encroachment phenomenon, which includes various water contents and saline concentrations to mimic the real subsurface environment. Pure water has an overall negative influence on gas adsorption and sequestration, whereas, promoting the recovery efficiency of CH4 by CO2 injection. Moreover, saline has a further enhanced negative influence on gas adsorption due to the presence of ions, whereas, encourages the displacement process by CO2 injection. Ethane (C2H6) impacts the CH4 adsorption negatively but favors the recovery process. This work shows significant importance in underlining the kerogen slit nanopores structure and develops the knowledge of the comprehensive underground conditions effects on gas adsorption and recovery mechanisms at a thorough level to enhance CH4 extraction and CO2 utilization and sequestration, and provides a solid background for gas industrial production.
Pilot Deployment of IIoT-SCADA by Leveraging Low Power Communication Technologies, Sensors, and Legacy Scada Controllers
Authors: Ahmed Muhammad Shahzad , Al Bloushi Mahdi Abdula , Ali Asad , Yousef Ahmed Alhammadi , Mistry Kalpit Jayendrabhai , Henson Hushish Hernandez , Shar Aijaz Ahmed 
Published: October 2023

Abstract
Remote monitoring and operation are a key aspect in oil and gas facilities due to remoteness of producing and gathering facilities. Traditionally, SCADA system based on wired Fiber Optics or wireless radio communication is used to gather this remote data and perform supervisory actions. During last decade IoT (Internet of things) solutions are being adopted in oil and gas industries because of their cost efficiency and ease in deployment.
Most of industrial internet of things solutions (IIoT) available in market are utilizing LPWAN (Low Power Wide Area Network) wireless technologies e.g., LoRaWAN, SigFox, NB-IOT with backbone network infrastructures based on GSM/Satellite/ public cellular network and cloud-based application/network servers. Such solutions, due to the involvement of 3rd party/public networks pose a concern related to data security and complete network ownership.
This paper explains the deployment of a pilot project executed in Giant Oil and Gas Production Field (X Field) in ADNOC Onshore with following features,
Deployment private LPWAN based on existing telecom backhaul consisting of FoC and WiMAX network. Data was taken from exiting active instrumentation and converted to Modbus RTU routed over LoRa wireless modulation as Physical Layer by adding LoRa Slave Modules. Data from slave modules was wirelessly communicated through LoRa Master Gateways to SCADA Master Controller (MTU). This solution embeds IIoT technologies i.e. Low Power Wireless Gateways to industry proven SCADA controllers for remote monitoring as well as some operational commands such as oil well closure.
At present, in ADNOC Onshore there are multiple remote facilities e.g., oil wells, water injection wells, CP system solar stations etc. which are without centralized remote monitoring; at the same instance, the field has a widespread SCADA network based on WiMAX and FoC. This situation is equally applicable for most of oil and gas brownfield facilities. Private LPWA networks built upon these existing SCADA networks are cost effective solutions to cover the gap for remote monitoring of the facilities where near real-time data monitoring is required.
In this deployment ADNOC onshore has successfully achieved the flexibility and cost effectiveness offered by LPWAN along with the hardened centralized SCADA controller to eliminate the cyber security concerns related to Application and Hardware Security.
Below LPWA technology was primarily utilized as an added function for this development IIoT SCADA
Private Lora (Modbus RTU over physical layer of Lora)
Energy Storage Study for Water Electrolysis Based Green Ammonia Plant
Authors: Choudhury Soumya Jyoti , Singhal Sunil Kumar 
Published: October 2023

Abstract
As the world is battling to reduce CO2 emissions to combat climate change, green H2 and ammonia as green energy carrier are new buzz words in the industry. The biggest attraction of green H2 is as alternate fuel to gasoline and diesel. In fact, many believe that green H2 will play a bigger role in heavy vehicle industry as an alternate to diesel since it has been found uneconomical to run battery driven heavy vehicles. For long haul transport of green H2, either it must be liquified or H2 can be converted to green Ammonia (NH3). There is no established infrastructure for long haul or large quantity transport of liquid hydrogen. On the contrary, the world is quite familiar with handling of liquid NH3 and transport infrastructure is well in place for long haul and /or large quantity ammonia transport. Ships with different capacities are already in use for long haul transport NH3 with adequate facility at many ports for unloading and loading of NH3. Many counties also have infrastructure in place for inland transport of NH3 via rail route. One of the ways to produce green ammonia is electrolysis of water using renewable power followed by Ammonia Synthesis process.
Continuous Supply of renewable power is required for continuous production of green NH3 from water electrolysis. But there are some challenges. On average solar and wind energies are available for ~25% and ~35% hours respectively in a year. Though they are somewhat complimentary, together they can at best provide renewable power for 50-60% hours. This still leaves a gap of 40-50%. When only solar or wind power is a source of energy, then hours when renewable power is unavailable increase significantly. Hydro power is a continuous source of energy, but it is heavily geography dependent, capital intensive and in most parts of the world hydro power has been nearly maximized just to meet regular power demands. Upcoming and developing sources of renewable power like Geothermal, tidal, ocean wave etc. are at nascent stage of development and has only been explored at limited small-scale installations. Another continuous source renewable energy that is slowly gaining interest and is witnessing scaling up is generation of electricity from waste material. However, this paper does not include evaluation of energy generation from waste.
Fully Automated Land Rig Pipe Handling: Learnings from the First Year in Operation
Authors: Craig C. , Gupta A. , Yenzer D. , Hasler D. , Towns J. 
Published: October 2023

Abstract

Objectives/Scope
A look at learnings from the first year of operations on a fully automated rig floor package retrofitted to a 2000hp Permian Basin rig. Technical issues and optimization efforts will be reviewed as the factors driving next-generation pipe handling system that improves safety while meeting well delivery metrics.

Methods, Procedures, Process
The retrofittable automation system controls several tools and technologies automating pipe handling for drilling, tripping, casing running, offline stand building and routine BHA handling. Keeping the focus on this area provides a drilling environment where risk due to man / machine interactions are substantially reduced or eliminated. During this proof period, improvements have continued in casing handling and running that are being optimized based on the learnings from the current pipe handling system. These improvements are being flowed through engineering and will support the next generation automated rig floor improvements.

Results, Observations, Conclusions
While the industry continues to focus on improvements in crew safety and consistency, applications of automated drilling systems often cannot justify the expense of a next generation drilling rig. Automation systems specifically designed to be retrofitted to existing rig designs provide these capabilities for a fraction of the cost of a new rig. This means the next evolution in safety can be affordable and installed on current drilling rigs with only short windows of down time. Existing technologies like robotics, modern control systems, closed-loop feedback, and zone management for both machines and crew all combined to focus on getting the job done safely are no longer exercises in what could be, rather what is available. Within the contractor fleet several rigs of the same design are working in the same field drilling the same wells which allows for direct comparison of key performance indicators for the automation system. Learnings from the first year will be reviewed and discussed.

Novel/Additive Information
Versions of pipe handling have been with the industry since the advent of harsh environment floaters. Today's automated functionality brings a new level of crew-less operations. Keeping crew separated from hazards is the next step in rig floor operations. This improved level of safety can now be achieved through more economical, retrofittable upgrades while maintaining similar rig performance metrics.
Offline Stimulation Through a TAML Level 5 Multilateral Junction: Operational Success Within a Carbonate Formation Through Design Collaboration and Joint Planning
Authors: Bjørnseth Fabian , Tjensvoll Anna Vigrestad , Lande Hans Petter , Sastre Johanna , Barron Angus , Falnes Morten , Kogsbøll Hans-Henrik , Jakobsen Erik 
Published: October 2023

Multilateral well construction is generally accepted as a beneficial method of field development within the Norwegian Sector, however methods of production enhancement in combination with multilateral technology are less common and have produced varied results. Specific to carbonate formations within the region, low complexity multilateral junctions – such as open hole laterals – in which offline stimulations have been performed, have resulted in limited production uplift or issues with junction integrity resulting in a short well lifetime. These latter issues become more apparent in weak reservoir rock, where high stress effects from reservoir compaction can result in collapse even in cased intervals.
Considering the case history and the expected stresses applied at any in-reservoir junction, a high strength Technology Advancement for Multi Laterals (TAML) level 5 junction was required to provide mechanical and hydraulic integrity. Unlike previous attempts at multilateral technology (MLT) evaluation of the field, where the focus was on the functional requirements of the equipment, an alternative approach was made whereby the operator and MLT vendor collaborated to identify suitable reservoir targets and make specific business cases for different multilateral designs. This resulted in the development of a 7-5/8 in. TAML level 5 multilateral stimulation system over an 18-month period.
The system was successfully deployed in a dual lateral application in March of 2022, acid stimulated by bullheading in June 2022 and subsequently put on production. Production data indicates flow contribution from both production legs, with a productivity in line with expectation. This paper covers an overview of the junction design, key points in the job planning process and challenges with the execution.
Field Application and Performance Evaluation of a Cost-Effective Matrix Acidizing Technique in Naturally Fractured Carbonates - Case Studies from Gulf of Suez
Authors: Hegazy Amr , Hakim Emad Abdel , Ramadan Ahmed , El-Shiekh Kareem , Saleh Khaled 
Published: October 2023

Abstract
Improving production in offshore brownfields presents significant challenges, particularly in extracting additional oil from layers unaffected by water breakthroughs, especially in commingled completions. Conventional matrix stimulation treatments in commingled completions often require straddle packers to achieve effective zonal coverage and selective treatment. However, the complexity escalates when mechanical isolation methods are more expensive than chemical diverters.
This research paper introduces a comprehensive approach encompassing several vital factors to enhance production in these challenging scenarios. The approach includes understanding the inflow productivity of wells, addressing water breakthrough and low specific productivity index in commingled layers, formulating appropriate acid chemical recipes, selecting suitable chemical diversion methods, identifying optimal well candidates, and optimizing job execution to improve success rates. To illustrate the application of this approach, three candidates from the Gulf of Suez basin, a complex and heterogeneous basin located in the Eastern Desert of Egypt, produced from carbonate reservoirs, are examined as case studies.
Extensive laboratory tests were conducted to develop a chemical diversion technique that simultaneously serves as a water conformance agent and a diverter. A viscous pill was prepared to temporarily isolate fractures or fissure networks while diverting the treatment away from water zones before proceeding with the complete acid treatment. The results of this innovative diversion technique demonstrate a significant four-fold increase in well productivity while reducing water cuts.
This paper presents our approach and showcases the laboratory test results of this unique recipe and cost-effective diversion technique designed explicitly for fractured and watered-out carbonate reservoirs. Additionally, it highlights the valuable lessons learned while applying these methods, offering insights and practical knowledge for future similar projects.
A Novel Approach to Delayed Survey for Stuck-Pipe Prevention Practices and Drilling Performance
Authors: Khader C. , Soh A. , Lawati Al. A. , Humaidi H. A. , Harrasi F. A. , Elanbiya M. , Bahri S. A. , Hinai A. A. , Habsi Y. A. , Belushi M. A. , Noumani A. A. 
Published: October 2023

Abstract
In onshore Oman, difficulties are encountered where required dogleg for horizontal wells exceeded 8 degrees and execution put it above 10 degrees due to the added geological factor. Optimized landing in thin targets needed real time adjustments, which increased the stress on the trajectory, and increased the risk of hole instability due to limitation on hole cleaning capabilities, while running high tech tools in a high Dog-Leg Severity (DLS) area, where fishing comes with a low success rate. A precise well trajectory is crucial and the way to ensure the integrity of the well path is by surveying the borehole at an acceptable frequency as per the well surveying program. Which in accordance with world wide industry practices. Such acquired data is utilized in the drilling campaign starting from the planning phase throughout execution all the way to post drilling activities.
The 8.5in section is executed with a high dogleg severity (DLS) application. As such, a flexible-designed BHA (bottom hole assembly) is utilized to deliver the high deviation required to accurately land the well 0.5m true vertical depth (TVD) into the desired zone of interest. The current survey procedure of this BHA takes approximately 5-7 minutes of stationary time, not inclusive of connection time, leading to higher stuck-pipe risk such as solids-induced pack-off and differential sticking. Therefore, an optimized mud weight is planned to support the borehole with its Nahr Umr (shale) and Shuaiba (Limestone) formations exposed. With such high mud wight, differential sticking risk becomes high in the limestone, and drill string stationary time becomes crucial to stuck-pipe prevention measures. Delayed survey was trialed in the past to be an option to overcome low efficiency pumps on some rigs, and also for under-balanced or foam drilling. In this case study, it was decided to adopt such practices to eliminate any possible survey stationary time while drilling.
The trial proved successful and reduced stationary time after connection, from 7 minutes per stand to 0 minutes per stand (100% survey time reduction). As an additional benefit, drilling performance improved and saved approximately 4.5% of well AFE time due to reduction of survey time. This experiment helped to redesign the stuck-pipe prevention practices, deploy it on all wells, and start implementation on the 12.25in hole also to save another 6% of AFE time. As a result of the trial, such practice is adopted in all rigs by the operator, and this contributed to the increased performance and reduction of stuck risk in this drilling campaign.