bluuebunny/crossref_metadata_2025_split huggingface dataset:
Electrification in Industry: The Most Efficient Way Towards Decarbonization
Authors: Diezinger Stefan , Dennhardt Benjamin 
Published: October 2022

AbstractElectrification of process industries (e.g., oil & gas, chemicals, pulp & paper, steel, cement, etc.) will be key to meeting emissions targets established in the Paris Climate Accord. Organizations across several sectors are making progress on this front, particularly in Europe where carbon taxation heavily incentivizes emissions reductions measures. However, today, the overwhelming majority of mechanical power and heat generated globally for industrial processes still comes from fossil fuels (i.e., gas turbines/engines, coal or gas-fired boilers, etc). Electrifying these assets with renewables or other low- carbon energy sources is an important step on the decarbonization journey but it can present many challenges for operators.This paper presents various possibilities for electrification of the production of heat and mechanical power in industrial applications. For power, the replacement of gas and/or steam turbine mechanical drives with electric motors is discussed, as is the potential for hybrid (i.e., dual drives). The use of industrial heat pumps and electric heaters as a replacement for gas-fired boilers/furnaces is also discussed. Drawing from real-world applications, the paper aims to show how these technologies can be applied economically and also outlines potential hurdles that need to be addressed to make a compelling business case for electrification, particularly in brownfields.
Digitizing Drilling Process Using Low-Code Cloud Powered Solution
Authors: Alshardi Sultan , Asemebo Ericson , Acheerakath Shabeer , Ismail Ahmed , Elabsy Eslam , Alshkeili Anoud 
Published: October 2022

Abstract
This paper will demonstrate how digitizing drilling operations and addressing operational inefficiencies through a cloud-powered solution, can increase efficiency and profitability. Control the drilling operation was previously considered a complex task and utilized conventional methods. However, with high operational demand, digitizing the end-to-end process and integrating all stakeholders into one platform, ultimately allowed the workflow to be standardized.
The entire workflow was automated using the Agile methodology and the low-code platform, PowerApps. The solution has streamlined operations and resolved the difficulty in obtaining accurate and instantaneous information by using a single platform and establishing an efficient event driven workflow.
The solution integrated eight applications that cover: contract review, scope of work, well planning and design, base and location preparation, job execution, along with post job activities, and performance validation.
The event-driven workflow eliminated transactional errors and enhanced the flow of information and data between different disciplines within the drilling group. This was achieved by digitizing the complex processes across several stakeholder bodies and integrating the workflow into one comprehensive platform.
The digital solutions, such as this one, can be applied to the oil and gas industry are representative of the advancements that can be made when leveraging cost-effective solutions.
Initially, by aligning expertise from different disciplines (business context, IT collaboration, strong system integrators and a state-of-the-art technology platform) the necessary elements were present to achieve success. Secondly, the 6-month turnaround time to design and implement the solution was achieved by customizing the low-code PowerApps platform and integrating it with the master and sub-application principles, enabling application developers to reduce complexities and produce powerful results.
Integrity Challenges and Restoration of Sub-Surface Safety Valves by Innovative Rigless Techniques
Authors: Ahmad Zeeshan , Al Hosini Abdullah Alhaj , Al Janahi Mohammed Ibrahim , Al Marzouqi Abdulla Mohammed , Siddiqui Muhammad Ali , Al Zarouni Abdulla Haidar Abdulla , Alhamadi Reem Mohamad 
Published: October 2022

Abstract
Sub-surface safety valves are the integral critical part of the well integrity management and their functionality cannot be compromised at any stage of well life. Unavailability of SSSV's due to integrity issues company was facing serious challenges in production and well availability during high gas demand. Moreover, workover solution led to 7-8 months for completion of workover and reinstatement of surface facilities. In this paper, case studies of different integrity related problems with sub-surface valves discussed and extensive study conducted to restore the critical sub-surface safety system. These case studies highlighted encountered problems such as landing nipple profile damaged due to corrosion/scale, movement of SSSV from its profile, broken flapper during hydraulic frac operation and conversion of TRSSSV to insert type with challenging well interventions issues.
High pressure gas well was restored with redressed SSSV by using nipples gauge hanger above the valve to avoid any jumping of newly installed valve due to nipple profile washed out limitation. Insert type valve option evaluated for the same well with 40 MMSCF/D flow and concluded not suitable due to production constraints as ID of IVC was less than 2" which may be suitable for low producers.
Special KMH tool designed and E-line utilized for real time monitoring during trouble shooting of TRSSV with broken flapper and successfully resumed the well accessibility for workover operation. Wireless technology can improve the accuracy of response and safety system of wells with limitation of relatively less flow specially in gas wells with scale challenges. Such approach may avoid the work over in case of more accurate control.
Sustainable Removal of Re-Occurring Scale & Corrosion Products by Textural Analyses Using Petrographic Thin-Sections: A New Cross-Disciplinary Application of a Traditional Geological Technique
Authors: Hujer Wolfgang , Kadnar Rainer , Hönig Stefan 
Published: October 2022

Abstract
Corrosion and scale products are frequently encountered in the oil & gas industry and often are main concerns regarding flow assurance. They form due to chemical conditions that are in most cases not within the operational specifications. The same chemical conditions are quite often also responsible for corrosion failures. Removal of scale and corrosion products is often a time-consuming process including a significant proportion of human work in areas with high HSSE-risks; e.g. cleaning of tanks. Furthermore, the interruption of production processes is generally accompanied by financial losses. Scale and corrosion products form due to environmental conditions that are often outside the normal operating conditions (Burns, 2016). Therefore, identifying those conditions can be very challenging and if the reason(s) for scale/corrosion product formation are not discovered they are likely to occur again. The detailed analyses of the texture as well as mineralogical-chemical composition of scale and corrosion products and fluids present can provide valuable information on formation conditions. This information can be crucial to identify reasons for scale precipitation or corrosion thus providing involved experts with the knowledge to prevent recurring issues with both.
However, our own experience has shown that analytical programs of scale & corrosion products are often not designed to answer the most important question why they have formed are missing. This can result in reoccurring formation of scale & corrosion products and repeated cost-intensive removal.
Three crucial points have been identified strongly influencing the quality of scale & corrosion product analyses and interpretation. These points are:
Sampling Analytical methods used Interpretation of results
In course of the described case studies, a work-flow has been used that aims to ensure to avoid any failures in the identified crucial points. This work-flow will be discussed based on the experiences from the case studies with special emphasize on description of sampling, application of individual analytical methods including utilization of petrographic thin-sections and integrated interpretation of the results together with the customer.
Unlocking Oil Reserves from Inaccessible Platforms Utilising DSL (First Implementation in Egypt)
Authors: Koriesh Mahmoud Mohamed , Elwan Mahmoud , Shahin Eman , Basyouni Ali , Soliman Hamdy , Okasha Osama , Saleh Mohamed , Heaney Frank 
Published: October 2022

Abstract
Offshore Oil accounts for 30% of the world's liquid hydrocarbon production. As offshore platforms age, as is the case with some of the production facilities in the Gulf of Suez, these structures will have a increased load restriction, which makes it difficult to perform simple interventions, and forces the operator to deploy a Jackup rig or do a barge assisted operation. Some identified opportunities are not performed due to the high cost and the inherent subsurface uncertainty with brownfield assets. An alternative solution is a new generation intervention tool that allows signal transmission on conventional slickline wire.
Real-time slickline (DSL) perforations use a unique technology to allow signal transmission on a standard slickline. The technology uses downhole battery-powered telemetry embedded in the downhole tool string. A radio-frequency (RF) antenna installed below the stuffing box is responsible for sending & receiving RF signals through the wire. The wire is coated with a proprietary engineered coating to ensure quality signal transmission and protects against corrosive wellbore fluids. The technology allows real-time depth correlation, pressure, temperature & vibration measurements while perforating. Moreover, the technology offers on-command explosive triggering, which improves safety over the older memory/timer version.
Real-time slickline perforating was successfully introduced in the Gulf of Suez, accessing two platforms with structure load weight limitations that could not accept a conventional e-line unit. The optimized weight of digital slickline equipment was only 8 tons, compared to 35 Tons for e-line. Two wells were successfully perforated on two different platforms, adding 1200 BOPD at 10% of the rig-assisted intervention cost. The real-time slickline deployment enhanced the intervention efficiency and saved $950,000 in operating expenses.
In addition to the successful deployment of several perforation runs without operational problems, the additional capabilities of DSL for surface readout (SRO) pressure & temperature data allowed the operator to optimize the time on the platform and maximize efficiency. The ability to add feedthrough jars to the string helped complete one job when the tool BHA struggled to get into the tubing after perforation. This capability is not available in conventional E-line.
Real-time slickline (DSL) operations are the next generation for rigless interventions providing access to wells that e-line could not cost-effectively intervene and complete this task at a much lower cost.
Implementation of Autonomous Ground Robots on Operational Sites
Authors: Bartoli Eric , Munoz Jean Michel , Audouin Gregoire , Collin Gildas 
Published: October 2022

Abstract
One of the missions of the TotalEnergies’ R&D is to pave the way for tomorrow's simpler, streamlined and less expensive facilities. The vision is focused on unmanned installations in which autonomous ground robots are key components.
In 2017, the ARGOS (Autonomous Robots for Gas and Oil Sites) Challenge delivered the first prototype of a new generation of autonomous, ATEX-compliant ground robots capable of detecting anomalies.
Based on this success, TotalEnergies started a few projects with the aim to introduce and standardize robotics on O&G sites.
The first project is the development of a series of autonomous robots, designed to withstand the rough O&G environment for long durations: an inspection robot and an operator robot.
The second project is the adaptation of the standard methods of engineering operations for green-field developments as well as preparing the implementation of robots on brownfields.
The third one is the development of a specific environment to remotely supervise a fleet of robots operating simultaneously on a same site.
A major take away for the success of robotics implementation is increasing the technological readiness as well as usability and acceptance of the whole robotics operation system. This can be verified only through exposure to users in a realistic environment.
After each major development, their proper achievement is measured following a robust process of observation in different contexts. An incremental approach for trials was implemented from testing in specific laboratory conditions up to long duration pilots on major installations under the custody of the future users. Those complex tests are a tremendous source of deep insight in understanding robotic operations and allowing the research to be pushed further towards a more practical solution for the petroleum industry.
The presentation will highlight the first tangible results from the operational implementation and prototypes testing of robots and the readiness of robotics for Oil and Gas.
The experience gained by TotalEnergies in developing Robotics Operations through testing it extensively in various industrial contexts, represents a unique case with this large scale of usages. It was already shared with some of our peers and this paper is a great opportunity to expose to the Oil and Gas industry to our vision of how to prepare the future of unmanned, safe and environmentally friendly operations.
Curing Packer Leak Riglessly Using Bismuth: Results of the Field Pilot
Authors: Yugay Andrey , Ahmad Bilal , Akhtar Mohamed Masud , Vorozhikhin Sergei , Almuharrami Abdulla Omar , Nadeem Amir , Varshney Mayank , Agarwal Apurv , Al Harmoodi Eisa Abdelaziz Abdalla 
Published: October 2022

Abstract
The concept of the well double barrier envelope is a common industry practice and main philosophy of well integrity discipline. This is well-described in some of the international standards: API RP90 (1 & 2), Norsok D10, ISO 16530 (1 & 2).
This double barrier policy applies to wells with positive pressure at surface capable to flow naturally. Primary barrier envelope consists of well equipment which is continuously under pressure and in direct contact with hydrocarbon. In case primary barrier element fails, secondary barrier envelope will be the one exposed to well media and holding the pressure. This content of this paper is related to such kind of wells that can flow naturally and should comply to the double barrier policy.
Any failure in the primary barrier envelope (means - completion) normally is addressed during workover by simply re-completing the well with new completion (after retrieval of the old one). This can be done almost unlimited number of times, as long as there is a place to set the packer. Failure in the secondary barrier envelope (means - casing) can be repaired as well, but not that easy and very limited amount of time. In some cases, especially for onshore wells it might be economically more reasonable to drill the new well rather than to deal with complicated workover. Depending on the Company policy, casing integrity can be restored in sections using casing patches or the entire length can renewed by running and cementing casing of smaller diameter. Obviously, in both cases it impacts the size of the completion, further well objectives and cannot be done multiple times.
Be in Control of Your Operation - Integrating Real-Time Optimization with Advanced Process Control for Optimum Energy Management and Optimization
Authors: Singh Arvin 
Published: October 2022

Abstract
Owner operators are tasked with the challenge of maximizing energy efficiency and overall energy management for highly complex and integrated operations, to which the downside has cost industry millions of dollars yearly. To realize optimum value of energy management and optimization, delegates will see how real time optimization is crucial with respect to advanced process control for complex operational conditions - not just integration, but what" to do" and "not to do".
Using an integrated approach of real-time optimization and advanced process control, delegates are shown the value of advanced process control, and under what scenarios real time optimization supports, compliments, and drives the overall energy optimization opportunities operationally. Demonstrated through successful industry use cases, the focus will be on identifying the right architecture and the right decision-making processes required for optimum energy optimization, including core considerations and limitations faced by the industry. Further, this paper will explore and articulate operational challenges faced during design, implementation, and scaling - providing delegates the insight to both the risk and reward.
This paper will detail the result of successfully integrated real time optimization and advanced process control architectures, providing different levels of return to operational requirements and complexity. Using core industry use cases, delegates will be able to see both the successes and lessons learned of the applied architectures reflecting different operational conditions. In conjunction, this paper will re-emphasize the design and deployment requirements for success, pivoting around the limitations of advanced process controls within certain operations.
To this effect, this paper will highlight the main return on investment opportunities to delegates, focusing on maximizing profits and production whilst minimizing overall utility costs. With complex integrated operations, delegates will get an insight into these tangible potentials and how they can benefit from different architectures which address different operational requirements from an energy management and efficiency domain.
From Drawing Board to HP award, the Success Story of Annular Injection Mixer (AIM) Using CFD
Authors: Maktar Fariz , Chauvet Christian , Sabey John 
Published: October 2022

Abstract
Annular Injection Mixer has proven to have superior performance in providing rapid and uniform vaporization of liquified petroleum gas (LPG) fractions into natural gas. This article focuses on presenting the validating process of evaporation performance of Annular Injection Mixer (AIM) via computational fluid dynamics (CFD) simulations to meet client requirements. Evaluating the dynamics and kinetics characteristic of droplets’ evaporation has always been a challenging aspect. This is where CFD simulations had the leverage over the conventional 1D process simulators.
This challenge was tackled in two steps using CFD simulations. The first step was the determination of droplet size distribution. Multiphase modelling was conducted with Volume of Fluid (VoF) model. A buffer zone was introduced downstream of the "knife-edge". In this buffer zone, an in-house script was developed to instruct the CFD software to generate droplets based on the incoming liquid characteristics. With information such as liquid volume, surface tension, and liquid velocity within this buffer zone, the droplets’ size was determined and reinjected into the domain as Lagrangian particles.
The second step was modelling the droplets’ secondary break up and evaluating the droplets’ evaporation. Droplet size distribution measured from the first step were reinjected downstream of the "knife-edge". Based on the latent heat of vaporization and local flow conditions surrounding each droplet, droplet break-up and later evaporation into natural gas were simulated. Evaporation length and homogeneity of LPG vapour within the natural gas were some of the other crucial criteria evaluated. These steps were conducted at each extremity of the operating envelope ensuring a consistently reliable and robust vaporization performance of the AIM.
Additionally, the CFD setup was fine-tuned, through adjustment of the Weber number, and validated through flow loop testing. The commercial system resulting from the initial CFD study and technology optimization has been in operation for more than 2 years.
This methodology of validating the AIM evaporation performance via CFD has not only provided prompt responses to any client operating needs but also has reduced the development cost and lead time by minimizing experimental assessments. This innovative approach in AIM development has led to multiple awards accumulated over the years, most notably, the Hydrocarbon Processing (HP), downstream processing sector's leading technical journal, awards for Best Gas Processing LNG technology in 2021.
A Successful Rigless Water Shut Off Solution in an Open Hole Horizontal Water Injection Field in the Sultanate of Oman Using a Water-Swelling Polymer System
Authors: Khalil Mohamed Amin , Al Kharusi Sharifa Nasser , Persac Stephen , Al Harthi Hamood , Al Naabi Ahmed , Al Mufarji Hilal 
Published: October 2022

Abstract
Premature water breakthrough between injector and producer wells through natural fractures can be a significant challenge leading to poor waterflooding performance in fractured reservoirs. Thus, applying a cost-effective Water Shut-Off (WSO) technique to stop injected water from flowing into fractured zones has become paramount to increasing production from mature fields and enhancing hydrocarbon recovery from such reservoirs by modifying the injection profile.
This paper presents a successful chemical WSO solution designed to help improv injection systems’ sweep efficiency by stopping injected fluids in waterflood fields from flowing into fractured or highly vugular zones, leading to direct communication with the producing wells. Each water injector well supports two to three oil producers forming a horizontal waterflood pattern. Since the early days of injection, water cut has increased dramatically, reaching almost 100% in some producers to indicate direct communication through the fracture network.
The treatment consists of bullheading a water-swellable agent into the injection well along with an aqueous solution to swell the agent. The agent is a synthetic polymer capable of absorbing 30 to 400 times its weight in water to seal off the fractures without penetrating most matrix systems. The carrier fluid helps determine the agent's swelling rate, and a shutoff period is required to give enough time for the polymer swelling to take place.
After the treatment, the injection pressure response was observed between 200 psi to 600 psi at the same injection rate. Water cut dropped gradually; a drop of 0-15% in water cut was observed in the nearby producers, resulting in an oil gain up to 100 Bbls in some of the oil producers. The result was a cost-effective treatment, producing more bbl. of incremental oil in one year.
This paper will discuss the job planning process along with the treatment design. The treatment execution is summarized, followed by the results obtained from the job's realization with key lessons learned and recommendations.