bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhancing Operational Safety Through Mechanization and Intelligent Automation of Drill Floor Operations
Authors: Mwansa Peter Levison , Varma Esha Narendra , Grayson Paul , Norton Justin , Webber Daniel , Ligardo Emmanuel 
Published: December 2021

Abstract
Our rig crews regularly work around structures that pose risks such as dropped objects and pinch points. HSE and operational performance is highly dependent on human performance. Human performance or human factors have resulted in a relatively high frequency of serious Health, Safety and Environment (HSE) incidents associated with tubular handling on ADNOC Onshore rigs. An example is the fatality on a rig in Abu Dhabi while preparing to run casing in February 2018.
We believe we can prevent major incidents, enhance efficiency and reduce risk by removing our people from harm's way through mechanization and intelligent automation of drill floor activities. The objective of this work is to reduce the human factor as low as reasonably practicable through mechanization and intelligent automation of tubular handling operations on ADNOC Onshore rigs.
An incident prevention workshop recommended a technology search to enable hands free operations and reduce the human to machine interaction as much as reasonably practicable. A quick market research and a "Go, See, Assess" exercise with ADNOC Shareholders revealed several potential offerings on the market. ADNOC Onshore collaborated with two major technology providers and jointly designed a mechanized set up for ADNOC Onshore land rigs. The solution involved the use of mechanized equipment such as Casing Running Tools complete with hydraulically actuated single joint elevators, hydraulic catwalk, automated power slips, remote operated tong system with supporting alignment systems, air operated elevators, remote operated stabber, etc.
The solution was successfully implemented on multiple rigs. The mechanized set up reduced the number of people in the so called RED Zone by 50% (Stabber, Tong Operator, Thread Inspector and Floor man) during casing and completion running operations. Other benefits realized include:
Reduced reliance on human performance Reduced risk of harm to people due to dropped objects and pinch points on the rig floor Assured consistency in executing repetitive tasks such as running casing, etc
This level of mechanization and intelligent automation is a first in the ADNOC Group, represents a STEP CHANGE in operational safety and has transformed how we do our business, underpinning HSE as priority number one.
Maximizing Production by Perforating with Accurate Dynamic Underbalance Using Electric Coiled Tubing Offshore Egypt
Authors: Ghonim Ahmed ElSayed , Elfarran Amr Zeinhom , Okasha Osama Aly , Haridy Ehab Mohamed , Koriesh Mahmoud Mohamed , Mousa Aly ElBasyouni , AbdelSabor Ahmed Gaber 
Published: December 2021

Abstract
This paper represents a challenging rig-less intervention in highly deviated wells with heavy oil that has always been a challenge to conventional electric line (e-line) that is not a valid intervention technique due to its inherent limitations in these harsh environments. Electric Coiled Tubing (E-CT) was utilized not only to achieve safer deployment of the guns, but also to allow real-time operations on three wells which were inaccessible due to heavy oil content and restricted e-line accessibility.
A case study is presented for a campaign performed using E-CT to convey the perforating string while pumping nitrogen (N2) to lift the well and achieve flowing under-balance to maximize perforation clean-up and minimize skin. Real-time readings from gamma ray, pressure and temperature sensors were used to accurately position the guns, generate the desired dynamic underbalance, and finally validate successful detonation based on pressure and temperature responses. This was achieved while N2 lifting and firing the guns to optimize the required under-balance value providing immediate feedback related to the production gain to determine the zonal contributions and maximize the economical production gains. Dynamic wellbore behavior software modeling was also used to predict the dynamic under-balance effect for maximizing perforation efficiency.
Deployment of E-CT was very challenging in terms of operational execution but was extremely beneficial for the safety of the pipe during such operations. A total of 13 runs comprising of milling, tubing cleaning and drifting were performed to remove the accumulated scales inside the production tubing and to ensure full accessibility to target intervals. Coiled Tubing (CT) dynamic modeling software was utilized to simulate the N2 rate needed to achieve the target underbalance while maintaining safe perforating parameters for the CT while firing the guns. As a result of software simulations, one of the three wells was then recommended for an acid wash treatment which achieved very effective results.
15 perforation runs were performed on the three wells re-perforating a total of 188 ft of interval, resulting in a production increase of more than 300%. This was a significant improvement compared to the previous campaign carried out in 2017 where perforating in static conditions showed no increase in production without work-over rig intervention. E-CT intervention also eliminated the need for waiting on rig schedule and avoiding deferred production.
Development of a Digital ESP Performance Monitoring System Based on Artificial Intelligence
Authors: Diker Göktug , Frühbauer Herwig , Bisso Bi Mba Edna Michelle 
Published: December 2021

Abstract
Wintershall Dea is developing together with partners a digital system to monitor and optimize electrical submersible pump (ESP) performance based on the data from Mittelplate oil field. This tool is using machine learning (ML) models which are fed by historic data and will notify engineers and operators when operating conditions are trending beyond the operating envelope, which enables an operator to mitigate upcoming performance problems. In addition to traditional engineering methods, such a system will capture knowledge by continuous improvement based on ML.
With this approach the engineer has a system at hand to support the day-to-day work. Manual monitoring and on demand investigations are now backed up by an intelligent system which permanently monitors the equipment. In order to create such a system, a proof of concept (PoC) study has been initiated with industry partners and data scientists to evaluate historic events, which are used to train the ML-systems.
This phase aims to better understand the capabilities of machine learning and data science in the subsurface domain as well as to build up trust for the engineers with such systems.
The concept evaluation has shown that the intensive collaboration between engineers and data scientist is essential. A continuous and structured exchange between engineering and data science resulted in a mutual developed product, which fits the engineer's needs based on the technical capabilities and limits set by ML-models. To organize such a development, new project management elements like agile working methods, sprints and scrum methods were utilized.
During the development Wintershall Dea has partnered with two organizations. One has a pure data science background and the other one was the data science team of the ESP manufacturer.
After the PoC period the following conclusions can be derived: (1) data quality and format is key to success; (2) detailed knowledge of the equipment speeds up the development and the quality of the results; (3) high model accuracy requires a high number of events in the training dataset.
The overall conclusion of this PoC is that the collaboration between engineers and data scientists, fostered by the agile project management toolkit and suitable datasets, leads to a successful development. Even when the limits of the ML-algorithms are hit, the model forecast, in combination with traditional engineering methods, adds significant value to the ESP performance.
The novelty of such a system is that the production engineer will be supported by trusted ML-models and digital systems. This system in combination with the traditional engineering tools improves monitoring of the equipment and taking decisions leading to increased equipment performance.
Managed Pressure Drilling and Underbalanced Drilling Compounded Role in Solving the Exploration and Appraisal Challenges of Biogenetic Gas Resources in the United Arab Emirates -Case Study
Authors: Al Mutawa Ahmed , Hamdy Ibrahim , Al Shamisi Eias Daban , El Yossef Bassem , Amin Mohamed Sameer , Nunez Ygnacio , Saleh Mujahed , Hadj-Moussa Ayoub 
Published: December 2021

Abstract
Biogenic gas resources have gathered importance recently due to its widespread availability, occurrence at geologically predictable circumstances, and existence at shallow depths. It is estimated that biogenic gas forms more than 20% of the global discovered reserves. However, the exploration and development of these unconventional resources come with numerous drilling and reservoir challenges. This paper showcases a novel approach used in the United Arab Emirates to overcome these challenges using managed pressure and underbalanced drilling.
To tackle both reservoir and drilling challenges, a hybrid solution combining Underbalanced (UBD) and Managed Pressure Drilling (MPD) was applied. UBD was used to characterize the reservoir in terms of pressure and productivity index to ultimately enhance productivity by eliminating formation damage. MPD was used next to continue drilling through the problematic zone which had high instability due to the presence of highly sensitive salt, in addition to the presence of high pressure and loss zones. The fit for purpose hybrid application design allowed the operator to immediately switch between UBD and MPD conditions, as the well required with the same equipment.
Three of the four targeted formations were in the 8 ½″ hole section, UBD was selected to drill the first reservoir formation which allowed pore pressure verification and avoided using excessive mud weight that was the culprit of many challenges like slow ROP, drilling fluid losses, bit balling, and fracking the formations. UBD has proved that mud weight can be reduced by 20%-30% comparing to conventional drilling. The second formation was a salt formation that has caused previously hole collapse and losses-kicks problems as heavy mud used to drill this salty formation. MPD used successfully drill this section by constant bottom hole pressure and lower mud weight as it was found from analyzing offset wells reports that hole collapse occurred at connections and pump off events. Constant Bottom Hole Pressure (CBHP) also eliminated tight spots and excessive reaming resulting in optimized drilling. The third formation used MPD as well to minimize overbalance pressure over previous sections while the fourth formation was drilled by UBD as it had a separate 6″ hole section as it formed an independent reservoir.
The combined MPD and UBD approach eliminated most the NPT encountered in offset wells, enhanced Rate of Penetration (ROP) by 200% to 300% and slashed the well drilling time by 27 days.
The Future of Learning
Authors: Cesaro Mario 
Published: December 2021

Abstract
The unexpected discomfort caused by Covid-19 pandemic and all the consequent government restrictions on travels and social distancing have pushed all the Training Organizations worldwide into an unusual challenge, being forced to support their Customers from afar.
This work aims to thoroughly analyze the success of the Remote Learning methodology, highlighting key factors impacting the learning curve, and to share effective improvement ideas for this approach to deliver training focused on technical and human skills.
Many companies reacted to this situation by investing largely in and increasing the adoption of digital technologies to facilitate internal and external communications and more specifically to support Remote Learning. However, despite the prompt response, many Training Organizations found themselves delivering their products through a series of trials, mistakes and lesson learned on methodology and tools.
The detection of few but significant improvements increased effectiveness and improved interaction in our Remote Classes. The improvement actions concerned learning how to make the most of the available digital technologies and identifying the most effective applications for sharing documents and interacting with participants; at the same time, a great focus on the human skills approach was crucial to learn how to promote trust, motivation and interaction between our staff and Customers’ personnel.
In this perspective, Operator Training Simulations (OTS) and Remote VR Training have emerged as one of the best applications to increase the attendees’ learning curve and help develop Customers’ personnel skills.
Our study, however, isn't all about bright stars. The feedback told us that some Customers still prefer to take in-person training classes rather than remote ones. Sometimes this relates with biases against remote or digital activities, but it often applies where hard activities need to be performed.
Maximizing Condensate Production Opportunities in a Giant Stacked Reservoir-Case Study
Authors: Al Agbari Zainah Salem , Al Yaaquibi Nouf Sulaiman , Sudarev Maxim , Mohamed Ihab Nabil , Al Hosani Mariam Ahmed , Latypov Eduard , Al Bairaq Ahmed Mohammed 
Published: December 2021

Abstract
This paper addresses the opportunities of maximizing the condensate production in a giant Recycle Gas-Condensate Reservoir in UAE. The condensate reservoir is producing many years under recycling mode to maintain the pressure and maximize the gas condensate recovery. The producers and injector wells are in a line drive pattern where the injected fluid is lean gas to maintain 100% VRR. The condensate production declined through the years due to gradual pressure decrease as well as injected lean gas/N2 breakthrough. Several studies were done to increase condensate recovery and extend gas production plateau.
Achieving Operational Efficiencies from a Centralized Alarm Management System
Authors: Al Mahmoud Mahmoud AbdulHameed , David Joseph Sylvester Pius , Jaffer Askar 
Published: December 2021

Abstract
Alarm Management Systems ("AMS") have been adopted in the oil & gas industry where several benefits were realized. Such as improved panel operator effectiveness, maintaining higher levels of plant uptime and integrity, reducing the number of abnormal situation. Which ultimately leads to higher asset productivity.
Several OPCO have multiple operational assets/sites that are geographically diverse. Where each asset might have a different Integrated Control System ("ICS") due to the time and availability of technology at the time of commissioning. Requiring diverse locally implemented AMS.
A unified CAMS thus reduces time and effort to develop, deploy, and maintain alarm systems and is an essential toolkit for enhanced safe operation of the plant.
Some sites have multiple plants wuth common pocess control section. The process control enginners needs to visit individual plants access DCS alalrms. By carryinhour corporate alarm management, engibbers at their office PCs have the access to the DCS alarms.
Implementing CAMS requires the presence of a robust data presence infrastructure in place. Notably a centralized plant information management system, where several real time data points with regards to alarms and operator inputs can be captured.
A CAMS unifies the approach of how alarm management is conducted in the company. Where a CAMS system generates a set of standard and custom templates that highlight the performance of each operating asset/shift/panel operator. Providing insights into the performance of each asset, efficiency of each operational shift and response of the panel operators. That when addressed, will lead to an overall performance and production of the operational asset.
With this alarm management data, it can be further enhanced through data analytics to identify areas where operational efficiencies can be achieved. Additionally, the CAMS reduces the times and effort to deploy an alarm management system for any future operating asset expansions.
CAMS coupled with real time data and Machine learning algorithms, past behaviours of the plant can be correlated, which can then be utilised for future predictions on alarms. This would further enhance our data driven decision-making, and would reduce the dependence on personal driven decisions.
It can be concluded, that the CAMS is worthy investment for operating companies that have geographical/ICS diverse operational assets.
Circular Economy in the Oil and Gas Exploration and Production: Resource Recovery from Drill Cuttings and other Oily Wastes
Authors: Castilla Alejandro , Zeuss Michaela , Schmidt Michaela 
Published: December 2021

Abstract
With an increasing awareness of minimising the environmental footprint combined with the inclusion of circularity in the oil and gas industry, stricter laws and therefore more rigorous treatment targets will have to be implemented in the waste/resource management. Increasingly complex solid and liquid waste streams result in the further need to implement safer, more advanced technologies. Emission levels, resource recovery, energy efficiency, worker safety, and input material flexibility will become key assessment factors. The vacuum thermal desorption process allows for the recovery of resources from different industrial hazardous wastes. At the core of the process is a specially designed vacuum evaporator chamber utilizing indirect heat and controlled vacuum to evaporate contaminants. With this process, resources can be recovered and solids/mineral fractions decontaminated therefore minimising the hazardous waste and bringing valuable resources back into the value chain. A wide range of input materials, independently from their consistency, can be treated using the same process, as a result of the batch-wise working principle of the vacuum evaporator. The process reduces air emissions derived from two sources. One originates from the thermal oil heating system (flue gas), the other from the vacuum desorption process (exhaust). For the latter, in an oily waste recycling facility that processes approximately 30,000 tonnes per year, &lt;&lt;100 m3/h are emitted, of which on average 96 % are nitrogen. Regarding resource recovery, typical output material parameters include clean solids with a TPH (up to C40) content &lt; 0.5 %, oil in product quality with a recovery rate &gt; 99.5 %, and clean water for moistening of the solids. Highest energy efficiency is achieved because the vacuum reduces the boiling point of the hydrocarbons by more than 100 °C. In addition, the recovered oil can be used as fuel to run the equipment. In conclusion, resources will be recovered and therefore hazardous waste reduced, emissions decreased and highest safety for workers observed. Aside from the above stated advantages of using indirectly heated thermal desorption, this process also offers the possibility to be operated using renewable energy. Therefore, guaranteeing zero emissions supporting the health & safety of our environment and its people.
Redefining Light Weight Structural Design for Gas Marginal Field Development Through Conductor Supported Platform CSP Concept
Authors: Wong Shiiun Bak , Alias Nur Dalila , Arif Mohd Kamal , Shabazi Majid 
Published: December 2021

Abstract
The rise of offshore marginal field development and low-cost CAPEX has given an impetus to O&G operators to challenge the common structural platform design especially for wellhead platform type. Demand to reduce the platform weight has been observed for the past 20 years. Typically, the challenge to meet this demand will be tremendous once the water depth exceed 50m. This paper will elaborate on how using an engineered design approach was implemented to obtain fast track onshore fabrication and offshore installation and meet the operator demand for minimal structural concept.
Integrated Project Management Approach for Production Well Tie-In in Upstream Projects-Case Study
Authors: Nair Sreekumar , Thebet Salah , Al Obeidli Ibrahim , Adi Mohamad Bara , Al Reyami Maher , Al Romaithi Ebraheem 
Published: December 2021

Abstract
Al Dhafra Petroleum Operations Company Limited, (Joint Venture between ADNOC and KADOC, established in late 2013 and assigned with Onshore and Offshore concession areas in Abu Dhabi) had the challenging task to achieve the sustainability of crude production to 40,000 BOPD by end of 2020 from their Haliba field. Current production profile with available wells could not meet that target, for which additional 4 production well Tie-in and construction of 8 km 6″ flow line became necessary within next 3 months. Regular Tie-in program may complete the first Tie-in only by Q2, 2021 and no possibility of enhancing this Tie-in works by 2020.
Al Dhafra Management has appointed the Project Management Team (PMT) to take up the challenge by attempting many methods and the timeline was very limited (approximately 90days) to obtain First Oil from those wells.
Wireless Coiled Tubing Disrupts the Industry by Enabling Use of Conventional Coil Tubing for Access and Matrix Acidizing of Multilaterals and Extended Reach Carbonate Reservoirs
Authors: Saeed Abubaker , Fellinghaug Jarl André , Bouldin Brett 
Published: December 2021

Abstract
As the number of Extended Reach Wells (ERW) with multilaterals and restricted access due to electric submersible pumps (ESP) increases, so does the challenge to enable access and stimulation to these wells to maintain production rates. This paper describes a Slim Access and Stimulation System (SASS) development program launched to develop a game changing technology to give operators the ability to maintain high production rates in unconventional developments. There is available technology today to accurately access extended reach lateral wells, even with restricted access. But the technology is limited to logging only, as the tools and/or control wire are not acid resistant and would limit the pump rate through the coil tubing for pumping acid. The new system would require a tool suite which was acid resistant, enable slim access to the laterals, and have the ability to perform multiple stimulation jobs in one run, with monitoring and control from surface without a wire inside the coiled tubing. The SASS development program gave birth to three separate and revolutionary new technologies: two-way wireless communication and energy harvesting with integrated production logging suite, slim and high-power open hole tractor with a wire bypass to power the tool string, and semi-autonomous lateral access sub, which finds, enters, and confirms the lateral access. The three game changing technologies have application as standalone products, however the real value occurs when they combined as a Slim Access and Stimulation System, run on conventional coiled tubing. The paper will describe working methods and technology incorporated to provide access to restricted extended reach laterals and perform multiple stimulation jobs in a single run. The SASS development program is a testament of how the industry can tackle complex challenges, introducing new technologies across in multiple domains while still adapting to conventional methods. The paper highlights the full system design approach method used to understand and combine features of downhole tools, surface equipment, and operational and handling routines to achieve the overall design goal.