bluuebunny/crossref_metadata_2025_split huggingface dataset:
Collaborative Working Environment CWE Strategy: An Enterprise Approach to Operational Excellence
Authors: Ibrahim ElFadl Z. , Al Hendi Mariam A. , Al-Qamzi Abdulla , Ballaith Nasser A. , Al Naqbi Maha A. , Al Azawi Bahir , Al Hammadi Omar I. , Traboulay Ian , Muhamed Salim Muzahidin , Dewan Rashi 
Published: December 2021

Abstract
Collaborative Working Environments (CWE) are a business solution that improve the quality and speed of decision making by enriching the collaboration between teams and individuals, which results in tangible business benefits. The advantages of working in a collaborative environment are well understood in the organization and the concept is widely embraced throughout the petroleum industry.
CWEs provide seamless communication between disciplines and between teams in different locations. Traditionally, they have been used to connect staff in remote locations to teams in the headquarters, allowing real time monitoring of the health of the field, and fast decision making on operational issues and short to medium term optimization opportunities. The main goal is to be quickly alerted to events and make smarter, faster decisions using key capabilities available to the company with access to all relevant knowledge, data and analytical tools required to reach a decision. But this drive to make smarter, faster decisions is applicable to all levels of a company. In fact, it becomes increasingly important as more complex decisions are required at higher levels, which can be influenced by interpreted data, personal opinions and perceptions.
In line with strategic objective of digital transformation, a national oil company (NOC) has extensive plans to develop asset specific CWEs and enterprise level CWEs. These will be centralized collaboration facilities to provide more rigorous, effective, and consistent surveillance & optimization to help reduce deferment costs and inefficiencies and accelerate decision-making with a measurable business value to enhance HSE, Reservoir, Drilling, Well and Production system performance through emerging digital innovation. All these centers shall be equipped to receive real time and episodic data and perform exception-based surveillance through trending, analysis, and condition diagnosis. All these CWE Centers shall enable decision making with efficient multi-disciplinary collaboration to address business challenges and increase the efficiency of day-to-day operations. They will have clear roles and responsibilities serving as an integral element of the value realization across the assets.
The paper will describe the enterprise CWE strategy, key technical considerations, methodology and standards that have been set up to achieve the ultimate objective of the organization to maximize oil field recovery, eliminating non-productive time, enhancing HSE aspects and increasing profitability through the deployment of these various centers.
Successful Deployment of Metal Expandable Technology with Inner String Stage Cementing System Overcomes Well Construction Challenges in Bab Field, UAE
Authors: Mwansa Peter Levison , Varma Esha Narendra , Aguilar Victor Jose , Amorocho Alexander , McPherson Daniel , Wood Kevin , Khodr Omar 
Published: December 2021

Abstract
Inability to effectively isolate depleted aquifer formations due to severe losses during cementation leads to accelerated corrosion of the production casing. Per current practice, a top job is performed from surface to fill the annulus with cement, but with limited success in a severe losses’ scenario. The objective is to improve zonal isolation by applying V0 rated multiple stage cementation technology with inner string thus enhancing well integrity during the life cycle of the well.
A metal expandable annular sealing system was selected as a reliable isolation mechanism for effective cementation behind aquifers due to its ability to provide high expansion in potentially washed-out wellbores and the feature of long multi-element sealing systems with built in redundancy. The inner string operated stage cementing system provides a reliable solution to selectively and accurately place cement above the metal expandable packer whilst maintaining V0 casing integrity once closed. Additionally, the unique combination of technologies provides a cost-effective life of well solution compared to current stage cementing methodologies.
Following successful execution of three trial jobs, the multi-stage cement using V0 rated tools and an inner string was compared to similar jobs done per current cementing practices. Analysis involved reviewing the cement bond column coverage and quality (CBL) with offset wells.
Cement bond log results showed that this technique enhanced the cement column quality behind the 9 5/8" casing across the aquifer zones with moderate to good cement for the most part. Contaminated cement was observed just below the previous casing shoe and this could be addressed by adding another stage tool just above the previous casing shoe. Overall results show improved cement column quality for this section when compared to conventional jobs with similar conditions and is recommended for future use in severe to total losses scenario. In a situation where losses are seen at the previous casing shoe, a three-stage job is recommended.
Other benefits include:
Security and confidence in gas tight sealing capability and mechanical integrity Precise and conclusive operation for open, close and lock with no risk of accidental lock Ability to squeeze cement below the metal expandable packer No reduction in pressure rating regardless of OH ID and full bore ID of casing No post operation drill out required of the stage tools
V0 stage cementing tools with inner string and metal expandable annular sealing system are not available on Oil & Gas market as a single tool. Therefore, this combined technology application of solutions from different technology providers to access a dedicated solution is totally novel and creates an opportunity for future applications across the industry.
Asset Integrity Management - Implementation Plan During Front End Loading Phases
Authors: Ferrario Giorgio , Grimaldi Salvatore 
Published: December 2021

Abstract
Capitalization of lessons learned on Asset Integrity Management during Front End Loading phases of a green field Project Development, by defining plan for implementation of a diagnostic digital tool for reducing downtime and introduce predictive maintenance during Operation.
Eni developed a platform of Digital applications for enhanced Operations management by implementing an Integrated Asset Management (IAM) system. Advanced Analytics tool is part of it and is designed for monitoring, foreseeing and preventing production upsets and anomalies; the tool is set up by verification of areas of interest and criticalities, with identification of main equipment data sets and by the implementation and validation of predictive models. Starting from historical data, data scientists supported by experts develop algorithms capable of finding interdependencies between a set of input variables and an output variable (phenomenon to be predicted/monitored), thus detecting anomalies and criticalities.
Main areas of benefit are envisaged on Production continuity, capable of predicting problems on static and rotating equipment and giving information on the most impacting variables on the incipient problems. The tool will support technicians to help them preventing failures and out-of-specs events which may cause loss of production or asset integrity issues, with the activation of predictive maintenance and the aim to strive a continuous monitoring and improvement of plant operational performances. An Energy Efficiency predictive model will also be set up, capable of forecasting the future energy performances of the asset through the prediction of the Stationary Combustion of Carbon Dioxide (CO2) emission index (t CO2/kbbl) and providing the list of the main influencing equipment and variables. The plan for implementation of the tool from the Early phases of development help the organization on prioritizing the implementation of Digital tools as part of the execution and realization of the Asset to be delivered to the Operational personnel, by easing the transition and avoiding subsequent retrofitting carrying brownfield works and additional costs.
The implementation of Advanced Analytics tool has been embedded in a new green field initiative of a Development Project since Front End Loading phases, thus fostering digital implementation and minimizing deployment costs by including those as part of the Investment Proposal presented to Joint Venture Partners and Authorities.
Case Study of Identifying and Minimizing Formation Damage in Tight Reservoirs Caused by Drilling Fluids in Abu Dhabi Onshore Operation Using Compatibility Coreflood Studies
Authors: Saragi Raymond , Husien Mohammad , Abdullah Dalia Salim , McLaughlin Ryan , Patey Ian , Green Justin , Wright Leigh 
Published: December 2021

Abstract
A study was carried out to examine formation damage mechanisms caused by drilling fluids in tight reservoirs in several onshore oil fields in Abu Dhabi. Three phases of compatibility corefloods were carried out to identify potential to improve hydrocarbon recovery and examine reformulated/alternate drilling muds and treatment fluids. Interpretation was aided by novel Nano-CT quantifications and visualisations. The first phase examined the current drilling muds and showed inconsistent filtrate loss control alongside high levels of permeability alteration. These alterations were caused by retention of drilling mud constituents in the near-wellbore and incomplete clean-up of drilling mud-cakes. Based upon these results, reformulated and alternate drilling muds were examined in Phase 2, and there was a positive impact upon both filtrate loss and permeability, although the Nano-CT quantifications and visualisations showed that drilling mud constituents were still having an impact upon permeability. Candidate treatment fluids were examined in Phase 3, with all having a positive impact and the best performance coming from 15% HCl and an enzyme-based treatment. The interpretative tools showed that these treatments had removed drilling mud-cakes, created wormholes, and bypassed the areas where constituents were retained. The compatibility corefloods on tight reservoir core, alongside high-resolution quantifications and visualisations, therefore identified damaging mechanisms, helped identify potential to improve hydrocarbon recovery, and identify treatment fluid options which could be used in the fields.
Deployment of State-of-the-Art Horizontal Pumping System HPS Technology in Two Water Wells to Avoid ESP Workovers
Authors: Alrabeh Majed Nahed , Samsudine Zulkiflie Bin , Ruvalcaba Velarde Salvador Alejandro , Alhajri Faisal Mohammed 
Published: December 2021

Abstract
The objective of this paper is to present the findings obtained from a detailed engineering evaluation resulting from trial testing two state-of-the-art surface horizontal pumping systems (HPS's) in two water supply wells. The two horizontal pumping systems were deployed as an alternative to downhole electrical submersible pumps (ESPs) to provide the benefits of eliminating ESP workover costs, modularity regarding wellsite deployments, and enhanced maintenance operations.
For this trial test evaluation method, two HPS's were deployed to boost water production to the water injection plant (WIP). To ensure a thorough evaluation, the trial test well candidates were designed to accommodate both a subsurface ESP as well as a surface HPS to provide an accurate comparison, and representation, between the different artificial lift methods. The trial test and comparison method described in this paper focused primarily on the following items; maintenance and well intervention requirements, evaluation of operational availability, including potential for cavitation and effects of interference, maximum production rates, as well as root cause engineering evaluations for mechanical seals and cooling unit auxiliary motors. Various best practices and mitigation measures were identified and are presented in this paper.
With regard to the results, it was observed that each artificial lift method comprised a set of advantages and disadvantages. The decision on which type of technology to use can be dependent on several factors. Overall, the HPS's demonstrated the ability to supply water production to the WIP. The HPS did experience operational challenges in providing higher production requirements. Additional challenges were also observed in the sealing mechanism as well as the auxiliary cooling unit. Precautionary pump tripping automated protocols were taken to prevent pump cavitation due to sub-optimal intake pressure resulting from possible interference. The HPS, unlike the ESPs, did not require any workover as it is located at the wellsite and therefore resulted in substantial cost savings and was easy to maintain due to its surface application.
In summary, this paper adds a new and very beneficial evaluation of HPS's, and highlights best practices and lessons learned to the existing body of literature. The new information discussed in this paper is highly beneficial to engineering selections of artificial lift methods and to the successful implementation of HPS's in the industry.
Boosting Gas Processing Energy Efficiency by Waste Heat Recovery
Authors: Al Ketbi Waneya Abdulla , Sajjad Saqib , Al Jenaibi Eisa Salem 
Published: December 2021

Abstract
A continual improvement in energy efficiency of existing plants is imperative to achieve ADNOC target to reduce greenhouse gas emissions (GHG) intensity of operations by 25% in year 2030. The waste heat recovery (WHR) from incinerator stacks of existing Sulphur Recovery Units (SRUs) in ADNOC Gas Processing exhibits a substantial potential & contributor of energy savings and emission abatement. A high level assessment was carried out for various heat sources, results showed substantial WHR potential can be availed from SRUs. Consequently, a feasibility study was carried out to evaluate several options to recover energy from incinerator stacks of existing Sulphur Recovery Units (SRUs). The feasibility study addressed three options of recovering energy from SRUs incinerator stack exhaust; generating saturated steam, generating power and combined solution of steam & power. Those options were assessed in terms of technical feasibility and commercial viability.
The study indicated that steam generation by HRSGs is technically viable and economically feasible, and considered as the best option for WHR from the existing SRU Incinerator Stacks. The WHR benefits that can be realized from just one incinerator stack by recovering the waste heat and reducing the flue gas temperature by 400 °C only (from 700 to 300 °C) are: More than 80 TPH saturated HP steam generationFuel gas savings and corresponding monetary benefitsSignificant abatement in GHG emissions
The study revealed that WHR does not pose acid condensation risk due to the safe margin between the acid dew point and the actual flue gas temperature. The study also established that other constraints like pressure drop, space, tie-in location and emissions dispersion are not the showstoppers.
Developing Next Generation Petrotechnical Professionals in the Age of AI
Authors: Agbaji Armstrong Lee 
Published: December 2021

Abstract
The most common challenge facing the oil industry in the Age of AI is talent scarcity. As digital transformation continues to redefine what it takes to work in the industry, staying relevant in the industry will require knowledge and understanding of the underlying technologies driving this transformation. It also requires a re-evaluation of how next generation petrotechnical professionals are nurtured, educated, and trained. The human talent that is needed in the Age of AI is different, and simply obtaining a science or engineering degree will no longer suffice to survive and thrive in the industry. While it is vitally important that students continue to take fundamental engineering and science courses and learn industry-specific skills, we must recognize when an existing curriculum or way of teaching and learning has either run its course or has evolved.
This paper examines how artificial intelligence will impact the training and development of the industry's future workforce and what organizations must do to retain existing talents while at the same time developing new ones, so they are not rendered irrelevant by AI. It proposes novel ways by which practical digital transformation and energy transition technologies can be integrated into core oil and gas education and training curriculum. It also outlines various innovative ways that academic institutions can join forces with industry to educate and train technical professionals, who, right out of college are sufficiently grounded to analyze, evaluate, and communicate data findings to drive better business decisions. For students and young professionals, it lays out the roadmap to readiness, and how to thrive in a digitally transformed world, as well as several ways to robot-proof their career and stay ahead of the curve.
The task of training industry leaders of the future is enormous, sensitive, and demanding. The ability of next generation petrotechnical professionals to succeed in the digital age, and compete in a data-centric world, depends on their ability to develop, adopt, and apply next generation skills. Having the right mix of skills is not only essential to their success, it is critical to the survival of the industry. In the Age of AI, classroom learning needs to be deemphasized and experiential learning needs to be emphasized.
The workforce of the future will be dominated by people with analytics skills and capabilities. Preparing next generation professionals for the future of work calls for a re-evaluation, re-design and recasting of the synergy between academia and industry. Universities and industry will need to routinely intersect to create symbiosis and enhance our educational system. Success will depend on sustained partnership and collaboration, not merely shifting the problem to one another.
An ESP Production Optimization Algorithm Applied to Unconventional Wells
Authors: Bermudez Fernando , Al Nahhas Noor , Yazdani Hafsa , LeTan Michael , Shono Mohammed 
Published: December 2021

Abstract
The objectives and Scope is to evaluate the feasibility of a Production Maximization algorithm for ESPs on unconventional wells using projected operating conditions instead of current ones, which authors expect will be crucial in adjusting the well deliverability to optimum frequencies on the rapidly changing conditions of tight oil wells.
Actual production data for an unconventional well was used, covering from the start of Natural Flow production up to 120 days afterwards. Simulating what the production would be if a VFD running on IMP Optimization algorithms had been installed, new values for well flowing pressures were calculated, daily production scenarios were evaluated, and recommended operating frequencies were plotted.
Result, observations, and conclusions:
A. Using the Intelligent Maximum Production (IMP) algorithm allows maximum production from tight oil wells during the initial high production stage, and the prevention of gas-locking at later stages when gas production increases.
B. The adjustment of frequency at later stages for GOR wells is key to maintaining maximum production while controlling free gas at the intake when compared against controlling the surface choke.
Novel/additive information:
The use of Electrical Submersible Pumps for the production of unconventional wells paired with the use of a VFD and properly designed control algorithms allows faster recovery of investment by pumping maximum allowable daily rates while constraining detrimental conditions such as free gas at the intake.
Unlocking the Potential of Electrical Submersible Pumps: The Successful Testing and Deployment of a Real-Time Artificially Intelligent System, for Failure Prediction, Run Life Extension, and Production Optimization
Authors: Bermudez Fernando , Al Nahhas Noor , Yazdani Hafsa , LeTan Michael , Shono Mohammed 
Published: December 2021

Abstract
This paper is a summary of the collaborative work between a Gulf Cooperation Council (GCC) national oil company (NOC) and Nybl, a deep tech development company, and the results of applying Nybl's proprietary science-based AI to the GCC NOC ESP wells in real-time applications. The paper demonstrates the potential benefits of the real-life application of AI / Machine Learning in conjunction with traditional Petroleum Engineering concepts and algorithms to predict imminent and future failures, extend and monitor run life, and maximize the production of Electrical Submersible Pumps (ESP's). This paper will highlight the NOC's innovative approach to pilot new technology through successful deployment on 27 wells, spread onshore and offshore, in real-time, with prescriptive actions.
Acoustic MEMS Transducers: Look Ahead of the Bit and Geopressure Monitoring
Authors: Turolla Axel , Zampato Massimo , Carminati Stefano , Ferrara Paolo 
Published: December 2021

Abstract
This paper describes the design and implementation of Acoustic Micro Electro Mechanical Systems (hereinafter referred to asA-MEMS)working in fluid-coupling mode for HP/HT specifications relevant to downhole applications such as drilling, well and reservoir monitoring. Many cutting edges applications ofA-MEMS in Oil & Gas industry are envisaged. The current work refers to the case study of a "Look Ahead of the Bit"/geopressure monitoring technique (hereinafter referred to asPPM) developed by the authors.
A–MEMS with magnetic shuttle transducers have been designed so that they are not affected by environmental pressure like piezoelectric devices commonly used in MWD commercial sonic tools, which are impaired by volumetric shrinking/expansion working principle. This performance is also achieved by embedding an environmental pressure compensator tuned in the whole working bandwidth to grant pressure balance even with oscillatory motion at sonic frequencies (up to 5 kHz). Transmitter acoustic power and receiver sensitivity have been optimized in a bandwidth between 500 and 3500 Hz.
A couple of A–MEMS prototypes have been built and successfully tested by using an oil filled pressure vessel at downhole T–P conditions (200 °C, 700bar) and an ad-hoc measurement setup including force, displacement, temperature sensors, transmitter (TX) driver, receiver (RX) lock-in amplifier and anacquisition system. Moreover, modal analysis at typical drilling conditions has been carried out by Stewart platform. Shock up to 1000 g and random vibrations up to 12 g RMS in 5 ÷400 Hz bandwidth have been tested. A–MEMS performance have turned out to be consistent with theoretical model predictions andhave exhibited robustness to T P variations and applied structural stress.
PPM method has been validated through a triaxial compression cell in a rock mechanics laboratory, implementing a lab scale scenario with a cap rock located above a permeable rock, undergoing all geopressures of interest. However, piezo transducers used in the experiment underwent a significant failure/damage rate along with performance degrading at pressure increasing. These observations confirmed and motivated the need for A-MEMS technology development in downhole applications.