bluuebunny/crossref_metadata_2025_split huggingface dataset:
Value of Condition Monitoring Data in Safety Management Decision Support
Authors: Jeeves Simon 
Published: November 2018

Abstract
ValveWatch can be a powerful tool as part of an operational strategy, as it provides valuable information that can be used to track operational Safety according to IEC 61511/508 (Functional Safety Assessment - SIL – Safety Integrity Level).
Within an operating plant, Functional Safety Management for automated on/off valves, PSVs and manual valves it is required to understand why the valves fail and how it is possible to mitigate these failures. The common factor is that the Faults that one has experienced i.e the valve/actuator has failed to carry out its intended task has caused a loss in production or a reduced the level of safety that the plant has been operating under. – These are expensive lessons and lessons that are repeated often.
The reason why these "lessons" get repeated is because the failures that have been experienced are due to hidden failures that are not possible to discover with traditional instrumentation (I.e limit switch, Partial Stroking, opening/closing time). In the terms of IEC 61508 these faults are categorized as DU Faults (Dangerous Undetected). Often these faults may have been introduced due incorrect maintenance, incorrect operation of the valve/actuator or simply due to wear and tear.
Critical valves have requirements with respect to functional testing and also perhaps through leakage tests. The manual methods in testing are flawed and it is difficult to uncover the DU's and even the DD (Dangerous Detectable Faults). Furthermore, the manual tests are often carried out when there is no pressure present, hence the valve is not tested under realistic conditions.
Case Study of Pilot Application and Efficiency Analysis of Waste Heat Recovery from Gas Engine Generator Jacket Cooling Water to Heat Waxy Multiphase Fluid at Offshore Platform
Authors: Kenoth Sasidharan Adiyodi , Kottappuram John , Henry Samuel Isaac 
Published: November 2018

Abstract
The oil and gas industry is in continuous look out of innovative means to improve the efficiency of its energy-intensive oil- and gas-processing operations through improved energy use and waste-heat recovery. This paper details about an integrated pilot application of two waste-heat-recovery units designed and implemented in an Offshore platform off Caspian Sea. Actual results are compared with simulation / design results. A thermodynamic analysis of a gas generator engine waste-heat-recovery cycle is carried out.
The offshore platform has a water injection plant supporting water flooding project for reservoir pressure maintenance. The Sea Water Lift and Main Injection Pumps are powered by multiple Gas Engine Generators of @ 1000 kW power rating. The exhaust gas from each of these gas engine contains approximately 10 million Btu/hr recoverable heat. Also the heat energy from the jacket cooling water used for engine cooling is used for heating the waxy crude oil and natural gas. A Shell & Tube Heat exchanger is used for recovering the heat energy.
By utilizing the heat energy of flue gas and jacket cooling water the energy efficiency of gas engine can be doubled from 35% to 75 %. Two such Gas Generators with Heat Recovery system has been introduced which collectively creates an energy saving of approximately 1500 KW daily for crude oil heating. Approximately 8000 bbl oil with 100 scf/bbl gas oil ratio was able to heat to get a temperature differential of 25-35 degree C. The cooling water temperature was dropped to 60 degree C.
With rising fuel costs, energy conservation has taken on added significance. Installation of waste heat recovery units (WHRU's) on gas turbines is one method used in the past to reduce gas plant fuel consumption. More recently, waste heat recovery on multiple reciprocating compressor engines also has been identified as having energy conservation potential. This paper reviews the development and implementation of a WHRU potential. This enhance hydrocarbon recovery, and reduce utility cost in a plant.
In an era when energy conservation and fuel shortages are not uncommon, mechanical systems designed to improve the thermal efficiency of fuel-consuming equipment have become a necessity. This paper presents an energy efficient process and mechanical design along with footprint saving.
9.2 MW GLC Compressor Motor Starting – Use of Induction Motors
Authors: Manna Malay , Kotrappa Murugendrappa N. , Al-Ammari Sara Jamal 
Published: November 2018

Abstract
The electric motor for the Gas Lift Compressor is 9.2 MW, 4-pole construction, and induction type. The motor rated voltage is 11kV, fed from 33kV switchgear via a captive 33/11.5 kV, 15 MVA transformer.
A review has been performed to examine the feasibility of the gas lift compressor (GLC) motor starting with below starting methods, and to highlight advantages and disadvantages among the starting methods: –With pony motor during motor start-up–Direct On Line (DOL)–With additional auto-transformer
The study results indicated that the GLC motor is able to start up successfully with either type of above motor starting methods.
Motor starting with pony motor is technically feasible. However, the pony motor starting method is not a common practice for induction motor, it requires additional equipment including pony motor, 415V VFD for the pony motor and MV Panel with Capacitor Bank.
Motor starting Direct On Line is the simplest option; it takes the advantage of the mechanical variable speed drive (Vorecon unit) design, i.e. the motor and the compressor is disconnected during motor starting, and the motor starting loading torque is limited below 5% of rated load torque. The motor is able to start up successfully with acceptable upstream bus voltage dip during normal operation and even when one major component of the power system network is out of service. In the cases with two or three components of the power system network out of service, the motor is still able to start up with upstream bus voltage dip exceeding the project limit but less than 15%. This is considered acceptable technically as the other running motors will not stall.
Motor starting with additional autotransformer will improve the upstream bus voltage dip during motor starting marginally, but further extend the motor starting duration.
Rigless Pulling Unit - First Time Worldwide, A New Concept for Workover and Recompletion
Authors: Sreeroch Asadawut , Nicolson Don , Abu Jafar Feras , Charoensil Teeranun 
Published: November 2018

Abstract
In a global first, Mubadala Petroleum in Thailand has successfully completed a three-month trial of a new technology designed to improve the operational performance of the regular program of well maintenance workovers required for its Gulf of Thailand fields. The trial tested the use of an innovative modular Rigless Pulling Unit (RPU) in place of a conventional Hydraulic Workover Unit (HWU) in a program of workover operations.
Historically, the RPU used by most operators worldwide for Plug and Abandon (P&A) type of operation. However, Mubadala Petroleum has pushed the technical limits for the RPU to perform ESP change out and running upper/lower completions (Re-completion) on existing wells that has ESP failures, or any recompletion opportunities.
During the trial period, this new unit achieved similar operational efficiency to a HWU, while proving its capabilities to execute the most complicated tasks that are challenging even for the HWU, in terms of reducing rig time, well cost, and most importantly minimizing the HSE risks. This technology can be developed to be a "fit for purpose" intervention method for the future workover, recompletion and decommissioning activities. The utilization of RPU for a long well services campaign, for post-drilling completions, for slot recoveries and for a decommissioning campaign will have more potential of cost saving vs using the Rig or HWU.
With this first worldwide successful trial of a RPU for well workover operations, we have opened the doors for new opportunities to perform workover activities other than with standard hydraulic workover rigs. The RPU technology offers many advantages and capabilities to perform more efficient complex workovers or recompletion operations.
Material presented is from actual workover operations, including electrical submersible pumps (ESP) change outs and cycling lower completions, wellbore cleanout, etc. It will also display the operational efficiencies increase and risk reduction achieved.
Maintenance Job Plan Alignment Using 5S Lean Process
Authors: Sianipar Tumpal , Pande Girish , Thonnan Thodi Shameer Babu 
Published: November 2018

Abstract
As part of the ADNOC Gas Processing Sustainability Program – Enhance Maintenance Strategy, the review of Maintenance Job Plans across all sites was one of the top action items for implementation. The objective of this task was to align the maintenance practices to achieve an agile, efficient and fit-for-purpose maintenance program across all sites. This included the review of job plan activities, man-hours and skill level.
The lean management process with 5S was adopted for the implementation of this task; the process was progressing through the cycle elements i.e. sort, set, shine, standardize and sustain. The "As-is job plans" were segregated by equipment type during the "Sort" stage. The order of review priority was set based on the highest manpower spent using the Pareto principle. Non-value added tasks were removed during the "Shine" stage. The job plans across all sites were then aligned to deliver "To-be job plans" which brings in a standardized approach. To ensure the standardization across all sites, the job plan codification procedure was developed. Such job plan codes library will be centrally controlled and updated by the focal point who will be the custodian of corporate job plans. In the "Sustain" phase, periodic reviews will be conducted to ensure sustainability over current and future of asset maintenance practices.
As the quantum of job plans to be reviewed was very large, the task was divided into two phases. The first phase included a review of quick win items that covers job plans that spent 80% of man-hour, while the 2nd phase was for the remaining job plans. Phase-1 has been completed successfully which included pre-defined 10 equipment type. Phase-2 is well in progress, slated to be completed by quarter 4 of 2018.
As a result of the phase-1 project, the numbers of job plans were significantly reduced to 119 from 3851 which contributed to man-hour optimization of approximately 15 %.
This task enabled us in aligning the practices across the sites, optimizing man-hours in asset maintenance and achieving synergy in maintenance policy adoption. This task will eventually lead us to have optimized, comparable and fit-for-purpose maintenance practices at all sites, which will improve the efficiency and profitability of the maintenance organization.
Holistic Study to Identify Root-Cause of Corrosion in Christmas Trees of Oil Producer Wells
Authors: Kumar Amit , Al Dahmani Ahmed , Kunhi Shaheen , Iqbal Asif , Amad Muhammad , Morrow Timothy 
Published: November 2018

Abstract
During field inspection of Christmas (X-mas) trees in a giant oil offshore field in Abu Dhabi, a small subset of wells were reported to be severely corroded on X-mas tree studded outlets imposing high HSE risks due to possible loss of containment. A holistic analysis was conducted to identify corroded X-mas trees, establish the root-cause of corrosion and recommend a remedial action plan to control future corrosion damage and reduce HSE risk exposure.
Advanced modeling tools and lab tests were used to analyze the flow behavior and field samples, respectively. Advanced modeling was performed to analyze inorganic scale potential, identify flow regimes and calculate corrosion rates in the X-mas trees to correlate with operating conditions. Solid samples from X-mas trees were analyzed using advanced microscopy techniques to identify the elemental composition and phases. Water samples were also analyzed to check bacteria content. Available data on historical operating conditions, modeling and lab analysis results were segregated into in-favor and against factors for each of the mechanisms to identify the potential root-cause of corrosion. Modeling results were used in conjunction with actual field data such as corrosion feature morphology, historical operating conditions, etc. to evaluate corrosion damage. Based on corrosion feature morphology, wells were categorized into different groups to compare the flow behavior and operating conditions with observed corrosion patterns.
A thorough analysis of corrosion feature morphology and operating conditions identified flow-induced localized corrosion (FILC) as the root-cause of corrosion in severely corroded X-mas trees. X-mas tree design, fluid properties and operating parameters such as well head pressure (WHP), wellhead temperature (WHT) and flow rate were found to be key contributing factors of accelerated corrosion. Results of computational fluid dynamics (CFD) modeling showed that the horizontal section of X-mas tree is exposed to higher turbulence, water wetting and transient gas bubble formation/collapse phenomena than the vertical section due to changes in flow direction and gravity effects. Several mitigation strategies were implemented to control corrosion in the X-mas tree flange area, and reduce likelihood of leakage through the X-mas tree flange. Findings from this work led to development of an Excel based tool which can be used to assess and predict the corrosion risks to X-tree based on operating conditions.
Best Design & Engineering Practices to Enhance Centrifugal Compressor Reliability
Authors: Abbas Zafar , Kumar Yogesh 
Published: November 2018

Abstract
Centrifugal compressors are vital part of industry due to wide range of their application and operating flexibility. However several challenges are encounterd in all phases from FEED, construction, commissioning to smooth operation. ADNOC-onshore Sahil oil and gas production facility has gone through major expansion in 2013 allowing to enhance its production capacity by 55%. During FFD commissioning and start up of centrifugal compressor during FFD has been challenging. Several breakdowns, equipment & auxiliary failures and start up hurdles have been faced, which extended equipment shutdown durations to few weeks causing the O&G production company to loss thousands of barrels of oil production and hence suffer huge financial loses. During the course of time several innovative solutions were devised and successfully implemented to address these challenging issues. This paper describes these failures with solutions, which are common with similar machines, so that these vital interventions are considered and integrated into design and engineering practices to enhance centrifugal compressor reliability. Critical part of this problem is sub-vendor's provided components and subsystem. These systems have been seen to have performance and capacity issues along with deisgn and safety system incompatibilities. Maintenance, inspection and replacement of such parts are challenging for O&G production companies owing to local market constraints and vendor unavailability.
Design and engineering practices by OEM, EPC, sub-supliers and oil & gas production companies need immense improvements for bumpless commissioning and startup of such critical equipment. A multi-descipline engineering team from manufacturer, constrction and O&G producuction & process companies with very specific responsibilities pertinent to design, construction and operation reviews at all stages, would play vital role to overcome such issues.
This team would closely monitor all key activities for precision and design amendments, during construction-commissioning, startup and smooth operation phases, in order to avoid these issues in 1st place. This would results in tremendous savings(in terms of losses minimization and early & smooth production) to the O&G producuction Company as well as all involved vendors and Construction Company, by timely commissioning the compressor, ensuring smooth start up and maintain bumpless operation.
Three-Phase Flow Visualization and Characterization for a Mixed-Wet Carbonate Rock
Authors: Scanziani Alessio , Alhammadi Amer , Bijeljic Branko , Blunt Martin J. 
Published: November 2018

Abstract
A novel method is presented to characterise in situ three-phase flow, including wettability, pore occupancy and displacement mechanisms, at the pore scale. We used X-ray microtomography to obtain 3D images of a carbonate reservoir rock saturated with crude oil and formation brine at subsurface conditions. The sample had been aged with crude oil from the same reservoir to replicate the sunsurface wetting conditions. The pore occupancy analysis shows that brine is non-wetting to oil and gas is non-wetting to brine with a wettability order of oil-brine-gas from the most to the least wetting fluid. The waterflood recovery after 1 pore volume injected was only 14%, but this increased to 48% after further gas injection. New multiple displacement mechanisms were observed, with gas displacing brine, which in turn displaces oil. The results from this work can be used to improve the prediction accuracy of the three-phase network models and helps in the design of gas injection processes.
Project Knowledge Harvesting: The Case of Improving Project Performance through Project Knowledge Sharing Framework
Authors: Al-Awadhi Rima , Tharayil Abdul Jaleel 
Published: November 2018

Abstract
Driven by KOC 2040 strategy, the process integrated approach to project knowledge sharing is evolving to be the knowledge-sharing model in KOC. It integrates with various organizational process and policies such as Project Gate System and Performance Excellence and Change Management. KOC is one of the largest crude oil exporter in the world, and managing highly complex multi-million dollar projects over the last 80 years. Therefore, managing critical project knowledge is vital to the success of the project and the organization. However, due to the very nature and complexity involved, each project engagement generates a lot of ‘learnings’ that need to be factored into while new projects are initiated and thus avoid repeating the same mistake. Nevertheless, many a time these learnings are localized and remains as ‘tacit knowledge’ leading to scope re-work, schedule overrun, adjustment orders and claims. While KOC follows an asset based organization structure, with a multi-cultural and multi-ethnic workforce and larger chunk of the work is carried out through complex, long term project engagement, diffusion of ‘learnings’ across assets while dealing with the natural entropy of the organization is of great significance. The project knowledge harvesting through process-integrated approach encompasses knowledge assessment and prioritization, knowledge mapping and classification, user engagement, branding and communication, knowledge exchange with service providers, quality control through collaborative review and publishing process including a quick demonstration of the lessons learnt sharing & reuse platform.
A Biomarker and Isotopic Study of the Source Rock Organofacies, Oil Families, Source-oil Correlation and Thermal Maturity of Cenomanian Petroleum Systems in the Offshore Abu Dhabi
Authors: Amo Miki , Taniwaki Takash , Yamanaka Motoyoshi , Kato Ayato , Shinbo Emiko , Shibuya Setsuko 
Published: November 2018

Abstract
Crude oils and rock samples from Cenomanian carbonate oil field (Field A) in the offshore Abu Dhabi were investigated in order to define oil families, paleoenvironment, origin of organic materials and thermal maturity because the origin of crude oils and their thermal history in this field has not been understood well. Especially, maturity profile in this area has not been determined yet because the source rocks don't contain enough amount of vitrinite due to the dominance of marine organic matters. Field A has two culminations above OWC: North structure and South structure. Therefore, we investigated oils from both structures to figure out the geochemical features of each culmination. The Cenomanian carbonate rocks of Field A are composed of shallow marine porous limestone (reservoir rocks) and deep marine lime mudstone (seal rocks and source rocks). Saturated biomarkers (n-alkanes, isoprenoids, steranes and triterpanes) of crude oils from shallow marine porous limestone and core samples from deep marine lime mudstone were determined using gas chromatography-mass spectrometry (GC/MS), gas chromatography-mass spectrometry-mass spectrometry (GC/MS/MS) and gas chromatography-combustion-isotope ratio mass spectrometry (GC/C/IRMS). Ternary diagrams of C27-C29 steranes of all oil samples and core samples show significant similarity among crude oils and source rocks in Cenomanian age. High amount of C30 sterane and the ratio of C27-C29 steranes suggest that the crude oils were generated from Cenomanian marine source rocks. Biomarker maturity parameters such as Ts to Tm ratio and diasterane (Dia) to regular sterane ratio (Reg) were slightly different among the crude oils. The crude oils from South structure were slightly more maturated than those from North structure. The stable carbon isotopic values of individual n-alkanes in the crude oil would be classified into two crude oil families: dominance of lighter carbon in North structure and relatively heavier carbon in South structure. These results were consistent with the results of biomarker maturity parameters such as Ts/(Ts + Tm) and Dia/(Dia + Reg). Thus it was confirmed that the crude oils of North structure and South structure were from same Cenomanian source rock, however, thermal maturity of the crude oils were slightly different between North structure and South structure.