bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evidences for the Formation of Aromatic Hydrocarbons in Claus Process from Contaminants in H2S Feed Gas
Authors: Raj A. , Mohammed S. 
Published: November 2015

Abstract
Claus process is used in oil and gas industry to produce sulfur from H2S. The presence of aromatic contaminants in its feed is believed to have detrimental effect on the process, as they are able to survive the high-temperature environment of Claus furnace and reach the catalytic units, where theyform soot, clog catalyst pores, and deactivate them. Along with aromatics, small hydrocarbons (CH4, C2H6, and C3H8) are also present in feed that are capable of forming polycyclic aromatic hydrocarbons (PAHs) and soot in anoxic, high-temperature environment of the furnace. In this work, a detailed reaction mechanism with 258 species and 1695 reactions for Claus feed containing H2S, aliphatic andaromatic hydrocarbons, CO, CO2 and H2O is developed. The mechanism includes reactions for PAH formation (up to coronene) from hydrocarbons, H2S oxidation, and the interaction of hydrocarbonswith S-containing species. The mechanism is validated using experimental species and aromaticsprofiles. Through furnace simulations, the fate of aromatic contaminants and the amount of PAHs formed from hydrocarbon contaminants are determined.
Utilization of Mega Projects & Major Equipment's Manufacturers for People's Development
Authors: Bin Hamoodah Ali G. , Omar Samir , Sherif Mohamed Aly 
Published: November 2015

Abstract

Objectives/Scope
Pioneering in tackling business challenges like ageing facilities; matured reservoirs, emerging technologies, high demand on the oil, workforce numbers associated with mega projects and to meet Emiratization target, ADMA-OPCO utilized mega projects and major equipment manufacturer's as opportunities for the development of qualified national engineers. Over 50 years, ADMA-OPCO as an Oil and Gas producer in offshore areas is evolving through proven and systematic development approaches like this.

Methods, Procedures, Process
ADMA-OPCO initiated and utilized a new strategy with a defined process established a roadmap on how to utilize the ongoing mega projects in the development of UAE national engineers to reach specialist / expert level. This strategy calls for integrating ADMA's employees with contractor's team to deliver project tasks as contractor employee's capacity in delivering project scope.
The process covers several sub-processes like; nominating right engineers to right projects at the right time using right criteria; A committee to establish clear roles & responsibilities of all stakeholders; Define clear scope of work for engineers assigned with project; Sign work agreement between all parties; Performance follow up throughout the assignment; Compensate engineers based on their achievement.

Results, Observations, Conclusions
Of five engineers reached specialist level three Rotating Machinery engineers became gas turbines specialist. Two other engineers proved competent to function as Project Management team members with a mega offshore project; corrosion & material selection and rotating machinery engineering.
Further two more engineers become engineering team leader and operation team leader for the same project after its completion.
The assignment also developed four project engineers and they have reached project managers post within 5 years.
Success including more than 20,000 man-days (121 Engineers) during the last 3 year and the practice extended to cover additional engineers from other ADNOC operating companies for more than 2,400 man-days.

Novel/Additive Information
The delivered tasks like 132 KV offshore electrical cable and subsea pipelines calculations are very advanced topics which are new to oil & gas production companies.
The paper also demonstrates the established proven process details its key success factors including the preparation and execution phases along with the built in assurance mechanism. It will also reveal the types and level of the quality deliverables achieved by UAE's national Engineers in almost all disciplines.
Successful Application of Reverse Gunk Pill to Cure Losses in Basinal Limestone with Interbedded Marl and Shale Formation Drilling Offshore Abu Dhabi
Authors: Ryan J. , Akyabi K. , Saleh M. , Omgbu J. , Kustanto S. , Ivan C. , Mihalic B. 
Published: November 2015

Abstract
A giant oilfield offshore Abu Dhabi is being further developed with artificial islands and extended reach drilling (ERD). Several lost returns events while drilling the intermediate intervals using non-aqueous fluid (NAF) have occured. NAF and high mud weights are required to stabilize the shale intervals in the overburden due to high inclinations, but have increased the frequency and severity of the mud losses.
To prevent losses while drilling with higher mud weights, combinations of sized ground marble, fibers, and resilient graphite are used to reinforce the NAF fluid to control losses in the formation. With the reinforcement material added to the NAF losses were still experienced on some wells.
Traditional leak off type loss circulation material (LCM) pills were trialed but unsuccessful. Due to the NAF damaging the permeability of the rock, treating losses with NAF mud are difficult because the leak off rates are reduced. Reverse gunk was selected as a good option to treat losses in NAF due to the fact that it does not require leak off to cure the losses. The reverse gunk pill relies on downhole mixing to build integrity.
Reverse gunk pills were used successfully in wells to build sufficient integrity to maintain shale stability mud weight. This enabled drilling through the unstable shales and to casing point. The successful application of the reverse gunk prevented the need for the contingency liner, which eliminated a hole section and allowed use of the originally planned completion size.
Risk Analysis for Integrated Asset Modeling to Support Decision-making: A Real Case Application
Authors: Cerri Paolo , Scaramellini Sara , Bianco Amalia , Masi Silvia 
Published: November 2015

Abstract
This paper shows a field application of the risked-based approach to an innovative tool based on a biogenetic algorithm for the integrated production optimization of surface facilities. The tool was applied to analyzed different solutions available in the PLEM configuration for a new well tie-in. Uncertainties related to a planned acid job on a well of the system has been taken into account in order to compare the probabilistic results of the analyzed configurations.
The described tool has the ability to integrate in a unique environment the whole production system, handling a high number of optimization variables simultaneously. In the first phase, the integrated optimization process with genetic algorithm takes place. The result is an optimized field configuration characterized by a deterministic production increase. In the second phase, after having identified the uncertain input variables in the optimization process, a Monte Carlo simulation for the optimized field configuration is performed. The result is a probabilistic distribution of the production increase. Different PLEM configurations have been compared on the basis of the probabilistic results obtained.
The integrated production model was developed for a FPSO treating the production from different subsea oil wells. An additional well was planned to be connected through an existing PLEM to the FPSO. Different configurations were analyzed to connect the well and the deterministic results from the optimization have been compared. Additionally, an acid job was planned for one of the wells in the system. The risked-based approach has been used to compare the different possible configuration to be applied, taking into consideration also the statistical distribution of the productivity index expected after the work-over. The probabilistic results obtained for the different configuration studied were characterized by a defined level of confidence and were used as a support in the decision making process for the tie-in of the new well.
The tool is able to take into account uncertainties related to work-over on wells and to evaluate different scenarios with a desired level of confidence. Results from the study show the strength of the presented innovative risked-based approach to the integrated asset modeling, as a tool to support the decision making process.
Ensuring the Life of Safety Critical Systems
Authors: Bain Rob , MacKenzie Hugh , Jones Callum 
Published: November 2015

Abstract
An assets firewater deluge system is critical in the operation of any Oil and Gas producing asset. Non-compliance can have wide ranging, negative impacts, varying from reputational damage, commercial losses and in the worst case loss of life. Keeping these safety critical systems in good working order gives personnel peace of mind that the systems designed to protect them will work when required and can be vital in giving time to evacuate an installation in case of emergency.
This paper will outline a two year project undertaken in a major UKCS field to ensure that five, thirty five year old installations safety critical systems were all compliant with the relevant industry regulatory standards. This will include remedial technologies deployed, challenges faced in completing a large scale project, asset integrity management systems formulated and technologies developed to ensure continued compliance to the operator. This will also highlight the options which an operator can have at its disposal to ensure ongoing compliance of its safety critical systems that have reached the end of their design life, ensuring they remain fit for purpose for a further twenty five years of life of the assets in question.
Meeting Ultra-Low Sulphur Dioxide Emissions for Projects Based on Sour and Contaminated Gas Reserves
Authors: Kidambi Ganesh , Chilukuri Pavan 
Published: November 2015

Abstract
Designing gas treating line-ups for liquefied natural gas (LNG) and natural gas liquids (NGL) extraction facilities with low hydrogen sulphide (H2S) to carbon dioxide (CO2) ratios in the feed is challenging. The complexity increases by an order of magnitude as the emission requirements become very stringent. Sulphur dioxide (SO2) emission requirements vary from a more typical 150 to 50 ppmv. The acid gas from the acid gas removal units (AGRU) in these facilities is typically very lean, whereas Claus sulphur recovery units (SRU) prefer rich acid gas feeds.
The presence of benzene, toluene, ethylbenzene, and xylenes (BTEX) and mercaptans in the original feedstock add an additional layer of challenges. It is necessary to maintain a sufficiently high temperature in the Claus furnace for the efficient destruction of these components. This may not be easily attainable with lean acid gases. In this scenario, it may be necessary to add an acid gas enrichment unit (AGEU) to the processing line-up. However, including an AGEU in the line-up would introduce AGEU off-gas containing H2S and mercaptans, which would be routed directly to the incinerator. This increases the SO2 that is emitted to atmosphere, therefore making it very challenging to meet stringent SO2 emission (&lt;50 ppmv) limits.
The conventional gas processing line ups are inadequate when dealing with difficult natural gas reserves in low SO2 emission regimes. This is especially true in the presence of organic sulphur (mercaptans and carbonyl sulphide (COS)) and BTEX. While bulk COS removal can be achieved with secondary amines, removal of mercaptans will require hybrid solvents like Sulfinol. The integration of gas treating process units and new breakthrough technologies are necessary to achieve optimal designs.
Shell's novel gas processing line-ups address these challenges head-on. This paper focuses on one such innovative integrated line-up and compares it with conventional line-ups for compliance with SO2 emission requirements.
The chosen line-up involves the Shell CANSOLV* TGT+ (tail gas treating plus) system, which is an integrated sour gas treating solution that can ensure ultra-low SO2 emissions (less than 10 ppmv), even for natural gas reserves containing unfavourable H2S/CO2 feed ratios and significant BTEX and mercaptan contamination. It also minimises the complexity of the process line-up.
In addition, the Shell CANSOLV TGT+ line-up can improve operational flexibility and the gas processing operating window at comparable capital cost.
Resource Nationalism: An Analysis of Four Energy Nations
Authors: Playfoot Jim 
Published: November 2015

Abstract

Objectives/Scope:
This paper seeks to explore the concept of ‘resource nationalism’ as it relates to four oil and gas producing countries. The drive to capitalise on hydrocarbon resources goes far beyond the sale of concession rights. An oil and gas sector run for and by the people is a vision that many countries share. This paper explores the case of four countries who have attempted to make that vision a reality and seeks to identify key lessons through that exploration.

Methods, Procedures, Process:
My approach has been to identify four countries - Brazil, Mexico, Nigeria and Iraq - and to then engage in extensive primary and secondary research (significantly informed by my participation in global events relating to the oil and gas sector in these countries) to understand how each nation has attempted to make real the vision of resource nationalism. Within this context, an analysis has been made of government policy, industry involvement and the contribution of the education and training system. Through doing this - and through a comparison of the four approaches - we can draw powerful conclusions about how a country rich in hydrocarbons is able to build an industry that truly serves the people of that country.

Results, Observations, Conclusions:
Analysis of the target countries identified reveals a complex picture and one that demonstrates the importance of an integrated approach to local content, local participation and skills development. In each of the four cases explored, the aim of the respective governments has been to build a nationally-led hydrocarbon sector through proactive policy, skills development and interaction with the private sector. The role of the national oil company has also, in each case, been critical. However, comparative impact has been mixed and lessons can be learned from both the successes and failures of these approaches. Ultimately, the ability of a country to fully capitalise on the social, economic and employment benefits of a thriving hydrocarbon sector will rest on a number of inter-connected factors that create the context for long-term, strategically driven programmes of workforce and skills development allied to coherent and well-implemented policies in relation to local content and a modern, dynamic national oil company.

Novel/Additive Information:
There has not been a study of this kind undertaken that explores the factors that contribute to resource nationalism and the role of education, local content policy and a national oil company in relation to the comparative strength and resilience of the hydrocarbon sector. By understanding this dynamic, governments, educators and the industry can achieve better economic and societal outcomes in oil- and gas-producing countries, particularly in those countries that are relatively new to oil and gas production.
A Plastic Plate to Protect Buried Pipelines
Authors: Joubeaux Yannick , Turion Alain 
Published: November 2015

Abstract
Third party interference (TPI) is clearly the main cause of accidents on buried pipelines. As shown in all international reports, it counts for 40 to 50% of all accidents on pipes.
Besides the most common solution used in Europe to prevent third party damages, i.e. concrete slabs, the need for a new solution appeared after an accident in Belgium in 2004: a gas pipe hit by an excavator bucket exploded and caused 23 fatalities, 132 casualties and considerable damages.
The French Government decided then to pass a law obliging the pipe owners (45,000 km of HP gas pipe) to make QRAs on their networks and to protect their existing lines where they came near to inhabited areas.
As using concrete slabs on hundreds of km in busy areas was just impossible, Yannick JOUBEAUX was asked in 2005 by the Direction of Research of Gaz de France to participate to a working group to imagine a new type of protection.
As it must be as resistant as a concrete slab, it was decided that it would resist the assault of a 32 tons shovel excavator. It was rapidly obvious that the only possible solution was a HDPE plate
It took time to get the right product but in 2009 the injected HDPE plate proposed by Yannick JOUBEAUX passed all the tests and was considered as an appropriate solution by the main French oil&gas and chemicals companies. The solution of an HDPE plate was also recognized as a valuable solution by the French government and included in the official regulations (GESIP 2008/02, rev. 2014).
As the plates used the injection technology, the pipe owners added new specifications, as holes to avoid discrepancies in the measurement of the cathodic protection, anti-slipping surface (embossed pins) and beveled edges to ensure the workers ‘safety, full yellow body color to guarantee a very efficient and durable warning.
Recognized as an efficient and relevant solution in France, HDPE plates now start to spread in Middle East, as being yet tested and approved by the major Saudi oil&gas company.
Infinite Plug and Perf - The Value of a Full Bore Degradable System
Authors: Aviles I. , Dardis M. , Jacob G. 
Published: November 2015

Abstract
Plug and Perforate is the number one stimulation technique used in unconventional reservoirs. This solution relies on the sequential pump-down conveyance and placement of plugs using Wireline to temporarily isolate sections of the well to be hydraulically fractured. After all the stimulation stages are concluded, plug removal is necessary to enable production. A milling assembly must then be passed into the well, usually by Coiled Tubing, to remove the restrictions used during the stimulation.
The inherent need for Coiled Tubing when using Plug and Perforate technique limits the process itself. This costly operation is required at the end of every well, as well as every time that a plug unintentionally pre-sets. In addition, on long horizontal wells, plug conveyance may be possible, but plug removal may not be possible. This is also true for wells with low reservoir pressure, where the risk of milling out plugs increases significantly. As an industry response, technologies based on dissolvable material have emerged as preferred solutions for increasing efficiencies and reducing operational risks. Degradable composite plugs, big bore plugs and cemented sliding sleeves are among the most notable. Nevertheless, these technologies are only partial solutions and often have major components that are not capable of being dissolved, having only incomplete dissolution. In addition, these technologies can be difficult to remove in the event of a pre-set, or after stimulation in case a later intervention is needed in the well.
A new fully degradable plug and perforate technology has been developed to solve the problems mentioned above. This new innovative method relies on material dissolution to avoid the need to mill out plugs. During fracturing, the new method follows the isolation process of the Plug and Perforate technique. After all stages are stimulated, the seat assemblies (or plugs) remove themselves by simple contact with flow back water; no mechanical remediation is needed. Immediate production is possible and the well is left with a full-bore ID. The ultimate production potential of the reservoir can be achieved as the complete assembly degrades away, leaving no restrictions in the well that can choke production and can prove problematic during any future workover intervention.
This paper discusses a new fully degradable isolation assembly for plug and perforate technique. The technology is explained in detail and field experience is presented to examine this technique over current industry alternatives.
Successful Management in New Offshore Field Startup: Meeting Challenging Targets and Exceeding Expectations
Authors: Shuaib M. , Al-Ameri A. , Zidan M. F. , Ahmed H. S. , Al-jaberi S. M. , Al-Kaabi F. , Al-Akbari S. , Okotie V. U. , Clemens C. , Hernandez E. J. , Kilic A. , Maalouf C. B. 
Published: November 2015

Abstract
The ultimate success of an offshore field startup depends on the strategy and integration within an organization. Even more challenging is managing the dynamic interface of subsurface and surface project delivery through the design, construction, hookup, commissioning, and startup operations. This paper presents the case study of a new field startup in Abu Dhabi from the early concept selection through the critical startup phases.
Integrated multi-discipline approach underpinned the successful startup when the field achieved first oil production ahead of schedule on February 2015 and exceeded expectation despite the backdrop of global sharp decline in oil price. This paper highlights the technical and functional preparation put in place by the subsurface and surface teams to ensure full integrated readiness and plan-in-place for production start-up. It also outlines the challenges encountered to achieve operational performance and the major lessons learned from the journey.
The results demonstrated in this paper shows that an integrated and cooperative approach is key in dealing with delays, prioritization, execution of processes, projects and operations. The lessons learned from subsurface and surface technical preparation, through surface project engineering and delivery phases are presented. Successful management was critical in handling the drilling rigs and barge logistics, offshore installation and commissioning phases, and simultaneous operations during the production start-up and ramp-up of the field. In addition, while encountering pressures to minimize rig time and execute the extensive data gathering program, good team synergy ensured that the milestones were successfully met even with the additional limitation of skilled technical resources.
Finally, illustrated in this paper are best practices applicable for new offshore field startups. This proves that even with the financial-demanding outlook and market-down conditions, the successful startup of a new field is essential and visible.
Embracing ESP (Ensure Safe Production) For Excellence In Process Safety
Authors: Khan Aamish J. 
Published: November 2015

Abstract
GASCO's leadership understands that Operational Discipline plays a pivotal role in achieving excellence in process safety & recognizes that it requires management commitment, resources, hard work & perseverance. But so does everything in this world, worth having! Excellence is never an accident. To achieve the objective of Operational Discipline, GASCO is embracing Ensure Safe Production Program, which makes sure that things are done right every time, without supervision.
Operational discipline & Process safety goes hand in hand. PSM (Process Safety Management) journey started by developing an Operational Excellence division, tasked to spearhead this transformative effort. Technical integrity & Operational integrity sections were formed, who prepared corporate guidelines in line with global best practices & shareholder's support, covering entire life cycle of projects. Roll out plans were formulated to align all sites with corporate guidelines. Corporate & site level PSM teams supported the daunting task of performing detailed Gap assessment at sites. Activity was followed by chalking out corporate Remedial Action Plan, which will ensure compliance to Process safety application manual. Ensure Safe Production is a part of Operational Integrity regime, directly related to improving Operational Discipline at site.
Ensure Safe Production constitutes a major portion of Operating Integrity framework, designed to operate asset safely.