bluuebunny/crossref_metadata_2025 huggingface dataset:
Field Development Plan Optimization for Tight Carbonate Reservoirs
Authors: Alyan Mohand , Martin John , Irwin Drew
Published: November 2015

This paper describes the simulation study done on optimizing the field development plans for undeveloped tight carbonate reservoirs with limited production history and surveillance data. The successful implementation of a water injectivity pilot test has enabled waterflood as a recovery method in the low permeability carbonate reservoir. The field optimization consists of three major components: well orientation, spacing and wellbore placement.

Based on this study, a data collection program was proposed to target the uncertainties associated with developing the assets. The first part of the study focuses on the proper orientation of wells considering the factors of thermal fractures mitigation, developing the highest oil in place and ease of well drillability. The second part is concerned on studying the optimum spacing for achieving the target rate while maintaining an effective water displacement performance. The third part involved studying the well's placement for achieving a high rate early on during the production build-up while maximizing recovery in the long term. The combination of these three parts has led improved understanding of the important uncertainties associated with the reservoir which will be targeted in the ongoing appraisal program.
High Efficient Metal Sulphide Based Porous Carbon Matrix for Mercury Removal
Authors: Reddy K. Suresh , Alshoaibi Ahmed , Srinivasakannan C.
Published: November 2015

The presence of elemental mercury in wellhead natural gas is an important industrial problem as even low levels of mercury can damage cryogenic aluminum heat exchangers and other plant equipment. Mercury present in the natural gas stream will also dramatically shorten the useful life of many precious metal catalysts. The present work focus on development of high efficient metal sulfide based adsorbents for mercury removal application in gas processing as well as refining operations, through preparation techniques that offer high activity and low pressure drop. The adsorbents were tested in bench scale setup for mercury adsorption capacity in a simulated environment mimicking plant conditions. The results show that a good improvement toward mercury adsorption capacity compared to its counter parts.
Implementing a Disciplined Process Safety Framework in Mature Assets: Two Case Studies on Onshore Sour Field
Authors: Petrone Annamaria , Scataglini Luciano , La Rosa Laura , Salvador Carlo , Frattini Luca , Manfredi Giusto
Published: November 2015

Objective/ Scope

Despite all the technological advancements and lessons learnt from past incidents, the oil and gas business has still a long way ahead in the journey towards an accident free working environment. In particular process-safety incidents characterized by low-frequency but severe consequences represent a big concern not only for downstream plants and refineries, but also for upstream activities due to their dramatic aftermath: loss of containments and release of toxic substances have in fact the deadly potential to escalate to fires, explosions and unwanted releases into the environment. Therefore e&p operators needs to get a better understanding of how managing major accident hazards through structured and systematic approaches. This issue becomes increasingly important when it comes to deal with mature assets where ageing wells, flowlines and facilities can pose integrity issues and operational risks. In such circumstances the possible presence of H2S can make the picture even more complex as regards health and Safety of people and Emergency Response readiness. This paper provides an overview of the holistic and systematic approach that has been set up in the company and implemented throughout the asset life with the precise aim to ensure integrity of its operation, managing major accident and deliver the fundamentals of process safety consistently across its subsidiaries

Method Procedures, process

In the Company efforts to enhance process safety have been translated into the identification of focus areas representing the main pillars for Process Safety: Risk identification assessment and management, assurance verification and continuous improvement and last but not least Process Safety Leadership, culture and training.

Results, Observations, Conclusions

Within each focus area, a number of elements have been singled out to define the key aspects of operations that organizations need to get right in order to assure integrity (e.g. management of change, incident investigation and analysis, emergency planning and response, Safety Critical Elements etc.)

Novel Additive Information

In the paper all support strategies, methodologies and dedicated tools (e.g. BART BAse line Risk assessment Tool, production checks, Safety Critical Element Management, PS Audits) that constitute the bedrocks of the system and contribute to an effective and thorough implementation of the Process Safety framework are described through its successful roll out on selected pilot cases, two sour mature fields onshore.
Integrating Community Well-Being in Business Decisions
Authors: Shah Vishal , Rivera Patricio
Published: November 2015

Ensuring the well-being of the local communities during flaring is considered as one of Al Hosn Gas' key areas of stakeholder management. While the Company endeavours to minimize flaring and there will be no continuous flaring during normal operation of the plant, temporary flaring has been carried out previously during well-testing and clean-up activities. It is also currently being carried out during the start-up phase of the plant until it achieves steady state operations.

Al Hosn Gas's stakeholder management process comprises of two stages. The first stage explores potential impacts of flaring on local communities using quantitative dispersion modelling tools. As an example, the potential impacts of flaring during start-up have been studied extensively to determine whether it would be safe to commence plant operations while the annual Moreeb Hill festival was being celebrated approximately 18km upwind of the gas plant. In a situation where flaring is imperative, the Company enters into the second stage of stakeholder management, under which a Flaring Awareness Program is executed in a systematic and co-ordinated manner.

Quantitative dispersion and risk modelling studies have aided Al Hosn Gas in making executive decisions, such as planning the plant start-up date after the Moreeb Hill festival to eliminate any impact on festival visitors. In another case, a Flaring Awareness Program was conducted prior to the Company's well testing & clean-up activities as a stage 2 activity. Based on the feedback, it was observed that all stakeholders were appreciative of Company's efforts. The effectiveness of the stakeholder management process has been demonstrated by a smooth flaring operation without community concerns. The stakeholder engagement activities have additionally raised awareness of the project within local communities resulting in increased interest to be part of the Company family in the future.

Al Hosn Gas is completely aligned with ADNOC's aim to reflect positive HSE performance by showing concern for its neighbours, contributing to sustainable development, and earning the confidence of the society at large. This in turn also helps the Company to win a "Local License" to operate smoothly.
Mapping of Mubadala Petroleum Asset Integrity and Process Safety Practices to International Best Practices
Authors: Grassian David , Scott Trevor , Bahatem Mohammed Hussain
Published: November 2015

This paper examines the development of best practices in Process Safety and Asset Integrity over the last thirty years and provides an overview of the performance of Mubadala Petroleum (MP) against the resultant best practices. Best practices are typically developed in response to catastrophic process events. The response to catastrophic events is usually a public outcry followed by legislative and industry initiatives and while it is unfortunate that the main catalyst for innovation is catastrophic accidents, this defacto process has yielded an impressive collection of practices. This research catalogs best practices from several sources and identifies the commonalities as well as the divergences. The comparison revealed that the commonalities significantly outnumber the divergences, which is indicative of an emerging consensus across the industry and across the world. There were some slight differences in the approach which are discussed in detail.

This research laid the groundwork for a comparison of Mubadala Petroleum's performance against international best practices. The elements of Mubadala Petroleum's Operational Management System (OMS) were mapped to the compiled list of twenty-seven international best practices. There was a corresponding OMS element and supporting procedures for each and every practice identified.
Evidences for the Formation of Aromatic Hydrocarbons in Claus Process from Contaminants in H2S Feed Gas
Authors: Raj A. , Mohammed S.
Published: November 2015

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

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

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

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

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

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 (<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

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

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

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

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

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.
Evolution & Acquisition of the World's Largest OBC 3D/4C Seismic Survey
Authors: Mercado Gary , Nakayama Shotaro , Benson Mark , Belaid Kamal , Al-Hendi Ahmed , Lecoq Thierry , Bourdarot Gilles
Published: November 2015

An Ocean Bottom Cable (OBC) 3D/4C seismic survey covering 2730 square kilometers and spanning 23 months has been undertaken by ADMA-OPCO. This survey covers 2 offshore congested producing fields, plus several exploration areas currently planned for development in the near future. This large acquisition when coupled with two previously acquired 3D OBC surveys (in 2000 and 2007) offers 4580 square kilometers of continuous 3D OBC converage.

Coordination and intensive communications between 6 shareholders, 14 ADMA-OPCO divisions and 4 governmental agencies were required to facilitate this survey. The initial survey design (used for 2 months) used Distance Separated Simultaneous Source (DS3) acquisition but was revised to Managed Source and Spread (MSS) acquisition for improved fold, offset and acquisition efficiency. During the course of survey acquisition, 3 different test data sets were also acquired for technical analysis. A short history on the feasibility and complicated process leading up to the start of the survey will be offered, as well as samples of the onboard processing from the various areas will be presented.

This survey was acquired in a little over half the time of previous OBC surveys in offshore Abu Dhabi. The data, based on limited onboard fast processing, is of high quality and illuminates deeper gas bearing structure and stratigraphy. Formal onshore processing has begun and promises excellent results.

This innovative acquisition has provided more efficient data acquisition saving time and money, reduced HSE exposure in busy fields and will in conjunction with previous surveys provided one of the largest continuous offshore 3D datasets in the Arabian Gulf.
Energy Integration Opportunities in GOSPs Through Gas Conditioning
Authors: Al-Zahrani Talal , Soliman Mohamed
Published: November 2015

This study evaluates different energy integration opportunities within a typical gas-oil separation plant (GOSP) to simultaneously achieve the export gas specifications and provide the wet crude handling heating requirements without the need for external energy consumption. The subject GOSP is designed to gather and condition the associated gas to a water content specification (spec) of 7 lb/million standard cubic feet (MMscf) and hydrocarbons (HC) dew point spec of 80 °F at plant export pressure.

Several approaches were studied through process simulation to utilize the available cold and/or high- pressure streams for providing the dew point control cooling requirement of the associated gas without using a refrigeration system, which is the backbone of dew point control units (DPCU) in Saudi Aramco and worldwide. In addition, this integration eliminates the crude dehydration/desalting steam requirements on the other side. The following options were evaluated to achieve the objectives: Heat exchange between hot compressed gas and cold crude received from subsea pipeline.Further gas cooling by HC condensates (Energy recovery of condensates pressure drop).Export gas cooling and re-compression through turbo-expander.

Technical evaluation showed that all options achieved the gas conditioning objectives with some limitations in Option 1. Eventually, Option 2 was selected as the optimum choice that meets all required export specifications in both summer and winter operations. Therefore, the existing propane refrigeration system could be eliminated as well as the need for steam consumption in the crude side, resulting in total power savings of 10 MW.
How the Petroleum Industry can Learn from the Ebola Crisis of 2014
Authors: Willemse Andre
Published: November 2015

Objectives/Scope

This session will review the Ebola outbreak from the viewpoint of an onshore and offshore petroleum operator. It will provide insight into the real threats the outbreak presented by looking past the media hype and diving into the real organisational effects of the outbreak. The presenter will show how, though contained to parts of West Africa, the Ebola crisis established a new model for medical risk management that can be applied the world over.

Methods, Procedures, Process

The presenter was on the ground in West Africa during the Ebola outbreak assisting various organisations, including the petroleum industry, to navigate the medical risks while helping to ensure minimal disruption to employee health or operations. Through this first-hand experience, the presenter will review the key takeaways from the outbreak to highlight how major infectious diseases, such as Ebola, cannot always be easily managed through traditional HSE protocols. It will establish key variables of medical risk and discuss how HSE and medical management must be part of every company's overall operational structure.

Results, Observations, Conclusions

The Ebola outbreak caused major disruptions to all industries operating in or around West Africa. Earlier, there were confusion and grave misconceptions about the extent of the outbreak which led to many petroleum operators unprepared for how to best manage the medical threats to their employees. Traditional models of HSE and infectious disease management did not easily apply to the developing threats. As organisations were caught off guard, they were forced to adapt to a rapidly changing situation as the outbreak spread. This medical incident quickly became a threat to all operations as basic infrastructure degraded, resources became unreliable and security threats increased. Those organisations who took a preventive and holistic approach to HSE management were better able to respond and ensure minimal impact to their operations.

Novel/Additive Information

The Ebola crisis of 2014 was one of the worst infectious disease outbreaks in recent history. It also occurred in a region with endemic medical risks and poor medical infrastructure. These two factors make it an important learning exercise for the global petroleum community. The presenter's first-hand experience will provide substantial insight into the long-term effects of the Ebola crisis and how organisations can learn from this event and benefit from implementing their own mitigation strategies.
From Exploration to Production in 4 Years: Industry Collaboration Leading to Accelerated Learning Curve for Large Tight Gas Project in the Sultanate of Oman
Authors: Al Riyami Qassim , Briner Andreas , Elliott David , Judd Tobias , Nadezhdin Sergey , Gurmen Nihat , Batmaz Taner
Published: November 2015

A large, strategically important unconventional (tight) gas project in the Sultanate of Oman advanced from the exploration stage with one discovery well to the pilot and development stages over 4 years. Project challenges in the first 2 years of exploration were poor initial success in both fracturing treatment placement and subsequent productivity and an ever-expanding scope of work in a demanding environment with limited resources. To address these challenges, the focus was shifted from routine delivery to an integrated approach and a strategy that included defined activity timelines, key performance indicators aligning with different stakeholders, and process reviews. Technology deployment and improved operations with allocated fracturing equipment spread gave flexibility to this new efficiency model. Integrated technology trials included cased and openhole completions; different well types; and several rock and core mechanical tests, such as reservoir coring, openhole stress testing, sonic measurements, and continuous unconfined compressive strength measurements. It also incorporated abrasive perforating, various fracturing treatment type designs, and advanced evaluation techniques such as microseismic monitoring, three-phase flow metering, tracers, and others. These technologies were implemented in a fast and efficient manner owing to strong collaboration between a dedicated Petroleum Development Oman (PDO) subsurface team and the service provider expertise. Personnel embedded in the exploration team greatly helped with linking to proper resources within the suppliers. An embedded engineer provided immediate technical and logistical support to the team. The improved process involved multiwell fracturing, a test campaign, and evaluation of individual zones. Finally, gaps and areas for improvement going forward were identified. Over the 4 years, with implementation of the new technology and strategy, the success rate of fracture placement and zonal evaluation increased from the low initial success of less than 50% to 100%; the improvement was particularly evident in the extremely tight lower intervals of the reservoir.
Custom-Designed Water-Based Polymeric Reservoir Drill-In Fluid leads to Successful Drilling, Coring and Logging Operations in a High Temperature, High H2S Environment; a Case Study
Authors: Walters G. A. , Elenbaas M. J. , Richardson D. J. , Rosener A. , Hussein M. , Anez M. J.
Published: November 2015

As a part of an appraisal campaign within a sour gas and condensate field in Abu Dhabi, an extensive coring, logging and testing program was planned for the target reservoir. One of the challenges was to design and implement a suitable water-based polymeric reservoir drill-in fluid (WB-RDF). Optimum lubricity and rheological properties were essential in this 8–1/2" section being drilled through the reservoir at approx. 45° inclination. Another key element of the design process was to ensure that the fluid remained stable during extended periods of coring and logging while being exposed to high levels of H2S and bottom hole temperatures of 288 degF.

Extensive laboratory testing was undertaken where the behaviour of the RDF was analysed after extended exposure to temperatures and pressures representative of the bottom hole conditions in the well. The mud formulation consisted of polymeric additives, a polymeric alkaline temperature stabiliser and an ammonium bisulfite oxygen and triazine based H2S scavenger. A graded calcium carbonate was included for bridging purposes, aiming to minimse the fluid invasion into the formation. The rheological and fluid loss parameters and stability of RDF were verified during extended periods of static conditions.

Specific fluid management procedures were implemented to ensure that the appropriate concentrations of H2S scavenger and temperature stabilizer were maintained in the mud system at all times. The Garrett Gas Train and its testing protocol was used to monitor H2S levels which, converts the soluble sulfides, bisulfides, H2S into gases which, then seperates the gas from the liquid, thereby eliminating effects of the liquid on the drager detection tube. It must be noted that this test converts all soluble sulfides to H2S and is therefore not specific to H2S alone and this test is a quantative analysis of sulfides. The monitoring process applied was during circulation. The GGT was ran frequently on bottoms up samples and specifically during the periods of circulation where the fluid had remained static due to extended logging.

Other fluid parameters, pH and alkalinity measurements were also monitored with basic mass balance and volumetric evaluations taken into consideration.

One of the key processes was the spotting of specifically formulated pills across the open hole prior to tripping. The risk of polymer degredation is increased during extended periods without circulation and the consequent elevation of bottom hole temperature.

This paper has been prepared to summarise the upfront fluid design and associated laboratory evaluation work performed to ensure fluid stability was maintained in challenging bottom hole conditions. An overview is provided of the fluids management procedures implemented during drilling, coring and logging to ensure a safe and successful operation.
Paradigm Shift from Seismic Array to S4 in Acquisition and Processing; Case Study of Onshore 3D Seismic, Abu Dhabi, UAE
Authors: Mahgoub Mohamed , Seo Youngtak , Dhafra Al , Busanello Gabriele , Roig Carlos , Glushchenko Anna
Published: November 2015

Single-sensor land acquisition technology pioneer's the approach of an integrated acquisition and data processing system to provide solutions in challenging environments. From fast-moving, low-density exploration surveys to wide-azimuth, broad bandwidth, point-source/point-receiver reservoir surveys.

Acquiring seismic data using conventional source and receiver arrays in areas with large elevation variations, from Sabkha to gravel plain to high sand dunes causes fluctuations in the signal arrival time, partial cancellation of the signal, intra-array statics and seismic noise aliasing issues. The use of S4 (Single Source Single Sensor) to acquire seismic data in the area of study helped to resolve all previous field acquisition issues and delivered outstanding 3D seismic data.