Aging facilities are a common issue within the oil and gas industry. This research demonstrates a practical approach to aging life extension, taking into account risks and constraints, such as budgets, resources and offshore field-level logistics. The case study reviewed is Mubadala Petroleum's (MPs) small, but aging, upstream offshore oil facility located in the Gulf of Thailand, known as the Jasmine/BanYen field. The field includes six offshore platforms, subsea pipelines and a Floating Production, Storage and Offloading asset (FPSO). The field, which commenced production in 2005, was initially expected to have a relatively short field life, and as a result, the facilities were genially specified for only a 10-year lifespan. As the field exceeded expectations in term of volumes and longevity, it became clear to MP management that a practical and cost effective life extension plan was necessary. As such, this research describes the approach to taken by MP to extend the life of the Jasmine/BanYen facilities. The approach taken by MP was closely aligned with the recommendations and best practices proposed by several regulatory authorities with extensive experience in managing aging offshore oil and gas facilities, such as the United Kingdom's (UK) Health and Safety Executive (HSE) and the Norwegian Petroleum Safety Authority (PSA). As such, the facilities were first functionally decomposed into a number of subsystems, such as Wells, Structures, Pipelines, Topsides, Risers and Floating Assets. A target life extension period was specified, which was followed by a series of focused risk assessments to determine the levels of risk expected during the life extension period, with the critical gaps identified. Each risk assessment involved specialist resources related to the subsystem under review, such as structural engineers, process engineers, marine engineers, instrument engineers, as well as technical safety and environmental engineers. For any risks that were deemed unacceptable, a mitigation plan was suggested and associated costs developed. Finally, a phased master plan was developed that took into account constraints while prioritizing actions based on the determined risk levels. The implementation of the plan was challenged by the intricacies of offshore logistics, including constraints on supply boats, Persons On Board (POB) etc., and budgetary constraints, which were considerable given the relatively high operational expenses of the field and the low oil price environment. As per the risk assessment, high priority activities were determined to be with respect to FPSO, well integrity and the integrity of subsea pipelines. The platform structures and topsides were considered to be lower priority, as they had already been verified for the life extension period by the company's Asset Integrity (AI) program. Additionally, MP also has a robust Safety Critical Element (SCE) system in place which is an integral part of the AI program, and as such there were no unexpected revelations with regards to the condition of the SCEs. Obsolescence was determined to be a low priority since the equipment on the platforms are relatively new, and most of the Original Equipment Manufacturers (OEMs) provided assurance on the availability of spare parts for the main equipment items. Highlights of the life extension plan are as follows: Production flexible riser connecting the steel pipeline network to the FPSO has been replaced Pipelines inspections are ongoing, and repairs are being prioritized The design life of platform subsea structures has been extended based on fatigue analysis Subsidence analysis has been carried out on all platforms and indicated no major anomalies Platform power generation facilities are progressively being upgraded A comprehensive well integrity systems have been implemented and critical activities such as barrier testing and well repairs are being carried out regularly Repairs to the hull of the FPSO have been carried out

The aim of this abstract is to focus on the Maintenance Management System (MMS) that was implemented at ADNOC LNG to accomplish operation excellence, effective decision-making regarding maintenance activities, and utilization of the Risk Management Process to assure asset integrity and major production revenues. Risk-based MMS is a continuous improvement (CI) system to proactively prevent failures through the early identifications of risks, failure modes, failure criticality, and risk mitigation by utilizing cost effective predictive maintenance tasks and routines. Risk-based MMS effectively provides support for high critical decisions to assure asset integrity, minimize plant trips, avoid unnecessary forced shutdowns, and guarantee safe operations. Asset Integrity Management (AIM) is important in the oil and gas business because it ensures reliable assets, performance, efficiency, cost effectiveness, sustainable production revenues, and achieve business objectives and operational excellence. Maintenance, Operations and Engineering are the key partners and custodians to assure asset integrity in compliance with HSE. The very close interface between the three result in high levels of asset reliability and availability. In 2016 ADNOC LNG's Maintenance Division deployed the Maintenance Management System (MMS) driven by the Risk Based Reliability Approach. The objective was to perform consistent maintenance activities and asset integrity assurance by identifying risks and mitigations to reduce the risks in early stages to As Low As Reasonably Practical (ALARP). The MMS Policy and Strategy was developed on the foundation of the risk-based approach in line with ADNOC LNG's corporate objectives, ADNOC's code of practice, and internationally accepted best practices. The alignment of MMS with the Risk Based Approach was achieved by ADNOC LNG through successful implementation of Streamlined Reliability Centered Maintenance (SRCM) as a risk-based reliability asset integrity management tool. SRCM implementation achieved +98% reliability, cost reduction, work force utilization, proactive maintenance, and sustainable production. SRCM is mainly for rotating equipment, electrical equipment, and instrumentation. RBI (Risk Based Inspection) is already utilized for static equipment. The combination of both RBI and SRCM are successfully assuring the integrity of all assets at ADNOC LNG. The key topics, which will be focused on, are criticality assessment, risk management, and asset integrity management reliability system SRCM (Streamline Reliability Centered Maintenance). The main challenges to implement MMS were: receiving the team's buy in, making sure the team was aligned with MMS policy and strategy, and cultural challenges. The system was successfully deployed with consistent processes and procedures helping maintenance end users perform in accordance to best practices.

Middle East offshore platforms installations started in the early 60's and continue today. Managing asset integrity and demonstrating compliance is increasingly challenging due to frequent brownfield modifications, increased safety factors with the introduction of international standards, changes in metocean data and age deterioration. From work with North Sea, Gulf Region and Asia Pacific operators, an approach was developed to manage ageing assets using real-time structural risk assessments and operational procedures that ensures consistent risk levels of life safety and environmental for all assets and is applicable to all regions. Utilising the improved accuracy of modern weather forecasts, in combination with structural reliability, a methodology has been developed to determine the forecasted risk level for any critical element. This is updated live, with each new weather forecast, to provide proactive notifications and alerts so operators have more up to date knowledge to make decisions on their assets. A live web-based system can be utilised to display this information. The approach splits the three risks of life safety, environmental and structural damage into separate requirements and calculates the probability of failure, which will lead to each of the three consequences, for the critical component or the overall structure. The risk is evaluated and compared with the industry standard and the operators own acceptance criteria to determine if operational procedures need to be enacted to reduce the consequence. It has been found that the acceptable risk levels for the ‘in a forecasted storm’ risk are governing over the traditional design ‘annual’ risk levels. If at any point in time the probability of a wave height approaching the field exceeds the maximum allowable for a structure, the system issues timely alerts and warnings to the relevant stakeholder for their actions. The operator then has the option of de-manning or shutting down operations to maintain the risk levels for life safety and environmental at ALARP (as low as reasonably practicable) levels. The system also provides information for post-storm structural damage likelihood. A combination of online monitoring, inspection and/or asset loading history, which can be incorporated using Bayesian updating methods, and advanced assessment have been used to reduce the occurrence of enacting operational procedures for structures that are non-code compliant to greater than every 10 years while also reducing the annual risks. An additional advanced feature can be utilised by connecting installed accelerometers to the structure for continuous live streaming of the structural response which can issue alerts if any damage is suspected.

Coral Sul FLNG is designed to produce, liquefy, store and transfer LNG and condensates directly at the offshore reservoir. Over 430 meters long, Coral Sul will be the first FLNG ever built to operate in ultra-deep waters, its wells are located 2000 meters below sea level. The vessel is currently under construction by Technip, JGC, Samsung Consortium (TJS) in South Korea for a joint venture led by Eni as operator and partners (ExxonMobil, ENH, GALP, KOGAS and CNPC). The main safety challenges for the FLNG technology, relate to the management of cryogenic spills on board and the protection of people and assets in a very congested environment. FLNG technology is introducing a set of new safety rules for the industry which are still under development by main international certification bodies. Today, the lack of industry standards regarding FLNG technology, and the congested nature of the installation, make the Risk Based Approach an essential step to validate the design and identify fit for purpose reduction measures. Coral project carried out several actions for Cryogenic Risk Management with the aim to: ensure safety of all the Personnel on Board minimize the potential for escalation and maintain asset integrity. This Paper describes the Risk Based Approach followed for Coral FLNG project and describes some of the most important design safety measures implemented on board to manage cryogenic spills: Design of Drainage System and Overboard discharge Designed against the Risk of Rapid Phase Transition Active Protection Methods: Water Curtains to protect hull side Improved Coating Materials (combined effect Cryogenic Spill Protection + Passive Fire Protection) Suitable design of drainage system is a key safety aspect for the design of the FLNG, since it is essential to minimize the vaporization which can create dangerous flammable gas clouds on board. The solution proposed for Coral Sul FLNG is a combination of open gutters, sloped open channels and vertical pipes which allow the quick discharge overboard of accidental spills, minimizing the vaporization in congested areas. In proximity of overboard spillage points, water curtains are implemented to protect the hull side, and the effect of discharge is evaluated for rapid phase transition. Steel decks and structures must be protected against fractures that can follow accidental cryogenic spillages and lead to structural failures which put at risk lives and assets. Specific coating materials have been developed for the protection of decks, piping and equipment to avoid the escalation of any incident. These coatings provide combined protection against embrittlement and fire. Application of coating is done used RBA approach. Design of drainage system and coatings have been identified as technical novelties. A technology validation program has been put in place for Coral Project in order to assess the maturity of the new technologies.

Studying the flow behavior in horizontal section addresses further challenges and complexity. Innovative technologies were developed to overcome the fluid segregation challenges in horizontal sections and cover the entire production profile. In Kuwait, horizontal production logging is typically conveyed on 1.75" electrical coiled tubing which is relatively large size and therefore increases the risk of choking the well or killing low flowrate wells. Also, there is a limitation on the availability of the electrical coiled tubing. Greater Burgan smart ICD wells require a periodic assessment of the production profile and the contribution from each port to overcome the increasing water cut challenge in such a mature field. To identify the source of water, the engineers planned a new strategy to minimize the choking effect through use of smaller coiled tubing size. However, the available small size coiled tubing are not equipped with an electrical line for real-time data streaming. This challenge was resolved by opting for a horizontal PLT logging recording in a memory mode acquisition. Running the production logging in memory mode is not unusual in vertical and slightly deviated wells, but it is not common in horizontal wells. Risk assessment was carried out trying to eliminate all the expected obstruction such as having a dummy run while monitoring production behavior on the surface using a testing unit, reducing the coiled tubing speed to avoid disturbing the flow stabilization and watching for any indication of coiled tubing tension-compression changes. A contingency plan was in place, for carrying out a nitrogen activation in case the well chocked below the accurate reading limits during the logging. Following the detailed steps and extensive planned procedure, the logging with memory mode in the horizontal section was successful and resulted in accurate flow profile determination along with contribution from each ICD ports. Using normal coiled tubing instead of the electrical coiled tubing has resulted in reduced operational cost and eliminate the challenge of the limited availability of electrical coiled tubing that was delaying the PLT jobs. The major production logging output was accurately presented from the memory mode. This paper includes the challenges from using memory production logging in horizontal section. A risk assessment for each of the challenges and contingency plan to apply this method.

A number of major process industry accidents have involved SIMOPS. Company conducted construction (modifications) activities inside its own plant during the period from November 2017 to May 2018. The Group Risk Acceptability Criteria Guidelines have been defined by Company for the purpose of providing Senior Management with quantitative information about the risk profile during SIMOPS activities and to help them in taking informed decision about the execution strategy to ensure safe operations. A DNV-GL Phast based model of the plant has been used to assess the risk level. Using Group Risk guidelines for On-site personnel based on the FN (Frequency – Number of Fatalities) Curve, Company evaluated and compared several SIMOPS options prior to the actual works to identify the optimal manning level and schedule to ensure the overall Group Risk laid in the ALARP region. The quantitative risk assessment served as a tool to derive the optimal manning levels and shutdown schedule during the SIMOPS activities. The manning levels were controlled through additional administrative measures to ensure its implementation. Moreover, the overall SIMOPS Risk (FN Curve) for the current activity was compared with the risk undertaken during similar previous activities conducted in 2015 and 2016. After the successful completion of the activities, the Risk Assessment was updated to take into consideration the actual manning and schedule inputs for the Pre-Shutdown and Partial Shutdown phases. The actual overall Group Risk (including Pre and Partial Shutdown) was within the Company Group Risk Acceptability Criteria. Additionally, valuable Lessons Learned were identified such as purging (with inert gas), rather than just the depressurization of the equipment in the units during Shutdown, can contribute to a significant risk reduction. This paper presents a novel approach to evaluate SIMOPS risk on personnel using a Group Risk criteria based on FN Curve. This provides an additional re-assurance to stakeholders involved in the activity to take informed decisions based on a quantitative risk analysis rather than a qualitative assessment.

Company conducted a Fatigue Risk Assessment Study to estimate the fatigue levels of approximately 9000 shifts and the risk of incidents occurring due to operator fatigue. The findings provided an insight into the likelihood of fatigue and risk of errors / incidents occurring for approximately 9000 shifts of control panel operators working on a 4×4, 12-hour, day and night shift pattern. The results presented in this paper are limited to the assessment conducted for day shifts in order to demonstrate the methodology. The study compared different shift patterns in order to identify shifts with higher fatigue levels and identify control measures to reduce operators’ fatigue levels and risk of incidents occurring to As Low As Reasonably Practicable (ALARP). Lowest fatigue and risk levels were identified for the current 4×4 shifts in comparison to 7×7 and 28×28 shift cycles followed by other Companies. In order, to lower the risk to as low as reasonably practicable (ALARP), additional control measures such as training, campaigns, ergonomic assessments, KPIs such as tracking incidents by fatigue levels, etc. are being rolled-out for implementation. This is a novel approach on the combination of a qualitative (IOGP) and quantitative (UK HSE) fatigue risk assessment methodology that has widespread applicability, prospectively in terms of shift design and prevention of incidents caused by fatigue induced impairments and retrospectively for incident investigations. This Fatigue Risk Assessment Study fosters proactive occupational health management by promoting health of employees and preventing / reducing fatigue and thus plays a vital role in the prevention of sickness absenteeism and illnesses associated with chronic fatigue.

Production of Oil, Gas and Petrochemical from production units is becoming very competitive every day. As products are sold in open market, production cost drives an organization's profitability. To keep a plant available for production as much as possible, Asset Performance Management (APM) or Asset Integrity Management (AIM)is the key. Risk based inspection (RBI) is a decision making tool that deals with integrity management of static equipment and piping through focus on prioritizing inspection based on the risk. Review of published guidelines for RBI such as API RP 580/581, ASME PCC3, DNV-RP-G101, EN 16991 etc., suggests that they provide either oversimplified or complex explanations which makes it difficult for beginners to grasp all the aspects that are critical for a successful RBI project. Therefore, this paper is aimed to provide and discuss the essential elements for effective RBI implementation project in a simplified way. RBI project can be divided into four major phases i.e project initiation and pre-requisites, workshops & trainings, RBI analysis phase and post RBI actions. Each of these stages is discussed with details in this paper. An overview of successful RBI program used within the industry and from the ADNOC LNG RBI implementation experience, is provided with details. Project management approach for RBI program implementation is conveyed by dividing project into different phases and highlighting the inputs/outputs and activities for each phase. Objectives, time and resources such as data and personnel required, software features that are essential, project planning and monitoring are provided. RBI program implemented efficiently in accordance with suggested plan, results in an overall optimization of inspection for static equipment/piping while maintaining their integrity as part of a broader APM or AIM strategy.

The most significant threat to oil exploration and development is an uncontrolled release of reservoir fluids during drilling operations, commonly called a blowout. Besides its tragic environmental and human impacts, Macondo accident fostered the awareness in the industry that blowout risk goes further the idea of an implicit risk of drilling activities: blowout is an operative risk to be properly assessed, as reported in the European Directive 2013/30/EU on offshore operations. In order to tackle such request, Eni developed a standardized methodology called e-wise™ (eni Well Incident Systematic Evaluation) that provides an objective and reliable assessment of blowout risk. As a prelude, the common criteria based on statistical occurrence of blowout was considered neither exhaustive, nor accurate. Actually these statistics are suffering from many limitations: limited time span, outdated technologies, inconsistent environment (now deeper wells), variety of technical approaches, and no consideration of risk exposure duration. ENI decided to measure blowout probability with a comprehensive methodology accounting for the three key elements affecting blowout occurrence: geological uncertainties, equipment reliability and human errors. The methodology put together automatically in properly designed fault tree, the three root causes and it applies them on specific well designs. The result of this approach is a standard way to calculate blowout risk that can be applied on rig/rigless operations, supporting well engineering and permitting process. This solution, named e-wise™ is able to generate two types of standard outputs: full breakdown of blowout frequency by section/flowpath and extensive bow-tie for communication and certification purposes. The full breakdown of blowout frequency allows the engineering and the operations to focus their attention on the most critical phases of the well. The model can be used for further sensitivity analyses foreseeing alternative operating procedures or additional safety technologies in order to have an univocal assessment of their benefits in term of blowout probability reduction. As a matter of fact, specific R&D programs are assessed through e-wise™ to address their potential value in terms of safety improvement. The bow-tie depiction of the results provides a synthetical representation of all detailed calculations, where some models encompass more than 20 scenarios, each one having dozens of sub components. A bow-tie supports the communication of the results toward management and authorities by giving a complete vision of the blowout with the relative reliability of safety barriers and the different impact scenarios including containment and relief strategies.

Objectives/Scope The drive to Goal Zero (or no harm to people, damage to asset and impact to environment) has been the cornerstone of the company as a highly reliable and caring organization. It is the " Northern Lights " of Iceland, considered as the majestic natural phenomenon known on earth. Simply put, it is the auroras or bright lights across the darkened night sky in vivid colors. There is never a guarantee that they will lit up the sky the moment we decided to look up. Anyone who wishes to see the "Northern Lights" requires an enormous amount of patience, collaboration, strategic planning, and flawless execution. Similar to Goal Zero, we all have a common goal of no harm people and through collaboration, strategic planning, execution and patience- we will strive to reach Goal Zero. In THE COMPANY, one of the ways to achieve Goal Zero is to promote safe behaviour at the workplace amongst frontline staff by equipping the Frontline Supervisors with the right tools and techniques through FLS Academy. The FLS Academy or "Safety Leadership for Front Line Supervisors Academy" was introduced in Well Engineering Directorate to address the growing number of incidents; including high potential incidents due to lack of or ineffective supervision at the worksite. The top 3 common causational factors from 2015 are: ▪ People (ACTS): Inattention/Lack of Awareness: Improper decision making or lack of judgment ▪ Process (CONDITIONS): Organisational: Inadequate hazard identification or risk assessment ▪ Process (CONDITIONS): Organisational: Inadequate work standards/procedures. In a number of Level 2 audits, it has been identified as one of the major gaps when it comes to frontline supervisory skills, certification and qualification. The objectives of FLS Academy in supporting and achieving Goal Zero are divided into two parts: For Frontline Supervisors: To improve the Frontline Supervisor’s knowledge of the Safety Leadership responsibilities with emphasis on Behavioral Safety issues and develop a mindset of Chronic Unease amongst staff. To energize and recognize ones role in achieving Goal Zero. To up-skill the Frontline Supervisors to become highly effective in crew engagement at the worksite. To experience a unique opportunity to engage with Senior Leaders (e.g. Managers and Team Leads), breaking down organization barriers and introduce a new approach of safety conversations. For the Senior Leaders: To transform our Managers and Team Leads into Safety Leaders and be advocate of FLS through engagement and facilitation of FLS modules with their Frontline Supervisors (e.g. Drilling Supervisors, Hoist Supervisors, Rig Managers, Night Toolpushers). To bring Senior Leaders closer to the Line/worksite and create a new approach of safety conversation.

More and more leading companies are moving to digital systems to support their operations, maintenance and turnarounds. This marks huge progress and sees impressive results: incidents and injuries decrease, risk becomes more understandable, and processes streamline and simplify. But if the information used within these digital systems is not connected or up to date, the concept simply does not work effectively. Collaborating closely with major industry players such as Shell, BP, RasGas, Borouge, and others, eVision Software developed bespoke daily maintenance and turnaround management solutions, which address and mitigate many common turnaround and maintenance challenges. The enterprise-ready tool combines powerful Permit to Work, Risk Assessment, Isolation management and advanced (Mobile) visualisations, and integrates these into the client ecosystem. This study pertains to a major derivatives manufacturer in the UAE, in which a platform was implemented to help achieve ambitious hands on tool time increases during their planned shutdown. Integration gets the most out of existing client data and solutions. From preparing digital permits and risk assessments in eVision's software using up-to-date equipment and location information from Maintenance Management Systems (MMS); to creating context-sensitive work execution packs linked to Oracle Primavera, which can be mass signed, enabling continuous scheduling optimisation; to effective and efficient maintenance execution empowered by mobile tools for front-line crew; to monitoring real-time data through connected dashboards. Data and systems are connected, information is shared in real time, reducing Turnaround time and improving capacity planning and Hands on Tool Time, thereby decreasing the number of contractors required for the next shutdown. This continuous feedback loop further enables the client to take lessons learned and improve their next turnaround, getting maximum return out of their digital solutions. By taking a platform approach to shutdown preparation and execution, and utilising the vast amount of data available across systems throughout the asset, challenges could be met head-on and mitigated, without large-scale changes to infrastructure or methodology. Creating a synergy between existing systems, new solutions and effective and improved procedures allowed staff to focus on what really matters: quick and safe turnarounds. During the 2016 planned shutdown, a core goal was to increase the HoTT of staff and contractors by a minimum of 7%. eVision was able to improve HoTT by more than 17% overall, by tackling key challenges, such as permit cycle duration, work instruction time, and vast reduction of indirect productive hours. By implementing the integrated software platform, the workforce was able to more effectively utilise their time on plant.

Objective/Scope; ADNOC onshore has overcome yet another challenge in drilling longest horizontal well 10,000 ft in aggressive environment having ±30% H2S and ±10 CO2 with reservoir temperature around ±300°F. This project is part of the country strategy in meeting energy growth in sour gas wells for the coming future development. Methods, Procedure, Process; the strategy is to enhance the well productivity by minimizing the footprint and drilling long horizontal well in harsh environment by achieving maximum accessible reservoir contact. A detailed well design was generated for each zone separately that touched different aspects from the planning phase to the execution and production in safe operating manner. It required an integrated approach bringing together many different technical and operation solution to achieve the drilling of long horizontal well. The well design was reviewed at each step was agreed One the challenges to start drilling Sour Gas exploration well was penetrating multiple high temperature high pressure reservoirs with minimum geosteering to maintain smooth trajectory thru the structure of the reservoir to enhance well accessibility intervention. The objective was achieved by using rig capable to drill long horizontal well and drilling fluid which is compatible with logging tools that contains low salinity and low solids which assists in enhance the efficiency of the tools and achieving the target of drilling 10,000 ft horizontal sour gas well. The torque and drag calculation were reviewed and accordingly the drilling assemblies were selected. The well was completed with specialized material that will withstand the temperature and pressure changes during production and toxic environment having ±30% H2S and ±10 CO2. Moreover, this was also subjected to comprehensive review of HSE rules and regulations including safety and precautions while drilling. Results, Observations, conclusions; Drilling and developing sour gas well with more than ±30% H2S and ±10 CO2 is an accomplishment. ADNOC onshore has studied the opportunity of drilling long horizontal well achieving maximum reservoir contact with the minimum footprintwhich will assist in reducing the cost of the future wells. Over the past years, ADNOC onshore has developed experience in drilling long horizontal wells in sour wells keeping in mind the safety and environmental aspects. A team of professional expects and support is available to achieve the objective safely & efficiently. Novel/Additive Information; Developing sour gas wells has always been challenge due to the sour environment and accessing deeper horizon that require advance theology. Sour gas opens new marketing channels for ADNOC by maximizing the investment opportunities for the future investors and stakeholders. This will open new cost, maximizing the productivity without compromising the safety and allow drilling long horizontal wells in challenging atmosphere. The paper will describe the various issues faced while drilling sour gas well.

This paper identifies a field with challenging well operating conditions for OCTG Corrosion logging in gas well that include pressure, temperature, carbon dioxide (CO2), hydrogen sulphide (H2S) and well completed with high Ni corrosion resistant alloys (CRA). This case study, describes how periodic well interventions to measure the wall thickness of various strings, required specialised technologies in gas well to the high chromium and nickel content in the tubing which reduces the magnetic properties of the string(s). All well interventions require careful tool selection, planning and implementation, however when the conditions are extreme and present HSE related issues, the planning must reflect a greater level of detail and understanding. Additionally, the logging and interpretation process required for high end CRA tubulars is more detailed and sophisticated and little public domain data is available to assist in the well programme implementation. The Operator required logging tools to be fitted with highly sensitive and fast responding sensors, housed in titanium casings and run in memory mode with a slickline conveyance. In this case study two wells were logged with multibarrier corrosion logging tools combined with multi-finger calipers, to determine tubing and casing thickness status of three tubular barriers. The flow wetted areas were completed with high end chrome/nickel tubulars with potential challenges for data acquisition and subsequent analysis. However, pre-logging planning was supported and bench marked by yard testing where identical composition materials had been used. On retrieval, the data package showed provided a composite set of data, throughout the well and log interpretation clearly identified the well status to be positive. This provides excellent support for the applied logging technology. Pre-logging data searches within SPE and other locations for academic papers describing similar scenario could not be found and this paper is understood to be the one of first kind. These specialized principles and procedures likely to provide with much needed BASE CASE guideline for such future corrosion monitoring logging in similar field conditions.

Artificial Intelligence (AI) is a relatively new concept for oil and gas industry. Yet, its agile nature and massive potential give a promise for constantly evolving oil and gas business in tackling such issues as environmental protection. AI systems utilize a variety of technologies making it possible to produce comprehensive, nonetheless easy-to-use tools, which can be used by Health, Safety and Environment (HSE) professionals in their daily activities. This paper examines a so-called HSE AI Assistant - another tool aimed to provide support to HSE professionals in getting instant answers to questions on a variety of regulatory topics in occupational health, safety, and environmental protection. This AI tool will utilize latest NLP technologies to retrieve data from a bank of up-to-date HSE regulations and standards, and provide answers to required questions. The tool is a much more efficient alternative to traditional search engines and closed intranet data retrievals, as the AI system has an ability to understand human questions, hunt for applicable data in attribute files, and produce the most relevant answer to the questions. The system utilizes latest machine learning technologies, and has a capability of constant learning and evolvement. This will be especially useful in terms of changing local legislation and updates to the HSE regulations. The HSE AI Assistant can also be supplied with a capability to assist HSE specialists in classification of hazardous materials and help to perform regular HSE audits in the areas where hazardous materials are used and disposed. Developed locally in Turkmenistan by a team of HSE and IT professionals, the HSE AI Assistant can become a very accessible and easy to maintain reference and solution tool for HSE specialists working on COSHH audits and environmental impact assessment. The HSE AI can also assist those who control the chemical stock in the warehouse, and who manage the hazardous waste at the disposal sites.

This paper is a case study on developing and implementing a pipeline integrity management system (PIMS) for a medium-enterprise operator in the Middle East. It explains the stepwise, collaborative, applied learning approach adopted by the operator’s focus group that helped to show the value proposition of the system to higher management at each phase. It further explains how this approach subsequently acted as a catalyst between project phases resulting in an operational risk-based PIMS. PIMS must address elements such as people (organized team of various disciplines contributing to the overall objective i.e. pipeline integrity management), process (standards, procedures, and policies on how to achieve the objective) and tools (resources to achieve the objective) to manage pipeline integrity. This paper describes the way BHGE (the consultant) and the operator have worked together and adopted a stepwise approach to address these elements to setup a PIMS within the constraints of a limited budget. The process consisted of PIMS gap analysis, development of PIMS manual and procedures and Excel-based comprehensive, semi-quantitative risk assessment, and is based on an effective contracting strategy that resulted in use of the PIMS consultant as a trusted partner. Pipeline operators fall into three common categories with respect to PIMS implementation: (1) those with large pipeline networks and substantial budgets for integrity management, (2) those with relatively small pipeline networks but relatively high integrity management budgets due to business-critical pipelines being part of the network, (3) those with a relatively small pipeline network and correspondingly small integrity management budget. This paper focuses on this third category of operators. Many challenges arise while implementing an integrity management system in any operation. This paper highlights these challenges and how they were resolved through knowledge transfer, a technical workshop, and an astute contracting strategy. It explains how the subject-matter experts (SMEs) from the consultant were used to manage the pipeline network through a risk-based approach before investing in in-house software tools and personnel. It also highlights the importance of a pilot phase which results in a detailed understanding of the scope and organization-specific requirements before deciding on major capital investment. It further explains how knowledge transfer and a cooperative relationship resulted in various stakeholders for the operator becoming brand advocates for the system. Also, the paper explains the practical steps adopted in setting up risk-based PIMS with a limited budget and how that could be used as a road map for other small-or medium-enterprise operators. And finally, it elaborates on the role played by the applied learning approach, knowledge transfer, inclusive relationships, a smart contracting strategy, and use of the consultant as a trusted partner to implement a risk-based PIMS with limited investment.

Wireline cable sticking is most frequently experienced during formation fluid sampling. In this situation, if the cable cannot be freed, strip-over fishing is the only remedy; this is a cost and risk-intensive activity which may extend the logging job by several days and result in further inefficiencies such as wiper trips or pipe-conveyed logging to fully satisfy the formation evaluation objectives. In this paper, the authors outline a proven engineering approach that permits the systematic identification of high-risk wells for cable sticking, where the deployment of wireline standoffs (WLSOs) may facilitate safe and efficient sampling on wireline. The precursor of all cable sticking is slot cutting into mud-cake or formation. The slot is generated by sustained lateral pressure from the moving (tensioned) logging cable, referred to hereafter as "cable thrusts". A sophisticated 3D cable force model evaluates the cable contact zones and thrusts along the open hole section under analysis. For differential sticking, a cable contact and sticking limit in mud-cake is computed, having adjusted the pore pressures to offset data. For keyseating, the well is benchmarked against wells with similar trajectories, gained from a global study on cable sticking. Sticking-linkage is also assessed, whereby overpulls from tool sticking may induce cable sticking, via amplified cable thrusts against mud-cake or formation. To reduce cable sticking risks to an acceptably low level an array of WLSOs may be deployed, combined with optimised logging procedures and winch techniques. Operators are now employing this approach on a regular basis as an important risk management tool, from the well planning stage through to completion. WLSOs have been successfully deployed for 40 sampling runs on 25 wells, in fields with a history of severe cable sticking or fishing. Prior signs of sticking have largely been eliminated, resulting in significantly reduced well costs, whilst avoiding pipe-conveyed logging or LWD, and without consideration to the value of lost data or samples. Well Engineering may now use this approach to design and optimize ambitious well trajectories, potentially saving a hole section, in the full knowledge that future wireline fluid sampling can be performed within the bounds of acceptable risk. Real-time risk assessments have proven invaluable, to track the risk trend as the well is drilled, leading to a final decision on the requirement for WLSOs, with additional optimisation of the sampling procedures if needed. Operational best practices and lessons learned are summarized, as well as an outline for future R&D to understand and reduce wireline conveyance risks even further.

This paper is a case study relating to the development and implementation of a pipeline integrity management system (PIMS) for a major pipeline operator in the Middle East. This paper provides an overview of the project and underlines the practical steps and systems adopted by the operator in order to maintain the integrity of their pipeline network. A successful and effective integrity management requires a comprehensive support system. As a minimum, that system must address people (organized teams of various disciplines contributing to the overall objective i.e. pipeline integrity management), process (standards and policies on how to achieve the objective) and tools (resources to achieve the objective such as software) to manage the pipeline integrity. This paper describes the development and implementation of a geospatial pipeline data model, supported by a software system which fulfils the PIMS support requirements and is aligned with pipeline integrity management industry best practices and international codes and standards. The paper explains the importance of gathering accurate data in the development and implementation of PIMS. The paper highlights the challenges faced during the PIMS implementation stage and how these were resolved through collaboration with the various stakeholders. For example, the paper discusses data completeness difficulties commonly faced for older pipelines and provide practical solutions for data maintenance and information reliability (e.g. interviews of personnel, documentation of methodologies and engineering judgments agreed by stakeholders, etc.) which provides consistent application of integrity procedures. The paper further details how the PIMS assisted the operator in maintaining the safe operation of their pipeline network in compliance with international codes (i.e. ASME B31.8S and API 1160) and industry best practices. The paper explains the practical steps adopted and could be used as a road map for development and implementation of PIMS by other operating companies.

The spherical shaped tanks/separators represent a common type of equipment in the Oil & Gas industry. The spherical shape is preferred due to the robustness that the geometry offers, in addition to the large fluid surface area that maximizes the gravity separation process. However, these convoluted shapes introduce difficulties in routine inspection and integrity assurance. This paper studies a fitness for service (FFS) assessment of complex damage mechanisms which include localized bottom bulge formation, local shell buckling and underside soil corrosion. This research analyzes a case study of atmospheric Horton Spheroid separation tank with 20,000 barrel capacity, 20 m diameter and 15 m height. The analysis includes a design calculation review of the spheroid via Finite Element Analysis (FEA), API 620 ( API 620 1962-2014 ) standard review from 1962 to 2014 and simulation of the steam desludging maintenance procedure. 3D nonlinear Finite Element model (FEM) was introduced to analyze the spheroid fitness for service under several bulgings and localized buckling. The FEA results were compared to inspection results to validate and confirm the bulging locations, bulging sizing and spheroid integrity. The FEA model results showed that the vacuumed spheroid is subjected to inward bulge formation at the crown upper shell and lower bottom plates. Due to the non-uniform curvature of the spheroid, the bulge locations are difficult to be predicted, however, the FEA results were able to detect precisely the location and geometry of bulges. The plastic strain failure criterion was used to assess the fitness for service of the spheroid for continuous operation with the presence of those deformations. The FEA model results showed excellent agreement with internal inspection results and findings. The FEA model results were used to conduct semi-qualitative risk assessment on other identical spheroids; an endorsement extension was granted based on the semi-qualitative assessment.

Well planning is one of the most demanding aspects of drilling engineering requiring integration of engineering principles, HSE philosophies and learnings from incidents. Although well planning methods and practices may vary but the key objective is a safely drilled well meeting operational requirements. As per Drilling HSE requirements, well development is subjected to Site Specific Safety Plan (SSSP) and the purpose of this Site Specific Safety Plan (SSSP) is manage risks associated with release of well bore gases or fluids and to ensure a quick and effective response to emergencies that can be implemented. A web based Electronic Well Delivery Process (e-WDP) was developed to facilitate generation of SSSP using QRA data base for efficient and fit for the purpose SSSP.

Buildings that are manned and/or housing critical equipment are ideally conceived to be sited at safe distance away from potential explosion sources of the gas processing facilities. However it is not always possible to maintain the required stand-off distance due to several layout/operational constraints in brownfield projects and hence plant buildings are invariably subjected to the blast effects. The paper discusses challenges confronted and best practices followed in GASCO for blast protection of plant buildings. Quantitative Risk Assessment study forms the basis for blast considerations on the building, wherein potential Vapor Cloud Explosion scenarios are identified and blast overpressure are quantified in the form of contours on the plot. Buildings located within the blast contours and are manned/housing critical equipments are classified as blast-resistant to ensure safety to occupants and facilitate safe shutdown of process units during explosion. Building performance requirement defining acceptable level of damage is determined based on criticality of the facility/expected occupancy (control room, FAR, etc.). Structural system/material appropriate to blast intensity is chosen and a dynamic or equivalent static analysis is performed. Blast resistant design followed for buildings in GASCO plants incorporates a practical approach blending past experiences with best known practices in the industry. Building Blast Design Requirements (BDR) data sheet is introduced at early stages of the project and specific requirements such as blast load parameters, building configuration, structural system & foundation type, building response range and other special requirements are developed and firmed up before the commencement of detailed design. Single-storied regular shaped buildings with no windows or minimum windows with special features are preferred. Elevated ground floor is permitted in certain cases such as Substation to create cable vault. However this presents unique challenges in establishing blast pressure distribution due to lack of guidelines for such set-up, which is overcome by own novel solutions. For low blast loads, simplified static approach is adopted for structural analysis, while dynamic analysis with SDOF approach yields economical design for medium to high blast loads. In specific cases where SDOF idealization is inappropriate (as in multi storied building), a MDOF non-linear FE analysis is carried out. RC framed structure with reinforced masonry walls, or steel structure is adequate for low blast, while RC shear wall structure is found most effective to sustain moderate to high blast. The paper presents best practices and unique approach followed in GASCO for such design amid growing challenges of achieving high performance at low cost. These requirements are common for similar expansion projects and hence can be adopted across the industry.