bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhancing Risk Management Process on Rigs through E-JSA
Authors: Devnani Girish Kumar , Dash Deepak Kumar , Salem Muneef , Salama Mina Aziz 
Published: November 2016

Abstract
As Drilling industry continues to bring-in more complex systems and new generation rigs, it is becoming increasingly more difficult to carry out Job Safety Analysis (JSA). Hazard and corresponding control systems identification put in front noteworthy problems as hidden and complex hazards are not easy to identify and corresponding controls sytems should match with and counter the potential severity of hazards. To respond to these issues, there is an increasing requirement of SMART automation of Job Safety Analysis.
This Paper describes the components of electronic Job Safety Analysis (e-JSA) system and how ease of personnel interaction with the system has led to the output of more systematic and authentic Analysis of Hazards and Control assignment at rig sites; enhancing the JSA quality to much higher level and thereby resulting in reduction of Incidents/Accidents.

Methods, Procedures, Process
With the introduction of e-JSA, NDC has gone that extra mile in managing the JSAs across rig sites. This system guided step by step approach ensures that potential hazards and consequences are not missed out thereby increasing safety aspect. This new system delivers unparalleled benefits like capturing of JSA at the rig site with details of the operation type, activities, IPM, PPEs, responsible persons and authors involved for the JSA. Submission, review, approval and evaluation process is fully automated along with authorization control ensuring speedy approval and getting rid of paper document circulation with complete traceability at any given point of time.

Novel/Additive Information
NDC HSE commitment and quest for innovation is further supplemented by e-JSA system. NDC is has already taken initiative to take the e-JSA system on the rig floor, so that the JSA can be opened & discussed by the entire team before commencement of any job. Based on the success of e-JSA system, a Proof Of Concept is in progress which after implementation will facilitate the rig crew on the rig floor to access the JSA documents from rig floor itself.
We are exploring the option to transfer the same software for Risk Assessment with minor modifications such as changing terms like ‘Hazards’ to ‘Risks’, ‘Hazard Categories’ to ‘Risk Types’ etc. By Q4 of 2016, we are targeting to demonstrate the e-JSA system to other ADNOC group companies. On successful completion & positive feedback of the e-JSA system over the last 2 years of launch, we have started automation of most of the processes pertaining to HSE.
Re Engineering of Training to Success
Authors: Ali Adeib 
Published: November 2016

Abstract

Objectives/ Scope
The performance of the Training unit was on the decline despite increase in allocation of manpower and additional funds during the previous couple of years despite induction of fresh blood and benchmarking across sister companies. Similar tendencies were observed in some companies across the industries. This resulted in the restructuring of the unit by movement to a new division and with increased immediate focus led to automation of a few processes and improved performance but still resulted in continued gaps between planned and achieved figures. The resultant loss of learning opportunities led to introspection of existing processes, procedures, activities, RACI matrix etc. It was decided to bring in fresh ideas and explore new concepts which were not used across the group of companies hoping to be a role model whereby we can share the success in future once achieved.
In 2015, there was a call by Senior Management to optimize costs and the decision was to curtail a few of the training sessions that were deemed comparatively less critical to Business Continuity after consultation with the line. The spare time available to the Training unit members were utilized creatively to undergo courses in ISO Lead Audit & 6 Sigma. Upon return, as a proactive measure – employees decide to lead the objective in implementing Quality Assurance and Control measures that could help in identifying wastes or leakages in productivity and then on to proceed with implementing measures to enhance performance.
ISO 29990 was specifically considered as it was a specific standard for Learning Providers and was unique to the region unlike ISO 9001 standard which is generic and common. None of the sister concerns or any other company in the oil and gas industry at that time functioning in Abu Dhabi had achieved the accreditation in the same. However, the quality enhancement mechanism in this standard was left to each company and the decision was taken to explore 6 sigma options along with other TQM tools to be implemented by 2016. A task force was created to proceed with implementing the same with the additional objectives of handling monitoring as well controlling issues along with exploring future options in 2017 once the same has been achieved.
Sustaining High HSE Performance by Effectively Transforming Data into Information - the Al Hosn Gas Integrated HSE Database
Authors: Krishnamoorthy Prakash , Boardman Benjamin N. 
Published: November 2016

Abstract
Al Hosn Gas Executive Management saw the benefits of an integrated solution to managing Health, Safety and Environment (HSE) data aligned with the other Company business processes and using the same core data e.g. locations, terminology and key database tables to ensure a comprehensive strategy of centralised data management.
The new SAP Environmental, Health and Safety Management (EHSM) Modules are Incident Management, Risk Management, Waste Management, Environmental Compliance, Audit, Sustainability and Performance Measurement and Action Tracking.
Each ESHM module has an integral action tracker. Once entered actions are tracked and expedited automatically through the systems workflows (defined for each module on an activity by activity basis). The range of subject matter covered by the SAP EHSM modules surpasses the limitations of procuring individual specialist packages that do not share data without certain user manipulation. Within EHSM specific data can be downloaded to a variety of formats including Excel, Word, Pdf etc. and used in whatever software is required.
A substantial effort was dedicated to ensuring the system satisfied the requirements of the ADNOC CoPs and contained enhanced features. The system went live in 2015 and has been recognized throughout the company as a great success that’s adds considerable value to the organization.
Challenges & Opportunities in Implementing an Integrated Asset Operations Model IAOM in Mature Field
Authors: Das Rupa , Salem Salem El-Abd , Hafez Hafez H. 
Published: November 2016

Abstract
The objective of this paper is to present the challenges & opportunities in implementing an Integrated Asset Operations Model (IAOM) for a super giant field. Conclusions of this paper are drawn based on an actual project that prepared an interactive production and injection network system to accurately simulate the overall system from completion intervals to export point in a super giant field of UAE discovered in ′60s.
The subject super giant field has now crossed a life span of 50 years. As this field was built around the technologies of ′60s and ′70s, any efforts to develop infrastructure failed to keep pace with evolving technology. In addition incremental benefits of asset model were perceived to be marginal over huge business impact of supply interruptions, expensive brownfield modifications, and effort required in retrofitting. However continued focus on improving operating efficiencies has slowly begun to change the way organizations respond to their production optimization & surveillance needs.
This field is producing from carbonate reservoirs and the remaining producing life of the field is expected to be another 50 years. It has over 600 wells which include oil producers, water & gas injectors, water supply & disposal wells along with large oil processing plants, and water injection clusters. The subject field's journey toward having IAOM tool started in a modest way in 2012 when the management wanted an integrated solution to optimize production, identify and remove bottlenecks, artificial lift selection, linking reservoir simulation models, managing production & injection allocation forecasts, and last but not the least, managing operational downtime. Higher production rate, and larger remaining producing life coupled with big infrastructure made it a perfect candidate for implementing an IAOM solution.
This paper highlights how the asset selected a fit for purpose IAOM solution, developed the solution over time, overcame challenges in planning & execution, and realized benefits of initiative. Amongst the main challenges were ageing infrastructure, integrating & consolidating information, and overcoming organizational resistance to change.
In a nutshell, the implementation of IAOM solution presented unique sets of challenges & opportunities in every field. It was observed that when it comes to mature & super giant fields with complex organizational structures, these challenges only multiply. In addition to justifying the capex involved in hardware & software, the decision makers also have to plan for operational, organizational, process & information challenges that could be more difficult to solve. Amongst the main benefits from IAOM implementation is integration, standardization, and improved operational efficiencies. This paper will be a useful reference in situations where decision makers face dilemmas of choosing between businesses as usual approach over IAOM in mature fields.
First Expandable Liner Hanger Installation in United Arab Emirates in HP/HT Well
Authors: Ragsdale Eric , Mohamed Zeid , ElSin Rami Samir , Monneyron JC , Roy Christophe 
Published: November 2016

Abstract
This paper discusses the planning and deployment of an expandable liner hanger (ELH) system in an offshore high pressure/high temperature (HP/HT) well for the first time in the United Arab Emirates (UAE).
New technologies and methods were used to quickly and reliably drill and complete the HP/HT well.
The technological advances of ELH systems have increased well life and improved safety during liner installations globally compared to traditional systems. Sealing capabilities with expandable systems have evolved beyond conventional tools and the smooth radial flow paths, allowing for greater ease of installation. A series of redundant sealing elements provide a gas tight liner top seal, which helps prevent possible gas migration. Also, with the ELH system, rotation and reciprocation while cementing are possible.
The result shows consistent material cost savings, reduced installation time, improved reliability, and increased versatility compared to the conventional liner hanger system or a casing to surface design.
During well design, the service company proposed use of an ELH to the operator for large casing sizes (16 in. inside 20 in. and 11 3/4 in. inside 13 3/8 in.) to help reduce rig time and material costs for the HP/HT offshore well. This was critical to the project time and material costs.
Design and preparation were challenging for this well, particularly during the assembly and make up of this large sized liner hanger in the UAE. The system was assembled, inspected, and tested using the service company's workshop and an approved third-party shop, when needed.
Selecting and securing drillpipe for liner running operations was challenging because of the heavy weight of the 16-in. liner. The service company and the operator worked together closely and located the necessary heavy weight drillpipe from a third-party supplier in the UAE.
The running operation was also challenging because of the liner hanging up at numerous points during installation. However, because of the robust capabilities of the ELH system to rotate, reciprocate, and support a high rate of circulation, the liner cleared all hang-up points.
This paper elaborates on common operational problems encountered while running liner hangers offshore and how the ELH technology overcame said issues.
This paper also describes issues faced in terms of liner deployment in HP/HT wells in UAE waters and a reliable solution that saved time and material costs.
Identification of Thief Zones and Water Allocation in Dual Water Injectors with Temperature & Spectral Noise Logging
Authors: Sarsekov Arlen , Al-Neaimi Ahmed Khalifa , Zhao Wenyang , Saber Mohamed , Tauk Raj , Volkov Maxim , Makhiyanov Ruslan , Barghouti Jamal , Vishnu Raveen 
Published: November 2016

Abstract
The problem of evaluating injection profile in Short Strings (SS) in a dual completion wells has been solved. The HPT/SNL combination to describe accurately and economically the injection profile within the borehole and behind pipe through long string will be demonstrated.
It is difficult and cost prohibitive to monitor injection in a dual completion. Because of this, injection with such completions often goes unchecked for years, wasting water, making wrong assumptions in reservoir performance and missing opportunities for effective water-flood management. Conventional production logging cannot be performed in Short String due to accessibility and are unable to determine the injection profile, therefore, advance tools are required. The objective of this study is to demonstrate how the HPT-SNL logs, run riglessly in the Long String(LS) only, track flow geometry and assess completion integrity.
The well WI-01 was re-completed as a dual water injector in Unit C and Unit D in SS and Unit F in LS in 2005. Due to several unresolved issues with well performance, it was decided to confirm injection distribution, determine any communication between the strings and check for cross-flows behind pipe. HPT/SNL in combination with standard production logging tool was run to meet the objectives reliably at minimal cost. Three logging runs were made in the Long String: First, with both strings shut-in, second with injection into SS and third, both string shut-in to measure transient responses.
The integrated response of High Precision Temperature (HPT) and Spectral Noise Logging (SNL) indicated Unit C and Unit D were active as expected. Additionally, HPT-SNL combination identified a thief Zone (Unit B) in a non-perforated interval contributing to injection. Injected water was observed flowing upward behind pipe between Unit C and Unit B even when the well was under shut-in condition, indicating cement failure.
The survey revealed no communication between the two strings, whereas minor injection was evident below the surveyed interval. The results from this survey will lead to injection optimization in both strings to increase ultimate recovery.
Key Tool for Production Optimization in Low Oil Price Environment- A Case Study on Integrated Asset Operation Model IAOM
Authors: Al Selaiti Iman Hamad , Al Haj Jassim Mohammed , Ranjan Kumud , Soni Sandeep 
Published: November 2016

Abstract
This paper describes an efficient approach to implement IAOM project and evaluate subsurface well performance and surface network facilities of a supergiant oil field flowing from multilayered carbonate reservoirs. The field is produced via several gathering stations and pumping stations. The current manifold pressures at the RDS stations are high, which will increase by the introduction of gas lift and by the additional production from new wells.
In IAOM implementation process, individual well strings and robust network model was built for the asset on the IAOM platform. This model was further utilized in meeting various production optimization challenges such as well surveillance, production and Injection optimization, forecasting and allocation and field development planning. This paper demonstrates how IAOM project was used to run different production optimization scenarios, describing the objective, methodology, analysis and results to address various challenges in production optimization. Following case studies were carried out for this purpose: Well potential rate analysis and optimization: To determine well potential rate based on the well performance, reservoir guidelines and back pressure in the network system.New producer well tie-in to existing network: To investigate optimal option for a new producer well flowline tie-in to existing well flowlines carrying fluid to remote degassing station and study well flowline performance after tie-in.Wellhead shut-in pressure analysis and optimization: To estimate wellhead shut-in pressure at which well ceases to flow when reservoir pressure is increased to new pressure.New pattern injectors tie-in to existing clusters: To estimate tie-in options for new water injector wells for new developments project to the existing clusters based on availability of water supply and closest distance.
Contracts with Cloud Providers for the Oil and Gas Industry: A Legal Perspective
Authors: Kafeza Irene 
Published: November 2016

Abstract
Oil and gas industry is influenced by the cloud computing era. The urgent requirements for employee safety and social responsibility demand quick and efficient response times thus immediate access to data and processing that can scale up based on the needs in a price effective manner. Due to the sensitivity and the criticality of the information transmitted in the oil and gas industry applications, the clients and the service providers need to customize their agreements appropriately. While standardization of cloud services as well as virtualization can contribute to lower costs of IT infrastructure for the oil and gas industry, still specific details need to be explicitly addressed in the contracts that will guarantee the aforementioned requirements that are very sensitive in this industry. In this paper I am looking into the problem of cloud contractual agreements between clients of the oil and gas industry and the cloud service providers.
Remote Sensing Technologies for Gas Leak Detection, Visualisation and Quantification Using Infrared Imagers
Authors: Xavier Watremez , Labat Nadège , Audouin Grégoire , Lejay Bertrand , Xavier Marcarian , Dubucq Dominique , Marblé André , Foucher Pierre-Yves , Poutier Laurent , Danno Ronan , Elie Damien 
Published: November 2016

Abstract
TOTAL, ONERA - The French Aerospace Lab - and ADCIS companies are undertaking a multiyear R&D collaborative project to develop remote sensing technologies and methodologies for gas leak detection, visualization and quantification. The history of gas leak incidents in the Oil and Gas Industry has shown the need for efficient and accurate tools for quantifying the gas leak rate and the extent of the hazardous areas to manage efficiently an emergency situation. Besides, detection and measurement of gaseous hydrocarbon emissions in industrial facilities is a must for obvious environmental reasons. The current generation of infrared imagers detects the presence of gas in the atmosphere but needs improvement for accurate estimation of the size of the gas leak.
In this context, a test campaign held on September 2015 in TOTAL’s Lacq Pilot platform in France was organised to determine if infrared multispectral or hyperspectral imaging could provide reliable and quantitative data in the event of a release in the range of 1g/s to 50g/s of methane.
Several gas spectral imaging systems were installed to observe a methane emission point:hyperspectral cameras in Long-Wavelength InfraRed (LWIR) (7.7-12µm);multispectral cameras in Medium-Wavelength InfraRed (MWIR) (1.5-5.5µm; 3.2-3.4µm and 3-5µm);multispectral cameras in LWIR (8-9.6µm);one Spectro-Radiometer system in MWIR/LWIR (3µm-14µm).
The performance of infrared imagers in different wavelengths has been compared for methane emissions. A set of algorithms and software has been developed and successfully tested to measure, compute and visualize in real time a methane plume from the infrared imagers, and with reasonable accuracy for the methane emissions of 1 and 10g/s. For the 50g/s flowrate, quantifications have been under-estimated with this methodology. Further works should allow improving the accuracy of these quantification methodologies. The gas imagers enable to visualize and quantify in real time and in 3D a methane plume.
This technology could be applied in different ranges of gas leak flowrates (small leaks in environmental monitoring, medium size leaks in safety monitoring, and major leaks in crisis management). The objective over time is to qualify a system that would economically complement the plant gas detection system and bring valuable information should a gas leak incident happen.
Case Study on Frequent Failure of Dry Gas Seals
Authors: Manikandan Arumugampillai , Moorthy Subramanian 
Published: November 2016

Abstract
Case study on frequent failure of dry gas seal in centrifugal compressor
The process gas high pressure compressors used in oil & gas industries requires highly safe and reliable operating requirement. This case study represents the frequent failure of dry gas seal (DGS) in Re-injection Gas Compressor within 20 Days of previous dry gas seal replacement.
DGS systems are specially designed to seal the process gas in centrifugal compressor. The seal gas is extracted from the discharge of same compressor and supplied to DGS after filtration with necessary control (Pressure or flow) based on the requirement in the seal cavity. Ingression of foreign material into the running gap of the seals leads to degrade sealing performance and eventual failure of the seal. After sealing the process gas, a very small amount of the sealing gas passes through the primary seal faces which are connected to the flare.
In this case study we found sudden increase in primary vent leakage was observed during operation and after investigation it is decided to perform the internal inspection of DGS. Black/brown contaminates were found in seal cavity and DGS cartridge. After cleaning seal cavity the spare DGS was replaced.
After restart, the unit tripped again due to high primary vent pressure within 20days in normal operation. It was decided to disassemble the DGS cartridge again. The same contaminants were found in next inspection. Additionally inspection on DGS panel and piping were checked. ➢Seal gas supply line which was taken from compressor discharge was confirmed as heat traced.➢External gas supply into the dry gas seal during startup and shutdown ensured.➢Found C6+ component percentage higher in the seal gas than the previous gas composition which was analyzed before 5 years.➢The condensation occurs in the seal gas injection line due to JT effect and condensates/liquid drops affects the seal faces of DGS which leads to high leakage in the primary vent.✓Performed DEW Point analysis for the current gas composition and identified the required seal gas temperature.✓The heat tracing was found insufficient to meet the changed gas composition.✓Installed heater (15 KW) in the seal gas injection line after the gas filter to maintain the gas temperature.✓Increased the heat traces capacity from 5 KW to 10 KW in the seal gas injection line.
The gas compositions changes over period of time from the offshore well which requires period analysis (Every 6 months) and monitor the heat tracing system.
This case study is providing the trouble shooting experience and useful information for all the re-injection gas compressors incorporated with dry gas system in oil & gas industry to have more reliability.