bluuebunny/crossref_metadata_2025_split huggingface dataset:
Challenges and Redesign Requirements Drilling High Angle Surface Holes in Giant Offshore Oilfield
Authors: Ryan J. T. , Grini M. , Al Junaibi H. , Al Katheeri Y. , Edwards H. E. , Day T. , Rachi H. , Chandran K. , Espeland K. 
Published: December 2014

Abstract
The island development strategy of the giant offshore oilfield requires the use of extended reach drilling (ERD) design wells. Compared to the typical wells drilled from the wellhead towers in the same field, higher inclinations are required in both the surface hole and intermediate hole to facilitate drilling three dimensional wells of more than 35, 000 ft. While the challenges of drilling the intermediate hole at higher angles had been identified early on due to field experience, the challenges leading to stuck pipe events encountered in the surface hole were not anticipated due to limited experience drilling high angle surface holes in the region.
Historically total loss of returns has been a common issue in the region when drilling the surface hole. Typically when drilling from the Jack Ups, the wells are drilled with sea water and high viscosity sweeps once total losses has been encountered. Any potential aquifer flows are diverted overboard. In order to divert the aquifer flows on the newly built Artificial Islands, the fluids must be pumped 200 or more meters to the gulf. Mud cap drilling (drilling with seawater down the drill string with heavy mud in the annulus to control well flows) was implemented to solve the issue of losses and flows on the island.
The early wells with surface holes drilled at high angle experienced stuck pipe while tripping out of the hole after reaching casing point, leading to significant non-productive time (NPT) and risking project objectives and planned designs. A detailed investigation was performed, including running six arm caliper logs to better understand the mechanism for stuck pipe events. After analyzing and understanding the issue, operational practices and bottom hole assembly designs have been changed to reduce the stuck pipe risk, and specially designed stabilizers have been manufactured and used to mitigate stuck pipe events. Geologically, significant data gathering within the overburden sequence to characterize lithological, stratigraphic, and diagenetic heterogeneities, as well as structural discontinuities, has improved understanding of aspect ratio and vertical scale of features being drilled that may have caused the previous hole morphology effects. No stuck pipe events have been experienced to date in the surface hole due to the same effects after implementation of the new equipment designs and improved drilling practices.
Effective Asset Integrity Management through an Effective Risk Based Inspection Program- ADGAS’ Experience
Authors: Sabry Houssam 
Published: December 2014

Abstract
Abu Dhabi Gas Liquefaction Company Limited (ADGAS) is producing LNG since 1977. ADGAS is the pioneer LNG producer in the Middle East. In 2010 ADGAS started exporting sales gas to Abu-Dhabi through its first gas treatment complex (Offshore Associated Gas). This was followed by the commissioning of additional three gas treatment trains (commissioned in 2013). The total Export gas volume is 1.4 MMM SCFD. During its 37 years of operation, Safe and Efficient production is one of ADGAS core values. Since commissioning of its first two LNG trains and as per the industry practice at that time, time based inspection was being practiced to inspect the static equipment (pressure vessel and piping) for any degradation. Time based inspection generally inspects everything without looking at the risk inherent in an equipment failing; time based inspection is governed by minimum compliance with rules, regulations and standards for inspection. Following time based inspection, where there was no prioritization of inspection activities, this sometimes led to surprises. As The Risk Based Inspection (RBI) approach emerged in the nineties of last century, ADGAS was among the first few companies studying the advantages and implementing RBI. In 1999 ADGAS started its first qualitative RBI. Following the qualitative RBI approach, ADGAS moved towards quantitative and semi-quantitative RBI approaches. Through the implementation of RBI, risk ranking was well established for all static equipment, inspection activities and turn around activities were optimized. Hence, following RBI, receiving surprises leading to unplanned shutdowns decreased if not avoided. This paper presents ADGAS asset integrity management experience moving from time based inspection towards effective RBI approach. RBI experience is being addressed in terms of the different concepts of RBI, different implementation stages, human factor in RBI, RBI lifecycle, implementation and ever-greening.
Internal Chloride Stress Corrosion Cracking of Austenitic Stainless Steel Risk Based Assessment of a Gas Plant
Authors: Sabry Houssam 
Published: December 2014

Abstract
Post commissioning of the new AGDAS gas treatment facility (Offshore Associated Gas (OAG)), several failures in 316L stainless steel piping and equipment occurred. Since OAG commissioning in November 2010 till October 2011, 13 failures were recorded. All failure investigatios concluded that the immediate cause of failure was internal Chlorides Stress Corrosion Cracking (ClSCC). ADGAS considred actions to ensure the safe and efficient operation of OAG. To quantify the inherent risk associated with the operation of OAG assets under the likelihood of failure due to ClSCC, a Risk Based Assessment (RBA) exercise was conducted by an ADGAS multi-disciplinary team.
Results of this assessment were used for as the basis for determining the risk associated with each and every stainless steel asset, prioritise the replacement works and plan for inspection and monitoring. In otherwords, provide the basis to evaluate the extent of the problem and hence put a mitigation plan. A tool for risk (RBA) evaluation of ClSCC was developed in house.
This key activity paved the road towards setting an overall action plan to contain the OAG risk of ClSCC. The action plan has managed to prevent further leaks in OAG. Action plan included the launch of special advanced nondestructive testing program capable of detecting premature stress cracks in stainless steel, temporary composite wrap repairs at specific high risk locations, a dedicated emergency and HSE program in addition to other actions. Chlorides stress cracking leaks could have resulted in major consequences in terms of HSE, loss of production and disruption in gas supply.
Innovative Assessment Approach to Quantify the Impact of Load Additions and Mitigation Strategies on Existing Offshore Platform Structures
Authors: Azouz Amr Mohamed , Aita Raja Srinivasa , El-Khouly Wael Saad , Atia Mohamed 
Published: December 2014

Abstract
Offshore structures usually experience many stages of alterations, modifications, load additions and strengthening work during its operational life to meet increased production plans and/or changes in process/safety philosophies. Significant load increases are likely accompanied with strengthening schemes to cater for such additions. Conventional design methods for assessing these modifications employ linear structural assessment that do not account for actual history of loading/strengthening. Conventional design practices and current design codes do not provide specific guidelines covering the effect of progressive loading and staged strengthening in a manner that ensures accurate distribution of loads into the supporting structural elements. This paper illustrates the benefits of employing progressive loading and staged strengthening over conventional approach. The benefits are highlighted through two case studies involving the Re-assessments of ADMA's Collector Separator Platform (CSP) and Bridge B5 connecting the CSP to Riser Platform. The assessment of these structures utilizing this innovative approach were carried out to demonstrate that these structures are meeting code (API WSD/ISO19902) compliance under the proposed additional loading.
A Risk Management Roadmap for Capital Oil and Gas Projects
Authors: Kenzhetayeva Zarina , Ribeiro Maria T. , Oliveira Nuno , Carvalho Álvaro , Bicho Margarida 
Published: December 2014

Abstract
Project partners want field operators to achieve production targets and deliver projects in the defined timeframe within budgetary limits. However, operators are frequently unable to achieve the goals projected at the launch stage of the project. This compromises the initial project economic value and originates conflicts between partners' anticipations and the actual project outcomes. Such inconsistency is frequently due to wrongful and/or insufficient perception on risk management policies employed by both parties: operators often compromise the application of a holistic risk management framework, by concentrating their efforts around particular project segments, such as HSE, fluids production and/or oil price; partners, being heavily dependent on operator efficiency and competence, have limited tools to control project performance and usually rely or accept selected risk management methods.
This paper presents a general risk management approach for the oil and gas industry based on the knowledge gained in petroleum projects. The proposed methodology offers a coherent approach, which can aid in improving the risk management strategy of both operators and partners. The challenge is in developing a simplistic, but yet effective and dependable method, which can be utilized by consortiums in any oil and gas ventures.
The result of this paper is a Risk Management Roadmap (RMR) that provides all stakeholders with concrete tools to assess and categorize project risks, quantifying their potential economic impact and hold major threats within acceptable levels.
This paper attempts to provide relevant implications for both parties: operators enable an effective communication with partners facilitating a clear and common language for mutual cooperation and progression towards the project targets; partners benefit from taking better informed decisions, protecting shareholders' interests, having stronger control and influence over the desired project outcome.
Talent Attraction and Management of Competencies in Challenging Oil and Gas Environment.
Authors: DORDAN Jean Pierre 
Published: December 2014

Abstract
The Oil & Gas industry is facing increasing challenges with more complex, highly technological oil & gas developments and growing expectations from stakeholders in regards to acceptability and HSE. Major IOCs are facing more competition from NOC in accessing resources and developing reserves and the produced barrels require more technology and expertise than ever. Furthermore, Total, a major integrated international oil & gas company, cannot rely on domestic hydrocarbon resources and therefore need to keep an edge on technology and innovation in order to continue to operate and grow. Key Company objectives to maximize existing production, to economically develop new Projects to increase production level and to renew reserves cannot be achieved by only keeping an edge on technology through extensive R&D, but require highly qualified and competent human resources. Operational Excellence relies on three pillars, well designed, built and maintained facilities, comprehensive procedures, and competent personnel both in Head Quarter and affiliates.
Today, O&G industry is faced with challenges such as availability of competent resources, and competition for talent between competitors, contractors and other industries.
Total has developed a strategy and tools to cope with those challenges articulated around three aspects. –Attract and recruit talents.–Bringing all new recruits to professional autonomy in a reduced period of time–Managing and Developing competencies through a dedicated Company management system
A Novel Fully Plastic Caliper Pig for Low-risk Pipeline Inspection - Design, Characterization and Field Test
Authors: Di Lullo A. , Tasso A. , Cocuzza M. , Pirola M. , Canavese G. 
Published: December 2014

Abstract
Pipe in-line inspection by "intelligent" pigs is a fundamental oil and gas industry practice but still considered as an exceptional operation. In fact, the instrumented pigs addressing such a purpose are expensive and delicate tools with non-negligible operating risks, thus making their deployment rather infrequent (typically, once every several years). In eni we have started a number of R&D initiatives targeted to making pipeline inspection easier and more frequent by significantly reducing the operating risk faced when deploying inspection pigs.
In this context, we present a new, low-cost and low-risk plastic pig with inspection capabilities analogous to those of a multichannel caliper pig (i.e. able to detect, locate and size inner diameter changes and deformations) together with additional features allowing to detect internal roughness changes (e.g. due to corrosion) and perform some pH / salinity determinations, also useful for corrosion assessment purposes.
One implementation of the new tool makes use of a foam pig "body", providing the required push with a good capability to negotiate restrictions, equipped with specialized sensors and modules for acquisition and storage. Another implementation, targeted to gas lines and called "skeleton caliper pig", deploys the light plastic system without any foam pig carrier, pushed by the gas velocity alone, and is suitable to prevent the massive displacement of condensates from gas lines.
The paper describes the design, construction and field testing of this new low-risk caliper pig, together with some comparisons with the information gathered adopting a conventional tool.
Thermal Fatigue in Gas Treater Columns
Authors: Shagar Nabil 
Published: December 2014

Abstract
In aging equipment, failures can occur after long run in operation due to accumulation of thermal cycles. A case study of in-service failure of C4 Treater vessels as a result of thermal fatigue has been studied. Thermal fatigue cracking took place in four C4 treater vessels after 36 years of service life. Cracking took place at the welded attachments, which is typical of thermal fatigue cracking. Failure investigation was done. Vessels repair was carried out to remove all cracked locations till vessels replacement. Unique features of thermal fatigue cracking shall be presented. The effect of surface geometry and design factor on crack initiation and propagation were reviewed. Repair procedure, short and long term recommendations have been concluded to avoid such failure reoccurrence in future. Paper illustrates quantum of the thermal fatigue cycles for this case, other damage mechanisms affecting thermal fatigue, cracking morphology, material of construction of the vessel and effect of stress raisers. Advanced nondestructive testing techniques for premature detection are studied. Factors affecting thermal fatigue in pressure vessels are also discussed. Hence, paper is an illustration of an actual Thermal Fatigue Cracking case study in a carbon steel C4 treater column, how cracking was discovered, metallurgical investigation, repair, advanced inspection techniques and the recommendations to avoid recurrence of cracking in similar vessels under similar conditions.
Utilization of Expanded Polystyrene EPS Waste as Sorbent for Oil Spill Cleanup
Authors: Nasir Mohammad Ibrahim , Hameed Zainab Mohsen 
Published: December 2014

Abstract
EPS is a major constituent of plastic waste. Reuse of waste EPS which is non-biodegradable, to useful products is a way of effective waste management. Oil is one of the most important energy sources but oil spill accidents often take place during the oil utilization process, resulting in threats to the environment. We report the use of EPS waste to obtain an adsorbent material to cleanup crude oil spill from water. The effects of major factors such as sorption time, adsorbent surface areas, kind of surface (smooth or rough) and thermo-modification and mechanical modification (punching holes) were investigated. The experiments carried out with about 0.900 g EPS sorbent were tested for oil sorption for 5 to 120 min at 400 g oil only and at 50 g oil over 800 mL water surface. Oil sorption increases with increasing the sorption time's and surface areas. Surface areas increase with cutting the EPS pieces with serrated edge knife or/and cutting the EPS to 2, 4, 6 and 8 pieces.
Oil sorption capacity (OSC) increased with increasing surface area, and so two pieces have OSC of 1.733 g/g more than one piece of 1.208 g/g of the same weight (0.900 g) and sorption time (5 min). Rough surface of EPS adsorbed more oil than smooth surface. Most of adsorptions were taking place at first 5-15 min. Thermo-modification (50- 90 °C) has no significant effect on oil sorption. Making holes by punching nails (0.1 mm diameter) into EPS contributed to increases OSC to 2.538 g/g for 5 min sorption time (1 piece). Increasing the nails diameter to 1.65 mm resulted to increase in OSC to 3.280 g/g for 5 min sorption time (1 piece) and 7.998 g/g for 6 pieces. The results of investigation indicated that the oil sorption mechanism of EPS waste meanly adsorption with slow capillary action. Oleophilic action between EPS and oil is the mean force governing the oil adsorption into EPS. The use of EPS waste in oil spill cleanup will reduce pollution in two ways. Reducing the garbage and oil spill remediation.
Economics Of Steam Generation For Thermal EOR
Authors: Chaar Marwan , Venetos Milton , Dargin Justin , Palmer Daniel 
Published: December 2014

Abstract
The thermal EOR steam generation projects in Gulf oilfields are on such a large scale that they affect an entire country's economic position. As such, the policies related to oilfield steam generation should be decided at the national level using the cost of the marginal fuel. This paper calculates the steam cost for three methods: 1) once-through steam generator (OTSG) 2) once-through heat recovery steam generator (OT-HRSG) and 3) solar steam generator (SSG).
We have created detailed performance and economic models of the steam generation methods and used them to calculate the levelized cost of energy and the Fuel Break Even (FBE). We explore the environmental and economic burdens on the cost of steam generation. The effect of fuel price on the cost of steam is also analyzed with a focus on the marginal fuel price.
The analysis shows that the fully burdened steam costs using $6/MMBTU fuel, for OTSG, OT-HRSG, and SSG are $27/ton, $20/ton, and $17/ton, respectively. The FBE for SSG vs. OTSG is $4.95/MMBTU when the OTSG is unburdened and decreases to $2.25/MMBTU when the environmental burden of Carbon Cost is added. The FBE for SSG vs. OT-HRSG is $7.70/MMBTU when burdened with Power Opportunity Cost and $4.50/MMBTU when the additional burdens of Carbon Cost and Water Opportunity Cost are accounted for.
Finally, we analyze the limitations of OT-HRSG in an isolated oilfield where the electric:thermal demand necessitiates electricity-matched cogeneration. This limitation along with the steam cost at the marginal fuel price provides the decisionmaker with a steam supply curve.
The Hierarchy of Collaboration
Authors: Jakeman Simon , Al-Azawi Bahir , Alkarbi Ahmed 
Published: December 2014

Abstract
Collaborative Work Environments provide seamless communications between disciplines and between teams in different locations. Traditionally they have been used to connect staff in remote locations to teams in the headquarters, allowing real time monitoring of the health of the field, and fast decision making on operational issues and short to medium term optimisation opportunities. The ultimate goal is to be quickly alerted to events and make smarter, faster decisions using the key capabilities available to the company with access to all relevant knowledge, data and analytical tools required to reach a decision.
But this drive to make smarter, faster decisions is applicable to all levels of a company. In fact it becomes increasingly important as more complex decisions are required at higher levels, which can be influenced by interpreted data, personal opinions and perceptions.
To assist decision making at all levels ADCO and ADNOC are implementing a hierarchy of collaboration centres: The traditional asset based Collaboration Work Environments (CWE) will be responsible for the day-to-day management of the fields and ensuring delivery against the business plans.An ADCO Corporate Production Real Time Operations Centres (RTOC-P) will manage the production-related interfaces between the asset teams, the oil and gas customers and the shareholders. Through the interfaces between asset CWEs and the RTOC-P, technical experts positioned in the Head Office will also be able to provide technical support to the fields in critical areas such as rotating equipment.ADCO will implement a second Corporate RTOC with the specific purpose of managing and optimising ADCO's expanding drilling programme.At the highest level, ADNOC, as the main shareholder, will implement collaboration centres to interface with all operating companies, allowing ADNOC to provide more effective support in their evaluation and approval processes.
The key objective of making smarter, faster decisions applies at all levels.
Deficiency Management as Part of Asset Integrity - a Case Study
Authors: Ellis Eric 
Published: December 2014

Abstract
As part of the company's strategic plans, Oxy has implemented an asset integrity program across its global business units to ensure that surface equipment provides safe and reliable operation over its life cycle. This program involves static, rotating, power, and control equipment, and encompasses four major elements: mechanical integrity, maintenance, quality assurance/quality control, and corrosion management.
A case study involving a production water skim tank will be presented that highlights Oxy's deficiency management process, a key component within the mechanical integrity and maintenance elements. This tank, located in one of Oxy's production fields, suffered localized corrosion due to a design flaw that put the tank at risk of being removed from service after only 2 years of operation, with a significant impact to field production. The time line and sequence of events will be presented to show how Oxy's deficiency management process is used to support sound decision making regarding continued operation of assets with known anomalies or defects.
Attendees can use the content from this presentation as a reference for their asset integrity program or deficiency management process. While this case study is from an atmospheric storage tank, the deficiency management process applies to all equipment types and is an integral part of successful mechanical integrity and maintenance programs. This topic is directly related to Operational Excellence and HSE and is of value to established integrity programs as well as programs yet to be implemented. It highlights the full life cycle of deficiency management, including deficiency identification, engineering assessment (fitness for service), temporary/on-stream repairs, ongoing monitoring, and decision making regarding continued operation of affected equipment and facilities.
This case study shows how a successful outcome can be achieved through application of a robust deficiency management process, even with equipment that suffers premature damage due to design flaws (or unanticipated changes to operating conditions). Results from on-stream inspections and fitness for service evaluations will be shared as part of this presentation.