bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gaslift Compressor Initial Start-Up Outside of the Design Envelope
Authors: Ab Halim Azuani Haslinda , Samad Johan Alimin Abdul 
Published: March 2016

Abstract
Centrifugal compressors are very sensitive to changes in operating conditions. Operations outside of the design envelope may result in sub-optimum performance and risk serious equipment damage. To accommodate different process conditions, a booster compressor may be required or the existing compressor may be re-rated or re-wheeled. However, this option is costly, time consuming and must be undertaken with due diligence. A good understanding of the compressor's process requirements and field operating limitations is necessary for the full benefits to be realized.
Low gas availability led to development of a strategy to startup a compressor outside of its normal design parameters. The implementation required only modifications to setpoints software, instrumentation and process line-up, thus eliminating the need for a booster compressor and subsequently simplifying the compression system. This strategy was applied on a first time basis without any available analog reference, and proved successful.
Analysis and Design Challenges and Solutions of 3 Sided Passive Fire Protection PFP on Steel Beam Decks for Offshore Installations
Authors: Munoz-Garcia Enrique 
Published: March 2016

Abstract
Passive fire protection (PFP) is consistently used in the oil and gas industry as a method to avoid and or delay global collapse of offshore installations. Current practice is to leave the top flanges of passively fire protected beams on coated, commonly named 3-sided protected beams. The reason for this is to ease the installation of grating on top of those beams. Although discussed in guidance documents such as API 2218 there is, to the author's knowledge, no defined design guidance or standard that allows structural steel designers to calculate the response of such configurations and assure that partially fire protected beams survive the design fire scenarios. It is therefore of interest to gain more knowledge on the heat up process and failure mechanisms of these members. Partially 3-sided protected beams engulfed by hydrocarbon and jet fires are subject to large thermal gradients on their cross-section, high temperatures which in turn cause the beams to be susceptible to a series of possible failure mechanisms such as local buckling, loss of bending or shear capacity and more commonly lateral-torsional buckling.
This paper discusses the thermal and structural response observed on typical 3-sided PFP beams used in the offshore industry. Several heat transfer finite element (FE) analyses were performed on a range of rolled I sections and plate girders, the results provide an understanding of the influence of conduction, convection and radiation in the heat up mechanism of the beams.
This study provides an understanding of the structural response and failure mechanism of 3-sided protected beams. From these results a series of design solutions are proposed and their structural performance analyzed. The pros and cons of each solution are identified as well as their range of applicability. Finally recommendations and conclusions on analysis and design approaches for partially protected beams are made based on the results of this study.
The New Frontiers of Offshore Drilling Activities: Hand-Off Drill Floor and Capability to Talk Continuously With the Bottom Hole
Authors: Calderoni A. , Angeli S. , Colaianni F. , Cantalupo P. , Parnivoda Y. 
Published: March 2016

Abstract
Offshore drilling projects are inherently more challenging to execute due to the increased risks and complexity associated with extreme working condition and unpredictable drilling formation pressure margins.
Since the time we have begun to drill with mud circulating in the hole, the mud pumps have to be turned off every time a pipe or a stand have to be added to the drilling string.
The time spent for those simple operations is not short and the crew involved is often exposed to potential risks: the mud acts as the first safety barrier in the well, without mud circulation drilling accidents, like connection kicks, stuck pipe, etc, could occur. Moreover, repetitive tasks with rig staff and heavy machinery operating in the same tight space is often very dangerous.
The offshore packages discussed in this paper introduce a new frontier for the offshore drilling activities, where everything is designed to satisfy HSE standards and the needs of improve efficiency in offshore activities.
These solutions are composed of a modular hydraulic hoist unit, of an innovative online and offline automated carousel and of a innovative drilling package directly integrated with the other rig equipment.
Not only footprint and weight reduction will be the targets of the next future; in fact, drilling continuously in a fully automated way, without interrupting the mud circulation in the hole even while adding or removing pipes, is crucial in the next future to be safe and competitive in all offshore activities.
Case Study - Hull Block Heavy Lifting Challenges for a Tension Leg Platform TLP
Authors: Ab. Majid Mohamad Azhar Bin , Mohd. Nor Mohd. Shahrizal Bin , M. Hanafi Hisham Bin 
Published: March 2016

Abstract
This paper is to provide the technical overview of the challenges encountered during the hull block heavy lifting for Malikai tension leg platform (TLP). This paper covers the methodology for the integration of the upper column block during the construction phase.
The 500 MT upper column hull block is required to be installed at a height of about 30 meters from ground. The lifting operation required usage of two (2) nos. of 1600 MT crawler cranes, which is the biggest crawler crane available in the market. A lifting procedure was prepared covering the operation, design criteria and analysis for assessments on the structural integrity of the block. The cranes and lifting gears to be used were determined and evaluated based on worst case scenarios.
Site preparations involved clearing and barricading of the operation area, ground works, cranes and other supporting equipment, facilities, lifting and installation aids such as padeyes, back-up structures, strong-backs, corbel, guide and dog plates. The lifting operations have two (2) stages. The first stage is lifting of the block from temporary supports and the second stage is shifting and installation onto the final position. The heavy lifting and integration operations for four (4) upper column hull blocks were carried-out safely and successfully within January 2015 to March 2015.
Since this is the first Tension Leg Platform (TLP) Hull constructed in Malaysia, the heavy lifting of the upper column hull blocks was treated as a critical operation. The multiple challenges and lesson learnt by production engineering and construction team during the lifting operations would be beneficial for future projects of similar structure within this region.
Multi Column TLP McT - Advanced Tension Leg Platform Technology for Marginal Field Development
Authors: Tahar A. , Nurtjahyo P. , Suardin J. , Chaniadi F. 
Published: March 2016

Abstract
Over the years, technology in marginal shallow-water development evolved and surface facility alternatives flourished. The Multi Column TLP (McT) has now been developed to respond to the challenges in shallow-water and marginal fields. This proven design is based on the same design principles that have been used successfully in deepwater for many years, and applying them to overcome some of the main challenges with exploitation of shallow-water platforms.
Innovative solutions for marginal field development should focus on cost reduction, shorten development schedules and exploit previously uneconomical fields. It is well understood that the economic viability of a marginal field development is not only dependent upon the quality of reservoir but is also dependent upon the development cost of offshore facility starting from engineering, procurement, construction, installation until decommissioning.
For oil and gas operators, consideration for cost reduction is of strategically imperative to fully realize the commercial value of offshore projects. Cost savings may derive from the use of the platform for several fields so that platform cost can be distributed, or through the use of other lower specification vessels for transportation and installation when compared with those required for a jacket. Other potential cost reductions may be achieved from fabrication method, engineering requirements and decommissioning plan.
This paper present a technical capability and global performance results of McT for use in the offshore marginal field functioning as utility platform. Design philosophy of McT which is derived from proven and succesfull Cell Spar, TLP and Buoyant Tower technology is presented. A case study are provided to confirm the motions, accelerations, wire tendon tensions and stability. The economic assessment of McT is presented in a separate paper [Ref. 1].
Pioneering HPHT Field Development in Malaysia
Authors: Sofian Anas M. , Noreffendy Jayah M. , Farris Bakar M. , Fadzliana Azmi N. , Syahmi M. , Yusof M. , Rahman Iz'aan Irfan A. , Nizam Baharuddin M. Haidir , Kamil Ishak M. Izham 
Published: March 2016

Abstract
Recognised as the first high pressure and high temperature (HPHT) development ever embarked by PETRONAS as well as the first of its kind in Malaysia, KN-UUD Development had also marked a significant step change in well engineering design approach for Asia Pacific region.
Learning from experience of HPHT operators in the North Sea and the Gulf of Mexico, a detailed focus on lifecycle well integrity aspect had been thoroughly emphasised throughout the well design phase. Innovative design thoughts, meticulous process in selecting cost effective solutions and strong collaboration between operator and service providers proved to be the key ingredients for success.
This paper highlights the sophisticated journey of KN-UUD HPHT development well delivery, covering the initial scoping work, design phase, equipment (and material) planning and testing, execution phase as well as the lessons learnt from the campaign.
Challenges and experiences discussed include:
Depletion on shallow reservoirs, its impact towards pore pressure and fracture gradient profile and subsequently, overall well design. First implementation of big bore well design with liner and cemented tieback philosophy in Asia Pacific. HPHT lifecycle integrity aspect and considerations on worst case scenario i.e. reservoir compaction study, cement stress analysis, tubular connection and material testing. Challenges in dealing with non-availability of equipment (including material) and lack of service capability within the region. Complex process of identifying and procuring fit-for-purpose equipment solutions and unique contracting strategy. Annulus management philosophy for HPHT development. Lessons learnt from the actual well construction phase.
The well was successfully delivered to meet all of its objectives, producing from layers close to 16,000 ft. beneath the seabed. The complex process, obstacles and vital experience in overcoming the challenges has pioneered a path for future application of its kind within Malaysia and Asia Pacific region.
Understanding Noises from Different Flow Mediums in Near Well Bore Region: A Novel Approach for Detection and Characterisation of Sub-Vertical Natural Flow Paths in North Kuwait Gas Fields
Authors: Acharya M. N. , Al-Mershed A. , Narhari S. R. , Al-Azmi M. , Dashti Q. M. , Chakravorty S. , Abdulkadir R. I. , Prosvirkin S. 
Published: March 2016

Abstract
Kuwait Oil Company is developing deep tight fractured carbonate and kerogen rich shale gas plays in northern part of Kuwait. Understanding the flow medium is important to resolve ingress of offending fluids such as water and salt during production history in the vertical/deviated wells of this play.
These unconventional reservoirs have been established to be hydrocarbon producing in several prolific vertical producer wells, without having such early water breakthrough. The tight fractured limestone reservoir is sandwiched between salt-anhydride sequence above (Gotnia cap rock) and Kerogen rich carbonate below. A dedicated casing is set at the top of limestone reservoir with the main objective of isolating the Gotnia section prior to opening the reservoir, as some sequences of anhydrites with calcite stringers in Gotnia are high pressured and prone to high water, CO2 and H2S. Based on the current understanding, main source of offending fluids is suspected to be the overlying Gotnia formation, which has limestone stringers.
Fracture studies from several conventional cores and image log data could not conclusively infer through going fractures into Gotnia, although many sub-vertical fractures of different nature have been observed and interpreted in the reservoir section in these logs.
This paper highlights the approach for detection and characterization of flow mediums, in the near well bore region (NWR) within a diameter of investigation of 3 meters or 10 feet. Results of spectral noise log (SNL), high precision temperature (HPT), pressure and natural radioactivity (GR) of a vertical well logged in shut in and flowing mode helped in understanding different flow mediums such as channel flow, fracture flow and reservoir flow. Thus the detection and characterization of different flow path systems with respect to their spatial dimension and their interactive flow contribution could be ascertained with high confidence.
UBD Fractured Basement Pilot Project Case Study in Malay Basin: Transforming a Quartile 3 to Best in Class Performance
Authors: Hafiz M. , Makri M. , Ismail M. Mukhriz , Syafiq M. , Shah M. , Jawing Sherene 
Published: March 2016

Abstract
This paper highlights PETRONAS's journey and experience in the Underbalanced Drilling (UBD) fractured basement pilot project, a 2 wells campaign in the Malay Basin. An integrated UBD team, has set best in class performance, applying lessons learnt in the 1st well to the 2nd well. Major highlights are the key learnings implemented, challenges turned to opportunities, overall project management, well delivery process, well assurance safety processes, achievements and future enhancements for UBD operation.
The process started with a comprehensive UBD Fractured Basement Pilot Project Feasibility study, assisted by risks assessment process which turned into a full engineering and execution plan. Well planning, well constructions and execution of this project will be highlighted. Relevant operational excellence process in PETRONAS such as DWOP, AAR, HAZID, and HAZOP has contributed to excellence in HSE and well delivery performance. Internal assurance process including Wells Peer Review and COP has facilitated a safe and successful project delivery. A multidiscipline and integrated wider scale project execution successfully yielded a noticeable performance improvement in the 2nd well in comparison to the 1st well.
For a back to back UBD well, the key learnings have been immediately brought forward and implemented in the 2nd UBD well. Results were apparent and can be demonstrated by the well KPI performance and benchmarking against other operators in Malaysia within the same class. This UBD pilot project demonstrated the project feasibility to drill a challenging fractured basement using UBD technique, which can be further enhanced and replicated to a similarly suitable projects. Overall, the 2nd well was completed 27 days ahead the planned days, with significant cost saving and total NPT of only 4.72%; while managing to drill with additional scope as requested by subsurface.
This campaign provided a basic foundation to institutionalize UBD capability and also will open up a new chapter in PETRONAS's involvement in the whole process starting from well planning & engineering, well construction, and post mortem for UBD specific projects in the future. This template will be used, replicated and improvised to suit future UBD drilling campaign particularly in PETRONAS' operations. In line with the dynamism of this Company, and frequent approach for creative & non-conventional technology implementation, it has kept PETRONAS abreast with a niche and most advanced industrial practices for a better & more effective natural resources exploration supporting the ability to maintain the supply of global non-renewable energy demand.
Cost Effective Project Delivery Through Fire and Gas Mapping Study Performance Evaluation Using Improved Risk Based Approach
Authors: Cao Sunny , Yeung Mandy , Wan Jones 
Published: March 2016

Abstract
Traditionally, F&G detectors are positioned based on engineering experience, industry practices, or prescriptive standards. In recent years, Fire and Gas Mapping (F&G Mapping) studies which utilise 3D based computer aided mapping tools have been recognized as an effective way for Fire & Gas detection system design. Such a study has the advantage of quantified detection coverage to ensure prescribed performance targets are met and deliver optimised Fire & Gas detector layouts.
In the Oil & Gas industry, the most widely adopted F&G mapping assessment guidelines are BP GP 30-85 and SHELL DEP 32.30.20.11. Comprehensive F&G mapping requirements are described in these guidelines including: Risk grading of the fire and gas detection areas; Target fire and gas cloud sizes associated with the risk grade; and Performance coverage requirement (i.e. target coverage percentage) associated with the risk grade.
The BP guideline adopts the risk based mapping requirements, i.e. fire and gas detection zones are classified as different categories (high / normal / low fire risk areas, fully-enclosed / partially-enclosed / open areas based on congestion and blockage), and corresponding target fire and gas clouds of various sizes and target coverage percentages are assigned, in order to provide more cost-effective solutions to deploy the F&G detection systems. The SHELL guideline adopts a similar concept in gas detection by differentiating the target cloud sizes based on the congestion and blockage level of the detection areas.
A more recent challenge in the industry involves cost-effective project delivery through F&G mapping assessment to cater for two major concerns: Assurance of safety performance of the F&G detection system, i.e. provide adequate detection coverage; andOptimization of the F&G detection system to minimize CAPEX and OPEX.
The above trend requires improved F&G mapping calculations to reflect the actual performance of the F&G detection systems, meanwhile, taking into consideration the actual scenarios in fire & gas release events thus leading to further improvement of the risk based F&G mapping approach for performance evaluation. A consistent strategy for conducting F&G mapping studies at various project stages is also essential to minimize the discrepancies in conclusion due to changes in different engineering design stages.
This paper illustrates cost effective solutions through risk based approach F&G mapping study developed by ERM following completion of numerous F&G mapping projects. The paper also presents improved approaches to F&G mapping when evaluating the F&G detection system effectiveness.
A Novel Approach to Estimate Severity of Paraffin Deposition Inside Production Tubing for Vertical Lift Performance Matching in Well Models
Authors: Haindade Zishaan M. W. , Mundhe Pramod A. 
Published: March 2016

Abstract
The vertical-lift performance curves are often generated with the aid of computer software for creating well models of producing oil and gas wells. These models are used as tools for optimizing fluid production, generation of production forecast and well problem diagnosis. The well models are further used to plan for future requirement of artificial lift assistance.
One of the important components for development of representative well models is the Vertical Lift performance and Inflow Performance curve matching. The vertical lift performance curve is generated separately using well test data using various correlations and the best matching correlation to actual well pressure gradient is selected for VLP-IPR matching. The VLP depends on various factors such as tubing size, gas-liquid ratio, wellhead pressure, etc.
The producing oil wells having higher paraffin content tend to deposit paraffin wax inside the production tubing reducing the flow area and increasing the pressure drop. The deposition generally occurs near the surface and at greater depths the tubing is free from deposition due to higher temperature because of the geothermal gradient. Due to this an error is induced as the effective inside diameter of tubing is less than the actual diameter entered by the user, this leads to variation in the actual and calculated pressure drop ultimately leading to deviation by more than 10% in many cases.
This paper describes implementation of method to enter the severity of paraffin deposition in a particular length of tubing and dividing the total length of tubing into sections having different internal diameters. The estimation of deposition can be done by carrying out mechanical scraping operation in which the wax is cut mechanically using paraffin cutters of various sizes starting with the smallest and gradually increasing to higher sizes of cutters. The restriction due to wax is evident at the surface by monitoring the weight loss in the wireline weight indicator.
By using this method an accurate well model can be created which will represent the actual behavior of the producing well thereby increasing the accuracy of any further predictions.
Quest for Safety and Simplicity -Choosing an Appropriate Liquefaction Process Technology for FLNG Application
Authors: SIM Charles , TEH Erine Siew Pheng 
Published: March 2016

Abstract
Objectives/Scope: Keppel has identified the market need for a simple and safe natural gas liquefaction process to meet challenging offshore environments where production supports are limited. Such need is also amplified in smaller scale FLNG production plants of up to 2-3 MTPA.
Methods, Procedures, Process: Leveraging on Keppel extensive experience in FPSO conversion, Keppel is trusted to convert the first of its kind FLNG from an existing LNG carrier. In the pursuit of FLNG applications, operators desire a safe and robust process with easy operation consisting of low equipment count and low complexity. To respond to this market need and to leverage in its vast knowledge and experience in the FPSO conversion business; Keppel has developed a proprietary liquefaction process named PreNEx (Precooled Nitrogen Expansion), which is based on a widely accepted nitrogen expansion technology. It employs a single Nitrogen Expansion cycle together with an independent biphasic non-flammable refrigeration cycle for precooling, which is widely used in the air separation industries to achieve comparable liquefaction efficiency to that of multiple expander system without compromising safety, process simplicity, reliability, robustness and flexibility. Such innovative process allows for the conversion of old LNG carriers into FLNG facilities, thus providing a safe and simple alternative solution for small and midscale FLNG solutions. This study covers the optimization of the liquefaction process through simple heat flow redistribution with a process knowhow based on proven process cycles that are already in use, industry wide.
Results, Observations, Conclusions: PreNEx provides a simple, safe and sustainable alternative natural gas liquefaction process for deployment of FLNG. Precooling, condensate recovery and handling become independent from liquefaction operation. It has simple configuration of liquefaction heat exchanger and compression expansion of refrigerant, yet giving comparable thermal efficiency as other refrigerant compression expansion process.
Novel/Additive Information: While LNG liquefaction technologies in the market go towards complexity and fine process conditions to achieve efficiency, PreNEx uses the fundamentals of thermodynamic and heat transfer to achieve efficiency through redistribution of heat load in the process.