bluuebunny/crossref_metadata_2025_split huggingface dataset:
Prospect Exploration Risking Using Modern Geophysical Technology
Authors: Moreno Carlos E. , Perez Maria A. , Meyer Jeffrey Scott , Huffman Alan R. , Etemadi Mohammad , Benkovics Laszlo 
Published: July 2009

Abstract
Amplitude versus offset (AVO) and spectral decomposition (SD) techniques were used for direct hydrocarbon identification (DHI) in the Plio-pleistocene section in Deep Water Trinidad & Tobago to help to quantify better the risk during hydrocarbon prospecting. In order to understand and predict the seismic response for different fluid types and lithologies, AVO and SD modeling based on existing well log information close to the study area were performed. The controlled synthetic models simulated the seismic response for wet sands, commercially saturated gas sands, and partially saturated gas sands, as well as variations due to lithology. After modeling and validation of the technique with real pre-stack and post-stack seismic data on calibration well locations, seismic analysis supported with AVO and SD technologies was performed to evaluate prospects located in Deep Water in Trinidad & Tobago. Very subtle differences in the AVO and SD responses were the only way to discriminate between hydrocarbon and lithology. Very subtle variations during AVO and SD analysis suggest that the lithology factor can produce false DHI in the area. SD also showed the potential of helping separate fully saturated gas sands from partially saturated gas sands.

Introduction
The use of amplitude versus offset (AVO) and spectral decomposition (SD) techniques for direct hydrocarbon identification (DHI) in the Plio-pleistocene section in Deep Water Trinidad & Tobago can help to quantify better the risk during hydrocarbon prospecting. These seismic technologies require the use of pre-stack and post-stack seismic data that has been processed for preserving relative amplitude and frequency spectrum. In order to understand and predict the seismic response for different fluid types and lithologies, AVO and SD modeling based on existing well log information close to the study area was performed. The controlled synthetic models simulated the seismic response for wet sands, commercially saturated gas sands, and partially saturated gas sands, as well as variations due to lithology. The fluid substitution was performed using Gassman's equation after proper petrophysical analysis and invasion/dispersion corrections were done on the well data.

Petrophysics and Fluid Replacement
Invasion and dispersion corrections were applied to the well log data previous to fluid replacement. Fluid replacement was performed using Gassman's equation to simulate the fluid and saturation effect on the well log response on the P-Wave Velocity, Density and S-Wave Velocity due to the presence of brine, partially saturated and full gas sand cases. The resultant fluid replacement log responses are shown in figure 1. Figure 2 shows a sketch of the expected response for P-Wave Velocity, Density, S-Wave Velocity, Poisson Ratio and Acoustic Impedance for the same fluid cases.
Scenario-Based Assessment of Risks to Ice Class Ships
Authors: Kendrick Andrew , Quinton Bruce , Daley Claude 
Published: July 2009

Abstract
The rise in resource related projects in the Arctic has created the need for new approaches to assessing and minimizing risk. The new tankers and drill ships required for the Arctic will be larger and stronger than any previous ships, but will be very carefully designed and operated. The paper presents a methodology for assessing risk to large Arctic ships in a variety of scenarios. For the purpose of illustration of the approach, two ice collision scenarios are described. One is the case of a large ship with a bulbous bow hitting an iceberg head-on. The second is an aft waterline collision with a sea ice floe. Both scenarios are outside the conditions formally considered in standard ice class rules but are significant issues. The paper provides owners/designers/regulators with an example of a methodology to examine ice loads using a rational set of design scenarios. The results show that vessels can easily be operated in a manner that can create dangerous load levels. The results are directly relevant to the structural design of new large Arctic tankers (oil and LNG) and large Arctic drill ships. The second part of the paper presents some initial results from consideration of plastic structural response to moving ice loads. The significance of the movement (sliding) of the load increases as the response level increases. Elastic responses are only slightly influenced by the movement of the load along the hull, while the larger plastic responses are greatly affected by movement. This paper is mainly intended to raise this as an issue of potential concern.
The Value of Model Testing in Understanding the Behavior of Offshore Anchors: Towards New Generation Anchors
Authors: Ozmutlu Senol 
Published: July 2009

Abstract
This paper introduces the model testing of drag embedment anchors under laboratory and offshore conditions. As the anchors form the foundation of a floating unit (both permanent and temporary), the model tests help in designing new generation anchors with higher performance and reliability. Furthermore the physical models are used to test and simulate the anchor handling/installation procedures, and serve as powerful teaching aids for operating personnel offshore.
The new directions in psychical model testing of offshore drag anchors are highlighted. The benefits of well controlled testing and the ability of measuring new anchor-ground interaction variables are discussed. It is shown that the new model testing programs will increase our current understanding of the anchor behavior and performance in operational and storm loading conditions.

Introduction
A special category of drag embedment anchors is a commonly used foundation option for offshore mooring of floating units (i.e. MODU, SPM, FPU, FSO, FPSO, etc.). The anchors in this category are labeled as High Holding Power (HHP) anchors owing to their very high efficiencies or performance ratios. The old generation drag anchors had efficiencies (i.e. the ratio of Ultimate Holding Capacity - UHC to dry dead weight of anchor) as low as 3, and had suffered from penetration and stability problems in slightly challenging subseabed soil conditions. Today, the modern HHP anchors have reached efficiencies over 65 by overcoming the penetration and stability issues thus presenting a reliable as well as practical and economical foundation solution in challenging soil conditions. This development would not be possible without continues testing of scaled model anchors in laboratory, in centrifuge, and under actual field conditions.
This paper presents the model testing of both fluke (e.g. Stevpris - Stevshark series) and plate (e.g. Stevmanta VLA series) anchors (Figure 1) of drag embedment type. The drag embedment fluke anchors are commonly used in catenary mooring systems whereas the drag embedment plate anchors (i.e. Vertically Loaded Anchors - VLAs) are commonly chosen for semi-taut or taut-leg mooring systems. Both anchor types are installed by lowering the anchor to the seabed first and then by applying a pull load from a surface vessel (Vryhof 2005).
The quantities given in this text, unless otherwise referenced in the text, refer to the in-house testing database and track record of the company that the author is affiliated with.
Required Developments Towards Ultra High Pressure/Temperature Subsea Tree System Solutions.
Authors: Queseth Per-Olaf , Dyson Andrew 
Published: July 2009

Abstract
The need for oil and gas in the world wide market does not seem to have an established limit. With the hydrocarbon prices on to-days level and the long term tendencies of a steady average increase, new fields have to be found and produced regardless of existing technology gaps. For the subsea oil and gas production systems, there are many challenges but what seems to be a primary challenge is to provide good solutions for High Pressure, High Temperature reservoir exploitation based on an overview of already discovered potential fields and an evaluation of what might come.
The paper will present a résumé of Aker Solutions previous development in this area exemplified with experiences from testing and operator observations during production start.
Further improvements are required to comply with the extreme pressures and temperatures sought to overcome.
The presentation will therefore compile current international standards impact on this development, sorting of material parameters upsetting the progress, nominating materials with high potential and giving an indication on how to qualify these materials for use.
History have shown the importance of combined, cyclic testing with multi parameter variation and even forming and finding the right testing facilities is tedious and costly. An overview of current availability and future needs will be tabled and requirements formed.
To make a practical approach to all the details involved and all the standards impacting the end result, a program to qualify subsea production X-mas trees will be presented with high-light on feed-through solutions for hydraulics, electric and optic power and signal communication. Preliminary and intermediate test results will be presented and outstanding activities summarized.

Summary

Introduction
When newly industrialized and heavely populated countries like China and India really starts to increase their number of motorized viechles there will not be an immediate limit to their need for destilated hydro carbon products. Hence there will be exploration to find new reservoirs in places and under conditions not yet seen today.
Although hydrocarbon reservoirs are found onshore as well as offshore, this presentation will concentrate on offshore field developments and more specifically fields equipped with subsea production equipment. Production equipment is classed by API or ISO. The majority of current subsea completions are designed for Class U (10 Kpsi and 121 oC) and this is the level required for 80 - 90% of all found reservoirs.
High Pressure, High Temperature level is currently considered as above 10 Kpsi. and 150°C.
A number of HPHT discoveries, previously on hold while suitable HPHT technology has been engineered, are now being enquired about, considered for development, contracted and some already delivered.
SS: MODU Anchor-Changes in anchoring rules and regulations for MODUs
Authors: Ruinen Roderick Michael 
Published: July 2009

Abstract
The past few years have seen the updating of codes for the use of drag embedment anchors (fluke and plate anchors). Examples are the specific requirements for drag embedment anchors in the Gulf of Mexico due to the hurricanes and the updating of anchor codes in Norway. This paper will summarize the current rules and recommended practices for drag embedment anchors and their application. It will then show the effect on drag embedment anchors and the application for MODU moorings.

Introduction
Most floating MODUs are moored using drag embedment anchors, either fluke or plate anchors. Setting of the anchors using conventional guidelines has generally been sufficient to ensure a safe mooring. However recent hurricanes in the Gulf of Mexico resulted in a number of mooring failures. Storms in the North Sea have also resulted in a number of mooring failures. These mooring failures and specifically anchor failures have resulted in new guidelines and regulations being developed for among others the Gulf of Mexico region and the Norwegian section of the North Sea. This paper will focus on these guidelines / regulations with regards to the use of drag embedment anchors for MODU operations.

Background

Gulf of Mexico
In the period 2002 to 2008 a number of severe hurricanes passed through the Gulf of Mexico region causing severe damage to offshore infrastructure. Damage consisted of floating MODUs drifting off station due to mooring line failures and damage to fixed platforms and jack-ups. During hurricanes Ivan (2004), Katrina and Rita (both 2005) a total of 17 moored MODUs broke free from their moorings and drifted off-station for a distance larger than 1 mile. Of these, only four cases reported the drag embedment anchors dragging for a significant distance. The damage that occurred to the platforms has led to the development of interim guidance for the 2006 and 2007 hurricane seasons (API 2006) and an amendment to API RP 2SK (API 2008).

North Sea
The regulation of offshore safety in UK Continental Shelf (UKCS) is the role of Health and Safety Executive (HSE) and Department of Energy. In Norwegian Continental Shelf this role is shared by Norwegian Maritime Directorate (NMD), Petroleum Safety Authority (PSA) and Norwegian Petroleum Directorate (NPD).
For the UK continental shelf the audits and accident statistics between 1981 and 2003 are published by Health and Safety Executive (HSE 2005). Within this period, among 3485 reported incidents on all moored units (permanent and mobile), 240 incidents relate to mooring system failures (a failure frequency of about 0.2). The mooring system failures include problems with mooring lines, mooring devices, winching equipment or fairleads, and anchors. Among the 240 mooring incidents only 34 incidents are categorized as accidents, the rest are incidents of near misses or insignificant situations. Only one of the 34 incidents categorized as accident relates to anchor drag due to one line being damaged and the tension control on the winches could not be implemented.
Intelligent Wired Drill-Pipe System Provides Significant Improvements in Drilling Performance on Offshore Australia Development
Authors: Lawrence Luke , Redmond Bruce , Russell Richard Buchanan , MacNeill Dave , Reeves Michael E. , Hernandez Maximo 
Published: July 2009

Abstract
An ‘Intelligent’ wired drill-pipe system has recently been used on a large offshore development in North West Australia for Apache Energy Limited. The IntelliServ® network is designed to overcome the shortcomings of mud pulse telemetry in terms of real-time data transmission speeds and pulser reliability. By utilising this unique system of Intellipipe® wired drill pipe and associated drilling tools connecting the Rotary Steerable System and LWD string to the surface, transmission speeds of up to 57,000 BPS theoretically can be achieved.
For the development of the Van Gogh Field, Apache Energy Ltd decided to utilise the IntelliServ system along with Halliburton's rotary steerable system and LWD tools.
This paper will describe the wired drill pipe network and its integration with a drilling assembly containing a rotary steerable system, multiple formation evaluation and drilling dynamics sensors. The objectives for running the wired drill pipe system on this project will be discussed and the actual operational experience reviewed. Topics to be covered will include the improvements in drilling optimisation and drilling performance, the increased accuracy in wellbore placement, and the improved quantity and quality of the formation evaluation data received in real-time. The future uses and benefits of this technology also will be reviewed.

Introduction
Modern MWD and LWD sensors now generate so much data that it is not possible to take full advantage of this data due to the limitations imposed by conventional mud pulse telemetry systems. Although advances have been made in the form of data compression and batch transmission modes, mud pulse transmission is still the limiting factor in many potential applications.
Typical LWD assemblies may now consist of tool combinations including gamma-ray, multiple resistivity, density and neutron petrophysical measurements. The latest LWD sensors can provide formation images, sonic waveforms, and multiple geosteering signals, all of which require large bandwidths in order to take full advantage of them. In addition, directional survey data, downhole drilling optimisation measurements also may be transmitted. This amount of data can place a great strain on conventional mud pulse telemetry systems. As drilling rates increase the data density of the real-time measurments becomes increasingly sparse until at some point, drilling rates must be held back to ensure that a useable log is received in real-time.
Enabling Ultra-Deepwater Mooring with Aramid Fiber Rope Technology
Authors: Chi Cheng-Hang , Lundhild Evelyn Margaret , Veselis Todd , Huntley Mark 
Published: July 2009

Abstract
New high-strength synthetic ropes constructed of para-bonded aromatic polyamide (aramid) fiber are being developed for ultra-deepwater mooring applications. This paper highlights new laboratory tensile/fatigue testing of rope assembly, computer modeling analysis of mooring performance under operating conditions, and the potential economic impact.
As the industry moves into ultra-deep water, traditional steel wire rope and chain moorings are being gradually displaced by polyester ropes. These synthetic ropes have been used in water depths between 3,000 feet and 8,000 feet. Questions arise, however, about whether polyester mooring ropes provide enough stiffness to maintain acceptable platform offsets in increasingly deeper water in all cases. Aramid fiber ropes are inherently stiffer and stronger than polyester ropes and therefore offer new solutions for ultra-deepwater mooring, as well as for other applications where production platform offsets may be critical.
Advanced technologies are being developed to optimize aramid fiber performance and rope design configurations. New laboratory tensile and fatigue data are presented to demonstrate aramid fiber rope properties, performance capabilities, and minimum tension settings meeting API RP 2SM guidelines. Mooring analysis comparing the performance of an aramid mooring system with that of a polyester mooring system under simulated hurricane and loop current conditions shows significant reductions in platform offsets are achieved with the aramid system without compromising safety.
This paper describes a new technology for ultra-deepwater mooring. The new approach offers the opportunity to design mooring systems for deeper water without modifying certain platform components and systems by incorporating stiffer, high-strength aramid fibers in the platform mooring system. Potential benefits include achieving optimal offsets for production risers in ultra-deep water, easier handling and installation due to smaller rope size, and greater flexibility in mooring system design. Economic analyses are presented to illustrate the advantages of the new technology as well as the financial impact.

Introduction
Industrial and commercial grades of aramid fiber have been used successfully for more than 25 years in numerous marine rope and cable applications, because of their unique combination of physical characteristics and performance capabilities. The linear molecular structure of aramid fiber yields a strength-to-weight ratio more than five times that of steel wire in air and more than 20 times steel wire in water. Aramid fiber is corrosion-resistant, nonconductive, and exhibits low elongation properties—or stiffness--in response to high loads, variations of mean load and rapid cyclic loading. Aramid fiber also performs well in arctic or elevated temperatures and is highly resistant to tension-tension fatigue.
Advanced Flow Assurance System For The Ormen Lange Subsea Gas Development
Authors: Lunde Glenn Gahr , Vannes Knut , McClimans Ole Thomas , Burns Cathy , Wittmeyer Kristina 
Published: July 2009

Abstract
Ormen Lange Flow Assurance System (FAS) is to date the most advanced real time and simulation support system for operators, flow assurance engineers and management. The system is delivered by FMC Technologies with SPT Group and Prediktor as sub-suppliers.
The Ormen Lange field is the largest gas sub-sea development of its kind with onshore processing facilities at the Nyhamna on the west-coast of Norway.
Several flow assurance challenges must be taken care of to enable secure and stable production in deep water (down to 1100 m/ 3600 Feet), low temperature (-2°C/ 29F) at the seabed in addition to long distance (120 Km/75 Miles) to shore through rough sub-sea terrain. Such conditions highly expose the production system to potential flow assurance phenomena like hydrate formation, liquid holdup, water breakthrough etc..
Ormen Lange FAS represent a barrier breaking system and play an important role in production monitoring and operator support. The system includes the following modules:Virtual Flow Metering System (VFMS):Model generated values of flow rates (gas, condensate and water) as backup to physical multiphase meters, sensor surveillance and leakage detection.Pipeline Monitoring System (PMS):Model generated values of pipeline flowing conditions and onshore receiving facilities.MEG Injection and Monitoring System (MIMCS):Continuous MEG injection monitoring and optimization.Production Choke Control System (PCCS):Individual well production chokes control for overall field optimization.Formation Water Monitoring System:Monitoring and alarm generation when / if formation water breakthrough is indicated. The system is based on advanced usage of statistical process control.
Based on practical experience gained in the period from December 2007 up until now, this paper focus on the systems potential of early detection of flow assurance problems, sensor and metering surveillance and how the system is being used to solve practical day to day operational challenges.
During the last years, the status of the Ormen Lange development project has been reported during OTC, as well as in other conferences and in papers, covering a multitude of disciplines and methods in order to finalize such a grand challenge. In 2007 there was a dedicated technical session for the Ormen Lange development as part of the OTC program, /1/, /2/, /3/, /4/, /5/, /6/ and /7/.