bluuebunny/crossref_metadata_2025_split huggingface dataset:
High-power Subsea Electrical Connector Technology: Meeting the Challenge
Authors: Musker F. 
Published: October 2008

Abstract
Subsea electrical connectors are now common place for low voltage data communications with subsea control modules, sensors and actuators. This patented and proven technology, based on pressure balancing techniques, is now being applied to higher power applications, feeding electrical power to a variety of pumps. separators and pipe line heating systems. This paper details the advances in materials, connector design, testing and analysis which have been addressed to support voltages to 36,000V and current up to 1000A.
Applications for this technology first arose in 1987 when an 11,000V connector was developed for the SBS project for AGIP, followed by the SISL project (OTC paper 7289, 1993 by J.A. Nicholson1), which was the basis of the well head connector design for Petrobras RJS 221, the world's first subsea ESP project.
Since then, Amoco Liuhua - the first commercial ESP project, has provided reliability data for medium power connector systems across 20 wells, and many other projects are emerging. This paper outlines the various applications (past, present and future) and addresses the challenges now being faced by the connector manufacturer.
The demand for more power and smaller space envelopes has driven materials development to produce polymers which have high dielectric strength combined with tolerance of high temperatures and good mechanical stability. The paper will include an overview of material advances and will detail the significant impact which these new materials have made on the overall performance of power connectors. The subtle differences between varied applications are also described, including advanced termination practices.
The high power electrical connector represents key enabling technology and is of strategic importance to the industry as a whole as higher power pumps, complete multi element subsea distribution systems and separators proliferate.

Introduction
The development of subsea power connectors has been a continuously ongoing process for more than 10 years. The early designs concentrated on dry mateable subsea deployed connectors.
To appreciate the next steps we need to review the history of the development by a potted history of the progress attained to date.
From Tronic's viewpoint a major technological step towards wet mateable subsea connectors came with the successful qualification testing of the Controlled Environment (CE) principle.
The initial development of a 6.6kV single pin wet mateable connector (funded by AGIP) began in 1989, the project was successfully completed and fully tested in 1991. This successful completion led to the extension of the project to include an 11kV 400A 3 pin subsea mateable connector, this development was completed in 1992 after a stringent and successful test regime.
In 1991 the development of a wellhead power connector for ESP application was initiated by Subsea Intervention Systems Ltd, a joint venture between a number of oil companies and manufacturers.
Turret Mooring System: The Key to Oil Production in the Extreme Atlantic Frontier Environment
Authors: Vogt Christoph , Goodman Martin L. , Han Commandeur J.A. 
Published: October 2008

Abstract
This paper describes the engineering solutions for the mooring and fluid transfer system meeting the challenges for the Schiehallion FPSO installed West of the Shetlands Islands in the UK sector for BP Exploration. It will also highlight some of the related aspects met during the construction and installation of the system.
This FPSO was installed in summer 98 and started producing oil on the 29 July 1998, 27 months after project sanction. It will remain on station in this harsh environment for 25 years, weathervaning around a turret anchored to the seabed by means of an array of 14 composite anchor legs. The turret mooring system belongs to the family of the "passive free weathervaning internal turrets" and allows the installation of up to 24 risers for oil production, gas lift, water injection and well control.
The turret incorporates two novel design features including:–The main weathervaning system of the "passive internal turret" consisting of a sophisticated bogie arrangement instead of the more conventional single roller bearing solution.For the combined requirements for strength (extremely large mooring loads), space (multiple risers) and redundancy, the bogie solution, derived from crane technologies have now been applied.–The swivel-stack, which is inverted and is suspended from the gantry structure, so reducing the overall height of the turret manifold and gantry structure.The FPSO is now at its location for approximately 4 months. The turret mooring system has proven to be the ideal solution for applications in extreme environmental conditions, for large field developments and high production rates.

Introduction
A contract was signed in June 1995 between BP and an Alliance comprising B&R, Harland and Wolff and SBM to develop the FPSO for Schiehallion. Sanction was given to the project by BP and his partners in February 1996.
The harsh environment encountered in the Schiehallion field, offshore the Shetland Islands in the Atlantic Frontier area, in combination with the 24 risers, required a new dimension of a mooring system. An Internal Turret was chosen to allow the vessel to freely weathervane and to transfer the fluids and services from subsea to the vessel and reverse. The required turret diameter to accommodate 24 risers precluded the use of a conventional slewing ring arrangement as used in the previously built SBM turrets for the North Sea. Two designs were studied and compared, a split rollerbearing of 12m diameter, mounted at the vessel maindeck level and a bogey arrangement derived from previously used systems in the large Offshore cranes delivered by IHC' Gusto yard. The bogey system was chosen for the application, design features and some of the challenges for the construction are described in the following chapters.
Global Performance Comparison between Composite and Steel Tendons in Ultra Deepwater TLPs
Authors: Wu S. , Karayaka M. , D&apos;Souza R. 
Published: October 2008

ABSTRACT
Tendons that vertical moor TLPs are a major cost driver in deepwater TLPs. Carbon fiber composites have many of the desirable material properties for use as TLP tendon as an alternative to steel. This paper investigates the performance and cost impact on the overall TLP design. The focus is on the comparison of global performance of two generic Gulf-of-Mexico TLPs with steel and composite tendons in 7,000 ft water depth. Fully dynamically coupled TLP-tendon system dynamics of both TLPs has been analyzed in time domain with hydrodynamic input complete to 2nd order. The use of composite tendons leads to improvements on global performance related to airgap, maximum horizontal offset and maximum tendon tension. These improvements have been achieved despite the fact that the heave natural period of the TLP with composite tendons has been increased to 4.72 second from 4.2 second for the TLP with steel tendons. It is demonstrated that use of composite tendons in lieu of steel results in significant reduction in pretension, hull size and hull steel.

INTRODUCTION
The tension leg platform (TLP) is a proven floating offshore structure for deepwater drilling and production. However, the high cost of steel tendons is a major cost driver, perhaps even limiting its commercial application in water depths beyond 6,000ft. Alternative tendon materials must be investigated for TLPs to remain cost competitive in these water depths. The most promising appears to be carbon fiber composites, which have material properties highly desirable for use as TLP tendons. Although there is lack of experience in the use of these materials as critical components in offshore applications, interest has been growing in their potential use, such as TLP tendons.
This paper compares the global performance of Gulf of Mexico TLPs in 7,000 ft water depth configured with steel and composite tendons, respectively. Global analysis is done in time domain by considering the full dynamic coupling of the vessel-tendon system. The hydrodynamic computations are complete to 2nd order to account for the slow drift motions in the horizontal plane as well as the springing motions in the vertical plane. The analysis results have been discussed together with the potential benefits of composite tendons regarding reduction in TLP size, maximum tension on foundation, tendon dynamics and fatigue and platform response.

COMPOSITE TENDON

Material
Carbon fibers possess highly desirable material properties for use as TLP tendons. These include high stiffness/weight ratio, high strength/weight ratio, high resistance to fatigue and corrosion, and high material damping. With proper jacketing, adequate abrasion resistance can be achieved. Table 1 shows the properties of typical carbon fiber composites.
The Status for of the Submersible as a Useful Tool Offshore Resource Recovery
Authors: Horton Thomas F. 
Published: October 2008

Five years ago on the first of March 1964, the Shell Oil Co. leased the services of the Cousteau Diving Saucer for a one-day operation to evaluate the submersible in terms of its usefulness as an observation inspection tool for a subsea production well-head. This operation was conducted off of Gaviota in the Santa Barbara Channel. To my knowledge this was one of the first uses of a manned submersible as a useful tool for offshore resource recovery.
The offshore resources industry has changed and progressed dramatically in the past five years. This is particularly true of the offshore petroleum industry. In this five year period, thousands of acres of underseas leases have been taken and at greater and greater depths. New technology in both exploration drilling and production have been developed. Millions of dollars have been invested in new equipment and tools for offshore resource production.
If we consider the 1960's as the beginning decade for submersibles then the first five years, 1960 to 1965, will have to be considered as the planning and design phase of the first generation boats.
During this period the design and fabrication of a variety of submersibles was accomplished. This would include, the Perry Family of Submarines starting with the Cubmarine. In a11 the Perry submarine builders have manufactured five submersibles.
General Mills/Litton designed the Alvin, which has been effectively operated by Woods hole up to late 1968 when a Handling System failed, dropping Alvin into approximately 4,300 ft. where she now lies, but fortunately without injury or loss of life.
General Dynamics electric boat division have produced more large submersibles, at this time, than any other company. This would include the three Star Boats, Aluminaut, and two Alvin type submersibles for the Navy.
Westinghouse have now completed well over 500 dives with the Deepstar 4000 submersible. Deepstar is an excellent example of the first generation submersible and the problems of adapting what was basically an observation chamber into a work boat. Deepstar is equipped with a very frail manipulator and a three segmented claw which will lift 25 to 40 Ibs. Since the first contract for the submersible was in the area of Scientific Data Taking, a technique for carrying instruments weighing more than the submersible's payload, had to be found. The instrument packages also had to be mounted in such a way as to allow visual observation by the observer and pilot. The weight and placement of the instruments was also considered so as not to affect trim. Engineers from the U. S. Naval Undersea Warfare Center in San Diego solved the problem by designing an attachment rack for the instruments, which mounted on the front of the Deepstar in view of the occupants, buoyancy was accomplished by adding special syntactic foam which offset the instruments weight.
International Hydrodynamics have completed two manned submersibles" the PISCES I for 2000 ft. depths and the PISCES II 3500 ft. depth submersible. PISCES III a second 500 ft.
Modern and Ancient Hurricane Deposits
Authors: Walton William R. 
Published: October 2008

Four large destructive hurricanes have crossed the coast lines of Texas and Louisiana since 1960: Hurricane Carla in 1961, Hurricane Betsy in 1965, Hurricane Beulah in 1967, and Hurricane Camille in 1969. The severe damage done to property in the affected areas of these storms is measured in millions of dollars and in much personal suffering. The "geological damage" done by these storms is equally dramatic but is in many ways more difficult to measure. The opportunity to observe by overflights the shoreline effects of Hurricane Betsy, Hurricane Beulah and Hurricane Camille has indicated that large quantities of beach sand or sand and shell are moved from their site of temporary deposition and widely distributed both inland and seaward on the continental shelves as well as along shore. Some of the shoreline sediment moved during these massive storms is quickly returned to the normal transport system along the beach and in most cases the beaches are "healed" within a few months' time. Some of the shoreline material is moved beyond the reach of "normal processes" and becomes permanently incorporated with other kinds of sediments. The observation of hurricane deposits along the coast lines in the Gulf of Mexico makes an interesting analogy with older deposits of Oligocene age in the Gulf Coast Tertiary. The inference is that at least some part of the subsurface sediments in the Gulf-Coast Tertiary represents storm deposits and some Tertiary deposits have been so interpreted.

Hurricane Betsy
Hurricane Betsy entered the Gulf of Mexico on September 8, 1965, and on September 9th crossed the coast of south Louisiana in the vicinity of Grand Isle. Betsy was a fast-moving storm that had maximum wind velocities of 160 miles per hour as it crossed the coast. Maximum storm tides from Betsy were observed at Pointe a la Hache, Louisiana, and were measured at 16 feet above MSL. The area to the east of Grand Isle, Louisiana, took the brunt of the high tides and hurricane winds and storm waves and the most severe damage was done in the modern Mississippi delta east of Grand Isle. One hundred fifty miles per hour winds were measured 40 miles from the eye of the storm and 100 miles per hour winds were measured 100 miles from the eye of the storm. A series of photographs in the vicinity of Grand Isle, Louisiana, before and after this storm indicate the erosional effects on the beaches. Additional before and after photographs of Breton Island and Chande1eur Islands, Louisiana, and Ship and Horn Islands, Mississippi, indicate the movement of considerable quantities of sand.

Hurricane Beulah
Hurricane Beulah entered the Gulf of Mexico across the Yucatan Peninsula on the 16th of September, 1967. After cutting across the Gulf of Mexico, it crossed the coast line of south Texas near Port Isabel. Maximum wind velocities were measured at 136 miles per hour and 100 miles per hour winds were measured 90 miles from the eye.
Design for Reliability in Floating Drilling Operations
Authors: Harris M. 
Published: October 2008

Abstract
Floating drilling systems used in water depths greater than 1,000 feet in the Santa Barbara Channel, California, have been designed for maximum reliability, well control, and safety. Redundancy in systems, exacting maintenance and equipment testing, detailed written procedures and skilled personnel are all an integral part of maintaining these standards.

Introduction
Conditions are encountered in drilling from floating vessels that are different from those known in normal land drilling operations or in drilling from fixed offshore structures. It is the purpose of this, paper (1) to analyze the unique aspects of operating from this continuously moving drilling rig, (2) to discuss the equipment and methods available to provide safe, reliable operations, and (3) to review Humble's experience in drilling fifteen wells on the Federal leases in the Santa Barbara Channel, California.

The Unique Features of Floating Drilling
Three areas of major differences experienced in operating from a floating vessel can be readily identified. They are:
1. Motion and Motion Compensation
2. Remote Location of Well Control Equipment
3. Weather and Oceanographic Influence on Operations
The design of a floating drilling system includes an analysis of these differences to determine the possible consequences and to establish methods to provide full reliability. This analysis then becomes the foundation for the development of a basis for equipment selection and practices for floating drilling operations. Additional practices common to all land drilling operations but critical to well control and blowout prevention are then included to provide safety.
Offshore Application of a Real Time Computerized Microwave Positioning System
Authors: Jones J.J. , Johnston R.J. , Payne G.W. 
Published: October 2008

Abstract
Brown &Root, Inc., with assistance from Computer Usage Company, has developed, implemented and successfully tested a computer- based Microwave Survey System, which provides greatly improved accuracy and flexibility in positioning and navigating for offshore operations. Ease of operation and presentation of data in highly useful formats have been integrated with absolute positional accuracies on the order of ±2 meters over a 50 Kilometer range.

Introduction
The ability to determine the exact location of under-water pipelines has become of considerable importance in offshore exploration, surveying, construction and pipelaying. The congestion of the ocean floor, the cost of pipe and installation, the additional cost of acquiring a wider right-of-way, the pressure to quickly locate and repair leaking pipe, all dictate the need for improved mapping of existing fields and for improved precision in locating new pipe as it is laid.
To meet this challenge, Brown &Root, Inc., with assistance from Computer Usage Company, has developed, and subsequently field tested, the Microwave Survey System (MSS) described in this paper. This system is designed to enable precise and absolute navigation along a predetermined course. For pipelaying operations, it can guide barge positioning and record the actual location of pipe laid. It can additionally serve as a precision locating device for platform construction. In conjunction with acoustic devices, the system can be used for locating and tracking pipe, and for general area survey and exploration of the ocean floor.
For all these applications, the plots and printouts generated by the system provide real-time position indications, as well as hard copy records suitable for job certification; this data can also be recorded on paper tape for subsequent processing. The system has been shown to determine position to an accuracy of about ±2 meters at ranges of up to 50 Kilometers. Some 2500 hours of operational experience have been accumulated, and the reliability of the system has proven to be excellent.
SEMO FPU: The Efficient Floater
Authors: Haereid Kaare O. , Landbo Trond 
Published: October 2008

Abstract
This paper presents a concept for floating production, the SEMO (Semi-submersible MOnohull), an extremely flexible concept with regard to water depth, payload, storage capacity and fabrication site. The efficiency and robustness of the concept has been verified through conceptual design, structural and hydrodynamic analyses, mooring analyses and fabrication studies including cost and schedule.
The SEMO FPU was developed in response to the requirements for more cost efficient field developments. The SEMO can replace Dry Completion Units (DCUs), such as TLPs and Spars, as well as semi-submersibles and shipshaped FPSOs. In essence the SEMO is a monohull, different from the conventional floating monohulls used today. Due to the shape of the hull the issue of fatigue, which often is a challenge for TLPs, semis and FPSOs, is almost eliminated.
The SEMO can operate in a wide range of water depths and provide storage when required. The symmetric hull is spread moored and eliminates costly items in the traditional FPSO such as turrets and swivels. The favorable seamotion behavior and the very stiff and large deck area result in less sophisticated and cheaper process utility and simpler and cheaper topside structure. The seamotion behavior can be optimized to allow for surface wells, also in areas with harsh environment.
The shape of the SEMO hull gives a simple, robust, and cost effective platform with short construction time compared to traditional floaters. This is essential in today's "fast track" market. Fabrication does not require any "hard to find" facilities. The SEMO is a product with extreme flexibility that can be used for almost any field development. This gives the industry an increased opportunity to produce multiple units, taking the advantage of a learning curve in engineering and fabrication. Sensitivity to cost driving changes during project execution is minimized due to the robustness.

Introduction
Operators and oil companies are forced to cut cost to be competitive in today's Oil & Gas industry. A current trend is going into deeper water, and new and more efficient concepts for floating production is one possibility to reduce cost. Despite a rapid development of subsea and downhole technology there will be a demand for Floating Production Units (FPUs) also in the future.

Why do FPSO's have to look like a ship?
People in the oil & gas industry have asked this question for years. From an operational point of view there are no reasons why an FPSO, which is to be permanently moored, should be shipshaped. A possible exception is the factor of offloading using a tandem mooring system, however there are other options for offloading that will not depend on a shipshaped design. The idea of shipshaped FPSOs was related to conversion of old tankers, and to the efficiency of the shipbuilding industry worldwide. The history has shown that FPSOs are different from ships and need to be designed differently.