bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Heidrun Field: Global Structural Design and Analysis of the Heidrun TLP
Authors: Botros F.R. , Wilson T.J. , Johnson C.M. 
Published: October 2008

Abstract
The structural analysis and design of the Heidrun tension leg platform presented many technical Challenge a that had to be overcome in a fast and efficient manner to meet the demands of a very tight schedule. Some are inherent in the nature of a compliant structure such as a TLP with its complicated interaction between the structure, the mooring system and the environment and the importance of proper weight and at ability control during the different phase a of construction and operation. However, many other a were unique to the Heidrun platform. The Heidrun hull is the first large offshore structure built entirely of high strength lightweight aggregate (LWA) concrete. The topside modules form an integral component of the structural system of the platform. The interface between the steel topside modules and the concrete hull proved to be a very complex engineering task requiring very detailed analyses, tight fabrication and installation tolerances as well as testing of a number of key components. Ringing loads were included in the structural design of the platform for the first time in an offshore structure. The transportation of the large topside modules, mounted transversely on barges, and their mating to the hull was unique. The reserve capacity built into the design to provide additional safety in the critical components of the structure. The paper presents an overview of the multitude of challenges encountered during the detail design of the platform.

Introduction
The Heidrun TLP introduced several structural innovations not seen previously on any offshore platform. Examples of these include the concrete Module Support Beams (MSBS) as a main structural member of the platform and for supporting the topside modules, unique solutions for connecting the topside modules to the substructure, exclusive use of high strength LWA concrete in the construction of the hull, design and fabrication of very large diameter columns, and design of the platform for the structural effects of ringing.
This paper gives an overview of the structural analysis and design activities required in connection with the development of the Heidrun TLP and concentrates on design aspects which are novel or required more extensive consideration due to the nature of the TLP configuration or construction method. A short description of the platform is provided followed by the most significant aspects of thehydrodynamic and structural analyses. Special analyses and some of the unique design considerations associated with the hull and topsides design are presented. For completeness brief descriptions are given of the construction sequence of the hull, the foundations and the independent design verification performed for the structural design.
US Voluntary Semp Initiative: Holy Grail or Poisoned Chalice?
Authors: Powell T.A.F. 
Published: October 2008

Introduction
There are acknowledged differences in deregulation of offshore E&P safety by the US Minerals Management Service and the W(Health & Safety Executive. The US is part of the way through a patient reform of it's contemporary rules whilst the UK has almost completed the installation of a radically new and forceful regime.
Because both regulators share a common key aim, this paper explores the background to the status quo by going back to the beginning of this century to track oilfield and regulatory development on troth sides of the Atlantic.
The closing part of the paper identifies the nature of the current divide between the UK and US positions, which were once so close. At a time of consolidation for the HSE and a time of looking into the future for MMS, I speculate, at the close, on how the HSE might have responded to the choices confronting the MMS.

History of UK Oil Industry & Regulation
Early History. The E&P industry has always been dominated by the US. Some American companies can make money out of undertakings that most European companies would not glance sideways at, It is not just a question of scale and consequential opportunity, it is a matter of history - and, to a lesser extent, culture History, in fact, is the most important influence on the situation I describe in this paper.
Many people know that the US oil industry is nearly J50 years old, Fewer people know that the UK industry is 100 years old. 1a 1896, before the proper application of rotary drilling in the US, and the Spindle top gusher, a commercial gas development on the English south coast supplied a hospital and railway station with heat and light. However, the UK E&P industry didn't come to much for a long time and, with no production to speak of, in 1914 the UK Government took a stake in what was to become BP in order to secure supplies for the oil burning Naval fleet during World War 1
After the War the government attempted to ginger-up the exploration scene by offering monopoly licenses - effectively licensing people rather than leasing areas, which it had no powers to do, except on Government or Crown (belonging to the Storke) land. This proved only modestly successful: The Duke of Devonshire, one of the few to try their luck started the only ?significant' development near to his family seat at Chatsworth House in Derbyshire and for a while produced 1700 gallons per week.
Tile 1930's was most important, In 1934 the Crown took all undiscovered reserves into it's ownership and the Governmentpassed law' 10 appoint lease operators (licensees) - thereby creating the concept of sharecroppers, of which BP was to be the dominant party, and at the same time bringing the UK and US Federal lands systems very close together.
Applied Research Reduces Air Pollution from Platforms in Offshore California Waters
Authors: Konczvald A. , Shackell G.C. 
Published: October 2008

Abstract
The monumental task of reducing air pollutants generated from offshore oil and gas platforms while preserving safety and production safeguards is difficult. Recently, a group of scientists have pioneered the 'smokeless oil spill burn' concept using Enhanced Burning Additives (EBA), while the Minerals Management Service (MMS) entered the 8th year of monitoring the safe operational practices under air pollutant reducing measures such as water injected turbine generators and the use of new fuels on platforms along the Californian Pacific coast. This paper presents the conclusions of this trial period of selecting the right, technically feasible concepts.

Application
Our recommendations are applicable to any offshore platform, The field data have convinced MMS to endorse only the cost effective and safe technologies, The solution lies in avoiding the incompatibility of existing platform processes with new air toxics minimization measures.
Results, Observation and Conclusions in the category of 'Energy Savings', only Engine Retrofitting, Partial Electrification and Computerized Process Optimization have proved to be acceptable. In the category of 'Air Toxics Reduction Technologies', only the New Fuels, Smokeless Burns and the 8 new Desulfurization Methods showed reliable results.
Significance of Subject Muller:This paper presents a couple of revolutionary solutions in the groups of ozone precursor reduction and the natural gas desulfurization techniques, Information on Smokeless Burning and on the RAPRENOX process have not been addressed in such details before due to pending research and patent phases.

Introduction and Regulatory Background
Due to the Clean Air Act of 1990, the U.S. EPA has taken the power of offshore air quality regulation from the MMS and transferred it to the local Air Pollution Control Districts (APCD) of coastal county governments. The APCDS have developed a fee based system as a function of the mass of air pollutants generated by each platform and offering offsetting volumes if the operator chooses to reduce the same type of pollutant within a coastal city, or if it participates in the conversion of heavy diesel engines to natural gas engines in buses and trucks or engine replacement in resident fishing boats.
The platform operator companies have tried to reduce the air pollution fees and have turned to new research applications. First, the energy savings from on-site electric power generation, partial electrification and supplying near-shore platforms with onshore electricity have reduced the air pollutant output significantly.
Second, the computerized process optimization techniques have reduced waste of energy and improved safety, Finally, changes in operating routines have led to the development of computerized safety features such as toxic and explosive gas leak sensors, linked to the platform command room. Other routines have been modernized, and treated in detail under the flare related paragraph
A Method to Estimate the Limiting Sea States for a Docking Operation
Authors: Beldi A. , Chopelin P. 
Published: October 2008

ABSTRACT
A safe docking operation of a jacket against an existing structure at seafloor level, with or without crane assistance implies a sufficient knowledge of the jacket motions and the impact load. This paper describes the method in use to estimate the limiting sea states for a docking operation. This method uses a simple way to calculate the impact load. Allows the evaluation of the impact load between a jacket and a pile or a template to be done analytically and to estimate the limiting sea states. A correlation between the field data and the analysis results is done for the Nkossa project.
The assessment of the impact load requires little calculation and if provides a simple velocity criterion which can be used during the dotting operation. It is available for any operation including elastic impact (Jack-up installation, compliant jacket installation in deep water). The information in this paper provides useful help for similar marine operations.

INTRODUCTION
The installation of a jacket over a pre-installed structural requires a reliable analysis of the impact between two guides:a female guide (a bell) belonging to the jacketa male guide (a pile) belonging to the structure
Later in this paper we will describe the method in use to analyze the docking problem. It provides a velocity criterion to limit the motion of the bottom of the jacket. This criterion will be used in the field installation as an aid to making the decision to start the docking operation.
The period of time required in order to ensure that the docking operation takes place safely depends on the load impact caused by the encounter of the female guide with the male one, To decrease the risk of damage, permissible sea states are often used to limit the jacket motion. The ETPM impact load calculation method uses some simplification hypotheses allowing a calculation by hand. The method has now been used by McDermott-ETPM in a number of jacket installations. It is illustrated in this paper by the Nkossa project. A generalization of this method to a numerical algorithm is presented. The numerical algorithm will take into account all the forces acting on the bodies.

PROJECT DESCRIPTION
The Nkossa project involved installation of two similar jackets, NKFI and NKF2, by McDermott-ETPM for ELF Congo. The NKFI jacket (approx, 6000 t) was fabricated at McDermott-ETPM Jebel Ali Yard in the United Arab Emirates and towed to site on the launch barge Intermac 627 (14000 km voyage). The jacket was to be installed in 170 meters water depth over a pre-drilled template. Following launching, the jacket self-upended and was moved towards the template. Then, the ballasting and docking operation was made without crane assistance.
The NKF1 jacket was maintained over the template by connections with the POIARIS barge and two tugs (Fig, 1). This connection system allows an easy approach over the template and an appropriate orientation of the jacket.
Re-qualification of Ekofisk Pipeline Systems
Authors: Tangeland Tor G. , Collberg Leif 
Published: October 2008

Abstract
Re-qualification is an engineering service which will increase in importance and extent in the future, as the installations get older. A re-qualification is are-assessment of the design, but with changed design parameters. In some cases the original design requirements may be un-realistically conservative. The first part of the paper contain an introduction to the Ekofisk Field and a description of the generic justification for performing pipeline re-qualification assessments and explanation of the methodology which can be used The second part of the paper contain a description of the Ekofisk re-qualification performed for 19 pipelines and 29 risers. To enable the re-qualification to be performed new approaches had to be developed for the, (1) loads, (2) capacities and (3) deterioration evacuations and predictions. The paper contain selected results from the re-qualification assessment for some of the pipeline systems.

Introduction
Ekofisk is located in the south part of the Norwegian part of the North Sea. The field is one of the world's largest offshore oil and gas fields, it was discovered in 1968 and the first production started in 1971. The original design lifetime of the installations was 30 years.
The greater Ekofisk area is made up of eight oil and gas fields. The Ekofisk Center Complex serves as a production and transportation hub both for the Ekofisk fields and several other gas and oil fields. Approximately 85.000 m 3 (530.000 bop) of oil are being piped 354 km to the Teesside terminal in England, and around 56 Standard million m 3 (2 billion standard cubic feet) of gas are piped 441 km to the Emden terminal in Germany each day by the two Norpipe pipelines operated by PPCON.
When Ekofisk started production the recovery factor was estimated to be 17 to 18 percent, Presently the factor is more or less doubled to around 35 percent. The original operating license for the Phillips Group lasted until 2011. Due to the increased recovery it will take longer to produce the field and therefore the license has been extended to 2028. This implies that the Ekofisk installations are needed for a significant longerperiod than original designed for.
The Ekofisk Field has experienced seabed subsidence due to compaction of the producing formation. In addition to the vertical deformation, which is leas important for the pipelines, the compaction has caused the seabed to move horizontally inward towards the Ekofisk Center, this is termed Subsidence Related Horizontal Movement (N-M). The Phillips Group has decided to partly redevelop the Ekofisk complex to reduce the future operating cost and compensate for the vertical subsidence of the field. One new drilling platform (2/4X) will be installed in 1996 and one new process and transportation (2/4J) will be installed in 1997. Both platforms will be designed for 20 m total field subsidence.
Qualification of Large Diameter Duplex Stainless Steel Girth WeIds Intended for Low Temperature Service
Authors: Presser K. , Robinson A.G. , Rogers P.F. 
Published: October 2008

Abstract
British Gas recently had a requirement to fabricate some UNS3 1803 duplex stainless steel pipe work for an offshore opsides process plant. The pipe work had a maximum diameter of 600mm, with a corresponding wall thickness of 18mm, and it was designed to operate at a minimum temperature of - 40°C. There is a lack of published toughness data for girth welds in duplex stainless steel at this thickness and minimum design temperature. Additionally, toughness requirements for girth welds in current pipe work and pressure vessel codes are based on experience with carbon steels. As a result, a programme of work has been carried out to study the Charpy, CTOD and wide plate toughness of girth welds in 22%Cr duplex stainless steel pipe work. The welds were produced using a typical gas tungsten arc/gas metal arc pipe work fabrication procedure. In addition, non destructive evaluation trials have been carried out on a deliberately defective weld using radiography and ultrasonics. It was demonstrated that double wall single image y-radiography. single wall single image and panoramic X-radiography, and conventional shear wave ultrasonics were all able to detect planar root defects varying from 3 to 7mm in depth. There was good agreement between the sizes recorded by ultrasonics and those measured from macro sections. Small scale mechanical tests demonstrated that welds with overmatching tensile properties, and low temperature toughness properties whichwere acceptable to specification, could be produced. Wide plate tests demonstrated that defect size calculations from BS PD6493 were conservative.

Introduction
The process plant for a British Gas North Sea offshore platform topsides facility required the use of 22%Cr (UNS3 1803) duplex stainless steel pipe work. The pipe work varied in diameter from 26 to 600mm, with a corresponding wall thickness of 3 to 18mm. The work described in this paper had the objective of confirming that the material properties of this welded UNS3 1803 pipe work were such that the selected non destructive evaluation (NDE) procedures, would allow detection of the allowable defect sizes determined by fracture mechanics with reasonable confidence,
The design of the pipe work was generally to ANS1/ASME B3 1.3', and the material toughness requirements were derived from EEMUA 153*. This specification gives the appropriate Charpy test temperature, known as the materials reference temperature (MRT), for the particular design reference temperature (DRT) of the pipe work and the pipe wall thickness involved. The DRT at full design pressure was -40°C. although in the blow down condition, the temperature could fall to -50°C (in this case the stress would be less than the full design pressure). The EEMUA requirements for service in the as-welded condition are shown in Figure 1. It can be seen that, for the maximum pipe work thickness of 18mm the MRT is -40°C for a DRT of -40°C.
Auger's Lateral Mooring System: Key Learnings
Authors: Lohr C.J. 
Published: October 2008

ABSTRACT
Installation of the Auger TLP was completed in February 1994 with fit production in April 1994. The lateral mooring system (LMS) was critical to the successful mating of the hull and deck and installation of the tendons. The LMS is currently used to position the TLP over the wells during drilling operations and to assist the tendons in holding station during storm events. This paper describes the most significant lessons learned duringdesign, fabrication, installation and operation of the LMS. me results presented in this paper will be useful to mooring system designers, component manufacturers, installation contractors and other operators pursuing floating system options for development of deepwater fields.
Specific results to be addressed include design criteria component selection, corrosion protection systems, component manufacture, anchor performance, locked coil failures, buoy pin retainer failures, line tension measurements, installation procedures and offshore operations. ?the most significant aspect of this paper will be to provide the industry with the key Iearning from the Auger LMS so that deepwater mooring systems maybe further improved for future applications

INTRODUCTION
Auger's LMS is a combination wide chain mooring system with submersible buoys and drag embedment anchors secured on the TLP by linear winches (See Figure 1). The entire winching system, except for the bending shoes, is located in the TLP hull columns (See Figure 2), Each of the eight mooring lines has a minimum breaking strength of 2900 klps. All components are corrosion protected, except the chain, and designed for a 30 year service life, An overview of the Auger LMS is presented in Ref. 1. A general discussion of lateral mooring systems for TLPs is presented in Ref. 2.

SYSTEM DESIGN
Numerous studies were performed in-house, with mooring component manufacturers, and with outside consultants to optimize the LMS configuration in terms of performance, COSL weight and schedule. Joint Industry Studies conducted by Noble Den ton (DMOOR mooring analysis program, Wire Fatigue, Chain Fatigue) and Aker Omega (Large Scale Anchor Test) provided valuable information that influenced the LMS design. The LMS design also built on the experience gained from the Lena guyed tower (Ref. 3) and Placid FPS (Ref. 4) mooring systems.

Design Criteria
The LMS was designed by Shell in accordance with API RP 2FP1 (Ref. 5) and additional criteria developed within Shell. Limits were placed on ?TLP offset line tension, anchor loads, buoy depth and fatigue for both operating and design conditions. Higher safety factors were specific for the operating condition where the LMS is used to pull the TLP over an outermost well. Line dynamics and line fatigue were analyzed during the design process. A detailed description of the LMS design criteria is presented in Ref. 1.
Thin Walled Liner Hanger Equipment Enables Well Deepening Project
Authors: Sutherland Jamie , Weaver Chris , Aiello Peter 
Published: October 2008

Abstract
Shell Canada estimates that a thin-walled, slimhole design for liner equipment can save up to $3-4 million (U.S.) per well in deep re-entry applications by allowing existing wells to ix. deepened (or sidetracked) rather than drilling new wells from surface. The design makes it possible to reenter existing wells, successfully isolate depleted zones, and deepen the well into virgin-pressured reservoirs, The design includes thin-walled, close-tolerance liner hangers, liner top packers, tie-back seal assemblies, and liner setting sleeves that provide reasonable burst and collapse resistance while maintaining an inside diameter to facilitate drilling deep, deviated 4-3/4" hole with a tapered2-7/8" × 3-1/2" drill string, The authors will explain the design and the rationale behind it, and illustrate its value, using case studies from Shell Canada's Waterton field as examples. In this field, gas-producing wells originally drilled in the 1950s, '60s and '70s to depths of up to 14,760 ft (4500 m) were completed with perforations in 7" casing and open hole, These wells are now being reentered in an attempt to tap new reserves. The reentries encounter particular y challenging sour-gas/low-temperature/diverse formation pressure conditions. The objective of the reentry program is to seal off the depleted bottom zones of the wells and tap into the same fault-repeated formations at virgin pressure, at a deeper level.

Introduction
Like other operating companies, Shell Canada is faced with the challenge of continually lowering its finding and producing costs. One way of meeting [his challenge is through reentry and deepening projects, which use existing well structure to tap new zones. Reentering and deepening an existing well rather than drilling a new one eliminates a major new capital investment, resulting in drilling and construction costs potentially less than half of what they would be for a new well. Further benefits accrue if the project can be carried out using slimbole techniques, Both of these factors influenced Shell Canada's decision to undertake a reentry and deepening project in 1995 in its Waterton field in western Canada.

Waterton Field Background and Project Objective
Waterton field production capability has recently declined to the point where produced volumes are unable to fully utilize the Waterton Plant, particularly as a result of the near depletion of the prolific Sheet if Rundle-Wabamun'A' pool. New reserves and additional deliverability are of utmost importance in keeping the plant at capacity in order to maximize revenue and maintain low unit operating cost.
The purpose of the reentry and deepening initiative was to determine whether commercially viable pools of hydrocarbons exist at the south end of the Waterton complex, beneath the Devonian Wabamun formation.