bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design Challenges of a 48-inch Pipeline Subsea Manifold
Authors: Robinson Roy , Grass Jerry 
Published: October 2008

Abstract
Initially not part of the project design, one of the most significant design challenges of the BP Bombax Pipeline Project was the design, fabrication, and installation of a 48-inch pipeline subsea manifold. The manifold is multi-purpose and meets the following project needs:Looping the 40-inch and 48-inch systems;Minimizes seabed congestion around Cassia 'B';Allow early production of gas from Kapok;Allows for isolation of any sub-system for either repair, future expansion, or testing;Minimized the installation activities;Facilitates diver access and minimizes the number of subsea tie-in's;Ties-in the Cassia 'B' to Kapok import and the 48-inch export pipelines;Provided a secure location for the Cassia 'B' pipeline ESD isolation valves;Facilitates crossings of the existing pipelines;Provide for future expansion of the gas transportation system and provision for additional field expansion. The manifold was designed:For a 50 year design life;To provide double block-and-bleed isolation of all tie-in's;To withstand the pipeline design loads which included seismic loading;To house the Cassia 'B' platform incoming and export pipeline ESD valves (26-inch fail-closed ESD ball valve and 48-inch check valve) along with the actuated control valve in the 40/48-inch pipeline loop piping;To accommodate the anticipated expansion needs of BP's offshore assets. Procurement of the required 48-inch subsea valves, bends, and fittings provided numerous challenges. As a result the manifold has major components manufactured in 8 different countries.
The manifold structure was designed in accordance with API RP 2A and piping in accordance with ASME B31.8 and API RP 1111. Fabrication of the manifold took place in Trinidad and Tobago.

Introduction
In response to the increasing demand for energy in the form of natural gas, BP Trinidad and Tobago has started expanding its offshore fields and gas transportation system to supply new LNG trains at Point Fortin on the West side of Trinidad as well as the increased local domestic market. There are two projects currently underway to expand production and transportation of gas from 1.5 bscfd to 3.0 bscfd, the Kapok Project and the Bombax Project. The Kapok Project comprises a new 2.6 BCFPD production platform, Cassia 'B' that is bridge connected to the existing Cassia 'A' platform and a new drilling platform Kapok. The Bombax Pipeline Project includes 63 km of 48-inch offshore pipeline from Cassia 'B' to landfall at Rustville, on the East Coast of Trinidad. From the landfall, the pipeline extends 1.8 km onshore to the existing Beachfield slug catcher and production facility for onward transportation of gas to the various industries on the island including the LNG facilities on the West Coast. The offshore end of the 48-inch pipeline is connected to the existing 40-inch pipeline via a 20-inch subsea jumper. This jumper facilitates looping of approximately 2/3's of the existing 40-inch pipeline thereby expand the transportation system capacity.
Large Diameter Flanged Connection Make-Up With Zero Reworks
Authors: Aaron John W. , Johnson Waverly L. 
Published: October 2008

Abstract
Subsea installations of large diameter flanged connections can prove to be costly and dangerous. The use of Taper-Lok connectors for subsea make-up of tie-ins and manifold connections during the installation of the BP Bombax Pipeline Project provided safer and faster connection make-up times, damage resistance, reduction of weight and one time, leak free installation.
This paper will outline the reasoning behind the use of the Taper-Lok connection for this project and the areas of cost savings associated.

Introduction
The subsea pipeline portion of the BP Trinidad Bombax Project called for flanged connections to be used in 20-inch, 26-inch and 48-inch sizes. These were to be provided in Weld Neck, Swivel, Blind Flange and Misalignment designs. The need for ease of make-up at depths of 300 feet, in waters with limited visibility, high current loads and heavy weight considerations were driving forces in the connections to be used. Due to stringent BP policies, safety during installation was a major consideration, as well.
Discussions began in mid March of 2001 regarding the manufacturing of the required connections. Preliminary design requirements were developed and the Taper-Lok engineering phase began in early April. Taper-Lok offers a full range of product groups. All product groups have features, which are common elements, and several of the products offer additional, unique features and time saving devices.

Design Criteria and Requirements

General.
Operating Conditions.External Hydrostatic Pressure = 300 feet water depthOperating Max. Seawater Ambient Temp. = +80 deg FMin. Blow Down Temp. = +14 deg FMax. Internal Operating Pressure = 1480 psigHydrostatic Test Pressure = 1.5 times operating pressureOperating Temp. = 150 deg F Taper-Lok was selected due to the following inherent design features:Sealing Integrity;Self Alignment During Make-Up;Size and Weight Reduction;Safety During Installation;Forgivingness of Sealing Surfaces;Misalignment Capabilities.Annulus Test Port Capability.Meets or exceeds the requirements of ASME Section VIII, Division 1 and 2, API 6A, ANSI, and MSS flange design standards.Self-Energized/Pressure Energized, Reusable, Seal Ring.Smaller/Lighter Bolts

Flange Requirements.

Size Description Qty.
48" Weld Neck Flanges 12 48" Swivel Flanges 8 48" Blind Flanges 11 26" Weld Neck Flanges 16 26" Swivel Flanges 11 26" Blind Flanges 13 20" Weld Neck Flanges 11 20" Swivel Flanges 4 20" Blind Flanges 7 48" 5°?Misalignment Connectors 2 26 10°Misalignment Connectors 3

Total 98
Various Sizes Studs with 2 Nuts ea. 2,700 +
EXPRO-CFD: An Overview of European Research in CFD-Based Fluid Loading and Fluid Structure Interaction
Authors: Gallagher Paul , Woodburn Peter 
Published: October 2008

Abstract
This paper provides an overview of ongoing research in the collaborative project EXPRO-CFD. This project is aimed at developing and validating co-simulation systems combining CFD with hydromechanics models for floating production systems, hence improving the accuracy of calculations of fluid loading and response, and reducing design uncertainties. The paper describes progress to date in developing computer modelling systems which couple together commercial computational fluid dynamics software, wave diffraction and hydromechanics tools (vessel dynamics incorporating risers and mooring systems). It provides an overview of the experimental programme carried out at MARIN and Ecole Centrale de Nantes and some typical results for a vertical cylinder and an FPSO in regular waves using PIV techniques for quantitative flow measurement. Preliminary results from CFD validation studies are provided, and reviewed. Results are also provided for fully coupled calculations of fluid loading and response to extreme events. The paper also contains conclusions on overcoming the various technical issues associated with performing fluid structure interactions calculations using CFD, and the areas where such methods might be used in the future with some confidence.

Introduction
EXPRO-CFD is a collaborative project aimed at making substantial improvements to techniques for the prediction of non-linear and extreme wave loads and responses of offshore floating production systems. The project is supported by the European Commission as part of its Fifth Framework programme Growth2000, and has been running for just over two years of its three year planned duration.
The partnership consists of 13 organisations and research institutions from the UK, Norway, The Netherlands, France and Spain. It includes 2 oil companies (BP and Statoil), three design contractors (Aker, SBM and LMG Marin), three consultants (Atkins, Sirehna and CIMNE), one classification society (DNV), a model basin (MARIN) and three Universities (Imperial College London, University College London and Ecole Centrale de Nantes, who also have access to a model basin). The Coordinators of the project are Atkins.
The key themes of EXPRO-CFD are integration, validation and delivery systems.

Integration.
A novel but pragmatic approach has been adopted to provide integrated hydrodynamic and fluid-structure interaction analysis systems. No new software tools have been developed. Instead, existing and reliable methods in diffraction, CFD and Finite Element analysis, have been adopted and the means to allow them to communicate or run in parallel investigated. This allows the integrity of existing software tools to be retained along with all of the built-in knowledge and experience gained in their development and application. Their integration however opens up many new capabilities, opportunities to clear away uncertainty and conservatism, and improvements in the prediction of design loads, but at significantly lower cost.
Offshore Concrete Structures for LNG facilities - New developments
Authors: Haug Atle K. , Eie Rolf , Sandvik Knut , Kvaerner Aker , Aoki Eiji 
Published: October 2008

Abstract
During the last 5 -10 years the oil and gas industry has shown a growing interest for offshore and nearshore LNG liquefaction and regasification facilities as part of the LNG chain as alternatives to the traditional onshore plants. This is to a large extent driven by safety and environmental aspects as well as the need to find solutions for associated and stranded gas.
This paper primarily focus on the substructure part of such facilities and the LNG containment system. These solutions can be utilised for liquefaction plants as well as for regasification terminals as illustrated on Fig. 1.
Fig. 1 LNG Value Chain - Two offshore LNG facilities possible(AVAILABLE IN FULL PAPER)
Liquefied natural gas (LNG) is the most used method for gas transport over longer distances. A LNG chain starts at the liquefaction plant located nearby the gas production source. The LNG is transported by specialised carriers to receiving terminal(s) for regasification near the market. Developing a base load LNG chain requires an investment of several billion dollars. The need to exploit remote gas reserves is increasingly urgent as well as supplying the clean gas in a safe and environmental friendly way as close as possible to the larger consumer regions.
The use of high quality offshore concrete structures combined with LNG containment systems proven in the marine environment is currently being investigated for a number of applications in Europe, North America, South America, West Africa and South East Asia. The concrete material has well proven material characteristics in relation to cryogenic temperature exposures, high quality concrete used in offshore structures for more than 30 years have shown excellent durability.
Typically, the concrete structure based on a gravity based concrete box for shallow water or a floating concrete barge for deep water, is combined with an internal integrated LNG containment system offering spacious areas at the top of the concrete structure for liquefaction or re-gasification utility and loading facilities. The structures may also offer harbour protection, berthing and mooring arrangements for the LNG carrier. Some concepts are shown in Fig. 2.
Fig. 2 Offshore Concrete solutions for LNG plants and terminals(AVAILABLE IN FULL PAPER)
The facility may be built and completed to the highest degree of completion at a suitable site where infrastructure, manpower and facilities are available or can be arranged. Limited land claim or onshore areas will be exposed during operation and after use the facility can easily be decommissioned and removed for re-use or recycling.
During the last decade concrete offshore platforms have successfully been built in Norway, UK, France, Canada, Australia and the Philippines utilising local labour. Local labour force and engineers as well as local materials and facilities have been used giving a local content of 70% or more.
A Solution For FPSO Module Integration
Authors: Thomas P.A. , Malek S. , Tcherniguin N. , Bestel V. 
Published: October 2008

Abstract
Technip-Coflexip has developed a new installation concept called the "Jack-Deck" (Patent Pending - Patent N° FR 01.16835 registered on 24/12/2001) which enables installation of FPSO Topsides on to a FPSO Hull Deck in one or two "Integrated Modules" with weights of up to 19800T each (See Figure 1). This installation method facilitates extensive pre-commissioning and commissioning of the "Integrated Modules" at their Construction Yard. It considerably reduces the onshore hook-up and integration work required on top of the FPSO Hull Deck. Consequently the overall FPSO Construction Schedule and Cost are significantly reduced.
This paper describes the "Jack-Deck" installation method and discusses the consequences on Topsides layout and structural design. It also highlights the main benefits of the system.

Introduction
With the discovery of new Oil & Gas fields located in deep waters and the recent development of subsea completions and flexible risers, FPSO's have become more and more commercially attractive. They enable development of fields with little infrastructure for oil export and offer not only a low installation cost, but also a low decommissioning cost at the end of field life. They offer the advantage of being readily re-deployed on other fields. All these points have expanded the FPSO market and encouraged Oil & Gas Companies to invest in this type of production system. Many FPSO's have already been successfully installed in West Africa and other parts of the world. Several others are under construction, and many proposals for future FPSO Development Projects are in preparation with early installation objectives.
The traditional method for constructing an FPSO is to build the hull in a Shipyard and the Topsides in a separate Construction Yard. The topsides are split into several modules, typically 8 to 14 with weights ranging from 1000T up to 3000T. The modules and / or the hull are then transported to the integration yard where the modules are lifted and installed in place on top of the FPSO Hull Deck.
Fig 1: "Jack Deck" installation concept (AVAILABLE IN FULL PAPER)
Due to the large number of modules, the lifting and installation phase can extent for several weeks and the integration, pre-commissioning and commissioning work may have to be interrupted to allow the installation of the modules as they arrive at the integration site.
This traditional method has been imposed on FPSO Contractors by the high elevation of the FPSO hull deck above the quay, which can reach up to 30m, and by the relatively small lifting capacities of most of the Construction Yards, which are generally limited to 3000T. Selecting yards with higher lifting capabilities would reduce competition and further increase the fabrication and integration costs. In any case, the lifting capabilities of these particular yards are still limited to around 7000T, which is low in comparison with the "Jack Deck" 's installation capacity.
Reliability Analysis of a Wellhead Platform in Al Shaheen Block 5 Project
Authors: Kim Junhong , Min Joon Ho , Chang Kwangpil , Moon Kiho , Lee Sejoong , Lee Donghun , Nam Kiil , Chang Daejun 
Published: October 2008

Abstract
This study proposed the reliability analysis of a wellhead platform in Al Shaheen Block 5 Project. The reliability, optimal maintenance period, and appropriate redundancy policy were acquired by taking the failure rate of each component and methods from OREDA and PDS. The PDS is a method used to quantify the reliability of computer-based control and safety systems. The probability of failure on demand (PFD) was estimated for each safety function. The safety integrity level (SIL) of the overall system was evaluated to quantify failure risks. The SIL evaluation was applied to judging whether the reliability of process shutdown (PSD) functions of the present system was properly configured. In particular, the shutdown functions of the flare system and well isolation satisfied the minimum SIL requirement by IEC general recommendation.

Introduction
The Al Shaheen Oilfield is located in the Arabian Gulf, approximately 70km offshore northeast of the Qatar Peninsula. Hyundai Heavy Industries (HHI) has been awarded a contract for the Engineering, Procurement, Construction and Commissioning (EPCC) of a number of new platforms and additional facilities, by Maersk Oil Qatar (MOQ).
This study gives a detailed risk assessment of the high liquid level shutdown to prevent liquid carryover to the flare stack in Block 5 Development Project. The overall system consists of two sub-systems equipped with safety instrumentation: one concerning the Production Wellheads with isolation valves, and the other concerning the Wellhead Platform with the Inlet Separator, Test Separator, and HP Flare K.O. Drum. Depending on the field development phase and operating philosophy, the number of working Production Wellhead varies up to 30. The HP Flare K.O. Drum is not designed to receive the total liquid flow from Inlet or Test Separators. This situation has raised a concern whether the safety instrumentation of the Wellhead Platform is of sufficient integrity.
To analyze the reliability of the issued system, the functional boundaries are first defined in consideration of the design and operational philosophy. The reliability block diagram (RBD) is used to represent the system configuration. The failure rates of the overall instrumentation and equipment are obtained from the surrogated data such as OREDA and PDS. The SIL requirement by IEC is employed as the safety level determining the system integrity.

Safety Integrity Level Assessment

Safety functions and safety integrity level
In the IEC standards, a safety function is considered as a function to be implemented in order to achieve a specified risk reduction related to a hazardous event. A safety function is thus specified in terms of the action to be taken and the required probability to successfully carry out this action. This probability is also referred to as the safety integrity, and in the context of IEC 61508 the safety integrity is classified to discrete levels as indicated in Table 1.
Application of Wet Gas Metering in the Gulf of Mexico
Authors: Andreussi P. , Ciandri P. , Ansiati A. , Boschi S. , Paone F. 
Published: October 2008

Abstract
The application of a new Multi Phase Flow Meter (MPFM) for monitoring the production of three gas wells in the Gulf of Mexico, Allegheny TLP, is presented. The meter is based on a sampling method, does not make use of ?-sources and is selfcalibrating. In the present application, it has been possible to compare the measurement of the MPFM with production data obtained from a conventional well testing system certified for production allocation. The accuracy of present measurements of the gas and total liquid flow rates is similar (or better) than the accuracy of the well testing system (2% of the actual readings). A special feature of this MPFM is the direct measurement of the condensate and water phase densities. This allows a very accurate measurement of the Water Volume Fraction, with an absolute uncertainty of WVF measurements equal to 0.001%. This value is two orders of magnitude better that the accuracy of other MPFMs under development. The measurement of the water phase density also permits an estimate of the methanol flow rate injected in the subsea pipeline to prevent hydrate formation.

Introduction
In recent years a number of multiphase flow meters have been developed mainly for oil field applications. These instruments are characterized by a large uncertainty unless they are properly calibrated by in situ methods. Errors become relevant when any of the commercial multiphase flow meters are used for wet gas metering (Gas Volume Fractions, GVF, = 90%). Besides the low accuracy, these flowmeters often adopt a ?- source to determine the mixture density. This makes their use troublesome in respects to regulatory requirements and potential risks to health, safety and environment.
The problems encountered in the application of multiphase metering to wet gas led to the development of the flow meter presented in this paper, named VEGA, which is based on the isokinetic sampling of the gas-liquid mixture, followed by separation and metering of the individual phases. With respect to other MPFMs, the main feature of the meter is the advantage of self-calibration, [1], [2]. Moreover, sampling allows the water cut to be determined in the separated liquid with good accuracy rather than in the gas-liquid mixture.
The development phase of the meter and the preliminary tests carried out at Trecate field, in Italy, with a 2" prototype are described in [1] and [2]. In these experiments the self dcalibration features of the VEGA were fully tested and appear to be a characteristic unique to this flowmeter.
From the tests it has been found that the expected accuracy of both liquid and gas flowrate measurements was about equal to 2-3% of the actual readings. However, the accuracy of these measurements was affected by the presence of appreciable flow oscillations induced by the particular collocation of the meter and by the control system of the separator from which the gas and liquid streams fed to VEGA were drawn.
Field tests conducted with VEGA essentially covered the case of wet gas (high GVF).