bluuebunny/crossref_metadata_2025_split huggingface dataset:
HFAST: A Tool to Assess Human Error Potential in Operations
Authors: Noerager Jere A. , Danz-Reece Mary E. , Pennycook Wayne A. 
Published: October 2008

Abstract
HFAST (Human Factors Analysis Software Tool) is a self-help software tool used by operating sites to identify the potential for human error in the design, operation, and maintenance of site systems. Reduced error potential results in fewer errors in daily operations, leading to improved safety and more efficient operations. Through a process of consensus, the team rates diagnostic statements about the conditions at their site in as many as 14 general categories for improvement (e.g., field workplace design, procedures, training, communication structure). Based on these responses, the program produces a report that provides guiding principles for improving the design of systems and work processes to reduce the potential for human error. This paper describes the genesis and development of the tool, how the tool would be used by an operating site, and provides examples of site benefits from applying the tool.

Background
The petroleum industry has well-established safety and environmental policies that reflect a commitment to personnel safety and to protection of the environment and assets. However, the increasing complexity of industrial activities and rapidly evolving technologies have increased industry's safety management challenge. There is a need to build on and extend traditional practices to counter the increasing complexity of our operations.
Studies and incident investigations conducted within theoil industry and elsewhere clearly indicate that human error is a significant source of risk to safe and environmentally sound perations 1–9. Figure 1 indicates that human error is a contributor in 50-75% of incidents. In systems where a high degree of hardware redundancy minimizes the consequences of single system failures, human errors may comprise over 90% of the system failure probability 10.
Fig. 1 -- Addressing Human Error (Available in full paper)
A traditional emphasis on training, motivation, structured management systems, and discipline, coupled with hardware design improvements, has contributed to significant improvements to safety performance in industry. However, as technical components are becoming more reliable, the relative importance of human factors in achieving continued improvement is increasing. A recent survey of the literature 11 revealed that the estimated involvement of human error in the breakdown of hazardous technologies increased four-fold between the 1960s and the 1990s.
Many factors contribute to the potential for error. These factors may be out of the direct control of individuals or may not be obvious to individuals. Highly protected systems may also automatically recover from some adverse factors, hiding them from observation, unless there is an extreme error which results in a severe consequence. The potential for error is significant because it is influenced by the interaction of several factors, some of which may not be immediately obvious.
Supervisory Control Of Gas And Oil Production Offshore Australia
Authors: Carter Charles , Boxx Baxter 
Published: October 2008

ABSTRACT
One of the first supervisory control systems to extensively employ integrated circuitry in an offshore application has been supplied by International Controls Corporation (ICC), Houston. The computer production control system will gather data from and control and monitor two offshore gas producing platforms in the Bass Straits between Australia and Tasmania from a control center in Sale, Australia. It is the first offshore installation of ICC's new, third generation S-70 Supervisory Control System. The highly flexible S-70 system can be used for oil as well as gas production and can be expanded to include up to 18 more platforms.

SYSTEM DESCRIPTION
The system consists of the Master Station at Sale and two Remote Terminal units (RTU's), one on each platform. The Master Station consists of the S-70 Computer Interface Unit (CIU) interfacing the RTU's with a Digital Equipment Corporation PDP-8/I digital computer. Both the 70/000-word computer and the S-70 CIU are of integrated circuit design. Also located at the Master Station is the operator console operated by the computer through the CIU.

Master Station Operation
The console consists of display units, indicators and pushbuttons with which the operator can observe the status of as well as control the operating platforms.
This system is of the continuous scan type. Unless the operator wishes to observe a particular type of data or initiate a control, the system will continuously interrogate the two offshore platforms for their production data and also for the condition of all status and alarms.
In the event an alarm occurs the computer will initiate a printout which will identify what the alarm is and where it occurred. The computer will also output to the console to sound an audible alarm and activate a flashing light. The lamp will identify the class of alarm (major or minor) and also on what platform the alarm occurred. If for some reason the computer cannot communicate with one of the RTU's, it will indicate with a light that that platform is not communicating. The CIU features a security check system which generates a security check code a message is being transmitted to the RTU. The RTU has the ability to check the incoming data with this security check code to determine if he data is valid. When the RTU transmits to the CIU it will generate a security check code which will be checked by the CIU. If the code does not check, the CIU will notify the computer and the computer will then ignore the data just received and also output to the console and turn on a light that says the data just received from a particular platform was invalid.
Not only does the console indicate to the operator that alarms exist the state of communications to the RTU's, but it also has a complete set of indicators that mimic the valve and pump conditions on the platform.
With the use of the pushbutton section of the operator's console, the operator can send control, or set-point commands to that RTU.
Dynamic Positioning Systems
Authors: Shneider W.P. 
Published: October 2008

ABSTRACT
Dynamic positioning systems provide a highly versatile "anchoring" system for vessels that must remain on a given location out in the deep ocean. While no single system design can be universally used, general guidelines can be established to assist in the selection and the design of the various subsystems.
At the present time a dynamic positioning system has been designed and installed aboard a drilling vessel-The Glomar Challenger--and is currently being used with excellent success in water depths from 3,000 to 18,000 feet.

INTRODUCTION
As the interest and activity in the oceans increase, the need for "working platforms" that have the capability of being used in almost any water depth and at any geographical location has become significant. These working platforms require many peculiar characteristics but two of the more important ones are mobility and stationary stability; that is the vessel which forms the foundation of this working platform should have the capability of being rapidly moved from one location to another and once the desired location has been reached, it should have the capability of being essentially anchored at this location quickly and easily. At the present time, these characteristics cannot in general be obtained to the extent desired but, dynamic positioning systems can satisfy a major and necessary part of the requirements.
A dynamic positioning system uses the energy converted on board the vessel to provide the forces necessary to hold or "anchor" the vessel at a given location; no mechanical connection to the sea floor or other land masses are required. It should be noted that the mechanical connection considered here refers to constraining connections and not small lines that might be used to provide reference signals for the control system input since the necessity of having to set out anchors or make other mechanical connections to the sea floor is eliminated, the relative ease in which the vessel can be positioned at any given location as well as the ease in which the vessel can leave a location having once been maintained on "station" can be readily appreciated. Furthermore, in deep water (for example 18,000 feet) it is the only practical method of maintaining a given geographical position.

SYSTEM DESCRIPTION
A dynamic positioning system is composed of the following general subsystems:Postion measurement systemcontrollerVesselComparator
The subsystems are related as shown diagramatically in figure I. In essence, the positioning system can be considered as a closed-loop feedback servo or control system. In operation, a reference position (surface coordinates and vessel heading) is selected and provides the input to the control system. This input is compared to the measured position of the vessel and if a difference exists, an error signal is generated. This error signal is processed to provide the proper logic to the controller. The controller moves the vessel so as to reduce the error signal and when the error signal is zero, the measured position of the vessel coincides with the selected reference position.
Foinaven Super Duplex Materials Cracking Investigation
Authors: Taylor T.S. , Pendlington T. , Bird R. 
Published: October 2008

Abstract
Development of the BP Amoco Foinaven Field received a major setback when leaks were discovered during final commissioning of a subsea manifold. The problem was identified as hydrogen embrittlement, a phenomenon that can be created by the combined effects of the cathodic protection system (providing a source for hydrogen) and unacceptably high peak stresses applied to steels during the manufacturing, construction and installation phases. Although this mode of failure in conventional subsea materials was known, the limits of sensitivity of duplex stainless steels in a subsea environment were found not to be fully appreciated.
A BP Amoco Technology Team was formed who investigated the problem and then delivered a way forward that offered a long-term solution to the integrity of the subsea facilities in order to maintain a viable project. The challenge was to use the skills and experience of the team to review and adapt known and new technologies to engineer a "fit-for purpose" solution that integrated with, and met the rapid pace of the project.
Because a single solution to all of the scenarios generated by the cracking problem was not possible, it was necessary to identify and prove several options and then consider the merits of their application to every connector location. Sophisticated computer-modelling techniques, adapting known technology, laboratory testing of materials and full scale testing, were only part of the overall programme. Establishing an envelope of suitability for each option, and developing a justifiable case for each connector that accounted for all possible installation and operational start-up/shut-down cases, required the combined efforts of the multi-disciplined team with external specialist support. The investigative work carried out by the BP Amoco Technology Team has given the industry a fresh awareness regarding the use of these new materials for future subsea projects.

Introduction
The Foinaven Field development shown in Fig 1 utilizes dynamic Risers, Manifolds, Flowline Termination Assemblies (FTA), Pullheads, Subsea Xmas Tree Flowbases and a ipeline Umbilical Manifold (PLUM) which are installed on the seabed. These special items of equipment are all fitted with special forged steel connectors, similar to those fitted to the manifolds at the drill centres DC#1 and DC#2.
In addition to the 18 hubs on the two manifolds, there are a further 163 super duplex hubs in a full 24 well development which connect the various items of seabed equipment. These large, complex forgings were manufactured from "Super Duplex" Zeron 100 stainless steel because of its superior resistance to corrosion from the produced fluids. During routine pressure testing of various piping/flowline circuits some 6 months after the DC#1 manifold had been placed on the seabed, leaks were discovered in two of these special forged connectors (see Fig 2).
Fig 2 DMaC Super Duplex Hub Forging with Welded Pipe Connections (Available in full paper)
Steel Catenary Riser Configurations for North Sea Field Developments
Authors: Karunakaran Daniel , Lund Kjell M. , Nordsve Nils T. 
Published: October 2008

Abstract
Free hanging metal risers have become an important alternative to flexible risers for oil and gas field developments. These risers also have a potential benefit when used in high temperature and high-pressure applications.
This paper presents a summary of the work performed to establish Steel Catenary Riser (SCR) concepts for two fields in North Sea. They are: Statfjord C, a gravity based concrete platform located on the Norwegian continental shelf in a water depth of approximately 145 m and Heidrun, with a concrete TLP at a water depth of 345 m.
These developed configurations fulfil both the Ultimate Limit State (ULS) conditions and fatigue due to first order wave action and due to vortex induced vibrations. Also, as shown in this paper, the Fatigue Limit State (FLS) governs the global configuration of the SCR concept.
In order to achieve a confident design, several design aspects have been studied in detail:First order wave loadingVortex Induced Vibration (VIV)Diffraction effects (from the large volume structure)Riser/Soil interactionFatigue capacity

Introduction
A number of research and development projects are currently evaluating the applicability of the SCR concept to floating production systems mainly in deep-water environments (e.g. Karunakaran et al. (1996), Hatton et al. (1998)). However, as shown in this paper, the SCR concept could be an attractive alternative also for tie-in of pipelines to fixed platform structures, like Statfjord C, see Figure 1.
Even in the absence of top-end motions (as for floating production units), the design challenges for a SCR concept for this application are significant. Due to the relatively shallow water and quite severe wave and current environment, the riser is subject to large hydrodynamic loading causing extensive dynamic behavior.
For the Heidrun TLP shown in Figure 2, the design challenge for the metal risers is due to the riser dynamics from wave loading and the platform motions. Furthermore, for this concept the diffraction effects proved to be a key factor for fatigue response.
In this paper the developed SCR configurations for both these fields are discussed along with the key issues governing the design of such riser concepts.
Figure 1 Statfjord C and riser geometry (Available in full paper)
Figure 2 Heidru TLP (Avalaible in full paper)
Tomographic Updating for Residual Velocities
Authors: Thorson J. , Bednar J. Bee , Vinson L. 
Published: October 2008

Abstract
The depth mismatch of events at different offsets on a collection of common image gathers (CIGs) is minimized by backprojection of slowness values in a grid. Rather than laboriously picking events on given CIGs, (v,t) pairs are used to calculate necessary arrival times and depths. For each iteration of the prestack migration process, the previous velocity field is used to calculate ray paths, change in path length, slowness, and opening angles. Back-projection is constrained by (a) smoothing slowness laterally and vertically to stabilize the minimization, and (b) holding slowness constant in certain regions (e.g. salt bodies). The utility of the approach is shown through application to both finite-difference synthetic and real data in two and three dimensions.

Introduction
Figure 1 shows the migration paths for two different offset traces that make contributions to the CIG at a given surface image point.
To obtain a linearized relationship between the change indepth ?z of an image point of the CIG and the change in path length ?l of the ray note that with reference to Figure 2(Mathematical equations) (Available in full paper)
Fig. 1-Depth section showing raypaths for near and far offsets and indicating depth differences at z0 and zh and known dip ?. (Available in full paper)
Fundamentals of 3D Seismic Volume Visualization
Authors: Kidd Gerald  D. 
Published: October 2008

Abstract
Since the early 1980's, the volume of 3D seismic data has been steadily growing. Beyond the increase in size and number of 3D seismic surveys, there is also proliferation of attribute data. This increase places additional demands on the interpreter that is difficult to meet using traditional mainstream interpretation methods. A key element in solving this interpretation problem is the application of 3D volume visualization, which introduces new technologies and requires new skills. It enables the geoscientists to extract tremendous amounts of information in short periods of time. To maximize benefits, skills in the art of volume visualization must be established. Grasping the fundamentals of 3D seismic volume visualization provides a foundation for growth and creative solutions. Essential fundamental concepts and visualization processes, namely the Zone System, are discussed with examples of its application on stratigraphic, structural and amplitude interpretation problems. Important interpretation considerations, and discussions on color, and key strategies for quality visualization are included.

Introduction
3D volume visualization is a method of seismic interpretation in which the interpreter directly evaluates the seismic reflectivity of the subsurface in three-dimensional space by applying various levels of transparency to the data. The technology and philosophy of 3D volume visualization1 differs from conventional interpretation and includes new interpretation strategies and methodology. Through direct integration of structural, stratigraphic and amplitude data, both regional and prospect-specific details can be revealed and evaluated prior to significant digital interpretation. This helps the interpreter to design an efficient work plan to achieve higher quality interpretations in a shorter period of time.

Visualization Types
There are two basic types of visualization: surface and volume. Surface visualization is the result of mapping individual horizons and faults, and then re-interpreting them collectively in 3D space as a 3D model. This method is time-consuming, involving two major interpretation steps and utilizes only a portion of the 3D data. Volume visualization assumes that the reflectivity of the subsurface provides enough detail to allow interpreters to directly evaluate and integrate structural, stratigraphic and amplitude features in 3D space. Both 3D regional and prospect-specific evaluations, including the identification of potential fluid contacts, can be performed quickly in detail. In contrast to surface visualization, a large percentage of the data volume is often evaluated.

Interpretation Considerations
In general, conventional interpretation methods produce maps, while volume visualization methods produce 3D perspectives. When the purpose of the task is specific, we normally make a map.
A Sea-to-Ground Magnetovariational Method
Authors: Patella D. , Mauriello P. , Siniscalchi A. 
Published: October 2008

Abstract
The magnetovariational (MV) approach consists of recording the natural time-varying magnetic field at two different levels below the ground surface. The MV method can also be used in marine researches using waterproof sensor devices. However, a weak point of marine measurements is the lack of stability of any sensor hanging in seawater. To overcome this difficulty, in this paper we propose an alternative array design consisting of a magnetic sensor device firmly laid down on the sea floor and a second device located on land at a remote station where the subsoil conforms to a 1-D structure. This circumstance and the uniformity of the primary magnetic field over largely extended regions allow the electromagnetic components in seawater to be readily estimated using the measured magnetic field at the remote station. By these estimates, the two-level MV response across the sea water layer can be definitively simulated. The same procedure can be adopted to simulate the magnetotelluric sounding at any level in seawater. Finally, the installation of a second remote station inland is suggested in order to minimize the effect of noise on the estimates of the apparent impedivity functions. Reliability and usefulness of the new sea-to-ground MV method are tested on two synthetic examples.

Introduction
A pioneering approach to magnetotelluric (MT) sounding with electric and magnetic sensors immersed in seawater at a depth of a few tens of meters dates back to the late 50s1. The recent technological progress makes now possible to carry out more sensitive offshore MT measurements with the sensors lying on the sea floor2.
An alternative approach to offshore electromagnetic probing is the magnetovariational (MV) method formulated by Patella and Siniscalchi3. They introduced an appropriate MV apparent impedivity (dispersive resistivity) function, which can be used to retrieve reliable impedivity structural models below the sea water layer. Basically, the MV method requires the recording of only the magnetic field at two different levels in seawater. Fig. 1 shows schematically a seaborne magnetic sensor layout. It consists of a pair of waterproof horizontal two-component magnetic devices, one of which is laid down on the sea floor in S(b), while the other is located close to the air-water boundary in S(t), vertically above S(b). A weak point of this array is the lack of stability of the top sensor device, which can be subject to a motional noise causing unpredictable corrupting effects on the magnetic channels.
Fig. 1-Scheme of the magnetic sensors configuration for the two-level magnetovariational method. (Available in full paper)