bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improvements Achieved in the Project of FPSO P-50
Authors: dos Santos Aldemir Bonfim , Henriques Carlos Cunha Dias , Pimenta José Maria Mario Hollanda Alvares 
Published: October 2008

Abstract
In the last 10 years, Petrobras has converted 8 existing tankers to operate as FPSOs/FSOs in Campos Basin, offshore Brazil. The lessons learned from the conversion of those Units highlighted the importance of taking into consideration the concepts of constructability and clean arrangement in the design of FPSOs.
The project of FPSO P-50 was developed with those concepts in mind and then, the philosophy of the following main systems was changed from previous FPSO projects:Cargo and ballast systems: Use of individual submerged cargo pumps, eliminating the cargo pump room and the communication between the cargo tanks;Sea water lift system for water injection: Use of electric submerged pumps;Fire Fighting System: Use of Diesel hydraulic fire water pumps with submerged hydraulic driven booster pumps;Offloading system: Use of reels to store the offloading hose, instead of a chute system;Marine systems: Development of a new arrangement concept for the main deck marine systems pipe rack;Mooring System: Use of a spread mooring concept instead of turret system and use of free fall piles to anchor the FPSO. The intention of this paper is to describe the modifications made in those systems, explaining the reasons to adopt them and stressing the benefits brought to the project.

Introduction

Albacora Leste Field Project:
The Albacora Leste field (Figure 1) was discovered in March 1986 by the wildcat 1-RJS-342A. This 600-km2 field lies 125 kilometers off the coast of Rio de Janeiro, at water depths from 800 to 2,000 meters. The field is comprised primarily of Miocene turbidite sandstones (Ref. 1).
The Field Development will comprise 16 subsea production wells producing 180,000 bopd through individual bundles (Figure 2) to the FPSO P-50 located at 1,240 meters water depth. The water injection, totalizing 35,000 cubic meters, will be achieved through 15 subsea wells. P-50 (Figure 3) is a former VLCC that is currently under a process of conversion to a production Unit.
After processing and treatment in the FPSO, the oil will be stored inside the tanks and later exported to shore via shuttle tankers. The compressed gas will be exported through a 10- inch gas pipeline up to a subsea PipeLine End Manifold (PLAEM) that will be connected to an existing fixed platform through a new 20-inch diameter pipeline. From this fixed platform, the gas will be sent to shore through the existing gas network pipeline.

FPSO Projects In Campos Basin:
The first mono-hull floating production Unit to operate in Campos Basin (and one of the first FPSOs in the world) was the former tanker P.P. Moraes. This 33,000-dwt tanker was built in 1959 and, in 1975, it was jumboized to 54,000 dwt. In 1979, a 60,000 bpd process plant was installed on the ship to allow it to operate in the Garoupa field. In 1987, P.P. Moraes was relocated to Albacora Field. The system operated continuously from September 1987 up to March 1993 with no significant downtime (Ref. 2, 3 and 4).
The Influence of Passing Ships on Ships moored in Restricted Waters
Authors: Pinkster J.A. , Ruijter Michel N. 
Published: October 2008

Abstract
Ships moored in harbours are subjected to hydrodynamic forces due to other ships passing nearby. Such forces induce motions of the moored ship which may hinder loading/discharging operations or cause damage to the mooring system. These forces, sometimes known as suction forces, are associated with the primary pressure system around the sailing vessel which acts upon the moored ship. In this paper some of the aspects which play a role in effects due to passing ships will be treated. In order to do so, two computational methods developed by the first author to predict the low frequency forces due to a passing ship will be used. The first of these is based on implementation of the so-called 'double-body' flow method previously introduced by other authors.
The second, newly developed, method applied in this paper predicts passing ship effects also taking into account free surface effects due to the passing ship and the additional forces these exert on the moored ship. Results of both computational methods are compared. Full scale tests were carried out by Svasek Hydraulics and MARIN on behalf of the Port of Amsterdam. These tests involved, among others, measurement of the mooring forces of a fully loaded barge during the passage of large vessels in the Noordzeekanaal which joins the Port of Amsterdam to the North Sea. Results of these measurements are compared with computations. Finally, an unusual case involving the generation of solitary waves by a vessel in a canal is treated.

Introduction
Passing ships create disturbances in the water which result in forces on other ships and floating structures. Such hydrodynamic forces can result in high mooring forces and unacceptable motions of the moored vessels. In extreme cases, mooring lines of ships have parted which in one case, see NTSB report [1], resulted in loss of life and total loss of the moored ship due to fire. Such cases are extremely rare but hinder and damage due to passing ship effects are a regular feature of life along the waterways and in harbours. With the increasing awareness of and decreasing tolerance relative to personal injuries, environmental impacts and damage to facilities and ships, more attention is being focussed on evaluation of such effects whenever major changes are made with respect to the vessels plying the waterways (larger, faster), the waterway geometry or traffic volumes.
At the Delft University of Technology research has been conducted into methods to predict the effects of passing ships on moored vessels. Such effects have in the past concentrated on suction effects associated with the primary or "doublebody" flow around the passing vessel. See, for instance, King [2]. By definition, this means that real free-surface effects, i.e. surface wave propagation effects, are not accounted for. The reason for basing the effects of passing ships on double-body flow models is that generally such ships are moving at low Froude number values, even when viewed in relation to the waterdepth.
Eugene Island 322 'A' Drilling Platform Decommissioning After Hurricane Lilli
Authors: DeFranco S.J. , Fitzhugh J.T. , Locke H.A. , O&apos;Connor P.E. , Straub T.J. , Morahan D.J. 
Published: October 2008

Abstract
This paper describes the cause of failure of BP's Eugene Island 322 'A' (EI-322 A) Drilling platform during Hurricane Lilli and BPâ??s response to this event. BP's project team planned and implemented temporary strengthening of the platform so that well decommissioning could take place in a safe and environmentally sound manner during the peak of the 2003 hurricane season. Well decommissioning was successfully completed by November 2003. BP's health, safety, and environment (HSE) values were strictly adhered to throughout the project with zero injuries or environmental events.

Introduction
Hurricane Lilli passed through the Gulf of Mexico in early October 2002. At its peak, the storm reached Category 4 on the Safford-Simpson scale with maximum sustained winds exceeding 140 mph. The stormâ??s eye passed through the Eugene Island 322 block. In the days immediately following the storm, BP learned that the EI-322 A Drilling platform was leaning and had sustained severe damage to the deck and bridge.
The EI-322 'A' platforms are typical of TAMPA complex (Hancock and Peavey, 1975) that was widely used by Amoco from the late 1960s until the early 1990s. The TAMPA concept consists of two, adjacent, four pile platforms linked by a relatively large bridge. The main function of the TAMPA was to replace one large 8-pile platform, which was typical of that time, with two significantly lighter platforms. One of the TAMPA platforms serves as a drilling/quarters platform with on-board rig capability while the other platform provided tender support during drilling operations. Post drilling, the tender platforms were converted into the production facility. The bridge supported the production flow lines as well as several small buildings.
The EI-322 'A' platforms were installed in 235 feet of water by Amoco in 1978. The primary design criteria for the facilities were a 70-foot 13-second wave, zero current, and a 125 mph wind. The design drag (Cd) and inertial (Cm) coefficients for the Morison equation were 0.65 and 1.35 respectively. These design values are more conservative than the API RP2A 9th Edition recommended Cd, Cm values of 0.6 and 1.5 respectively thereby exceeding the design basis check in API RP 2A Section 17. A preliminary wind-wave-current hindcast of Hurricane Lilli indicated that the storm generated a 56-foot maximum wave (Driver, 2002) in the EI-322 block, which is significantly lower than the original design criteria.
Figure 1 is a photograph of EI-322 'A' drilling before Hurricane Lilli. Figure 2 shows the complex after the hurricane. The top deck translated approximately 85 feet from its original position causing extensive structural damage to the deck and deck legs. Figure 3 shows a closer view of the buckled A-1 leg (NW location). For reference, Figure 4 shows the orientation of the EI-322 'A' complex as well as the leg nomenclature. The B-1 leg almost totally separated from the deck as is shown in Figure 5.
Scientific (and Unscientific) Petroleum Supply Forecasting
Authors: Lynch Michael C. 
Published: October 2008

Abstract
In the past few years a number of publications have asserted that world oil production is near peak due to geologically derived scarcity. Although these analysts purport to be scientific, they are in fact merely curve fitting. Within a fixed, geologically homogenous basin it is possible to model discovery sizes. But at the national level, political factors such as fiscal regimes, access to perspective areas, technological challenges in different basins, and the economics of given plays tend to be determining. At the global level, demand determines production while politics heavily influences discoveries. That most of these analysts rely heavily on unproven-or disproven--assumptions is indicative of the quality of their research.
In fact, forecasting of both discoveries and supplies is extremely difficult, because of the uncertain nature of field size and because of the heavy influence of individual national economic conditions-infrastructure as well as fiscal regimes-and heavy restrictions on drilling by the private sector. Scarcity can be very roughly estimated by looking at a number of factors, including costs and reserve values, discovery size, drilling density, and well productivity, and none of these supports the alarmist views of a peak in world oil production over the next decade or two.
The importance of petroleum to world economy can hardly be overstated and is not at issue, nor is the importance of the adequacy of future oil supplies. But consideration of these topics should be based on real evidence and hard research rather than polemics. Much of the writings of the past few years, while aimed at a general audience, have not added to our knowledge of the subject and have often been misleading. There is a significant body of research on petroleum supply behavior, but much of it is ignored in the current debate.

All that's old made new again
A number of the arguments being heard have been around for quite a long time, including the general concern about resource depletion, fears of the inadequacy of capital to meet investment needs, as well as worries about concentration of petroleum resources in unstable areas. The fact that these concerns have never had any operational value does not mean they can simply be ignored. Nor does the fact that many mistakenly have predicted resource exhaustion for decades mean that current warnings should be ignored, rather they should be considered carefully in the context of past failures.
Unquestionably, there are numerous articles by industry insiders describing the difficulties and challenges which the explorationist faces when trying to find and produce oil. But the fact that it may be getting harder to find a given amount oil, or that capital needs may be growing, does not really tell us much about long-term oil production. It usually indicates a desire for tax breaks, or an appeal for more capital or easier access to prospective areas, rather than concerns that supply is about to peak. Similar warnings have been made for decades, without proving valid or relevant.
The Iron Grip of Depletion
Authors: Zagar J. , Campbell C.J. 
Published: October 2008

Summary
When we recognize that oil and gas were formed in the geological past, we admit that they are subject to depletion. Production in any place has to start at zero on discovery and end at zero on exhaustion, reaching a peak in between. Yet, such an understanding confounds classical economics, which holds that there can be no shortage in an open market and that one resource is seamlessly replaced by a substitute as need arises.
With modern methods, engineers can determine the size of an oilfield accurately, so there should be no particular technical difficulty in determining where we are on the depletion curve. The problem is in the reporting. In plain language, Proved Reserves, mean Proved-so-Far for financial purposes, not necessarily describing the full field. The consequential "Reserve Growth" gives the misleading impression that more is being found than is the case. Todetermine our position on the depletion curve we need the right numbers and the right dates of discovery, and we need to define carefully what to measure. Oil from a free flowing well is not the same as hydrocarbon extracted from a tar sand.
If we could hire detectives to smoke out the real 2002 data for what we can call cheap and easy Conventional Oil (excluding tar sand and heavy oils, deepwater and polar oils, and NGL from gas fields), we would probably find that the World has found about 1770 billion barrels. Of that, about 870 Gb are left. Extrapolating discovery shows about 130 Gb more to find. We are therefore close to the half-way mark when production must begin to decline, reflecting the peak of discovery in the 1960s. Furthermore, what is left is most unevenly distributed. It is as simple as it is disturbing. The last Century was driven by a cheap and abundant supply of oil- this Century won't be.

Introduction
Discovery of conventional oil peaked in the mid-1960s. Since the early 1980's production has out-paced discoveries by nearly 150 Gb-roughly one and a half times the reserves of Iraq. Today, even with advances in technology and including deep water developments, only one barrel is found for every three barrels produced. With declining discoveries and increasing demand, the debate within the industry is if world oil production is nearing peak and may in fact be on plateau.

Conventional vs. Non-conventional Oil Reserves
It is common practice to distinguish conventional from nonconventional hydrocarbons. The family of hydrocarbons is a large one. Each member has its own endowment in Nature, its own characteristics, costs, and depletion profile. It is obvious that you can deplete light oil flowing 20,000 barrels a day from a Middle East well much more quickly than you can extract oil from a heavy tar sand in Canada. About 95% of all oil produced to date-and 90% of todayâ??s production-comes from this group of hydrocarbons called conventional oil. It will continue to dominate supply until well past peak.
Statistics of Ocean Wave Groups
Authors: Nolte K.G. , Hsu F.H. 
Published: October 2008

ABSTRACT
Statistical parameters are derived that describe the occurrence probability for the number and height of consecutive waves in a group, which are large compared to the average wave height. Such wave groups can create extreme forces in mooring lines of large vessels. All of the parameters that describe the statistics of wave groups can be derived from the energy spectrum representing the sea state, if the energy spectrum is assumed to contain only a narrow band of wave frequencies. Good agreement was found between the theoretical expressions derived in this paper and actual wave data.

INTRODUCTION
It has been shown by Hsu and Blenkarn1 that the long period sway motion and peak mooring line force observed in a model study of a barge resulted from the combined action of a sequence of consecutive high waves in the rand Oil: wave train. Such a sequence of waves will be referred to as a wave group. Independent model tank tests conducted by Remery and Hermans2 substantiated the findings presented in Ref. 1. It is anticipated that the action of wave groups may also be important in other types of ocean engineering systems that are subjected to horizontal motions with periods much longer than the period of individual waves. Such systems could include dynamically positioned vessels. In the analysis and design of such systems it would be prudent to check whether the action of wave groups could subject the systems to motions beyond those calculated on the basis of individual waves. One can either use recorded wave groups measured in the sea, or wave groups generated in a model tank as a basis to perform such a check. There are also available electronic and numerical methods to simulate ocean waves. However, in order to make proper engineering decisions, one would need to know whether the occurrence of such wave groups is a common or rare event. More specifically, one would require a probabilistic description of the basic characteristics of wave groups in order to assess the likelihood of a system to survive.
The purpose of this paper is to develop tools with which one can characterize the statistics of wave groups in terms of occurrence probabilities. No attempt is made in this paper to illustrate how such statistical tools could be used in practical engineering. It is believed that development of rational procedures to utilize such tools for specific problems can best be developed by individual users.

THEORETICAL DERIVATIONS
In this paper a wave group will be defined in terms of the envelopes of wave crests and troughs as shown in Fig. 1. The distance between the crest envelope and the trough envelope will be called the height envelope, whereas the distance between the crest envelope and the mean water surface will be called the amplitude envelope. The height envelope indicates the change of wave heights. Similarly, the amplitude envelope indicates the change of wave amplitude. In reality, ocean waves are not symmetrical as is implied by the term, amplitude.
Does Our Prestack Data Support the Assumptions of Prestack Imaging and Inversion?
Authors: Calvert Rodney 
Published: October 2008

Abstract
The earth is heterogeneous at all scales. Our seismic reflection data is the result of waves that have traveled up and down through many heterogeneous layers. The data distortion caused by this is not corrected by current processing techniques and invalidates many of the assumptions we use interpret it.
We have developed a method to image through severely distorting overburden by placing geophones under it.

Introduction
When we compare the images from two surveys over the same area, as we might for 4D analysis, we find they are not at all equal. Even after trying to match them by scaling and a transfer filter their difference will generally be as great as the data itself. Clearly both of these images cannot be correct!
4D work has shown us that it is very difficult to repeat seismic data. The principle cause of non-repeatability is not obvious things like changes in source signatures or receiver coupling; transfer filters can readily fix these effects. We find that small geometry changes such as moving a shot or receiver a few meters gives us different data.
This means that unless we use fixed acquisition geometry our results are not reproducible. The effects turn out to be large. We will use the term "distortion" to describe the focusing, defocusing, scattering and local reverberation effects of transmission through heterogeneous layers. We are trying to do the equivalent of looking through multiple layers of toilet glass.
Our current seismic methods do not correct for this. PSDM only corrects for the long wavelength effects captured in our simplified velocity models. As we shall see, in 4D, if we closely repeat our geometry in two surveys we can difference or divide out the effects of distortion and systematic noise when we estimate the change signal. Our 3D one off data we do not have this luxury. This is the reason why good 4D data pairs can enable us to see reservoir changes where the reservoir may not be recognized on 3D. It is clear that our prestack data is distorted.
Thus our data does not support the simple idea that our imaged traces T(t) may be given byT(t) = Rxyz(t, ?) * w(t) + N (1) where Rxyz(t, ?) is the reflectivity at x,y,z for reflection angle ?, and w(t) is the wavelet. This equation, the basis for most inversions, AVO and quantitative must be generalized to account for distortion.
Our work suggests that it will never be practical to entirely correct surface data for overburden distortion and impossible for severe targets, for instance under karst topography, basalt or rugged salt bodies.
The solution for these difficult cases has to involve new acquisition and processing. We have developed, what we call a Virtual Source technique, which allows us to simply generate a known and controllable downward radiating source below the problem heterogeneities. The penalty for this technique lies in placing geophones below the problem heterogeneities. Drilling and sensor technologies now make this method technically feasible.