bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Application of Underwater TV and Video Tape Recording in Supervising and Documenting Offshore Operations
Authors: Hartdegen Fred W. 
Published: October 2008

ABSTRACT
This paper deals principally with the application of underwater television and video recordings applied to the underwater operations of drilling and inspecting. The approach to workover operations is also touched upon.
The emphasis of the paper is centered around the value of documenting underwater operations. The method of applying the documentary techniques in conjunction with the use of floating drilling rigs, divers, and submersibles is discussed.
Factors to consider in the selection and utilization of underwater television and photographic equipment are briefly discussed.

UNDERWATER DRILLING
Underwater drilling has been going on for almost a decade now. Such a drilling operation can be performed from almost any type offshore rig especially if the water depth remains less than 150'.
At present underwater drilling in water depths of 300' or more requires the use of very large floaters. The semi-submersible rigs are one type that have proved quite effective. The available number of such rigs is relatively small at present, numbering less than one hundred. This factor has contributed to the scarcity of deep water drilling. In addition to this, the need versus expense of very deep water drilling has made such drilling far from routine.
However, improvements in technology and logistics should make deep water drilling a more common occurrence in the near future. This, or course, will be dictated by market needs and field potentials. At any rate, the consensus seems to indicate that drilling in 300' or more of water will eventually become routine practice.
An invaluable tool for this type of drilling is underwater TV. The placement of the wellhead assembly, the running of the casing, the positioning of the casing hanger, the connecting of the BOP stack, the running of the kill-lines and many other facets of the drilling operation canall be aided by the use of underwater TV. At present, most of these procedures are done by guide lines and "feel". The use of underwater TV adds the element of sight. The added feature of Its "sight" means increased efficiency. Efficiency means savings in rig time and this means money saved.
Semi-submersible rigs range in price from $500/hour to $700/hour. At this rate, if the use of underwater TV can save 2 hours per month then the TV has more than paid its way on a month-to-month rental. When you consider that there are 720 hours in a 30-day month, this means that 2 of these hours is about one-fourth of one percent of the total time. From an economic investment point of view it is reasonable to assume that the proper USE of UTV will always save more than this amount of operating time.
Many people are aware of the economic value of utilizing UTV in drilling operations and are in fact taking advantage of the technique. However, one vital aspect of using UTV in drilling operations has been greatly neg1ected. This is the aspect of documenting the operation by use of video type.
Wave-Exciting Forces and Moments on an Ocean Platform
Authors: Kim C.H. , Chou F.H. 
Published: October 2008

ABSTRACT
The authors describe a new method of predicting the wave-exciting forces and moments acting on an ocean platform restrained in oblique seas. Procedures -are "based on strip theory.
The wave-exciting forces and moments on restrained cylinders have been investigated before, in beam seas as well as in oblique seas, but the cylinders were always Lewis cylindrical forms. In this study, the two-dimensional method developed by Frank is extended to the calculation of wave forces and moments, and the strip method devised by Grim is applied to obtain the three-dimensional forces and moments. The results of the numerical calculations for a Series 60 model are compared with the results of the latest experimental work by Lalangas. The results of an experiment conducted for the present study, on a rectangular light-drafted barge restrained in quartering seas, are compared with theoretical predictions. Theory and experiment are in generally good agreement in both cases.

INTRODUCTION
The vertical wave-exciting forces on Lewis cylindrical forms restrained in beam seas were calculated by Grim in 1960. 1 His method was later applied 9Y Tamura2 to the calculation of sway- and roll-exciting forces and moments on Lewis cylinders restrained in beam seas. Tasai then performed approximate calculations of the lateral wave-exciting forces and moments in oblique waves according to Watanabe's strip method. 3 Grim and Schenzle, in 1968, further refined the calculation of lateral exciting forces and moments on a ship restrained in oblique seas, by applying the strip method [crossflow hypothesis]. 4
Grim's method is based on the assumption that the disturbance of an incident wave caused by the ship's body is represented by the potential used in describing the water flow around the body when the body is oscillating harmonically in the calm water surface. This potential, together with the incident wave potential, constitutes the potential that describes the flow around the body under restraint in waves. In the present study, we select for disturbance the potential used by Frank. 5 His method enables us to compute hydrodynamic forces and moments not only for the non-Lewis cylindrical form, but also for the widely varying configurations of ocean platforms of the semisubmersible type.
To determine the degree of reliability of the prediction method, theoretical values are compared with Lalangas' latest experimental results for a Series 60 mode16 and with additional experimental results for a rectangular barge obtained in the present study

COORDINATE SYSTEMS
Let o-XYZ and o-xyz be the right-hand rectangular coordinate systems) as illustrated in Fig. 1. Coordinate planes o-XZ and o-xz lie on the calm water surface) and the Y- and y-axes point vertically upward.
Let the incidence of the wave be designated by µ and let the wave progress in the positive X-direction. Then the wave profile is.
Overview of the Gemini Subsea Development
Authors: Coleman Eugene , Isenmann Gregg 
Published: October 2008

Abstract
This paper presents an overview of the Gemini subsea development that was brought on stream in June 1999, sixteen months after project sanction. The field is located in Mississippi Canyon Block 292 (MC 292) and was developed by Texaco as operator with 60% working interest and partner Chevron with remaining 40% working interest.
The paper describes the early project decision making process and defines the basis for the selected development option. The fast track schedule adopted for the project required that a significant amount of flexibility be incorporated into the design to accommodate late changes to rig schedules and third party installation vessels.
An overview of the execution of the project highlights the team structure and contracting strategy required to maintain project quality and cost control under the fast track schedule constraint. The project results reflect success in the three critical areas of schedule, budget, and system performance.

Overview
The Gemini Field is located in Mississippi Canyon Block 292 (MC 292), approximately 90 miles southeast of New Orleans in a water depth of 3400 ft. The field was discovered in 1995 with the drilling and subsequent testing of MC 292 Well No. 1. The field is part of the three block Gemini prospect in the Mississippi Canyon area, MC 247, MC 291 and MC 292.
The Gemini Field is a subsea development tied back to the Viosca Knoll (VK) 900 Platform located 27.5 miles northwest of MC 292 in 340 ft of water. Chevron is operator of VK 900 with 75% working interest and Texaco holds the remaining 25%.
The subsea development consists of three production wells tied into a 4-slot cluster manifold, each well being located approximately 50 ft from the manifold. The manifold has two headers connected together via a pigging loop. Rigid pipeline jumpers connect the manifold to dual 12" flowlines that transport the produced fluids 27.5 miles to the host platform. The subsea system is controlled from the host via an electrohydraulic control system through a steel tube umbilical with electrical conduits. Fig. 1 illustrates the field arrangement.
The project marks a milestone for both partners, Texaco and Chevron in that it extends their experience base into greater water depths and longer offsets than any previous developments in which they have participated. This is illustrated in Fig. 2.

Discovery
Gemini is a subsalt field that was discovered in 1995 with the drilling of the MC 292 Well No. 1 rank wildcat. The discovery well encountered 120' net of lean retrograde gas condensate pay in the Allison reservoir. The Allison interval is a thin-bedded, channelized slope deposit located beneath a 2900' thick tabular body of salt. Also discovered in the Dean interval was a laminated, low resistivity, rich gas condensate sand. This well also encountered three other hydrocarbonbearing intervals: the Barry, Erin, and Luis/Marilyn. A total of approximately 160' TVT pay for the well was determined from log analysis. See Fig.3.
ISO Standards: Value?
Authors: Wisch David J. 
Published: October 2008

Abstract
ISO has been working to develop standards for the oil and gas industry for almost 10 years. With the recent events in the oil industry including the low oil prices of the recent past coupled with the consolidation of companies and role of national oil companies, the question of value is often asked.
This paper will discuss many of the issues surrounding development and use of standards in light of the recent events. It will draw upon the past, trends eminating from observation and draw conclusions as to value eminating from the ISO offshore standards efforts.

Introduction
Oil field standards started to appear in the early stages of the 20th century. Prior to standards in the early days, products serving the same function were not interchangeable often leading to costly and sometimes unsafe solutions for repairs and/or extensions, as well as additional costs. The American Petroleum Institute (API) started to address standardization of various aspects of the industry with a policty statement that read in part:
"API standardization activities identify and support proven, sound engineering and operating practices, ans safe interchangeable equipment and materials, for use in the petroleum industry..."
Until the 1970's, the API standards were generally the defacto standards utilized in various parts of the world. With the advent of the North Sea activities in the seventies, additional standards generated within various regions started to appear. This tendency of regional standards continued through the 1980's. With the formal joining of European Union in sight, some industry leaders started the process of reactivating a dormant international standards committee, ISO TC 67, in 1989. Concurrently, the oil industry was starting to undergo a transformation to a more global industry where many of the historically regional focused companies were becoming more and more global. A third change factor was the continued emegence of new oil producing contries as key participants in the oil industry at large.
The offshore standards parallel the overall standards with the key exception that it was the 1960's before the offshore industry had standards covering the key areas. As the offshore arena rapidly expanded in the late 1960's and 1970's, offshore standards garnered significant attention and many were initiated with many more expanded and extended as the knowledge increased.
The offshore industry, for the most part, has been a selfregulating industry. One of the biggest challenges facing the industry will be to what extent it will continue to be predominantly self-regulating. Development of standards that meet the needs of the industry at large, all of the stakeholders, is the principle means in achieving that objective.
One of the most common questions around standards has been, "What value does an ISO standard bring?" A oft heard corollary is "The existing standards are fine so what's in it for me?"
This paper will be focused on offshore facilities standards. To varying degrees, other sets of oil field standards can be viewed as being parallel.
Pierce Field Development by FPSO Solution
Authors: Hayes M.R. L. , Tangvald T.B. 
Published: October 2008

Abstract
The Pierce field, which is located in the UK sector of the North Sea, has been developed using a Multi-Purpose Shuttle Tanker (MST) converted into a field specific Floating Production and Storage Offshore (FPSO) facility. First oil from the development was achieved in early 1999. This paper describes the overall field development from reservoir through to export solution. Pierce is an oil field associated with twin salt diapirs with ultimate recoverable reserves of 110 million barrels of oil and 182 billion cubic feet (bcf) of gas located in Palaeocene sands in the North Sea Central Graben. The field has been developed using horizontal drilling technology with complex directional trajectories and long reservoir sections up to 6,500 ft in length. These well lengths were necessary to optimize recovery from the steeply dipping beds of the reservoir formation.
Six oil producers and two gas injectors have been drilled from two sub sea templates located 2.2 km from the FPSO. The "Berge Hugin" FPSO is of the MST design equipped with modular topside facilities. The subsea concept has enabled the use of a small innovative turret system totally enclosed within the hull of the FPSO.

Introduction

Field History.
The Pierce field lies within licence blocks 23/22a and 23/27 in the Central North Sea, 280 km east of Aberdeen in 272 feet of water. Enterprise Oil is responsible for operating the field on behalf of the Pierce owners: Enterprise Oil, Ranger Oil, MOC, Agip and Petrobras.
The Pierce South accumulation, previously known as Pierce, was discovered in 1975 by Ranger Oil with well 23/27-3. The discovery well encountered oil in Palaeocene sandstones and Palaeocene/Cretaceous chalks on the western flank of the Pierce South diapir. The well tested oil and gas at 3000 bopd and 2.1 mmscfgpd from the Palaeocene Forties Sandstone Member.
Several appraisal wells were drilled on Pierce South following discovery. Three wells were drilled from 1978-83, but all penetrated the Forties sandstones below the oilwater contact. The first appraisal well to encounter hydrocarbons was 23/27-8, drilled in 1991. The well encountered Palaeocene sandstones and Palaeocene / Cretaceous chalks on the western flank of Pierce South. The well had a maximum test rate of 5700 bopd and 5.1 mmscfgpd from Forties sandstones.
The remaining Pierce South appraisal wells are 23/27-9, - 10, and -10z. Well 23/27-9 was completed in 1992, having penetrated Palaeocene sandstones and Palaeocene / Cretaceous chalks on the northern flank of Pierce South. The 23/27-10 well was drilled on the southern flank of Pierce South in 1996, and again penetrated Palaeocene sandstones.
Pierce North, formerly known as Medan, was discovered by BP well 23/22a-2 in early 1990. The well encountered wet gas in a thin section of Palaeocene sandstones and Palaeocene/Cretaceous chalks on the western flank of Pierce North. An appraisal well, 23/22a-3, was drilled in 1991 on the eastern flank of the Pierce North diapir.
Explosives Return To Marine Seismic Surveying
Authors: Savit Carl H. 
Published: October 2008

ABSTRACT
Small explosive charges are now being used as seismic reflection and refraction sources. Half-pound charges of nitrocarbonitrate detonated at a depth of 40 or more feet are found to be the seismic equivalent of 150 1b at venting depth. Bubble effects are removed in digital computer processing. High repetition rates permit resolution equivalent to that of non explosives while achieving the maximum penetration provided by explosives.
Seismic exploration was conceived more than a half century ago with the expression of the basic idea that sound waves will-travel in a different manner in different kinds of rocks. Reginald Fessenden in his 1916 patent proposed to generate the sound waves by means of an electric oscillator. His oscillator and his listening devices were to be placed in water-filled holes in the ground.
It soon became clear that the primitive oscillators, microphones, and amplification systems of the 1920 era were incapable of achieving penetrations through the earth of more than a few tens of feet. Not until Ludger Mintrop and John C. Karcher in the early 1920's substituted explosive charges for the electric oscillator did seismic exploration become practical.
When seismic exploration moved to sea in the late 1940's and early 1950's, it naturally took along the explosive sound sources which had been so successful on land.
Unfortunately at sea; the reflection seismologist was faced with an apparently irreconcilable dilemma. He had, in the years of land work, learned through experience that his explosive charges were most effective when well tamped. He had drilled holes in the earth, placed charges in the bottoms of the holes, and filled the holes with water or mud to serve as a tamp or reaction mass. If he did not have enough tamping, he found that his charge produced a far smaller seismic wave than that which he could expect with adequate tamping. At sea, however, when he put his charges downdeep enough so that the water above the charge served as an appropriate tamp, he found an unpleasant side effect.
When an explosive is detonated, the explosive material changes abruptly to a gas at high temperature and pressure. If the detonation takes place deep under water, these gaseous explosive products expand rapidly to form a gas bubble of increasing diameter. Because of inertia, expansion continues after the gas pressure inside the bubble has fallen below that of the surrounding water. Cooling of the gas enhances the pressure contrast. When the expansion finally stops, conditions in and near the bubble are unstable. The water pressure around the bubble is substantially greater than the gas pressure inside the bubble. The bubble collapses with increasing speed as the water rushes inward. The result is another sharp acoustic pulse, frequently one more powerful than the initial detonation pulse.
Roncador Field Development: An Overview
Authors: Garcia A.L. , Bocos M.D. , Mihaguti M.K. 
Published: October 2008

Abstract
Roncador, a giant field in the northern area of Campos Basin, was discovered in October 1996 at water depths that range from 1,500 to 2,000 m. Its development was planned to perform parallel investments for the appraisal phase and the first development phase instead of a more traditional sequential strategy. This challenging field started production in January 1999 and has been producing since then through a pilot system, the FPSO Seillean, installed over de RJS-436 well at 1,853 meters of water depth - a new world record. The permanent production system for Phase 1 is scheduled to start in the first half of 2000 with the arrival of the P-36 platform (ex-Spirit of Columbus) and the FSO P-47. This paper presents the planning for the overall field exploitation and the final concept for the field development, emphasizing the first phase.
The concept of the first phase represents the conclusion of the analyses and technical studies related to the exploitation of an oilfield located in ultra-deep waters. The critical path of project schedule, the management of both the uncertainties of the reservoir and the ultra-deep water technological development and also the commitments assumed for the production start-up, add to this project some unusual and very challenging characteristics. Roncador field development success proved the commercial and technological feasibility, in large scale, for oilfields located in water as deep as 2,000 m, reaching the current goal for PROCAP-2000, Petrobras' deepwater research program. The achievement of this goal will allow Petrobras to set a new challenge - the 3,000 m water depth limit.

Introduction
Roncador field was discovered in October 1996 by the wildcat RJS-436. The "132 square kilometers giant field" lies 125 kilometers off the coast of Rio de Janeiro, at water depths that range from 1,500 to 2,000 meters (figure 1). The size of the field, the good quality of the crude and the concurrent benefits for the downstream, together with the economic results of the project, led the Company to adopt a fast track development plan.
In January 1998 another wildcat, RJS-513, confirmed the extension of the reservoir and the existence of oil in the southwestern portion of the reservoir. The first well presented the existence of 31°API oil and the second an 18°API oil. Immediately afterwards, Petrobras began the appraisal of the reservoir, drilling four other wells. Even though the area was not yet fully appraised, because of its extension, these four wells plus the initial information coming from the first two production wells drilled so far, confirmed the predictions and rised the field reserves to the current volumes, estimated at 3.3 billion barrels (boe). New wells have been planned in order to appraise the reservoir southwards and eastwards to provide more information for the overall development plan. The exploitation of Roncador field is planned to be developed in three phases (figure 2).