bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Low-Cost, True General-Purpose Telemetry System
Authors: Larson Roy 
Published: October 2008

Abstract
The following discussion will detail a new development in radio frequency telemetry systems. Rather than attempt to modify any existing aerospace-type high-speed telemetry systems to meet the typical requirements of industrial and offshore data transmission, it was decided by R-c Associates that a complete re-evaluation of the needs of these industries would result in a far less costly, and better suited type of system. It is felt that the results of these efforts offer an important and attractive method of data gathering and telemetering for monitoring and control functions than has been available previously.

Introduction
For a great variety of reasons, increased information on many of the aspects of industrial and offshore operations is suddenly becoming highly significant. Among these reasons are increased economy of operation, ecological and pollution control considerations, and tightening governmental regulations concerning the ability of these sites to leave the environment unaffected by their presence. In most cases, these functions can be handled by either on-site personnel, or, if the facility is reasonably close, through the use of wires or cables. However, as these sites become more remote, the cost of wire and cable installation becomes high, and RF telemetry begins to offer itself as an attractive alternative.
R-CAssociates has recognized this need and also the corresponding fact that very few, if any, low-cost RF systems have been available to fulfill these functions. It was with these facts that the family of systems here described was developed. The basic requirement was to design and produce a system inherently flexible as to the types of inputs and number of channels that could be accommodated, RF frequency allocations and regulations, and packaging for less than ideal environments. Following is a brief synopsis of the development of RF telemetry. It is felt that this will assist in showing how the need for the present system developed.

A Brief Review Of Telemetry
In order to define the present need for the system under discussion, it will be helpful to take a brief historical look at the over-all development of RF telemetry. It can be safely stated that the prime mover behind almost all telemetry development has been the aerospace industry and the military. Starting in the late 1940's and early 1950's with the early missile programs, it. became obvious that some means of transmitting data on the internal functions of a missile or rocket was necessary. Without some type of information on the internal behavior of these missiles, no orderly development would have been possible.
The first systems were crude by present day standards, primarily because of the fact that the transistor had not yet made its appearance.
Development of Dynamic Positioning for IHC Drill Ship
Authors: Sjouke John , Lagers George 
Published: October 2008

Abstract
This paper deals with the development of the dynamic positioning equipment for the drillship which is now under construction at a yard of I.H.C. Holland and which is expected to enter world-wide service by December 1971. The paper describes the philosophy of the design, the main components of the system and the results of model tests and their impact on the development of the control system.
Preliminary conclusions are given with respect to performance in relation to water-depth.

Introduction
The constantly increasing demand for oil has for a considerable time now focussed the attention of oil companies and contractors to offshore exploration and exploitation.
Step by step the operations are moving farther and farther offshore, entering deeper water. In this progress the designers of equipment have to work in close co-operation with the people in the field arid the theorists, for optimum adaptation of their equipment to the state of art and the demands of the operators. One very specific requirement for all offshore drilling equipment is that the equipment, ship or platform, barge or semi-submersible, should be capable of retaining a stationary position at sea. This requirement is often supplemented by the requirement of great mobility, so as to minimize the loss of time between two drillings.
These two requirements, coupled with the requirement of world-wide service in water-depths ranging between 50 and 300 metres and over, have led to the design of the drill-ship "PELICAN", which is at present under construction at one of the yards of I.H.C. Holland in the Netherlands.
The ship is being built for the French offshore contractor Somaser, a company which was founded 1t years ago by Foramer, CNP and Doris. The principal dimensions of the ship are as follows:Overall length149.32mBreadth21.35mDraught7.32mDepth 12.50mDisplacement 15420 tonTrial speed14 knotsInstalled power17000 h.p.
The outline of the ship is given in fig. 1.
Among the numerous applications of modern developments on board of this ship, the most outstanding feature is the dynamic positioning system.

What is Dynamic Positioning?
Dynamic Positioning is the technique of maintaining the position of a vessel, barge or floating platform by means of thrust.
A craft equipped with a D.P. system is independent of anchors or other conventional aids for remaining stationary in open water. Instead, it employs -in addition to apparatus for measuring its position with a high degree of accuracy-propellers capable of exerting thrust in controlled directions and a system for activating propellers to rectify deviations from a predetermined position. The underlying principle is not new of course. It has earlier counterparts in automatic pilots which maintain course as opposed to P9sition, and in the depth keeping systems of submarines.
Challenges Facing Contractors in the Brazil Offshore Market
Authors: Bobb Francis J. , Veirano Ronaldo Camargo 
Published: October 2008

Abstract
This paper identifies and presents some of the key challenges facing established contractors providing hardware to the Brazil offshore market. The list of challenges or issues was developed by a survey and follow up interviews with established leading companies in this market. While some issues are not new, the arrival of approximately forty (40) new players in a market historically dominated by one customer, has raised additional challenges. The paper will provide a brief overview of the challenges, and offer some feedback to mitigate costs and / or time loss. The offshore Brazil market continues to offer great opportunities for local industry, and an awareness of potential issues along with pre-planning will help improve the chance of success. In summary, all respondents identified the complexity and interpretation of the tax codes as the biggest challenge. At the center is the current imbalance of ICMS tax that local industry must charge in the range of 8.8 % to 18 % versus foreign imported goods at 0%. As of this writing new law (Law Edmilson) will go into effect on June 30, 2003, and will apply ICMS on all assets imported to the State of Rio de Janeiro.

Introduction
The Brazil market continues to present good opportunities for contractors with Petrobras planning capital expenditures of U.S. ﹩31.7 billion from 2001 to 2005. Forty Seven percent (47%) of that is directed to E&P. Sourcing between seventy five percent (75%) and eighty percent (80%) locally, Petrobras has been the key driver behind developing a local industry with a support network of universities, engineering houses, and CENPES (Petrobras' Research and Development Center). Together, the local industry and Petrobras have gained a wealth of offshore experience as witnessed by both the number of subsea tree completions and the series of world record water depths. Since installing the first Wet Christmas Tree (subsea tree) in 1978, Petrobras has installed four hundred and twenty six (426) through mid 2002. Looking ahead, they plan to install one hundred and thirty seven (137) subsea trees over 2002 and 2003. In addition the new entrants into the offshore Brazil market are at various stages of their blocks from round 0 (1998) to round 4 (2002). A lot of activity and change have occurred in a very short time. With that in mind, a survey of established local companies was taken to identify the key challenges they face in the Brazil offshore market. Respondents were asked to list the top challenges they face in ranked order. Following are challenges they listed in order of frequency:Table of Challenge/Issue and % issue appeared on responses (available in full paper)
The purpose of this paper is to provide some background onthe key challenges local contractors face. What is important to note is the issues can be mitigated with some thoughtful preplanning. Not covered in the paper are other issues raised by some of the respondents that fell below the average above:Other issues (available in full paper)
Technology Commercialization; Trends and Strategies for Funding E&P Technology
Authors: Schroeder Art J. , Warga Arthur 
Published: October 2008

Abstract
This set of speaker notes introduces the subject, which is the topic of a panel discussion for the 2003 Offshore Technology Conference. Participants include:Mr. Matt Simons; CEO, Simmons InternationalMr. Allen Parks; Executive Director, Oilfield Service Investment Banking, CIBC World MarketsMr. Satish Pai, Vice President, Oilfield Technology, SchlumbergerMr. Ricardo Rodriguez, Director of Investments, Shell Technology Ventures, Inc.Ms. Elena Melchert, Offshore Technology Development Program Manager, United States Department of Energy (DOE)Dr. Gérard Friès; Executive Vice President, Institut Français du Pétrole (IFP)Mr. Morten Wiencke; Program Director, Demo 2000

Introduction
A secure world economy depends upon reliable access to reasonably priced energy. Achieving this objective requires a consistent and steady amount of slight 'over-supply'. Considering the world's seemingly insatiable and growing thirst for energy, a clear challenge exists. Global oil consumption in 1970 was 46 million barrels per day. In 2001 according to the United States Department of Energy's Energy Information Agency it was 76 million per day. According to results published by Cambridge Energy Research Associates in their -Global Oil Trends 2002- report, by 2031 the demand will exceed 120 million per day. From where will these barrels come? While alternate energy sources may hold hope for the future, clearly fossil fuels will be important for many years.
Technology innovation and application has played a critical role in not only finding these additional resources, but for the last several decades has been doing so in an ever more efficient manner. However, the industry structure and corporate strategies that delivered these past results has changed markedly, with budgets for both funds and people being slashed. Duplication and overlap in research programs and piece-meal projects that don't provide end - to - end solutions continue to hamper efficiencies. Prolonged product development cycles (from innovation to meaningful market penetration) for ExP technologies significantly lag other industries. Reports by Simmons & Company, International and others show that investors in both energy operating companies as well as services companies have not in most cases even earned their cost of capital.
Generally these technologies are conceived, implemented and funded within the private sector. However, some governments are working in partnership with the private sector to ensure there are real opportunities for technologies to make the difficult transition from laboratory to market. Governments are motivated to assist not only because they have a responsibility for the pursuit of long-term societal stability and stewardship of the environment, but also because they understand that their policies help to determine whether markets develop and operate efficiently.
The panel will examine these issues and discuss strategies and new models of cooperation to help fund and commercialize technologies that can make a difference.
Calculating a -Rule of Thumb- - Unloading a Well
Authors: Watson Robert , Graham Reuben 
Published: October 2008

Abstract
For many years, air drillers have unloaded liquids from the hole prior to drilling out on air or gas. Generally, the operation takes place after cementing the casing and before using air or gas (dry, mist or foam) as a drilling media. This operation normally takes place using "seat of the pants" practices and/or experience.
The technique consists of injecting a small amount of air/gas into the liquid to lighten the hydrostatic liquid column. As the lighter fluid goes around the bit and starts up the annulus, the bottom hole pressure decreases. As the bottom hole pressure decreases, increase the air/gas injection and reduce the liquid injection until pumping only air/gas and the well is unloaded. Because of the compressible nature of the gaseous fraction, calculations are involved that are generally not adaptable for use with hand held calculators.
Recently, the efforts of Dr. Robert Watson (Penn StateUniversity) and the author, Reuben Graham (Reuben L, Graham, Inc.), yielded an engineered-process that enables these calculations without resorting to a -Black Box Calculation- approach. Fundamental to the calculation is a compressible fluid drilling program, which takes into consideration temperature, pressure, friction, and the compressibility -Z- factors for circulating fluids in turbulent flow. The authorâ??s model utilizes a -timed- macro and an approximating technique to generate the standpipe pressure, segregates the fluid slugs into five discrete intervals by depth (#1 through #5) and generates a bottom hole pressure versus time chart and table.
Included, are examples of wells (ranging in depth from 10,000 to 20,000-feet) that utilize various liquid-pump rates and methods (i.e. mud pump, mist pump and pump truck). The reader can reproduce the starting point calculation for any well using the examples provided.

Objective
The purpose of this paper is to give a methodology that can be used to unload any well from bottom. This process should save considerable time and money as compared to other ways of achieving the result. While the proprietary equations used in the authorâ??s model are not disclosed, the standard equations for making such a calculation are shown below:Basic correction for temperature and pressure to gas VolumesBasic equation for volume of gas to run at startBasic calculation of friction from flow in compressible gasified systems
The "U" tube principle (different densities plus applied pressure equates to equilibrium) and the resultant frictional effects are the main mathematics involved. Intuitively, given enough pressure, wells full of liquid could be unloaded by simply applying gas pressure and displacing the liquid. The downside of this approach includes handling the kick at surface and the cost of the pressure source. Typically, for underbalanced wells, the compressors and mist pump are on site and consequentially, there is no incremental cost for their use.
Development Program for Ekofisk Field - Offshore Norway
Authors: Jobin T.J. 
Published: October 2008

Abstract
The Phillips Group discovered the Ekofisk field on the Norwegian Continental Shelf of the North Sea with the drilling of the Ekofisk IAX late 1969. Three step out wells were drilled for confirmation and further geophysical, geological and reservoir information. Concurrent with the drilling of the later wells, plans were formulated and augmented for the development of the field.
The development program consists of a series of phases, each one being a continuation of the previous one, but with each phase having a definitive purpose in itself. Phase I is the test phase wherein the four original Ekofisk wells are produced by sub-sea wellhead equipment, temporary. producing facilities and S.P.M. tanker loading facilities. Its primary purpose is to obtain longer term production history, additional reservoir information and early operational experience. Phase II is the fabrication, erection and installation of permanent drilling and producing facilities. It consists of three drilling platforms, a production platform, compressor equipment for reservoir pressure maintenance, underwater storage and the repiping of loading facilities. Its purpose is the initiation and fulfilment of permanent producing facilities for the early and rapid build-up of production to the fields potential of 300,000 barrels of oil per day. Subsequent phases consist of a gas pipeline, a possible crude oil pipeline, onshore facilities, and the tying in of other fields in the vicinity of the Ekofisk field.
A number of problems have been encountered to date with respect to timing and scheduling. The most serious problem has been the weather.

Introduction
The Phillips Group, comprised of Phillips Petroleum Company Norway, Norske Fina, Norske AGIP and Elf Norge Group, discovered the Ekofisk field in September 1969. The Ekofisk No. lAX topped the Danian Limestone at about 10,000 feet. Continual drilling and accompanying excellent shows revealed an oil saturated section of about 700 feet. Definitive tests were incomplete because of the limited capacity of the test equipment on the rig. Also the weather was so adverse at the time that it would have been extremely hazardous to conduct the extensive testing that was necessary. However, enough information was obtained to indicate that the Phillips Group had an excellent discovery.
After this first well, three step out wells were drilled for additional reservoir, geological and geophysical information. These wells confirmed that the first important oil discovery in the North Sea had been made. Figure No.1 was taken during one of the early tests. Present indications are that it is the largest oil field found in Western Europe to date.
The Ekofisk field is located on the Norwegian Continental Shelf adjacent to the median line separating Norwegian and U.K. waters.
The Impact of Compressed Natural Gas Shipping upon Offshore Gas Development
Authors: White Charles , Grossweiler Phil , Ha Jae Keun , Naokawa Shigeru , McClure Scott 
Published: October 2008

Abstract
This paper introduces the marine gas transport technology under development by EnerSea Transport LLC as it is being incorporated in a new ship concept. The new Compressed Natural Gas (CNG) transport system and ship design have global applicability and allow a new perspective on remote offshore oil and gas development. The paper explains how key considerations and challenges have been reflected in the design of the new ship and how that new gas ship concept opens a new world of maritime and offshore field development opportunities.

Introduction
Industry is beginning to recognize that technology allowing marine transport of Compressed Natural Gas (CNG) provides flexibility that changes the economics for marginal fields. This is especially true for gas fields in ultra-deep waters or locations remote from suitable markets. A new solution for handling, storing, and transporting gas is making many operators appreciate the breakthrough potential for marine CNG as a means to commercialize stranded gas in remote reservoirs around the world. A new class of ocean-going vessels and gas handling facilities will play key roles.
Through its Maritime Work Program, EnerSea Transport LLC and its strategic partners have developed an advanced ship design employing the proprietary Volume Optimized TRANsport and Storage (VOTRANS?) gas handling concepts. EnerSea Transport selected the world's leading maritime companies and a top energy company to form a team of unmatched engineering and project development capabilities. The leadership of EnerSea's team includes Kawasaki Kisen Kaisha, Ltd ("K"-Line) and Hyundai Heavy Industries (HHI) with strong professional support from Paragon Engineering Services Inc., the naval architects of Alan C. McClure Associates Inc., and ABS Consulting. This team has worked together with the American Bureau of Shipping (ABS) over the past year to create and verify a safe, practical ship design that provides the basis for launching the world's first fleet for CNG marine transport, opening the way for a new maritime energy transport industry.
CNG marine transport allows emerging, energy-hungry markets around the globe to access gas reserves that would otherwise remain stranded. As compared to other solutions for de-stranding of gas reserves (LNG & GTL technologies), the shipping of CNG offers a solution that significantly limits the wastage of gas resources that are needed in the emerging markets and the amount of captive investment required of operators. Such value-adding features make this breakthrough technology and the new class of ships attractive to gas and power players on a global scale.
Saipem 10000 - Deepwater Salvage Operation
Authors: Cesaroni R. , Potter P.A. 
Published: October 2008

Abstract
This paper provides a detailed account of the successful salvage operation aboard the Saipem 10000 through the months of September, October and November, 2001.
The target of this operation was the recovery of a Subsea Blowout Preventer Stack which was buried below the sedimentary mudline in 6673 feet of water depth. (2034 metres)
The salvage operation involved the Saipem 10000 for 56 days. The equipment and human resources used in the operation were predominantly belonging to the Saipem Group.
Wherever applicable, the contribution of external resources is acknowledged.
The loss of the Subsea system was the result of a hoist system failure and occurred at the completion of an exploratory well drilled by Total Fina Elf (TFE) offshore Equatorial Guinea. The hook weight at the time of the loss was 575 metric tonnes. The associated marine riser string was also lost to the sea.
Innovative techniques, many empirical by nature, were used during the salvage operation. The success of methods used was achieved thanks to repetitive trial and error. Persistence paid off and two separate world records were broken during the salvage operation.
One record was set for the water depth in which high torque hydraulic tooling was used to disconnect the joints of a marine drilling riser.
The other record, since then broken by 151 feet, was the water depth from which the Blowout Preventer Stack (BOP) was retrieved.

Introduction and Background
The Saipem 10000 is an ultra deepwater drillship which can operate in water depths of 10 000 feet, has a Class III Dynamic Positioning system which allows it to keep its position at all times and a drilling capability which extends to 30 000 feet from the Rotary Kelly Bushings (RKB)
Its functions include: Drilling Activities Extended Well Testing Early Production Crude Oil Storage (140 000 Bbls) Crude Oil Export Well Completion Activities Figure (Available in full paper) The topsides drilling equipment package is outfitted with the latest integrated control and management systems and two drill centres, configured 'A' and 'B' are installed within a single derrick structure with the following specifications:-
Type: Dynamic Base Dimensions: 80 × 60 feet Top Dimensions: 60 × 20 feet Height: 200 feet Static Hook Load: 2 000 000 lbs per rig. Rated Maximum: 5 000 000 lbs The supplementary rig centre, located foremost, provides facilities for riserless drilling and other activities that require a full hoist system without riser and diverter capabilities.
The main rig centre, located aft, is a fully equipped riser drill centre.
The simultaneous setback and hook load for the substructure of each rig floor is 2 600 000 lbs.
The mud system has been designed such that cross connections exist between the two drill centres to maximize flexibility of operations involving drilling fluids.