bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Offshore Recovery Advancements For Deep Water Completions
Authors: Adams John R. , Manuel John F. , Cook Roger W. 
Published: October 2008

ABSTRACT
This paper presents a review of the development status of three subsea oil production systems under development by Subsea Equipment Associates Limited (SEAL). This international consortium owned by Bristish Petroleum, Compagnie Francaise Des Petroles, Groupe DEEP, Westinghouse and Mobil Oil Corporation, is presently testing two production systems designed for primary use in foreign fields. These systems should find application in the water depths greater th'an 150 feet with average well production ranging from 1, 000 to 10, 000 barrels per day. SEAL is also testing a subsea oil production in the Gulf of Mexico which is designed primarily for utilization with large numbers of domestic low-production wells which in turn generally require significant maintenance. Participating in these test projects from anon-owner standpoint are Continental Oil Company, Phillips Petroleum, Sun Oil Company and ELF/ERAP.
The SEAL Intermediate System (SIS) is described with particular emphasis on utilization of a Manned Working Enclosure (MWE) to permit men to perform maintenance operations in a dry environment at the sea floor. The MWE concept involves lowering the structure over the wellhead, expelling the water and transferring personnel by the use of a Personnel Transfer Bell (PTB). The status of this development project is reviewed.
The SEAL Shallow System is described including a review of present testing off the South Coast of France. This concept is similar to the MWE with the exception that the maintenance personnel are carried in the SEAL Bell. Once the bell is pulled to the subsea wellhead, water is expelled and the atmospheric pressure reduced to sea level to permit the men to enter the work chamber and perform the necessary operations.
The SEAL Atmospheric System is described in some detail in this paper. This system concept is based on the use of a large habitat-type structure permanently installed on the sea floor to house oil field equipment. Future applications of this concept would be as a manifold center, a test separator center or a complete oil production system. In a similar manner to the other systems, men are transported to and from the Subsea Work Enclosure (SWE) through the use of a Personnel Transfer Bell. In addition to the description of the production SEAL Atmospheric System this paper presents a review of the present test installed in the latter part of 1972 and details are presented on the installation of the base structure, the Subsea Work Enclosure and the Wellhead Connection Assembly. The present status of this test program is also presented together with plans for the future.
A common element in each of the three systems being developed by SEAL is the use of a Personnel Transfer Bell to transport maintenance workers to the subsea structure in a safe and efficient manner.
Development and Utilization of a Deepwater Pipeline Connector
Authors: DeJong J. , Brown R.J. 
Published: October 2008

ABSTRACT
This paper describes how one-atmosphere chambers might be utilized for making deepwater pipeline connections and, as well, provide the means whereby valves, controls, etc., can be encapsulated and readily serviced subsea.
A new connector device is described. It makes use of the high seawater pressure available at depth for pulling one pipe end into close proximity with another and through a port located within a subsea one-atmosphere connector chamber Control of the entire operation and final joining of the two pipe ends by means of conventional welding is accomplished within the manned chamber.
Anticipated utilization of the connector includes deepwater pipeline construction and repair connections. Modified connector chambers can be used for line tie-ins and riser connections.

INTRODUCTION
Related to growing world wide energy requirements, the search for oil and gas has expanded to deepwater areas which only a few years ago were inaccessible. In 1968, after extensive evaluation of alternative approaches for producing oil from these greater depths, Lockheed adopted the philosophy that a one-atmosphere chamber system at the seafloor provided the maximum opportunity for man to do useful work and at the same time maximize utilization of proven oilfield hardware subsea.
This work capability was first demonstrated in 1970 in up to 900 foot water depths during prototype tests of a one-atmosphere diving capsule for servicing seafloor chambers. More recently in 1972, this capability was again demonstrated in the Gulf of Mexico with an encapsulated subsea wellhead completion in 375 feet of water. A crew of three worked on bottom 11 hours out of each 12 hour shift.
At the conclusion of the 1970 tests, one of the companies supporting the test program suggested that the technology of the subsea work chamber should be extended to include deepwater pipe to pipe connection capability.
The seed having been sown, development work was undertaken. Several types of pipeline chambers were identified and were examined as to functionality, overall technical feasibility, and economic advantage. At the same time, a concept was evolved for mobilizing the ambient seawater pressure available at depth to generate a high controllable force, parallel to the seafloor, for pulling two pipe ends together.
This paper briefly describes the pipeline chamber development work conducted to this date and outlines the pipe pull concept and the experimental program conducted to establish its feasibility. The paper concludes with a discussion of situations where this subsea pipe-pull work chamber capability might be utilized as an aid to offshore pipelaying.

SERVICE CAPSULE and SURFACE SUPPORT
Fig. 1 pictorially shows the surface support vessel, the onboard support vans, launch and recovery equipment, and the Lockheed service capsule necessary for transporting men and materials to any sea floor chamber.
High-Integrity Protection Systems (HIPS): Methods and Tools for Efficient Safety Integrity Levels Analysis and Calculations
Authors: Signoret Jean Pierre 
Published: October 2008

Abstract
This paper shows how to deal properly with "Safety Integrity Levels" (SIL) as per IEC 61508 [1] and 61511 [2] for "High Integrity Protection Systems" (HIPS) which are more and more extensively used in oil industry to replace traditional protection systems. If IEC 61508/511 are rather efficient from an organizational point of view, some difficulties unfortunately exist at definition and calculation levels. The formulae proposed in part 6 of IEC 61508 are, for example, not really tractable for actual industrial systems. This paper describes the probabilistic methods and tools that we have developed in our company to overcome the above difficulties. Three main conventional methods are investigated: "Fault Trees" which, when properly handled, are very efficient for low demand topside HIPS, markovian approach which is interesting but tractable only for very small systems and Monte Carlo simulation on behavioural models (Petri Nets or AltaRica Data Flow formal language) which is efficient in any cases. Results are given on simple examples in order to show the principles of the various approaches. It is interesting to notice that using those approaches is simpler than what is proposed in the standards. Therefore, until the publication of an updated version improving IEC 61508 part 6, it seems better to replace it by sound conventional methods and tools adapted to SIL calculations for production systems. We have began to disseminate this approaches toward our contractors.

Introduction
In the oil industry, the traditional protection systems0 defined in API 14C are more and more often replaced by safety0 instrumented systems: the so-called HIPS (High Integrity Protection Systems). Therefore, according to IEC 61508 and IEC 61511 Standards, their SILs (Safety Integrity Levels) shall be calculated
Unfortunately, when using above standards some difficulties arises [3, 4]. They often remain ignored by those who perform SIL studies and the main ones are the next:insufficient failure taxonomy and definitions,tests and maintenance procedures handling,introduction of the Safe failure Fraction (SFF) which is not a relevant concept,probability of Failure on Demand (PFD) and
Probability of Failure per Hour (PFH) Calculations. After presenting briefly the 3 first problems, the 4th one will be detailed more in depth to show what we have done to cope with the various SIL assessment problems encountered in the oil industry:topside HIPS easily tested and maintained,subsea HIPS difficult to test and maintain,preventive HIPS.
According to the standards topside and subsea HIPS are so-called "low demand mode" safety instrumented systems (SIS) while preventive HIPS are so-called "continuous" mode SIS. This paper is mainly focused on methods and tools devoted to low demand mode HIPS.
Sonic Cover Survey of an Offshore Pipeline
Authors: Peebles E. Earl , Guerry T.L. 
Published: October 2008

ABSTRACT
All pipelines are subject to erosion as well as the removal of' protective earth covering due to the elements of nature. If permitted to continue to its ultimate conclusion, that of a long unsupported pipe span, failure of the pipe is almost sure to result. While it is fairly easy to patrol land pipelines to guard against excessive erosion, a measure specified by the Federal Minimum Standards, patrol of submarine pipelines have, for the most part, been unfeasible in the past. Attempts by divers and miniature submarines have been prohibitively expensive, and in many cases the findings have been inconclusive.
The advent of more sophisticated underwater electronic and sonic equipment suggested the possibility of an almost totally electronic survey, thereby increasing reliability and substantially decreasing costs. This paper presents the equipment and techniques utilized in such an offshore cover survey of a 16-in. submarine pipeline located off the Galveston coast. It begins with a detailed description of the equipment used, such as the differential proton precession magnetometer, recording fathometer, low frequency acoustic subbottom profiler and the ultra-sensitive dual channel side scan' sonar. All of these are readily available through most offshore survey contractors. Methods and techniques are developed enabling any offshore pipeline operator to conduct such a survey.
The actual survey, conducted during the summer of 1972, substantiates the belief that such surveys are both practical and economically feasible. Important side benefits of such a survey arethe precise location of the pipeline in the event that a leak must be located and a repair made at a later datethe detection of the presence of debris on or near the pipeline andthe assurance that the pipeline has not been moved an appreciable distance by a storm.

INTRODUCTION
The purpose of this project was to perform a detailed investigation and determine the existence and extent of any bridged sections of the approximately 36.4 miles of ballasted 16-in. pipeline owned by Black Marlin Pipeline Co., Inc. Located offshore, the Black Marlin pipeline extends from off the Texas coastline in High Island Block 136 to a point on the Bolivar Peninsula in High Island Block 194. Methods for the performance of this underwater location and cover survey utilized the latest and most modern equipment and techniques for obtaining the field data and for purposes of preparing the final report.
In order to establish the scope of work, a list of the information required with regard to the present status of the pipeline was set out. The desired information washorizontal location of the pipeline,vertical location of the pipeline,existence and extent of a bridged sections of the pipeline andlocation of any large metallic objects, exposed wrecks, sand waves, or other obstructions appearing in the immediate area of the pipeline right-of-way.
Subsea Pumping Systems: Intervention Prediction and Condition Monitoring Techniques
Authors: Eriksson Klas , Falk Kristin , Melboe Hallgeir , Mjaavatten Erlend 
Published: October 2008

Abstract
For subsea pumps, regular maintenance is required (in the order of every 5 years or so). Being able to plan this intervention to be "just in time" will reduce downtime, and optimize production. Such techniques have been applied to topside systems for a long time, and are now being extended to subsea pump systems. A data monitoring system with algorithms for monitoring certain Key Performance Indicators for a pumping system has been developed and applied, and is used to determine "time to service". Two subsea pumping systems (for King and Lyell fields) are used as real examples, with results from system operation (Lyell) and integration testing (King) for same.

Introduction
Subsea pumps need regular maintenance due to general wear. The service interval depends on the operating conditions of the pump. Servicing a pump basically involves replacing it with a spare pump. Such intervention is preferably scheduled in order to minimize the downtime. An unscheduled intervention can easily give a downtime of one week and up to 8 weeks in winter in case of rough weather in certain areas, while a planned intervention can be done in 24 hours. As an example, a pump providing a production increase of 5 000 bpd, and with an oil prize of 50USD, the lost production will be at least 1.7 MUSD with a 1 week unplanned shut down. The lost production can be as much as 14 MUSD in case of having the pump installed in areas where a rough winter weather can make it impossible to change the pump (for an 8 week shutdown).
For a planned 24 hour intervention, the corresponding production loss would be in the order of 0.25 MUSD. If we can avoid a single unplanned shutdown in good weather, we can thus save appr 1.5 MUSD.
If we can avoid a single unplanned shutdown in areas where bad weather is critical, we may save 14 MUSD. The intervention can be done based on several schemes, g.:"Run until it breaks". This gives 1-8 weeks downtime every time"Change every 4 years". This is based on worst case calculations"Change just in time". This is based on some knowledge of condition
Compared with how a car is serviced, option a) is seldom used. Option b) (scheduled on time / mileage) is the most common method. Option c) is used on more advanced cars, which keep track on how hard they are driven, and give advance warning on how many miles are left until service is required.
What we are discussing is thus basically what advanced car manufacturers have done for many years, i.e. scheduling maintenance based upon how hard the system is operated. Also, in the same way as for cars, regular maintenance can-not guarantee against unscheduled breakdowns, but it will reduce the risk for such. In order for such a system to give any real benefit, it must be able to give sufficient advance warning that a planned intervention can be made instead of an unscheduled one.
Electronic Survey Helps Assure Integrity of Offshore Pipelines
Authors: Rogers W.M. , Duckworth H.N. 
Published: October 2008

Abstract
On-land practices of excavating and sampling for detection and evaluation of corrosion in pipelines are, at best, inadequate. Such a practice regarding offshore pipelines would be very impractical for many reasons. However the need and concern for corrosion evaluation of pipelines in that area are just as great if not more so than land lines.
A more detailed method developed over the past few years is now in use for evaluating corrosion and mechanical damage in offshore pipelines. Electronic surveys have been performed on several major offshore lines. Data provided by the surveys enables the operator to locate, evaluate, and through subsequent surveys, monitor corrosion and other conditions.
Base line surveys were run on two lines from platforms in the Santa Barbara Channel to shore immediately after construction was completed. Subsequent surveys have been performed to monitor and assure the integrity of the pipelines. Other surveys have been made on offshore lines in or near metropolitan areas when leaks could seriously affect public opinion.
Electronic surveys may be performed on offshore lines under most conditions and without interruption of pipeline operations.

TEXT
Almost anything that would adversely effect the integrity of a pipeline has been of concern to the operators of those pipelines. In many cases, pipeline companies have taken elaborate steps to protect the lines from damage or deterioration. Pipe surfaces are frequently coated with a corrosion barrier, cathodic protection systems are installed to counteract corrosion processes, and other devices are used to further protect the pipe. In spite of that protection and attempts to safeguard systems, pipelines become damaged and/or otherwise deteriorate in some manner.
It is believed that most deterioration occurs in the form of corrosion. Even with the application of corrosion prevention coatings or devices, some corrosion degradation frequently develops. Pipeline corrosion control personnel work diligently to monitor conditions developing in their pipeline and upgrade the protective installations. In addition, pipe surfaces are frequently examined when and where possible. On-land procedures of excavating sections of buried pipeline have been an extensive practice for many years in order to observe pipe surfaces and evaluate corrosion conditions. For the industry, this practice requires the use of many men at the expense of many man hours and at best, the practice can only expose a limited portion of a major line. Since large sections of a line may go unexamined by this method for a time, extensive damage could go undetected and result in a line failure.
Such a practice on offshore pipelines is basically impractical because of the water environment and other factors.
Ice Breaking Drilling Ship for Offshore Exploratory Drilling In the Arctic
Authors: Jones Klemme M. , Schaff James C. 
Published: October 2008

INTRODUCTION &ACKNOWLEDGEMENT
About two years ago it became apparent that the offshore oil potential in the Beaufort Sea and Canadian Islands Arctic areas was sufficient to give serious consideration to a method of practically and economically providing a system capable of performing the needed exploratory drilling service. The practical approach was to utilize proven drilling techniques, systems and equipment to the maximum degree; but to synthesize these to an environment not previously considered in their design; and the imagination to accept opposing precepts from the preceeding and conceive a viable, practical compromise. The economics dictate that the results must reasonably be capable of profitable application.
Global Marine's long-stated preference for ship-shaped units for exploratory drilling and the existing technology of breaking navigable ice channels with ships afforded an immediately marriageable pair of disciplines which would yield fruitful results: The only total unknown was how to maintain drilling station in a slowly moving ice sheet.
Global Marine Engineering Company has been the chosen instrument to provide the synthesis, application and imagination leading to the desired results.
No single individual (or organization, for that matter) can claim parent to the total developing design presented herein. It is the result of many inputs, many thoughts, much joint effort. And it is a developing design. Manuscript time schedules being what they were for papers for this conference, much of the illustrative material and tabular data must be considered as developmental, a substantial amount of which are already obsolete in their detail and qualitative values.
The authors wish to acknowledge the contributions of time, effort and talent made by members of their staff, both professional and clerical. Further acknowledgements are made to the ideas, direction and support provided by Global Marine, Inc. - especially Russel B. Thornburg; Arctic Engineers and Constructors Ed Anders in particular; Wartsila Ice Model Basin's remarkable staff (Dr. Endquist, B. Johanssen, O. Makinen and K. Airaksinen specifically); and Prof. Grim and Dr. Waas of the Hamburg Ice Model Basin. Without them and many others we might still be floundering in a sea of uncertainties.

DESIGN CONSIDERATIONS AND PARAMETERS
The marriage of a drill ship with an icebreaker provided the basis of the design considerations (see Figure 1). Throughout the design of the vessel safety has been the overriding criteria. Safety not only for the personnel vessel and equipment but, also safety in terms of environmental protection. The design evolved around considerations of the environmental parameters such as climatic conditions and environmental impact; crew equipment and vessel safety; regulatory parameters; and of course ice-breaking and operational requirements.
Two New Operational Units for Steel Wire Line Work on Subsea Wellheads
Authors: Issarte Jean-Pierre , Masoriheimer R.A. , Vaissade Louis 
Published: October 2008

ABSTRACT
Two new units have been designed for adapting the steel wire line method, in universal use on land, to suit subsea wellheads.
The subsea lubricator method makes use of a swell compensating unit installed on board a surface support and enables wire line operations to be performed from a standard vessel and using a standard wire line winch.
The subsea winch is a unit which is lowered into the water and connected to the wellhead. It is completely remote-controlled from the surface by means of a multi-conductor electric cable.
These two units have been successfully tested several times on both experimental and producing subsea wells. They are now operational.

INTRODUCTION
There are still comparatively few oil wells in the world which are completed with subsea wellheads, no more than about a hundred in all. It is, however, very likely that this number will increase quite rapidly over the next few years with the development of subsea fields. The various systems being tested at present in several countries for the equipment and maintenance of such producing wells is evidence of this trend.
In all these systems there is generally some method of working inside the wells to carry out operations which are simple but necessary if the wells are to be operated in a rational manner, such as bottom hole pressure measurement, tubing scraping, handling bottom hole tools, etc. The methods proposed are sometimes rather cumbersome and some of them are not, in our opinion, satisfactory from the point of view of operating safety.
We have therefore studied a way of adapting for subsea operations the wire line or slick line technique, universally used on land. We would recall that this technique, which now has specialists with long experience, involves introducing equipment into the well through a lubricator and then running it to the bottom of the well at the end of a steel wire line, unwound from a winch. The seal is made around the line by means of a stuffing box.

OPERATIONS ON PRODUCING WELLS
In wells on land, as in the case of offshore wells operated from fixed platforms, the wire line technique is widely used. In wells with subsea trees, a new operating method has been developed and tested by various companies over the last few years.
This method abandons the use of slick line and makes use of a fluid to pump the tool string in the tubing. This "pump down'tools" technique probably has a great future ahead and the fact that almost all the subsea systems being tested or studied at the present time make use of this technique, demonstrates the success anticipated.